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1 0 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. Q j- 0 - 0 43 Well History File Identifier Organizing (done) ❑ Two -sided III 111 111 III ❑ Rescan Needed 1 11111 111 7 C SCAN DIGITAL DATA OVERSIZED (Scannable) • sr Items: ❑ Diskettes, No. ❑ Maps: reyscale 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: (V/ as 1 a /s/ 1 P Project Proofing I III II 111.11 I I /s/ BY: a- - Date: (Q � Via 1 I Scanning Preparation 1 x 30 = 30 + 3 = TOTAL PAGES 33 n Q n (Count does not include cover sheet) BY: Date: a(, O `cri /s/ n Scanning g 111111IIII II 111 Stage 1 Page Count from Scanned File: 3 (Count does include , cover rs sheet) Pa se Count Matches Number in Scanning Preparation: V YES NO BY: � 1(- - Date: (0 40/ 1g- !s/ f 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. I 111 I I 111111 III ReScanned 1 I 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111 llhIIIIIIIIIIIII 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 6/18/2012 Permit to Drill 2100430 Well Name /No. KUPARUK RIV UNIT 3K -09BL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21656 -60-00 MD 10034 TVD 6741 Completion Date 6/12/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Sury 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 M -d /Frmt Number Name Scale Media No Start Stop CH Received Comments ED Lis 19905 Induction /Resistivity 6529 10017 Open 7/27/2010 GR, ROP, RES Log CV Induction /Resistivity 2 Col 8059 10018 Open 7/27/2010 MD MPR, GR Log f/ Induction /Resistivity 5 Col 8059 10018 Open 7/27/2010 MD MPR, GR Log ` Induction /Resistivity 5 Col 8059 10018 Open 7/27/2010 TVD MPR, GR s�� Directional Survey 8040 10034 Open Rpt Directional Survey 8040 10034 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION 4 Well Cored? Yj Daily History Received? N Chips Received? ¥/-N— Formation Tops 1 N Analysis ' Received? Comments: Compliance Reviewed By: Date: 1 P 1 r 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 ❑ 1 b. 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 - 0430 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 27, 2010 50 029 - 21656 - 60 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 May 29, 2010 3K - 09BL1 Top of Productive Horizon: 8. KB (ft above MSL): 69' RKB 15. Field /Pool(s): 1830' FSL, 2379' FEL, Sec.35, T13N, R9E, UM GL (ft above MSL): 30' Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1720' FNL, 2043' FEL, Sec. 35, T13N, R9E, UM 10030' MD / 6740' 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 10034' MD / 6741' TVD ADL 25519 TPI: x - 531887 y - 6008835 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 532214 y 6010566 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 _8059' MD / 6728' 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 7863' 10034' 7221' 6741' 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: 7872' 10030' MD 7229' - 6740' TVD - ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMPLETI04 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED b .4 (?033' 17 ppg cement Id t 4 „. 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 • Sidewall Cores Acquired? Yes ❑ No Q 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 25.07 REC I�1L j 3 VE1D0 NONE . 11.0 03 Alas Oil & Gas In s$I,on RBDMS Anchorage Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 7-2._-/e) Submit original only 28. GEOLOGIC MARKERS (List all formations and mark e ncountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes EI No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Top A 8108' 6723' N/A Formation at total depth: Kuparuk A2 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265 - 1102 7/ r //0 Printed Na V. awv Title: Alaska Wells Manager / Signature Phone 265 -6306 Date i Z/ Sharon Allsu p -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory infomtation 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 v ,. KUP • 3K -09BL1 ConocolP Well Attribut Max Angle & MD TD Alaska Inc e .. Wellbore APUUWI F" Name Well Status Inc! (.) IMD (ftKB) Act Btm (ftKB) G[i<taco17tt1kPS 4 500292165660 KUPARUK RIVER UNIT PROD 1 _ Comment 11.128 (ppm) (Date Annotation End Date KB Grd (ft) R Release Date SSSV: TRDP _ I l . 120 2/23/2009 Last WO 6/17/2010 39 90 10/17/1986 W@II CmQg:._ 5tlte�i sS1r� 1, Vox 26 AM -- A otatlon Depth (ftK8) End Date Anrwtat — Last Mod ... End Date Last Tag: — 6/17/2010 'Rev Reason SIDETRACK, GLV C/O Imosbor 6/17/2010 — Casing Strings Casing Description IStr ng 0... ID ... Top (WE) Set Depth (f... Set Depth (TVD) .. String Wt... Str g String Top Thrd BL1 LINER i_ 23/8 [ String . 1995 I 7,863.4 100310 I 4.60 J L-80 STL Liner Details Top Depth R , (TVD) Top Inc! Nomi... 9; Top (ftKB) (ftKB) ( Item Description Comment ID (in) ': 7,863.4 Deployment Liner Top Aluminum Billet 1.000 sleeve HANGER, O -` i — _______ Perforations & Slots Shot Top (TVD) Btm (TVO) Dens Top tftKB) B1m (ftK8) (ftKB) (ftKB) gone_ Date tsh... Tea Comment 7,872 10,030 5/30/2010 SLOT Alternating solid /slotted pipe - ", 0. 125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered y .t, 18 deg, 3' non - slotted ends Notes: General & Safety _ ot io •�; '� = End Date Annotation 6/17/2010 NOTE: VIEW SCHEMATIC w /Alaska Schemattc9 0 n .Y '' 5 . i fit h CONDUCTOR,_ i II 38 -110 SURFACE, 37 -3,172 TD (36- 090L1), 3,172 PRODUCTION, 35 -7,559 b t_ " I I . , _ SLOT - 7,872- 10,030 r ' Mandrel Details Top Depth Top - -_ Port (T /0) Inc! OD Valve Latch Srse TRO Run ._ .� ftKB) (°) Make Model (in) Sery Type Type ( in) (Pa) Run Date Com... — Stn Stn Top(ftKBJ . ---" 1 2,396.3 CAMCO MMG 1 1/2 GAS LIFT GLV R -20 0.188 1,339.0 6/16/2010 1:7 2 3,532.7 CAMCO MMG 1 1/2 GAS LIFT GLV R -20 0.188 1,320.0 6/16/2010 3 4,606.5 CAMCO MMG 1 1/2 GAS LIFT GLV R -20 0.188 1,302.0 6/16/2010 4 5,586.4 CAMCO MMG 1 1/2 GAS LIFT OV rdo -20 0.250 0.0 6/16/2010 5 6,307.0 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.09/2/2008 BL1 LINER, 6 6,839.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/13/2010 7,863- 10,031 ConocoihiIIips Alaska ConocoPhilli ps (Alaska ) Inc. • Kuparuk River Unit Kuparuk 3K Pad 3K -09BL1 50- 029 - 21656 -60 Baker Hughes INTEQ M • Definitive Survey Report BAKER Y p HUGHES 22 June, 2010 1 ConocoPhillips ConocoPhillips Definitive Survey Report BAKER Alaska Company: ConocoPhillips(Alaska) Inc. y Local Co- ordinate Reference: 3K - 09 I Project: Kuparuk River Unit TVD Reference: 3K -09 © 69.00ft (3K -09) Site: Kuparuk 3K Pad MD Reference: 3K -09 @ 69.00ft (3K -09) Well: 3K - 09 North Reference: TRUE Wellbore: 3 - 09 Survey Calculation Method: Minimum Curvature Design: 3 K -09 Database: EDM Alaska Prod v16 Pro 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 +NI 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 I Wellbore 3K - 096L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength () (°) (nT) { BGGM2009 7/15/2010 17.14 79.87 57,394 Design 3K -09BL1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,040.46 Vertical Section: Depth From (TVD) +N/S +E /-W Direction • (ft) (ft) (ft) r) 69.00 0.00 0.00 45.00 F 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 8,040.46 3K -09B (3K -09B) MWD MWD - Standard 5/21/2010 5/25/2010 8,059.00 9,980.37 3K -09BL1 (3K- 09BL1) MWD MWD - Standard 5/27/2010 5/30/2010 6/22/2010 8:15:28AM Page 2 COMPASS 2003.16 Build 69 f ConocoPhillips Nal Conoco Phillips Definitive Survey Report HUGHES its Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordlnate 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/-8 +E/ -W Map Map DLS Vertical (ft) ( °) ( °) (ft) (ft) (ft) (ft) Northing Eas'ng (• /100') Sect(ft) ion Survey Tool Name Annotation • 8,040.46 89.88 56.94 6,727.61 6,658.61 558.11 2,528.28 6,008,796.63 531,831.74 9.88 2,182.41 MWD (2) TIP 8,059.00 90.01 55.43 6,727.63 6,658.63 568.43 2,543.68 6,008,807.01 531,847.10 8.17 2,200.59 MWD (3) KOP 8,080.28 94.67 55.20 6,726.76 6,657.76 580.52 2,561.16 6,008,819.17 531,864.53 21.93 2,221.51 MWD (3) Interpolated AZI 8,110.22 99.81 54.83 6,722.99 6,653.99 597.55 2,585.49 6,008,836.29 531,888.79 17.21 2,250,75 MWD (3) 8,140.24 104.14 54.06 6,716.76 6,647.76 614.62 2,609.38 6,008,853.45 531,912.60 14.64 2,279.71 MWD (3) 8,170.30 104.77 49.28 6,709.26 6,640.26 632.66 2,632.20 6,008,871.58 531,935.36 15.54 2,308.61 MWD (3) 8,200.17 104.61 44.16 6,701.68 6,632.68 652.46 2,653.23 6,008,891.47 531,956.31 16.59 2,337.48 MWD (3) 8,230.25 104.17 38.95 6,694.20 6,625.20 674.26 2,672.55 6,008,913.34 531,975.54 16.84 2,366.55 MWD (3) 8,260.41 103.41 34.34 6,687.00 6,618.00 697.75 2,690.03 6,008,936.90 531,992.92 15.06 2,395.52 MWD (3) 8,290.31 102.56 29.92 6,680.28 6,611.28 722.42 2,705.51 6,008,961.62 532,008.31 14.68 2,423.92 MWD (3) 8,320.38 102.06 25.76 6,673.87 6,604.87 748.39 2,719.23 6,008,987.65 532,021.92 13.62 2,451.98 MWD (3) 8,350.58 101.34 21.76 6,667.74 6,598.74 775.45 2,731.14 6,009,014.75 532,033.72 13.19 2,479.54 MWD (3) 8,380.41 101.68 17.07 6,661.79 6,592.79 803.01 2,740.86 6,009,042.34 532,043.33 15.45 2,505.89 MWD (3) I 8,410.42 100.28 15.45 6,656.07 6,587.07 831.29 2,749.10 6,009,070.65 532,051.46 7.06 2,531.72 MWD (3) 8,440.78 99.72 20.93 6,650.79 6,581.79 859.69 2,758.43 6,009,099.08 532,060.68 17.87 2,558.40 MWD (3) 8,470.88 96.43 23.49 6,646.57 6,577.57 887.27 2,769.70 6,009,126.71 532,071.84 13.80 2,585.87 MWD (3) 8,500.62 92.24 26.39 6,644.32 6,575.32 914.15 2,782.20 6,009,153.63 532,084.23 17.12 2,613.71 MWD (3) 8,531.66 89.51 28.35 6,643.84 6,574.84 941.71 2,796.47 6,009,181.24 532,098.39 10.83 2,643.29 MWD (3) III 8,560.41 89.91 24.13 6,643.99 6,574.99 967.49 2,809.18 6,009,207.07 532,111.00 14.74 2,670.51 MWD (3) 8,590.50 89.66 18.70 6,644.10 6,575.10 995.49 2,820.16 6,009,235.11 532,121.87 18.06 2,698.07 MWD (3) 8,620.34 90.98 14.17 6,643.94 6,574.94 1,024.10 2,828.60 6,009,263.76 532,130.19 15.81 2,724.27 MWD (3) i 8,650.12 91.17 9.51 6,643.38 6,574.38 1,053.24 2,834.71 6,009,292.91 532,136.19 15.66 2,749.19 MWD (3) 8,680.14 90.28 4.99 6,643.00 6,574.00 1,083.01 2,838.49 6,009,322.69 532,139.86 15.34 2,772.92 MWD (3) 8,710.61 90.92 359.27 6,642.68 6,573.68 1,113.44 2,839.63 6,009,353.13 532,140.87 18.89 2,795.24 MWD (3) 8,740.74 92.55 355.35 6,641.76 6,572.76 1,143.52 2,838.21 6,009,383.19 532,139.34 14.08 2,815.51 MWD (3) 8,770.22 92.95 356.66 6,640.35 6,571.35 1,172.89 2,836.16 6,009,412.56 532,137.17 4.64 2,834.83 MWD (3) 8,800.22 91.91 0.55 6,639.08 6,570.08 1,202.85 2,835.43 6,009,442.51 532,136.32 13.41 2,855.49 MWD (3) 8,830.23 90.58 5.18 6,638.43 6,569.43 1,232.80 2,836.93 6,009,472.47 532,137.71 16.05 2,877.74 MWD (3) 8,860.27 85.91 4.84 6,639.35 6,570.35 1,262.71 2,839.55 6,009,502.38 532,140.21 15.59 2,900.74 MWD (3) L 4 8,890.30 82.15 5.73 6,642.47 6,573.47 1,292.44 2,842.30 6,009,532.12 532,142.84 12.86 2,923.71 MWD (3) 6/22/2010 8:15:28AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips ,° ConocoPhl hlpS Definitive Survey Report MULES Alaska i Company: ConocoPhillips(Alaska) Inc. Local Co ordinate Reference: 3K - 09 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) I Well: 3K - 09 North Reference: TRUE 1 Wellbore: 3K - 09 Survey Calculation Method: Minimum Curvature 1 Design: 3K - 09 Database: EDM Alaska Prod v16 _ Survey MD Inc Azi TVD TVDSS +N!S +EJ-W Northing Easting O DES Section Survey Tool Name Annotation (ft) (1 el (ft) (ft) (ft) (ft) (ft) (ft) MOO') (ft) • 8,920.29 80.50 3.54 6,646.99 6,577.99 1,321.99 2,844.70 6,009,561.67 532,145.12 9.08 2,946.29 MWD (3) 8,950.29 74.71 4.26 6,653.43 6,584.43 1,351.21 2,846.69 6,009,590.90 532,147.00 19.44 2,968.36 MWD (3) 8,981.00 70.01 2.31 6,662.73 6,593.73 1,380.42 2,848.37 6,009,620.11 532,148.57 16.46 2,990.21 MWD (3) 9,010.14 69.75 358.94 6,672.76 6,603.76 1,407.77 2,848.67 6,009,647.46 532,148.76 10.90 3,009.76 MWD (3) 9,040.56 74.63 354.39 6,682.07 6,613.07 1,436.67 2,846.97 6,009,676.35 532,146.94 21.45 3,028.99 MWD (3) 9,071.07 80.53 352.85 6,688.62 6,619.62 1,466.26 2,843.66 6,009,705.93 532,143.51 19.96 3,047.57 MWD (3) 9,100.50 84.84 350.39 6,692.37 6,623.37 1,495.13 2,839.40 6,009,734.78 532,139.15 16.83 3,064.98 MWD (3) 9,130.27 89.45 348.38 6,693.85 6,624.85 1,524.35 2,833.93 6,009,763.97 532,133.56 16.89 3,081.76 MWD (3) 9,162.35 92.89 343.61 6,693.20 6,624.20 1,555.45 2,826.17 6,009,795.04 532,125.68 18.33 3,098.27 MWD (3) 9,190.32 92.43 340.88 6,691.90 6,622.90 1,582.06 2,817.65 6,009,821.61 532,117.05 9.89 3,111.06 MWD (3) 9,220.26 91.53 335.81 6,690.87 6,621.87 1,609.86 2,806.61 6,009,849.36 532,105.91 17.19 3,122.92 MWD (3) 9,249.97 91.07 332.92 6,690.19 6,621.19 1,636.64 2,793.76 6,009,876.09 532,092.95 9.85 3,132.76 MWD (3) 9,280.52 91.04 328.23 6,689.63 6,620.63 1,663.23 2,778.76 6,009,902.62 532,077.85 15.35 3,140.96 MWD (3) 9,311.04 90.52 326.07 6,689.21 6,620.21 1,688.87 2,762.21 6,009,928.19 532,061.20 7.28 3,147.39 MWD (3) 9,340.51 91.41 330.91 6,688.72 6,619.72 1,713.98 2,746.81 6,009,953.24 532,045.70 16.70 3,154.26 MWD (3) 9,370.30 91.96 336.65 6,687.84 6,618.84 1,740.68 2,733.66 6,009,979.89 532,032.45 19.35 3,163.84 MWD (3) 9,400.53 91.54 341.16 6,686.92 6,617.92 1,768.87 2,722.79 6,010,008.03 532,021.47 14.98 3,176.08 MWD (3) 9,430.58 92.03 345.82 6,685.98 6,616.98 1,797.66 2,714.25 6,010,036.78 532,012.82 15.59 3,190.40 MWD (3) • 9,460.49 93.47 349.87 6,684.54 6,615.54 1,826.86 2,707.96 6,010,065.95 532,006.42 14.36 3,206.60 MWD (3) 9,490.34 92.46 354.66 6,683.00 6,614.00 1,856.39 2,703.95 6,010,095.46 532,002.29 16.38 3,224.65 MWD (3) 9,520.45 90.89 358.25 6,682.12 6,613.12 1,886.42 2,702.09 6,010,125.48 532,000.32 13.01 3,244.57 MWD (3) 9,550.26 93.19 1.85 6,681.06 6,612.06 1,916.20 2,702.12 6,010,155.26 532,000.22 14.32 3,265.65 MWD (3) 9,580.33 94.55 6.69 6,679.03 6,610.03 1,946.11 2,704.35 6,010,185.18 532,002.34 16.68 3,288.37 MWD (3) 9,615.24 89.94 10.38 6,677.66 6,608.66 1,980.59 2,709.53 6,010,219.68 532,007.38 16.91 3,316.42 MWD (3) 9,645.38 85.67 11.43 6,678.81 6,609.81 2,010.16 2,715.22 6,010,249.26 532,012.96 14.59 3,341.35 MWD (3) 9,675.45 83.23 14.76 6,681.72 6,612.72 2,039.31 2,722.00 6,010,278.43 532,019.62 13.69 3,366.75 MWD (3) 9,705.39 80.71 18.62 6,685.91 6,616.91 2,067.70 2,730.51 6,010,306.85 532,028.02 15.29 3,392.84 MWD (3) 9,740.51 81.09 24.15 6,691.46 6,622.46 2,099.97 2,743.15 6,010,339.17 532,040.53 15.59 3,424.61 MWD (3) 9,770.55 85.02 27.61 6,695.10 6,626.10 2,126.79 2,756.17 6,010,366.04 532,053.44 17.37 3,452.77 MWD (3) 9,800.55 87.18 30.72 6,697.14 6,628.14 2,152.92 2,770.75 6,010,392.23 532,067.92 12.60 3,481.56 MWD (3) 9,830.57 87.72 35.96 6,698.47 6,629.47 2,177.97 2,787.23 6,010,417.33 532,084.29 17.53 3,510.92 MWD (3) 6/22/2010 8:15:28AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips Definitive Survey Report > KER 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 i Welibore: 3K - 09 Survey Calculation Method: Minimum Curvature J Design: 3K -09 y Database: EDM Alaska Prod v16 _____ Survey MD Inc Azi TVD TVDSS +N /-S +E/-W Northing Easting DLS Section Survey Tool Name Annotation (ft) (1 ( °) (ft) (n) (ft) (ft) (ft) (ft ( /100') (ft) • 9,860.31 86.68 39.71 6,699.93 6,630.93 2,201.42 2,805.44 6,010,440.86 532,102.42 13.07 3,540.39 MWD (3) 9,890,44 83.85 41.80 6,702.41 6,633.41 2,224.17 2,825.04 6,010,463.68 532,121.92 11.66 3,570.33 MWD (3) 9,920.15 79.50 42.28 6,706.72 6,637.72 2,245.99 2,844.72 6,010,485.58 532,141.52 14.73 3,599.68 MWD (3) 9,952.30 74.58 41.96 6,713.92 6,644.92 2,269.22 2,865.73 6,010,508.89 532,162.43 15.33 3,630.96 MWD (3) 9,980.37 69.81 42.13 6,722.50 6,653.50 2,289.07 2,883.62 6,010,528.80 532,180.24 17.00 3,657.64 MWD (3) 10,034.00 69.81 42.13 6,741.01 6,672.01 2,326.40 2,917.39 6,010,566.26 532,213.86 0.00 3,707.92 PROJECTED to TD III 6/22/2010 8:15:28AM Page 5 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" MO 3-1/2" Cameo MMG gas lift mandrels @ 2396' 3533' 16" 62# H -40 shoe 4607' @ 110' MD 5586' __ _� 6307' 6839' 10 -3/4" 45.5# K -55 shoe @ 3172' MD • 3 -1/2" X Nipple @ 6888' MD (2.813" profile) M c /, : 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 �— 7033' - 7035' WLEG @ 7049' MD r Tubing Tail @ 7050' MD t ' \ _ 2 - 5/8" Openhole anchor/whipstock @ 7150' Top of liner 7193' \ \ \ \ \ South Laterals III Top of Billet - 7749' 3K- 09BL2 -01: 8955' 2 -5/8" Openhole anchor /whipstock @ 7201' 7250' - Bottom of Pilot Hole North Laterals 3K- 096L2: 8879' A3 •sand perfs 7279' \ Top of Billet - 7863' - 7297' MD A2 -sand perfs 7310' -- - -- 3K - 09BL1: 10,034' - 7326' MD `� - -- -- - -- 7333' 7339' — `� ` t \..op of Billet - 8 059 T \ 3K -09B: TD - 9610' 7348' - 7352' \\ ( BOL - 9510' 7359' - 7363' r - _ 7" 26# J - 55 shoe @ �_ I 3K- 09BL1 -01: 8897' 7559' MD —...111111111 • 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 12:30 14:00 1.50 7,104 9,510 COMPZ CASING RUNL P Continue RIH. Stacked weight at 7320', 5K over pull, down clean. 9271' Stacked weight, did not PU, Got weight back. 14:00 15:00 1.00 9,510 6,690 COMPZ CASING RUNL P 28K PUW, Release liner at 9510', 1.2 BPM, 4000 psi, 23K PUW. Pump down backside while pulling out of open hole. Take out liner length from bit depth, - 1387.8. 15:00 15:18 0.30 6,690 6,720 COMPZ CASING DLOG P Log cased hole tie in, 0 correction. 15:18 16:36 1.30 6,720 0 COMPZ CASING RUNL P POOH 16:36 16:54 0.30 0 0 COMPZ CASING PUTB P Confirm no flow and lay down BHA 16:54 17:18 0.40 0 0 COMPZ CASING BOPE P Function test BOP, change stripper 17:18 18:03 0.75 0 0 COMPZ CASING PUTB P PU indexing guide shoe, 1 jt. slotted liner, 3 solid liner pups and anchored billet 18:03 18:33 0.50 0 0 COMPZ CASING SFTY P Crew change PJSM 18:33 19:03 0.50 0 0 COMPZ CASING PUTB P MU BHA to injector head 19:03 20:33 1.50 0 6,800 COMPZ CASING TRIP P RIH 20:33 22:03 1.50 6,800 7,320 COMPZ CASING DLOG P Tie in depth with gamma, +37' correction, Unsure of correction, RIH through window at 5 FPM to tie into RA marker 22:03 22:33 0.50 7,320 7,320 COMPZ CASING DLOG P Correct -5' tieing into RA marker, Overall correction +32' 22:33 22:48 0.25 7,320 8,125 COMPZ CASING TRIP P RIH to setting depth EDC closed, before running OH 22:48 23:03 0.25 8,125 8,125 COMPZ CASINGWPST P Tag TOL 8125.1'. P11 string weight 22K, 1K DHWOB. Online with pumps setting Anchor. .5 BPM, 3750 psi anchor set, 3.6K DHWOB. Line up pumps pumping across top displacing KWF keeping hole full. 23:03 23:18 0.25 8,125 7,350 COMPZ CASING TRIP P PUH to window 24.5K PUW. 23:18 00:00 0.70 7,350 COMPZ CASING TRIP P Line up pumping back down CT, POOH 05/27/2010 RIH with Coil Track drilling assembly 1.3AKO, Reed Hycalog Razor Bi- center, Displace well to Flo -Pro at window. Sidetrack for BL1 lateral off Alluminum Billet at 8059'. Drill BL1 Lateral 8059'- 8530'. Perform mud swap at 21:00 hours. 00:00 01:00 1.00 7,350 0 COMPZ CASING TRIP P POOH 01:00 02:00 1.00 0 0 COMPZ CASING PUTB P At surface, monitor well for flow, PJSM, LD BHA 9 02:00 03:18 1.30 0 0 PROD2 STK PULD P PU /MU BHA 10, Service injector head, clean gripper blocks, inspect BHI counter 03:18 04:48 1.50 0 6,750 PROD2 STK TRIP P RIH 04:48 05:42 0.90 6,750 7,300 PROD2 STK DLOG P Tie in depth with Gamma, Unable to get accurate tie in with gamma, RIH 50' above window, RIH 5 FPM tieing into RA marker. Tie in to RA, +32'. Page 12 of 26 • • Time Logs Date " From To Dur S. Depth E. Depth Phase Code " Subcode T Comment 05:42 07:12 1.50 7,300 7,300 PROD2 STK DISP P Displace KWF 07:12 08:00 0.80 7,300 8,059 PROD2 STK TRIP P RIH 08:00 11:42 3.70 8,059 8,072 PROD2 STK KOST P Tagged billet at 8059', start time milling at 1 FPH. 1.3 BPM, 3950 CTP, 250 WHP to maintain 4450 BHP, 24K PUW, 14K RIW. Some stick/slip. Increased to 2 FPH after 1 foot, then 3 FPH. increased to 10 FPH for 10'. 11:42 12:42 1.00 8,072 8,100 PROD2 DRILL DRLG P Drilling ahead, 1.3 BPM, 3990 CTP, 4460 BHP with 250 WHP. 11K surface weight with 2K WOB 12:42 12:54 0.20 8,100 8,100 PROD2 DRILL DRLG P Pick up and drift billet kick off. Up at .3 BPM, down with pump off. Clean both ways. 24K PUW, 14K RIW 12:54 16:06 3.20 8,100 8,230 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4000 CTP, 4475 BHP with 250 WHP. 11K surface weight with 2K WOB 16:06 17:18 1.20 8,230 8,230 PROD2 DRILL WPRT P Wiper trip to the window, 24K PUW, 13K RIW 17:18 19:39 2.35 8,230 8,380 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4050 CTP, 4485 BHP with 230 WHP. 11K surface weight with 2K WOB 19:39 20:39 1.00 8,380 8,380 PROD2 DRILL WPRT P Wiper trip back to window, 22K PUW, 13K RIW 20:39 22:09 1.50 8,380 8,530 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 4350 CTP, 4485 BHP with 325 WHP. 7K surface weight with 1 -2K WOB Mud swap 22:09 23:09 1.00 8,530 8,530 PROD2 DRILL WPRT P Wiper trip back to window, 22.8K PUW, 11K RIW 23:09 23:18 0.15 7,230 7,225 PROD2 DRILL DLOG P Tie into RA marker -5' correction 23:18 23:48 0.50 8,225 8,155 PROD2 DRILL WPRT P RIH 14K RIW 23:48 00:00 0.20 8,155 8,500 PROD2 DRILL WPRT P Set down at 8155', PUH 21.2K PUW, clean PU to 8130'. RIH, Slide through no pumps. Wipe back through area 8170 - 8130', Al shale area 8136- 8150'. Reduce pump rate 1 BPM RIH through shales on second run. Slide through. RIH to bottom 05/28/2010 Drill BL1 Lateral 8530'- 9430'. Low Level H2S Alarm at 430am. (Sensor #2 Cellar, False Alarm). 00:00 00:12 0.20 8,500 8,530 PROD2 DRILL WPRT P Continue RIH 00:12 01:27 1.25 8,530 8,680 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4520 BHP with 350 WHP. 6 -7K surface weight with 1.5K -2K WOB 01:27 01:42 0.25 8,680 8,680 PROD2 DRILL WPRT P Wiper Trip back to window, 22.2K PUW 01:42 02:24 0.70 8,680 8,680 PROD2 DRILL DLOG P Perform MAD pass as per GEO, 8290'- 8130', at 4 FPM 02:24 03:30 1.10 8,680 8,680 PROD2 DRILL WPRT P Continue wiper trip Page 13 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 8,680 8,750 PROD2 DRILL DRLG P Continue drilling, 1.38 BPM, 4150 CTP, 4520 BHP with 350 WHP. 6 -7K surface weight with 1.5K -2K WOB 04:30 05:00 0.50 8,750 8,750 PROD2 DRILL SFTY P PUH, Low level H2S alarm, muster rig. Notify security and Nordic 3. False Alarm, faulty sensor. RIH 05:00 07:00 2.00 8,750 8,830 PROD2 DRILL DRLG P Continue drilling, 1.38 BPM, 4150 CTP, 4520 BHP with 350 WHP. 6 -7K surface weight with 1.5K -2K WOB 07:00 09:12 2.20 8,830 8,830 PROD2 DRILL WPRT P Wiper to window, 24K PUW, clean run in hole 09:12 12:36 3.40 8,830 8,980 PROD2 DRILL DRLG P Continue drilling, 1.35 BPM, 4100 CTP, 4550 BHP with 350 WHP. 6K surface weight with 1.5K -2K WOB 12:36 13:42 1.10 8,980 7,225 PROD2 DRILL WPRT P Wiper to window, 25K PUW 13:42 13:54 0.20 7,225 7,250 PROD2 DRILL DLOG P Tie in at RA, -5' 13:54 14:48 0.90 7,250 8,977 PROD2 DRILL WPRT P Wiper back in hole, set down at 8818', PU and then run by clean 14:48 16:39 1.85 8,980 9,130 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4600 BHP with 280 WHP. 6 -7K surface weight with 1.5K -2K WOB 16:39 18:54 2.25 9,130 9,130 PROD2 DRILL WPRT P Wiper trip to window, 23K PUW 18:54 20:24 1.50 9,130 9,280 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4600 BHP with 280 WHP. 6 -7K surface weight with 1.5K -2K WOB 20:24 22:54 2.50 9,280 9,280 PROD2 DRILL WPRT P Wiper trip to window, 22.8K PUW 22:54 00:00 1.10 9,280 9,384 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4630 BHP with 260 WHP. 6 -7K surface weight with 1.5K -2K WOB 05/29/2010 Drill BL1 Lateral. TD'd Lateral 10018' 00:00 00:30 0.50 9,384 9,530 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4620 BHP with 240 WHP. 6 -7K surface weight with 1.5K -2K WOB 00:30 02:00 1.50 9,530 7,230 PROD2 DRILL WPRT P Wiper trip back to window, 23K PUW 02:00 02:12 0.20 7,230 7,230 PROD2 DRILL DLOG P Tie into RA marker, -7' 02:12 03:12 1.00 7,230 9,530 PROD2 DRILL WPRT P RIH 03:12 05:12 2.00 9,530 9,580 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4620 BHP with 240 WHP. 6 -7K surface weight with 1.5K -2K WOB 05:12 08:00 2.80 9,580 9,580 PROD2 DRILL WPRT P Wiper to window, 23K PUW. 13K RIW, clean trip both ways. 08:00 10:18 2.30 9,580 9,730 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4100 CTP, 4640 BHP with 250 WHP. 6 -7K surface weight with 1.5K -2K WOB Page 14 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:18 12:00 1.70 9,730 7,218 PROD2 DRILL WPRT P Wiper to window, 23K PUW 12:00 12:12 0.20 7,218 7,240 PROD2 DRILL DLOG P Tie in at RA, -6' correction 12:12 13:30 1.30 7,240 9,730 PROD2 DRILL WPRT P Wiper in hole, 14K RIW 13:30 15:06 1.60 9,730 9,880 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4100 CTP, 4700 BHP with 150 WHP. 7K surface weight with 1.5K -2K WOB 15:06 17:00 1.90 9,880 7,220 PROD2 DRILL WPRT P Wiper trip to window, Start mud swap. Over pull at 8145'. 17:00 17:12 0.20 7,220 7,240 PROD2 DRILL DLOG P Tie in , -4' correction 17:12 18:27 1.25 7,240 9,880 PROD2 DRILL WPRT P Wiper in hole 18:27 20:42 2.25 9,880 10,018 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4100 CTP, 4700 BHP with 400 WHP. 7K surface weight with 1.5K -2K WOB 20:42 22:42 2.00 10,018 10,018 PROD2 DRILL WPRT P Pump 5bbrl low/ 10bbrl high vis sweeps. TD BL1 Lateral, Wiper trip back to window chasing sweeps. 24.5K PUW Pull heavy 8940 - 8820'. Continue POOH not wanting to irratate shales 22:42 22:57 0.25 10,018 7,230 PROD2 DRILL DLOG P Tie into RA marker, -3' correction 22:57 23:27 0.50 7,230 8,230 PROD2 DRILL WPRT P RIH to TD, Large amounts of shale in returns plugging Choke "B ". Swap to choke "A ". Blow back choke "B" and MM, good amount of shale when blown back. 23:27 00:00 0.55 8,230 8,230 PROD2 DRILL WPRT P Continue RIH, pump minimum rate through shale areas, Keep MM bypassed until reach TD to keep MM clean of shale, to use MM on displacing liner running pill. 05/30/2010 Lay in liner running pill, POOH displacing well to KWF, PU 66jnts with Liner top Billet. RIH setting on bottom. POOH keeping well displaced of KWF. Start BOP testing 7PM 00:00 00:30 0.50 9,500 10,018 PROD2 DRILL WPRT P Tag TD 10018' 00:30 01:00 0.50 10,018 8,400 PROD2 DRILL WPRT P POOH laying in Liner Pill 1 for 1, chasing with flo -pro. 01:00 01:30 0.50 8,400 7,771 PROD2 DRILL WPRT P Confirmed able to pass bad area 8940 - 8820'. Start pumping KWF (formate). Continue POOH laying in Liner pill 01:30 01:45 0.25 7,771 7,250 PROD2 DRILL WPRT P Paint EOP flag 7700. 7771 CTMD, Continue POOH 01:45 02:03 0.30 7,250 7,350 PROD2 DRILL CIRC P RIH to spot KWF 7350' 02:03 02:45 0.70 7,350 4,971 PROD2 DRILL TRIP P POOH displacing well to KWF 02:45 04:15 1.50 4,971 0 PROD2 DRILL TRIP P Paint EOP flag 4900'. 4971' CTMD, POOH 04:15 04:30 0.25 0 0 PROD2 DRILL OWFF P PJSM, flow check well 04:30 05:42 1.20 0 0 PROD2 DRILL PULD P LD BHA 10 05:42 06:00 0.30 0 0 COMPZ CASING SFTY P PJSM for liner operations Page 15 of 26 • • 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 7 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 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 i 9 ; 4 Gal C / 99 0q/ AT1ChJr3Ce c2/0-64D , 0/0 -543 ggas alo -oGt5 /996(0 °>ai of 0 -0q5 l • /SEANPARNELLGOVERNOR sifor[E DIF ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 James Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K -09BL1 ConocoPhillips Alaska, Inc. Permit No: 210 -043 Surface Location: 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM Bottomhole Location: 1768' FNL, 1953' 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. Aer Sincerely, Daniel T. Seamount, Jr. cL � Chair DATED this / r day 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 20 AAC 25.005 Alaska Oil & Gas Cons. Commission , 1 a. Type of Work: - 1 b. Proposed Well Class: Development - Oil 0 • Service - Winj El Single Zone Q • lc. Specify if w e isll " 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 ❑ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 - 3K - 09BL1 • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 10050' • TVD: 6637' • 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 • Kuparuk River Oil Field • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1933' FSL, 2368' FEL, Sec. 35, T13N, R9E, UM 2555 4/26/2010 Total Depth: 9. Acres in Property: 14. Distance to 1768' FNL, 1953' 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: 8200 • ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 102° d Downhole: psig `t� 4/ / ,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 2855' 7195' 6652' 10050' 6637' 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 El Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 47,00 (7� 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265 - 1 1 02 ` Printed Name V. Cawvey Title Alaska Wells Manager Signature I Phon 265 -63o6 Date eF/9/246 Commission Use Only Permit to Drill API Num . Permit App val See cover letter Number: 2_16 � C.% _� 50- � 2_/ .;(-- -. 6( - ) Date: id 1 Li i D for other requirements Conditions of approval : If box i checked, well may not be used to explore for, test, or produce coal ed me ne, gas hydrates, or gas contained in shales: I * 560 PS,. L a? ie.s' Samples req'd: Yes ❑ o Mud log req'd: Yes LI No [� Other: * ?�0 � S� ,.'Kwi' ' s 1 H2S measures: Yes [+f No ❑ Directional svy req'd: Yes [v]r No ❑ G Cam- ) / AO. DATE: /�' APPROVED BY THE COMMISSION �` Q , COMMISSIONER 0 Form 10 (Revised 7/2009) This permit is valid fo r 4 �,.ikh ft t(r e,o artrval (20 AAC 25.005(8)) , Submit in Duplicate • 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 33/4" 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 23/4" slotted liner from to —7,195' MD, into the pilot hole inside the 7" 1 ,, TD casing Page 2 of 5 4/6/2010 rTh r` .� "� Permit to Drill Summary of Operations Cont KRU 3K -09B, 3K 09BL1, 3K 09BL2, and 3K 09BL2 -01 7. Set top of whipstock at 7,150' MD. 8. Mill 2.80" window at 7,150'. 9. 3K -09BL2 Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,075' MD b. Run the 2%" slotted liner from TD to 7,700' MD. An aluminum liner top billet will be placed at —7,700' MD. 10. 3K- 09BL2 -01 Lateral a. Kick off of the aluminum liner top billet at 7,700' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 9,075' MD 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 8,200 9,975 23/4", 4.7 #, L -80, ST -L slotted Unanchored aluminum billet 3K - 09BL1 7,195 10,050 23/4', 4.7 #, L -80, ST -L slotted 3K - 09BL2 7,700 9,075 2 % ", 4.7 #, L -80, ST -L slotted Unanchored aluminum billet 3K - 09BL2 - 6,970 9,075 23/4', 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 / 36 J -55 0 3,172 3520 2020 Casing 7" 26 J -55 0 7,559 4980 4320 Tubing 3'/2" 9.3 L -80 0 6,940 10,160 10,530 Page 3 of 5 4/6/2010 • • 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 • • 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 (Le. 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 3K -09B + Proposed CTD Sidetrack ` 3 -1/2" TRMAXX -5E SCSSV @ 2,183' MD ID = 2.812" O _ 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface ID = 2.992" 16" 62# H -40 shoe © 110' MD 3 -1/2" Camco MMG gas lift mandrels © 2396' 3533' 4607' 9 -5/8" 36# J-55 shoe 5586' @ 3172' MD 6307' Sri 6839' ti • Nieween 3-1/2" X Nipple @ 6888' MD (2.813" profile) 1 _1 , Baker PBR © 6922' MD (4" ID) m;:n ": Wi Baker KBH -22 Anchor Seal Assembly @ 6935' MD (3.0" ID) Packer to I , JPerfs for Cement Baker SAB3 Packer @ 6936' MD (4.0" ID) , Tubing Tail =104' -1�'ll `�� 4-- 7035' .�" n 4 i ' $ 2.813 " 'XN' Nipple @ 6984' MD (2.75" min ID) ER a - mi WLEG @7049'MD Tubing Tail to li��il "I1 Tubing Tail @ 7050' MD Top of Whipstock= 100' AN :z:::::::::::::::::::: 70'. \` 1 (South Laterals KOP - 7700' 3K- 09BL1: 9075' WP II�!i 7200' ; i: .: "� ■ I I r ouillll1 °'u "'� 7250' - Bottom of Pilot Hole 4 a h, 3K-09BL2: 9075' WP06 �,. @I i 'il,; "1411114.„, .. 1 INorth Laterals 1 �.�1NIr''". ,i,u , 74r, vXuuu , X7,1747 4,Z__, �7:�,_;- ;,ir'. I • A3 - sand pads 7279' 1' -729T MD '`2 .�� ! R���Ili�'�- ; +u .I !�Ilf 1nli * . , _ _ A2 -sand perfs 7310' 7326' MD .g IK OP - 8200' � 3K 09BL1: 10,050' WP07 7333' A 1,; 7339' , , - �„ 1 . ^ . T, . 'tiI7 7344' _ c r , __ 7348' - 7352' PBTD @ 7410'" - 7" 26# J-55 shoe @ I3K -09B: 9975' WP06 7359' - 7363' ' 11/22/0 7559' MD ■ KUP 3K-09A Conoco Phillips Ni Mak & MD 1111 ,,,.. , W ell 7 r , ::.== ''''.: .-- \- k14 ,h -,. pp -.6gaje Wellbore APVINI Field Name Well Status Incl r) MD (((KB) Act Earn (((KB) con.i.Vhdips f 500292165601 KUPARUK RIVER UNIT I PROD 37.33 4,675.00 7,580.0 H29 (ppm) Date Annotation End Date KB-Grd ((t) Rig Release Date ... SSSV: TRDP 135 1/12/2008 Last WO: 9/5/2008 39.90 10/17/1986 Well Cat160 • 31(-09A 100327 AM Annotation maw (((KB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,397.0 11/22/2009 Rev Reason: TAG Imosbor 11/26/2009 1 C aft i Iiiii St i hi 0 iiMEZA . 1. 5 ,- . 7 i1:*::, - ,t4. - fi -.',,,,--:- 74.: t. ,,,,- 4 HANGER, 0 0 . ' Casing Description String 0._ String ID Top (((KB) Set Depth ... Set Depth (TVD).- String Wt... String ... String Top Thrd :- I CONDUCTOR 16 15.062 0.0 110.0 110.0 62.50 H CONDUCTOR, Casing Description String 0... String ID - Top (MB) Sat Depth (f... Set Depth (ND) . - String Wt.. String ... String Top Thrd 0.1 10 SURFACE 95/8 8.697 0.0 3,172.0 3,169.4 36.00 .1 Safety Valve, 1 liV: Casing Description String 0... String ID ... Top (fIKB) Set Depth (f... Set Depth (TVD).- String Wt- String ... String Top Thrd PRODUCTION 7 6.151 0.0 7,559.0 26.00 J-55 zisa IIIIF N Tii blicft StriiigW4=?±Krifz:FM , Tubing Description String 0... String ID... Top (IIKB) Set Depth (f.- Set Depth (TVD) .- String Wt... String ... String Top Thrd .ft GAS LIFT, TUBING 3 1/2 2.992 0.0 6,940.4 6,434.6 9.30 L EUE 8rd 2.396 11&: - oiliiiiii - letkin:Detailiilici Top DePtn (TVD) Top Ind SURFACE, Top (((KB) ) MG) (I It De...101,,,, Comment 10 (in) 04,172 - I 0.0 0.0 0.00 HANGER 3.5" Gen V Tubing Hanger EUE 8rd Mod (Pup (1 3.66') 3.500 2,183.3 2,183.3 1.24 Safety Valve 3.5" TRMAXX-5E SCSSV w/ 2.812" X Profile EUE &d Mod 2.812 GAS LIFT, 11 3,533 6,888.0 6,390.0 31.54 NIPPLE 3.5" X Nipple w/ 2.813" profile 2.813 li 6,927.6 6,423.7 31.23 LOCATOR Baker 3.5" Locator O.D. 4.54" I. D. 3.99" 3.030 GAS UFT, Il 6,927.9 6,424.0 3123 SEAL ASSY Baker 80 PBR w/Seal Assembly O.D. 4.01" (.0. 2.99 2.990 4,607 Tubing Description String 0... String ID _ Top (((KB) Set Depth (f... Set Depth ((VD) ... String Wt... String ... String Top Thrd 1 TUBING Original 31/2 2.992 6,921.6 7,050.0 6,528.1 9.30 L-80 EUE 8rd GAS UFT, Completiorf_DetailsORitte-ft:gfh.:M5 5,586 Top Depth 1 (16/0) Top Ind Top (fIKB) MB/ r) Item Description Nomi- ID (In) GAS UFT, I 6,921.6 6,418.7 31.87 PBR Baker PBR Polish Bore Receptacle (6 Pins 40,000 lb Shear) 4.000 6,307 I 6,935.0 6,430.0 3125 SEAL ASSY Baker KBH-22 Anchor Seal Assembly (3.5" EUE 8rd Box Up) 3.000 6,935.9 6,430.8 3125 PACKER Baker 7* x 4.5" SAB3 Retainer Production Packer (LTC Box Down) 3250 GAS LIFT, 6,839 - 6,946.4 6,439.7 3128 XO-Reducing .Crossover 4.5" LTC Box x 3.5" EUE 8rd Pin 3.500 al 6,983.8 6,471.6 31.09 NIPPLE 2.813" 'XN' Nipple (2.75" No-Go) 2.750 NIPPLE, 6,688 ii- 7,049.1 6,527.4 31.59 WLEG Wireline Entry Guide 4.18" O.D. 2.992 i - tiiiiiiiiii4 - 6iii 7 ieiiiielifiio4 Top Depth 1 I I (IVO) Top Ind Top (MB) MKB) (*) Description Comment Run Date ID tin) LOCATOR. 1 - 4 1 1 7,400 FISH 11/2" OV 1.5" OV LOST 2/24/2006 2/24/2006 6,9213 IIIE 91311, 6922 ■ - i 7,473 FISH 1 1/2" DV 8 TG Latch Dropped to Rathole 12/16/1986 12/16/1986 SEAL ASSY, '411 6928" SEAL ASSY, Perritteaticiiii 6,305 Shot Shot PACKER, 6,936 ---- • - Top (ND) Btm (TVD) Dens Tap (MB) Btrn (MB) (((KB) (((KB) Zone Date Oh.- Type Comment ;` 1.--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 I 7,284 7,284 6,727.7 6,727.7 A-3, 3K-09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph 7,289 7,289 6,731.9 6,731.9 A-3, 3K-09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph XO ng, 111 7,292 7,292 6,734.5 6,734.5 A 3K 12/14/1986 1.0 IPERF 2 1/8' EnerJet, 0 deg ph 6,946 N 7,294 7,294 6,736.2 6,736.2 A-3, 3K-09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph al 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 le 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 2 1/8" EnerJet, 0 deg ph WLEG, 7,049 IL 7,339 7,339 6,774.4 6,774.4 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,344 7,344 6,778.7 6,778.7 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,348 7,352 6,782.1 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph = - IPERF, 7,284 - --- 7,359 7,363 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph ------ . RPERF, ---- = 7479-7,297 ..., __ ,... :771- Notes:aeneral &SafetVt .f IPERF, 7,269 End Date Annotation =="--_ 9/20/2008 NOTE: VIEW SCHEMATIC w/Alaslca Schematic9.0 IPERF, 7,292 77_.. -__ : IPERF, 7,294 _ i -_...- . 7. ' --_ IPERr --.......___M-,-t .7 7,310-7,326 ...-_,---- IPERF, 7,325 ----- = -_---- =_- • IPERF, 7,333 IPERF, 7,339 • IPERF, 7,344 - - Top Depth Top Port ITVDI Ind OD Valve Latch Slue TRO Run mad IPERF, 418 Top (ftl(ll) Mai) r) Make Model (in) Sera Type Type tin) (Pei) Run Date Com.. a :...= 1 2,396.3 2,3962 2.10 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,346.0 9/28/2008 2 3,532.7 3,523.8 11,53 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,327.0 9/28/2008 IPERF, ______M M 3 4,606.5 4,510.4 37.11 CAMCO MMG 11/2 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 11/2 GAS LIFT GLV RK 0.188 1,307.0 9/28/2008 5 6,307.0 5,900.3 33.83 CAMCO MMG 11/2 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 11/2 GAS LIFT OV RK 0.188 0.09/27/2008 FISH, 7,473 PRODUCTON, 0-7,559 N 1D . (3K-09A), \ ORIGINAL 7,560 , , , • Conoc�PhiIIips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K -09 3K -09BL1 Plan: 3K -09BL1 wp07 Standard Planning Report 05 April, 2010 Fd'Al BAKER HUGHES 4 2 4 L • • - ConocoPhillips 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 Weil: 3K - 09 Survey Calculation Method: i Minimum Curvature Wellbore: 3K - 09BL1 Design:- 3K- 09BL1_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 l Site - Kuparuk 3K Pad Site Position: Northing: 6,008,428.74ft Latitude: 70° 26' 2.781 N From: Map Easting: 529,306.18ft Longitude: 149° 45' 39.930 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.23 ° Well 3K - 09 Well Position +N/-S - 200.11 ft Northing: 6,008,228.65ft Latitude: 70° 26' 0.812 N +E/ - - 1.04 if Easting: 529,305.92 ft Longitude: 149° 45' 39.960 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Welibore - 3K - 09BL1 Magnetics Model Name - Sample Date - Declination = = Dip Angle - - Field Strength (°) _ _ ( °) - (nT) ° _; BGGM2009 7/15/2010 17.14 79.87 57,394 Design -- 3K -09BL1 wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,200.00 Vertical Section: Depth From (TVD) +WS +E/ -W - Direction =- ° (ft) _ (ft) (ft) - . _ r) 0.00 - 200.11 - 1.04 14.00 Plan Sections M easured TVD Below_ Dogleg Build = -_- _ ; Tum Depth Inclination Azimuth- - System +NI-S +E/ -W Rate Rate Rate TFO - - (ft) = (°) - ( °) -__ (ft) (ft) - (ft) ° _ (1100ft) (1100ft) ( °/100ft), - - (°} _ Tar 8,200.00 92.96 38.73 6,654.98 486.83 2,592.77 0.00 0.00 0.00 0.00 8,215.00 95.96 38.73 6,653.82 498.50 2,602.13 20.00 20.00 0.00 0.00 8,245.00 101.96 38.73 6,649.15 521.60 2,620.66 20.00 20.00 0.00 0.00 8,320.00 100.26 47.74 6,634.67 575.15 2,671.03 12.00 -2.27 12.01 100.00 8,420.00 97.97 35.81 6,618.77 648.66 2,736.66 12.00 -2.29 -11.93 260.00 8,550.00 89.57 22.63 6,610.20 761.56 2,799.72 12.00 -6.46 -10.14 238.00 8,750.00 87.17 358.73 6,615.98 956.57 2,836.52 12.00 -1.20 -11.95 264.00 8,920.00 90.12 338.54 6,620.05 1,122.31 2,803.20 12.00 1.74 -11.88 278.00 9,045.00 98.00 325.74 6,611.17 1,232.25 2,745.16 12.00 6.30 -10.24 302.00 9,170.00 91.50 339.31 6,600.77 1,342.48 2,687.91 12.00 -5.20 10.86 115.00 9,270.00 91.47 351.31 6,598.18 1,439.01 2,662.61 12.00 -0.03 12.00 90.00 9,370.00 89.98 3.22 6,596.91 1,538.70 2,657.85 12.00 -1.48 11.91 97.00 9,540.00 79.95 21.07 6,611.94 1,703.41 2,693.09 12.00 -5.90 10.50 120.00 9,610.00 87.24 16.88 6,619.74 1,769.14 2,715.67 12.00 10.42 -5.99 330.00 9,810.00 87.89 40.89 6,628.37 1,942.80 2,811.50 12.00 0.32 12.01 89.00 10,050.00 88.15 69.71 6,636.86 2,077.90 3,006.63 12.00 0.11 12.01 90.00 4/5/2010 9:19:29AM Page 2 COMPASS 2003.16 Build 69 • 0 ConocoPhillips redis 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 Survey Calculation Method: Minimum Curvature Wel!bore: ` - 3K - 09BL1 Design: 3K 09BL1_wp07 Planned Survey ` Measured TVD Below Vertical Dogleg Toolface Map Map DePth Inclination Azimuth System + w$ +Ej_ily Section Rate Azimuth "_ Northing Easting on (ft) (1100f) _ (°) (ft) (ft) 8,200.00 92.96 38.73 6,654.98 486.83 2,592.77 1,294.04 0.00 0.00 6,008,925.71 531,896.76 TIP/ KOP 3K - 09B � 8,215.00 95.96 38.73 6,653.82 498.50 2,602.13 1,307.62 20.00 0.00 6,008,937.41 531,906.07 2 8,245.00 101.96 38.73 6,649.15 521.60 2,620.66 1,334.53 20.00 0.00 6,008,960.59 531,924.51 End of DLS 20 8,300.00 100.74 45.35 6,638.31 561.62 2,656.76 1,382.09 12.00 100.00 6,009,000.74 531,960.45 8,320.00 100.26 47.74 6,634.67 575.15 2,671.03 1,398.66 12.00 101.30 6,009,014.32 531,974.67 4 8,400.00 98.46 38.18 6,621.63 632.85 2,724.75 1,467.65 12.00 - 100.00 6,009,072.23 532,028.15 8,420.00 97.97 35.81 6,618.77 648.66 2,736.66 1,485.87 12.00 - 101.56 6,009,088.08 532,040.00 5 8,500.00 92.82 27.67 6,611.24 716.32 2,778.49 1,561.64 12.00 - 122.00 6,009,155.91 532,081.55 , 8,550.00 89.57 22.63 6,610.20 761.56 2,799.72 1,610.67 12.00 - 122.77 6,009,201.22 532,102.61 6 i 8,600.00 88.94 16.66 6,610.85 808.62 2,816.52 1,660.40 12.00 -96.00 6,009,248.34 532,119.22 8,700.00 87.74 4.71 6,613.76 906.66 2,835.02 1,760.01 12.00 -95.92 6,009,346.45 532,137.33 8,750.00 87.17 358.73 6,615.98 956.57 2,836.52 1,808.79 12.00 -95.57 6,009,396.36 532,138.64 7 8,800.00 88.02 352.79 6,618.09 1,006.37 2,832.83 1,856.22 12.00 -82.00 6,009,446.13 532,134.75 8,900.00 89.77 340.92 6,620.03 1,103.55 2,810.13 1,945.02 12.00 -81.75 6,009,543.21 532,111.67 8,920.00 90.12 338.54 6,620.05 1,122.31 2,803.20 1,961.55 12.00 -81.52 6,009,561.94 532,104.67 8 9,000.00 95.19 330.38 6,616.34 1,194.33 2,768.80 2,023.11 12.00 -58.00 6,009,633.83 532,069.99 9,045.00 98.00 325.74 6,611.17 1,232.25 2,745.16 2,054.19 12.00 -58.38 6,009,671.65 532,046.20 9 9,100.00 95.17 331.74 6,604.85 1,278.94 2,716.83 2,092.63 12.00 115.00 6,009,718.22 532,017.69 i 9,170.00 91.50 339.31 6,600.77 1,342.48 2,687.91 2,147.29 12.00 115.69 6,009,781.64 531,988.53 1 10 9,200.00 91.50 342.91 6,599.99 1,370.85 2,678.20 2,172.47 12.00 90.00 6,009,809.97 531,978.71 9,270.00 91.47 351.31 6,598.18 1,439.01 2,662.61 2,234.82 12.00 90.09 6,009,878.06 531,962.85 11 9,300.00 91.02 354.88 6,597.53 1,468.78 2,659.00 2,262.84 12.00 97.00 6,009,907.81 531,959.13 9,370.00 89.98 3.22 6,596.91 1,538.70 2,657.85 2,330.41 12.00 97.08 6,009,977.72 531,957.70 12 9,400.00 88.18 6.34 6,597.39 1,568.59 2,660.35 2,360.01 12.00 120.00 6,010,007.62 531,960.08 9,500.00 82.25 16.81 6,605.74 1,666.04 2,680.27 2,459.39 12.00 119.95 6,010,105.14 531,979.61 9,540.00 79.95 21.07 6,611.94 1,703.41 2,693.09 2,498.75 12.00 119.07 6,010,142.55 531,992.29 13 9,600.00 86.20 17.47 6,619.17 1,759.60 2,712.72 2,558.02 12.00 -30.00 6,010,198.81 532,011.70 1 9,610.00 87.24 16.88 6,619.74 1,769.14 2,715.67 2,567.99 12.00 -29.56 6,010,208.36 532,014.61 14 9,700.00 87.48 27.69 6,623.90 1,852.20 2,749.71 2,656.82 12.00 89.00 6,010,291.55 532,048.32 9,800.00 87.84 39.69 6,628.00 1,935.18 2,805.04 2,750.72 12.00 88.50 6,010,374.74 532,103.31 9,810.00 87.89 40.89 6,628.37 1,942.80 2,811.50 2,759.68 12.00 88.01 6,010,382.39 532,109.75 15 9,900.00 87.92 51.70 6,631.67 2,004.85 2,876.43 2,835.59 12.00 90.00 6,010,444.68 532,174.42 10,000.00 88.05 63.71 6,635.20 2,058.15 2,960.75 2,907.71 12.00 89.60 6,010,498.31 532,258.52 10,050.00 - 88.15 69.71 6,636.86 , 2,077.90 3,006.63 2,937.97 12.00 89.18 6,010,518.24 532,304.32 1 TD i 4/5/2010 9:19:29AM Page 3 COMPASS 2003.16 Build 69 :a ! f ! , M f • • ConocoPhillips Fan 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 c 69.00ft (3K -09) Site: Kuparuk 3K Pad North Reference: True Well 3K Survey Calculation Method: Minimum Curvature Wellbore: 3K - 09BL1 3K 09BL1_wp07 Targets ' Name _ - _ - hltlmiss target Dip Angle Dip Dir. TVD +NiS +E!-W Northing Easting - Shape r) ( (R) (ft) (ft) (R) (ft) Latitude Longitude 3K -09B, BL1 fault 3 0.00 0.00 0.00 1,830.72 2,471.98 6,010,268.98 531,770.70 70° 26' 20.781 N 149° 44' 27.372 W - plan misses target center by 6605.28ft at 9400.00ft MD (6597.39 TVD, 1568.59 N, 2660.35 E) I - Polygon Point 1 0.00 1,830.72 2,471.98 6,010,268.98 531,770.70 Point 2 0.00 1,741.60 2,758.67 6,010,180.99 532,057.71 Point 3 0.00 1,679.85 2,950.45 6,010,120.00 532,249.71 Point 4 0.00 1,741.60 2,758.67 6,010,180.99 532,057.71 3K -09BL1 t5 0.00 0.00 6,611.00 1,696.84 2,690.47 6,010,135.98 531,989.70 70° 26' 19.464 N 149° 44' 20.961 W - plan hits target center - Point 3K -09BL1 t2 0.00 0.00 6,620.00 1,127.36 2,801.24 6,009,566.98 532,102.69 70° 26' 13.863 N 149° 44' 17.716 W - plan hits target center - Point 3K -09BL1 t1 0.00 0.00 6,610.00 765.32 2,800.81 6,009,204.99 532,103.69 70° 26' 10.302 N 149° 44' 17.732 W - plan hits target center - Point 3K -09B, BL1 fault 2 0.00 0.00 0.00 830.72 2,449.03 6,009,269.00 531,751.69 70° 26' 10.947 N 149° 44' 28.055 W - plan misses target center by 6619.86ft at 8550.00ft MD (6610.20 TVD, 761.56 N, 2799.72 E) - Polygon Point 1 0.00 830.72 2,449.03 6,009,269.00 531,751.69 Point 2 0.00 1,282.71 2,722.81 6,009,722.01 532,023.66 Point 3 0.00 1,782.50 3,048.78 6,010,223.03 532,347.63 Point 4 0.00 1,282.71 2,722.81 6,009,722.01 532,023.66 3K -09BL1 t4 0.00 0.00 6,597.00 1,524.96 2,657.79 6,009,963.98 531,957.70 70° 26' 17.773 N 149° 44' 21.922 W - plan hits target center - Point 3K -09B, BL1 Polygon 0.00 0.00 0.00 - 194.24 1,907.94 6,008,242.02 531,214.67 70° 26' 0.868 N 149° 44' 43.943 W - plan misses target center by 6722.39ft at 8333.96ft MD (6632.22 TVD, 584.53 N, 2681.07 E) - Polygon Point 1 0.00 - 194.24 1,907.94 6,008,242.02 531,214.67 Point 2 0.00 -28.19 1,900.58 6,008,408.03 531,206.66 Point 3 0.00 305.87 2,151.90 6,008,743.04 531,456.64 Point4 0.00 613.60 2,488.13 6,009,052.06 531,791.63 Point 5 0.00 932.94 2,666.39 6,009,372.06 531,968.61 Point 6 0.00 1,104.18 2,610.05 6,009,543.06 531,911.61 Point 7 0.00 1,410.84 2,448.22 6,009,849.05 531,748.59 Point 8 0.00 1,859.69 2,498.97 6,010,298.06 531,797.57 Point 9 0.00 2,376.14 2,913.01 6,010,816.08 532,209.54 Point 10 0.00 2,085.13 3,165.91 6,010,526.09 532,463.55 Point 11 0.00 1,828.97 2,939.89 6,010,269.07 532,238.56 Point 12 0.00 1,612.44 2,815.04 6,010,052.07 532,114.58 Point 13 0.00 1,441.38 2,825.38 6,009,881.07 532,125.59 Point 14 0.00 1,202.78 2,973.47 6,009,643.08 532,274.60 Point 15 0.00 798.56 3,017.91 6,009,239.08 532,320.62 Point 16 0.00 368.35 2,802.22 6,008,808.07 532,106.65 Point 17 0.00 112.52 2,495.19 6,008,551.06 531,800.65 Point 18 0.00 - 233.37 2,197.82 6,008,204.04 531,504.68 Point 19 0.00 - 194.24 1,907.94 6,008,242.02 531,214.67 3K -09BL1 t3 0.00 0.00 6,601.00 1,348.83 2,686.10 6,009,787.98 531,986.69 70° 26' 16.041 N 149° 44' 21.093 W - plan hits target center - Point 3K -09BL1 t6 0.00 0.00 6,637.00 2,077.63 3,007.01 6,010,517.96 532,304.70 70° 26' 23.208 N 149° 44' 11.665 W - plan hits target center - Point 4/5/2010 9 :19 :29AM Page 4 COMPASS 2003.16 Build 69 iy • • ConocoPhillips Fri_ 1 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 Q 69.00ft (3K -09) Site _ Kuparuk 3K Pad North Reference: -- True Well: 3K - 09 Survey Calculation Method: _ Minimum Curvature Weilbore: 3K -09BL1 .. _ Design: '_ - 3K- 09BL1_wp07 Casing Points Measured Vertical Casing Hol Depth Depth - Diameter Diameter ( ft ) ( ft ) N ame ( ") r) - -= 3,172.00 3,100.46 10 3/4" 10 -3/4 13-1/2 10,050.00 6,636.86 2 3/8" 2 -3/8 3 Plan Annotations - - = Measured Vertical Local Coordinates -_-_- - _ Depth Depth +14/4 +E/-W . - _- _ - -,____ -_- (ft) (ft) (ft) (ft) Comment = 8,200.00 6,654.98 486.83 2,592.77 TIP / KOP 3K -09B 8,215.00 6,653.82 498.50 2,602.13 2 8,245.00 6,649.15 521.60 2,620.66 End of DLS 20 8,320.00 6,634.67 575.15 2,671.03 4 8,420.00 6,618.77 648.66 2,736.66 5 8,550.00 6,610.20 761.56 2,799.72 6 8,750.00 6,615.98 956.57 2,836.52 7 8,920.00 6,620.05 1,122.31 2,803.20 8 9,045.00 6,611.17 1,232.25 2,745.16 9 9,170.00 6,600.77 1,342.48 2,687.91 10 9,270.00 6,598.18 1,439.01 2,662.61 11 9,370.00 6,596.91 1,538.70 2,657.85 12 9,540.00 6,611.94 1,703.41 2,693.09 13 9,610.00 6,619.74 1,769.14 2,715.67 14 9,810.00 6,628.37 1,942.80 2,811.50 15 10,050.00 6,636.86 2,077.90 3,006.63 TD 4/5/2010 9.19:29AM Page 5 COMPASS 2003.16 Build 69 A..'" h' Tne North .. Project: Kuparuk River Unit t Math 21.6M WELLBORE DETAILS: 3K -098L1 REFERENCE Site: : 3K-09 Strerglh.57673. Co-ordinate (N E) Reference Mean Sea True North BAKER Magnetic Field Parent Wellbore: 3K - 096 Well: 3K bn Vertical (ND) Reference. Mean Sea Level r oidAB9k6091° Tie on MD: 8200.00 Section S Reference: Slot - (0.000, 0.00E) /^ „ Wellbore: 3K -098L1 N ) 4�}I7 ©CClI IIIIIP S PIan:3K-09BL1 wp07(3K-09/3K-09BL1) '8;e„ Measured Depth Reference 3K -09@69.00f (3K -09) HUGHES Calculation Method Minimum Curvature 2550 I WELL DETAILS' 3K -09 3K- 09/3K -09BLI Ground Level: 0.00 2400 +N1 - •EI - Northing Easting Latittude Longitude Slot `.TD 0.00 0.D0 6008228.65 529305.92 70° 26' 0.812 N 149° 45' 39.960 W 2250 - SECTION DETAILS ANNOTATIONS 15 3 ` _..._ _ 2]00 - - - 3K Sec MD Inc Azi TVDSS +N/-S +E/-W Dleg TFace VSec Target Annotation 14 1 8200.00 92.96 38.73 6654.98 686.95 2593.82 0.00 0.00 1294.04 TIP /KOP3K -09B 1950 • ' 2 8215.00 95.96 38.73 6653.82 698.61 2603.17 20.00 0.00 1307.62 2 13 - 3 8245.00 101.96 38.73 6649.15 721.72 2621.71 20.00 0.00 1334.53 End of DLS 20 1800- 4 8320.00 100.26 47.74 6634.67 775.26 2672.08 12.00 100.00 1398.66 4 g 12 5 8420.00 97.97 35.81 6618.77 848.77 2737.70 12.00 260.00 1485.87 5 ' 6 8550.00 89.57 22.63 6610.20 961.67 2800.76 12.00 238.00 1610.67 6 00 1650 11 7 8750.00 87.17 358.73 6615.98 1156.68 2837.57 12.00 264.00 1808.79 7 8 8920.00 90.12 338.54 6620.05 1322.42 2804.25 12.00 278.00 1961.55 8 ' 1 o 9 9045.00 98.00 325.74 6611.17 1432.37 274620 12.00 302.00 2054.19 9 + 1500 1 • 0 9170.00 91.50 339.31 6600.77 1542.60 2688.96 12.00 115.00 2147.29 10 9 11 9270.00 91.47 351.31 6598.18 1639.12 2663.65 12.00 90.00 2234.82 11 1350 8 12 9370.00 89.98 3.22 6596.91 1738.81 2658.89 12.00 97.00 2330.41 12 - 3" 9540.00 79.95 21.07 6611.94 1903.52 2694.13 12.00 120.00 2498.75 13 '71 200 9610.00 8724 16.88 6619.74 1969.25 2716.72 12.00 330.00 2567.99 14 , 7 ' 1 9810.00 87.89 40.89 6628.37 2142.92 2812.55 12.00 89.00 2759.68 15 i8 10050.00 88.15 69.71 6636.86 2278.01 3007.67 12.00 90.00 2937.97 TD 0 1050 - . V) 6, .. 900- End ofDLS20 750- 2 TIP /KOP3K -09B - - - - M 600_ ' s 450- . 1500 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 T 3150 3300 3450 3600 3750 3900 4050 West(- )/East( +) (150 ft/in) 6400- 6450_ 6500- , . , , . C 6 • 550 End ofDLS 20 TIP /KOP3K•09B 10 11 12 C 5 6 7 8 9 r 13 14 15 3K- 09 /3K -09BL1 6600_ . 4 µ 2 - TD a d 6650 -- - - - - - _ _ - - - -- - - - - - cd rn 6700 -. - U 3K- 00/3K -00B 2 6750_ t l ) E 6800 - 6850- 6900- 6950_ - 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 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 3100 Vertical Section at 14.00° (50 ft/in) • • TRANSMITTAL LETTER CHECKLIST _ WELL NAME f 1l,, � /e/ , s < - ( ---C� „- / `” L PTD# � r (`Development Service Exploratory Stratigraphic Test Non- Conventional Well � � / FIELD: kly-')a--1 Gc k_ . iL.; l'' POOL: 21 -- 1. -(- f� / . C�-- � 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 K'Z cl (If last two digits in Permit No. zie:_'(_) (f ZA ; ' API No. 50- cZ - 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. 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