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209-137
T • • 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. o_q - 137 Well History File Identifier Organizing (done) ❑ Two -sided III IIIIII II III II III ❑ Rescan Needed III IIIIII II II III I I R DIGITAL DATA OVERSIZED (Scannable) Col r Items: ❑Diskettes, No. ❑Maps: Grey Items: ❑Other, No/Type: ❑Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: O .8 /s/ JO in .....=_____,.....,___ Project Proofing III 11111 II 11111 BY: Maria , Date: /c)../3//a /s/ VV Scanning Preparation a x 30 = 6e + = TOTAL PAGES (s (Count does not include cover sheet BY: Maria ) Date: ` ° c3 la ., /s / � Production Scanning I Stage 1 Page Count from Scanned File: l0 6 (Count does include covers t) Page Count Matches Number in Scanning Preparation: YES NO BY: (ia Date: ' 3/ f c /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11111111 III ReScanned 11111111 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked n111111111 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 8/13/2012 Permit to Drill 2091370 Well Name /No. KUPARUK RIV UNIT 2T -29AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20222 -60 -00 MD 12580 TVD 5847 Completion Date 1/20/2010 Completion Status WAGIN Current Status WAGIN UIC, REQUIRED INFORMATION Mud Log No Samples No Directional Sury Y:::), 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 Mfd /Frmt Number Name Scale Media No Start Stop CH Received Comments ED Vb Lis 19507 Induction /Resistivity 10053 12581 Open 4/6/2010 OH LIS MPR Togs Plus 1 CGM, TIFF and PDF graphcis Log/ Induction /Resistivity 2 CoI 10320 12580 Open 4/6/2010 MD MPR, GR Log -- Induction /Resistivity 5 CoI 10320 12580 Open 4/6/2010 MD MPR, GR Log i Induction /Resistivity 5 Col 10320 12580 Open 4/6/2010 TVD MPR, GR ED t Directional Survey 10210 12580 Open Rpt , Directional Survey 10210 12580 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? , N Chips Received? 1 / N Formation Tops ✓ N Analysis S71 Received? Comments: Compliance Reviewed By: Date: \ 3 1 L 1 • 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 REC APR 062 l iht:›ft V ellow i.. c 2-09 --(3(0 / 95b(.' A . U+ - /9503 U�c 2C)g ��Sb �sC (0 —DU i t g 5 3 • Page 1 of 1 Schwartz, Guy L (DOA) From: Eller, J Gary [ J.Gary.Eller @conocophillips.com] Sent: Thursday, March 04, 2010 4:05 PM To: Schwartz, Guy L (DOA) Cc: Gantt, LamarL Zo9- /37 Subject: Incorrect Deployment Rams Installed, Nabors CDR2 -AC, 1/6/2010, KRU 2T -29 Guy — As we discussed over the phone, on January 6, 2010 while drilling the KRU 2T -29AL1 lateral (PTD #209- 137) with the Nabors CDR2 -AC coiled tubing drilling rig we had an incident with our 2.375" deployment rams (i.e. rams used for deploying our drilling assembly under pressure, but do not serve as well control rams during drilling). It was noticed that one of the hydraulic actuators on the deployment rams was leaking, so we made plans to replace it while we were out of the hole. Replacement of the actuator requires opening the ram doors, so we had a detailed procedure, safety discussions, and plan in place for conducting this operation. The well was secured by closing the swab valve on the tree, and post- repair plans included a function -test of the ram and a pressure test (i.e. shell test) of the entire BOP stack including the deployment rams. Once the rig crew opened the deployment ram doors, however, it was noticed that the ram blocks showed significant wear and they made the decision to replace them. The ConocoPhillips Rig Supervisor was not notified of the change in plan, and neither Nabors Alaska nor ConocoPhillips Alaska management -of- change practices were properly employed in making this revision. Unfortunately, by not following management -of- change practices, the crew inadvertently installed 2" ram blocks instead of 2.375" blocks and they did not recognize that a function pressure -test should now be performed. When the rams were closed on the BHA during deployment, the rams did not hold pressure and the error was discovered. After installing the proper size rams, a full function pressure -test was conducted and passed. You asked me what has been done to ensure that there will not be a repeat of this incident in the future. The major errors were the failure to follow management -of- change procedures and failure to notify the ConocoPhillips Rig Supervisor of their findings when they opened the ram doors. Both of these issues have been addressed with the rig crews during subsequent safety meetings and pre job meetings. In addition, Nabors has verified that their procedure /checklist for replacing BOP components includes a step for proper testing of that component prior to putting it in service. The Nabors rig crews use these checklists for virtually every operation they perform, so this is perhaps the single most effective change that will prevent recurrence. Nabors has also said they will post a placard in the parts storeroom reminding crew members that a function pressure -test must be performed if they change out the BOP rubbers. Please contact me if you would like to discuss this further. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907 - 263 -4172 cell: 907 - 529 -1979 fax: 907-265-1535 3/4/2010 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT A LOU' o la. Well Status: Oil El Gas ❑ SPLUG El Plugged ❑ Abandoned ❑ Suspended ❑ AlaaII ai& Sas Gans. Common 20AAC 25.105 20AAC 25.110 Development ®Cherag#xploratory ❑ GINJ ❑ WINJ ❑ WAG El WDSPL ❑ Other ❑ No. of Completions: Service El Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: January 20, 2010 209 - 137 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 January 7, 2010 50 103 - 20222 - 60 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 522' FSL, 556' FWL, Sec. 1, T11N, R8E, UM January 11, 2010 2T - 29AL1 Top of Productive Horizon: 8. KB (ft above MSL): 122' RKB 15. Field /Pool(s): 2533' FSL, 1725' FWL, Sec. 35, T12N, R8E, UM GL (ft above MSL): 81' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1765' FNL, 2205' FWL, Sec. 35, T12N, R8E, UM 12580' MD / 5847' TVD Kupuruk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498945 y 5970503 Zone 4 12580' MD / 5847' TVD ADL 25569, 25548 TPI: x - 494831 y - 5977794 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 495310 y - 5978776 Zone 4 nipple @ 518' MD / 518' TVD 2667, 2662 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) 1525' MD / 1502' 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 10320' MD / 5869' 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 41' 121' 41' 121' 24" 210 sx AS I 9.625" 40# L -80 41' 4159' 41' 2878' 12.25" 790 sx AS III, 700 sx Class G 7" 26# L -80 41' 10557' 41' 6072' 8.5" 200 sx Class G 2 -3/8" 4.7# L -80 11265' 12580' 5892' 5847' 3" liner 24. Open to production or injection? Yes IN 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" 10121' 10093' MD / 5727' TVD alternating solid /slotted liner: slots from 11274'- 11569' MD 5893' -5888' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook - up Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No • Sidewall Cores Acquired? Yes ❑ No Ei If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. COMPLETION E240 NONE Form 10-407 Revised 7/2009 RBDMS FEB 1 8 �CONTINUED ON REVERSE Submit original only i rd--- Z ' e 4 . (0 28. GEOLOGIC MARKERS (List all formations and markeencountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q 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 1525' 1502' needed, and submit detailed test information per 20 AAC 25.071. A3 11485' 5893' N/A Formation at total depth: Kuparuk A3 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J. G. Eller @ 263 - 4172 Printed ame Von Cawvev @ 65 - 6306 Title: CT Drilling Manager � '_ /� Signature Phone 265 - 6306 Date l � / Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 7/2009 • vp-' .tt . KUP 1 2T -29AL1 ConocoPhiT ps ,' F Well Attributes 'Max Angle & MD TD ;:Uasha Inc WellboreAPYUWI Feld Name Well Status Inc/ ( °) MD (ftKB) Act Btm (ftKB) t,,,,,, . pkP, = - 501032022260 [Field RIVE U UNIT ,INJ Comment H2S (ppinl Date Annotation End Date KB -Grd (ft) Rig Release Date _Weft C4a3, ^11 1, 2 : 03,Y; _ nM _ SSSV. NIPPLE Last WO: I 6/9/1995 Io Annotation 11 (Dep (ftK th B) !End Date [Annotation Last Mod ... End Date Last Tai: [Annotation Reason WELL SIDETRACKED 1 Imosbor 1/23/2010 Casing Strings Casing Description rin String 0... Str y IIJ .Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... Str g ... String Top Thrd LINER AL1 ! 2 318 1 'lr 11.265 . 2 ! 12 580 0 4 L 80 i STL Liner Details HANGER, 37- Top rin th {I't (ND) Top Inc/ Nomi... ID (in) Top(ttKB) (ftKB) ( °) Item Des,viption Comment 11,265.2 BILLET Aluminum Liner Billet 1.995 TNbingStrings _ Tubing Description String 0. String ID Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String String Top Thrd TUBING AL1 312 ! 36.8 l 10,121.0 1 I 930 L80 1 .. _ ABM -EUE Completion Details CONDUCTOR. — Top 39 -121 ( Top Inc/ Nomi... To. ft B ( KB) r) Item Description Comment ID(in) 36.8 HANGEP. FMC GEN IV TUBING HANGER 3.500 518.0 NIPPLE CAMCO 'DS' LANDING NIPPLE w/2.856" NO GO 2.812 NIPPLE, 518 ' ";: 10,085.0 NIPPLE CAMCO W -1 SELECTIVE LANDING NIPPLE 2.812 r. 10,093.0 PAC f-. BAKER SAB -3 PACKER W /K -22 ANCHOR SEAL ASSEMBLY 3.500 "` 10,108.9 NIPPI CAMCO 'D'LANDING NIPPLE - milled out to 2.50" 2.800 10,120.1 - -�— 'SOS BAKER SHEAR OUT SUB -_ - -- 2.992 Perforations & Slots ____ ■ I .... Shot Top (TVD) Btm frA'D) Dens 1( 1(tKB) ftK87 z one Date ( Type Comment Top (ftKB] Btm (ftKB) ( ) ( ......... ., o ._. — ..__ PAlluveach, 1/1/2010 32.0 SLOTS Alternating solid/slotted pipe - 2T -29AL1 0.125"x2.5" @4 circumferential SURFACE, adjacent rows, 3" centers staggered 414,159 18 deg, 3' non - slotted ends Notes: General & Safety End Date Annotation GAS LIFT, 1/21/2010 NOTE: WELLS SIDE I I"CKED 2T - 29A, AL1, AL1 - 01, AL1 - 02 (off main wellbore) 16040 T.: II NIPPLE, 10,085 - - - - -- 1 �._.. r PACKER,_ 10,093 .v APERF, 10,101. 10,103 NIPPLE, 10,109 je SOS, 10,120 —. 502, 10,208 - 10,224 SOZ, 10,208- 10,224 SOZ, 10,246-10,259 so2, 10,246 - 10,259 SO2. 10265 - 10,278 002, 10,265-10,278 CEMENT SO2, Mandrel Details 10,109 Top Depth Top Port PRODUCTION, (TVD) Inc! OD Valve Latch Si.. TRO Run TD 2T 29AL10 Stn Top.,(RKB) (WKB) (°) Make Model On) Sam TYP• TyP• (in) (Psi) Run Date Com... 10,570 1 10,039.9 CAMCO MMM 1 12 GAS LIFT DMY TG 0.000 0. 0 9/17/1995 1 10,039.9 CAMCO 1 MMM 1 12 GAS LIFT DMY TG 0.600 0.0 9/17/1995 1 10,039.9 CAMCO MMM 1 12 GAS LIFT DMY TG 0.000 0.0 9/17/1995 sLOrs, — - 1 f 1 10,039.9 CAMCO MMM 1 12 GAS LIFT DMY TG 6.606 0.0 9/17/1995 11,274 11,569 — ( f . — w,.. 1 10,039.9 CAMCO MMM 1 12 GAS LIFT DMY TG 0.000 0.0 9/17/1995 , iiii LINER AL1, I . 11,285 - 12,580 ■ 2T -29 CTD Sidetrack - Actual Last Update: 1/22/2010 3 -1/2" Camco DS nipple @ 518' MD 3 -1/2" 9.3# L -80 ABM -EUE 8rd Tubing to surface 16" 62# H -40 shoe @ 121' MD 9 -5/8" 40# L -80 _ shoe @ 4159' MD 3 -1/2" Camco MMM gas lift mandrel @ 10,040 3 -1/2" Camco W -1 selective landing nipple @ 10,085' MD (2.812" min ID) Baker SAB -3 permanent packer @ 10093' MD (3.25" ID) '■■■■■ "` BELOW 2 -3/8" LINER TOP AT 10,109' MD*** 2 -3/8" 4.7# STL liner top @ = 3 -1/2" Camco D landing nipple @ 10,109' MD 10,109' and (10,086' ELM) � (Milled out to 2.80" ID) • 3 -1/2" tubing tail @ 10,121' MD • KOP @ 10,208' MD with 2.80" window anchor -WS at 10,208' _ - 2.80" cement pilot hole • li Aluminum billlets @ 11,097' & • to 10,238' MD • 11,265' and \'.;.` 2T- 29AL1, TD © 12,580' and �� Liner 11,265' - 12,580' MD 2T -29A, TD @ 12,996' and A3 sand perfs (sgz'd) ---..d .' _� - ---------------------------------- Liner 10,319' - 12,996' 10208' - 10224' MD 2T- 29AL1 -01 PB -1 11,323' - 11,716' md • _________ - _ _ ___ _ 2T-29AL1-01, TD @ 11,784' md A2 sand perfs (sgz'd) \��� `--------- '- - - - - -- Liner 11,097' - 11,765' 10246' - 10259' MD _ //}? " SS 7 L _ _ _ 10265' - 10278' MD .,r+,r+,,',r' �,.,, '.2; 1 ---- -- --- -- - ----- -------- - -- - -- I � 4'?'','+' Aluminum billlet @ 7" 26# L-80 shoe @ s _10,319' and 2T 29AL1 -02, TD @ 12,580' and Proposed Liner 10,109' - 12,580' 10,557' MD ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. 410 Kuparuk River Unit Kuparuk 2T Pad 2T -29AL1 501032022260 Baker Hughes INTEQ 1 U Definitive Survey Report BAKER S eport HUGHES 22 January, 2010 „°0- ConocoPhillips a CC?C1�1C4�11�5 Definitive Survey Report HUMES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 2T - 29 Project: Kuparuk River Unit TVD Reference: 2T -29 update @ 122.00ft (2T -29) Site: Kuparuk 2T Pad MD Reference: 2T -29 update @ 122.00ft (2T -29) Well: 2T - 29 North Reference: TRUE Wellbore: 2T - 29 Survey Calculation Method: Minimum Curvature Design: 2T -29 Database: EDM Alaska Prod v16 Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2T -29 Well Position +N / - 0.00 ft Northing: 5,970,502.58ft Latitude: 70° 19' 50.311 N +E / - 0.00 ft Easting: 498,944.66ft Longitude: 150° 0' 30.815 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 80.70 ft Welibore 2T - 29AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ( (nT) BGGM2009 1/4/2010 17.20 79.76 57,350 Design 2T - 29AL1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,300.35 Vertical Section: Depth From (TVD) +N / -S +El -W Direction (ft) (ft) (ft) ( °) 41.30 0.00 0.00 336.28 Survey Program Date From To Survey Survey (ft) (ft) Survey (Welibore} Tool Name Description Start Date End Date 50.00 10,199.00 2T -29 Gyro (2T -29) GYD -CT -CMS Gyrodata cont.casing m/s 4/9/2009 4/9/2009 10,210.00 10,300.35 2T -29A (2T -29A) MWD MWD - Standard 12/27/2009 1/2/2010 10,320.00 12,547.17 2T -29AL1 (2T- 29AL1) MWD MWD - Standard 1/7/2010 1/11/2010 1/22/2010 3:53:57PM Page 2 COMPASS 2003.16 Build 69 b. r ConocoPhillips mite C�i14?C6 e" 11 >llll }5 Definitive Survey Report HUM ES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 2T - 29 Project: Kuparuk River Unit TVD Reference: 2T -29 update @ 122.00ft (2T -29) Site: Kuparuk 2T Pad MD Reference: 2T -29 update @ 122.00ft (2T -29) Well: 2T - 29 North Reference: TRUE Wellbore: 2T - 29 Survey Calculation Method: Minimum Curvature Design: 2T - 29 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nt -S +El-W Northing Easting DLS Section Survey Tool Name Annotation (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) 10,300.35 77.75 316.07 5,865.85 5,743.85 6,207.48 - 4,446.52 5,976,710,07 494,499.45 45.95 7,471.87 MWD (2) TIP 2T - 29A 10,320.00 84.88 313.26 5,868.82 5,746.82 6,221.12 - 4,460.33 5,976,723.71 494,485.65 38.92 7,489.91 MWD (3) KOP . 10,350.36 85.11 326,78 5,871.48 5,749,48 6,244,25 - 4,479.72 5,976,746.83 494,466.27 44.36 7,518.88 MWD (3) 10,380.34 86,81 335.31 5,873.59 5,751.59 6,270.39 - 4,494.18 5,976,772.97 494,451.81 28.94 7,548.63 MWD (3) 10,410.38 88.96 345.13 5,874,71 5,752.71 6,298.60 - 4,504.32 5,976,801.19 494,441.67 33.44 7,578.54 MWD (3) 10,440.34 91.69 355.22 5,874.54 5,752.54 6,328.08 - 4,509.43 5,976,830,66 494,436.57 34.89 7,607.58 MWD (3) 10,470.40 92.27 5.89 5,873.49 5,751.49 6,358.08 - 4,509.14 5,976,860.66 494,436.87 35.53 7,634.93 MWD (3) 10,500.01 92.52 14.68 5,872.25 5,750.25 6,387.16 - 4,503.86 5,976,889.73 494,442.15 29.67 7,659.43 MWD (3) 10,530.47 92.83 22.31 5,870.83 5,748.83 6,415.99 - 4,494.22 5,976,918.56 494,451.79 25.04 7,681.95 MWD (3) 10,560.39 92.30 22.55 5,869.49 5.74749 6,443.62 - 4,482,81 5,976,946.19 494,463.20 1.94 7,702.65 MWD (3) 10,590.56 92.30 22.12 5,868.28 5,746.28 6,471.50 - 4,471.36 5,976,974.07 494,474.66 1.42 7,723.57 MWD (3) 10,620.48 92,33 21.52 5,867.07 5,745.07 6,499.26 - 4,460.24 5,977,001.82 494,485.78 2.01 7,744.51 MWD (3) 10,650.36 91.35 21.68 5,866,11 5,744.11 6,527.03 - 4,449.25 5,977,029.58 494,496.77 3.32 7,765.51 MWD (3) 10,680.46 90.86 20.97 5,865.53 5,743.53 6,555.06 - 4,438.31 5,977,057.61 494,507.72 2.87 7,786.77 MWD (3) 10,710.40 89.48 21.27 5,865.44 5,743.44 6,582.99 - 4,427.52 5,977,085.53 494,518.51 4.72 7,808.00 MWD (3) 10,742.21 88.65 21.24 5,865.96 5,743.96 6,612.63 - 4,415.99 5,977,115.17 494,530.04 2.61 7,830.50 MWD (3) 10,770.23 88,77 21.46 5,866.59 5,744.59 6,638.72 - 4,405.79 5,977,141.26 494,540.24 0.89 7,850.28 MWD(3) 10,800.17 86.87 22.03 5,867.73 5,745.73 6,666.51 - 4,394.71 5,977,169.04 494,551.33 6.63 7,871.26 MWD (3) " 10,830.08 85.45 22.43 5,869.74 5,747.74 6,694.13 - 4,383.42 5,977,196.66 494,562.62 4.93 7,892.01 MWD (3) 10,860.33 86.96 21.82 5,871.74 5,749.74 6,722.09 - 4,372.05 5,977,224.61 494,573.99 5.38 7,913.03 MWD (3) 10,890.34 87.23 22.02 5,873.26 5,751.26 6,749,90 - 4,360.86 5,977,252,41 494,585.18 1.12 7,933.98 MWD (3) 10,920.30 87.36 21.77 5,874.67 5,752.67 6,777.66 - 4,349.70 5,977,280.18 494,596.35 0.94 7,954.92 MWD (3) . 10,950.16 87.30 21.90 5,876.06 5,754.06 6,805.35 - 4,338.61 5,977,307.86 494,607.44 0.48 7,975.80 MWD(3) 10,990.28 87.39 23.22 5,877.92 5,755,92 6,842.36 - 4,323,23 5,977,344.87 494,622.82 3,29 8,003.50 MWD (3) 11,020.34 86.37 24.71 5,879.56 5,757.56 6,869.79 - 4,311.04 5,977,372.29 494,635.02 6.00 8,023.70 MWD (3) 11,050.34 86.74 24.71 5,881.36 5,759.36 6,896.99 - 4,298.52 5,977,399.49 494,647.54 1.23 8,043.57 MWD (3) 11,080.25 86.93 24.70 5,883.01 5,761.01 6,924.12 - 4,286.04 5,977,426.61 494,660.02 0.64 8,063.39 MWD (3) 11,110.27 87.08 24.74 5,884.58 5,762.58 6,951.35 - 4,273.50 5,977,453.84 494,672.56 0.52 8,083.27 MWD (3) 11,140.08 87.11 24,46 5,886.09 5,764.09 6,978.42 - 4,261.11 5,977,480.91 494,684.96 0.94 8,103.07 MWD (3) 11,170.35 86.77 24.59 5,887 71 5,765,71 7,005.92 -4,248.56 MWD (3) 5,977,508.40 494,697.51 1.20 8,123.20 . 1/22/2010 3:53:57PM Page 3 COMPASS 2003.16 Build 69 Iv ConocoPhitlips NM CC; t" oCC?6' 11 et lE s Definitive Survey Report BAKER RUCHES Ataska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 2T - 29 Project: Kuparuk River Unit TVD Reference: 2T -29 update @ 122.00ft (2T -29) Site: Kuparuk 2T Pad MD Reference: 2T -29 update @ 122.00ft (2T -29) Well: 2T - 29 North Reference: TRUE Weltbore: 2T - 29 Survey Calculation Method: Minimum Curvature Design: 2T - 29 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N / °S +E! °W Northing Easting DLS Section Survey Tool Name Annotation (ft) (°) ( °) (ft) (ft) (ft) ( (ft) (ft) ( °/100') (ft) 11,200.20 86.71 25.25 5,889.40 5,767.40 7,032.95 - 4,236.01 5,977,535.42 494,710.06 2.22 8,142.89 MWD (3) 11,230.18 87.08 25.11 5,891,03 5,769.03 7,060.04 - 4,223.27 5,977,562.51 494,722,80 1.32 8,162.57 MWD (3) • 11,260.19 87.05 25.30 5,892.57 5,770.57 7,087.16 - 4,210.51 5,977,589.62 494,735.57 0.64 8,182.26 MWD (3) 11,290.31 87.91 25.32 5,893.89 5,771.89 7,114.36 - 4,197.64 5,977,616.82 494,748.44 2.86 8,201.99 MWD (3) 11,320.23 89.26 25.10 5,894,63 5,772.63 7,141.42 - 4,184.90 5,977,643.88 494,761.18 4.57 8,221.64 MWD (3) 11,350.32 89.29 24.95 5,895,01 5,773.01 7,168.69 - 4,172.18 5,977,671.14 494,773.91 0.51 8,241.47 MWD (3) 11,380.08 89.26 25.18 5,895.39 5,773.39 7,195.64 - 4,159.57 5,977,698.09 494,786.52 0.78 8,261.08 MWD (3) 11,410,33 89.29 25.06 5,895.77 5,773.77 7,223.03 - 4,146.73 5,977,725.47 494,799.36 0.41 8,280,99 MWD (3) 11,440.19 90.34 25.31 5,895.86 5,773.86 7,250.05 - 4,134.02 5,977,752.49 494,812.07 3.61 8,300.61 MWD (3) 11,470.01 93.66 25.29 5,894,82 5,772.82 7,276.99 - 4,121.29 5,977,779,42 494,824,81 11.13 8,320.15 MWD (3) 11,500.29 93.93 25.56 5,892.82 5,770.82 7,304.28 - 4,108.32 5,977,806.70 494,837,78 1.26 8,339.92 MWD (3) 11,530.36 94.09 26.11 5,890.72 5,768.72 7,331.27 - 4,095.25 5,977,833.70 494,850.86 1.90 8,359.37 MWD (3) 11,560.18 94.03 26.30 5,888.61 5,766.61 7,357,96 - 4,082.11 5,977,860.38 494,863.99 0.67 8,378.52 MWD (3) 11,590.18 95.81 26.22 5,886.03 5,764.03 7,384.77 - 4,068.89 5,977,887.18 494,877.22 5.94 8,397.74 MWD (3) 11,620.43 96.21 26.50 5,882.87 5,760.87 7,411,72 - 4,055.53 5,977,914.13 494,890.58 1.61 8,417.04 MWD (3) 11,650.04 96.46 26.85 5,879.60 5,757.60 7,438.02 - 4,042.32 5,977,940.42 494,903.79 1.45 8,435.80 MWD (3) 11,680.47 94.86 26.61 5,876.60 5,754.60 7,465,06 - 4,028.70 5,977,967.46 494,917.42 5.32 8,455.08 MWD (3) 11,710.45 93,17 26.63 5,874.50 5,752.50 7,491.80 - 4,015.30 5,977,994.19 494,930.82 5.64 8,474.17 MWD (3) 11,740.42 93.16 26.76 5,872.84 5,750.84 7,518.53 - 4,001.85 5,978,020.92 494,944.26 0.43 8,493.24 MWD (3) 11,771.95 92.21 26.51 5,871.37 5,749.37 7,546.69 - 3,987.74 5.978,049.07 494,958.38 3.12 8,513.33 MWD(3) 11,800.44 92.15 26.68 5,870,28 5,748.28 7,572.14 - 3,974.99 5,978,074.52 494,971.13 0.63 8,531.51 MWD (3) 11,830.35 90,86 27.16 5,869.50 5,747.50 7,598.80 - 3,961.45 5,978,101.18 494,984.67 4.60 8,550.47 MWD (3) 11,860.45 90.15 27.84 5,869.23 5,747.23 7,625.50 - 3,947.56 5,978,127.87 494,998.57 3.27 8,569.32 MWD (3) 11,890.18 90.43 28.53 5,869.08 5,747.08 7,651.70 - 3,933.51 5,978,154.07 495,012.62 2.50 8,587.66 MWD (3) 11,920.39 90.03 28.70 5,868.96 5,746.96 7,678.22 - 3,919.05 5,978,180.59 495,027.09 1.44 8,606.12 MWD(3) 11,950.29 89.57 29.21 5,869.06 5,747,06 7,704.39 - 3,904.57 5,978,206.74 495,041.56 2.30 8,624.24 MWD (3) 11,980.33 89.88 29.53 5,869.21 5,747.21 7,730.56 - 3,889.84 5,978,232.92 495,056.30 1.48 8,642.28 MWD(3) 12,010,61 89.85 28,89 5,869.28 5,747.28 7,756.99 - 3,875.06 5,978,259.34 495,071.08 2.12 8,660.53 MWD (3) 12,040.44 89.94 27.68 5,869.34 5,747.34 7,783.26 - 3,860.93 5,978,285.61 495,085.21 4.07 8,678.90 MWD (3) 12,070.61 90.55 26.57 5,869.21 5,747.21 7,810.11 - 3,847.17 5,978,312.45 495,098.97 4.20 8,697.94 MWD (3) 12,100.25 90.52 25.42 5,868.93 5,746.93 7,836.75 - 3,834.18 5,978,339.09 495,111.97 3.88 8,717,11 MWD (3) , 1/22/2010 3:53:57PM Page 4 COMPASS 2003.16 Build 69 i ■ ♦-- ConocoPhillips rig 1, COMCOPhillipS Definitive Survey Report CHs Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 2T - 29 Project: Kuparuk River Unit TVD Reference: 2T -29 update @ 122.00ft (2T -29) Site: Kuparuk 2T Pad MD Reference: 2T -29 update @ 122.00ft (2T -29) Well: 2T - 29 North Reference: TRUE Weilbore: 2T - 29 Survey Calculation Method: Minimum Curvature Design: 2T - 29 Database: EDM Alaska Prod v16 Survey Map Map Vertical . MD inc Azi TVD TVDSS +Nt -S +Et ° Northing Easting DLS Section Survey Tool Name Annotation (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) 12,130.31 90.52 24.47 5,868.66 5,746.66 7,864.01 - 3,821.50 5,978,366.34 495,124.64 3.16 8,736.96 MWD (3) 12,160.43 90.83 23.76 5,868.30 5,746.30 7,891.50 - 3,809.20 5,978,393.82 495,136.95 2.57 8,757.17 MWD (3) 12,190.44 91.53 23.59 5,867.68 5,745.68 7,918.97 - 3,797.15 5,978,421.30 495,149.00 2.40 8,777.48 MWD (3) 12,220.30 91.44 23.02 5,866.91 5,744.91 7,946.39 - 3,785.34 5,978,448.71 495,160.82 1.93 8,797.83 MWD (3) 12,250.42 93.41 23,83 5,865.64 5,743.64 7,974.00 - 3,773.38 5,978,476.31 495,172,78 7.07 8,818.29 MWD (3) 12,280.25 93.87 23.84 5,863.74 5,741.74 8,001.23 - 3,761.35 5,978,503.54 495,184.81 1.54 8,838.38 MWD (3) 12,313.63 93.38 23.69 5,861.63 5,739.63 8,031.72 - 3,747.92 5,978,534.02 495,198.24 1.53 8,860.90 MWD (3) 12,340.93 93.75 24.09 5,859.93 5,737.93 8,056.63 - 3,736.89 5,978,558.93 495,209.28 1.99 8,879.26 MWD (3) 12.370 27 92 95 24 91 5,858.22 5,736 22 8.083 28 - 3,724.74 5,978,585 58 495,221.43 3 90 8,898.78 MWD (3) 12,400,38 92.15 25.39 5,856.88 5,734.88 8,110.51 - 3,711.96 5,978,612.80 495,234.21 3.10 8,918.56 MWD (3) 12,430.59 91.26 25.78 5,855.98 5,733.98 8,137.75 - 3,698,92 5,978,640.03 495,247.26 3.22 8,938.25 MWD (3) 12,460.42 90.49 25.60 5,855.53 5,733.53 8,164.63 - 3,685.99 5,978,666.91 495,260.19 2.65 8,957.65 MWD (3) 12,490.20 91.78 25.39 5,854.94 5,732.94 8,191.50 - 3,673.17 5,978,693.78 495,273.01 4.39 8,977,10 MWD (3) 12,520.32 94.24 24.79 5,853.35 5,731.35 8,218.74 - 3,660.42 5,978,721.01 495,285.76 8.41 8,996.91 MWD (3) 12,547.17 96,09 24.92 5,850.94 5,728.94 8,243.00 - 3,649.18 5,978,745.27 495,297.00 6.91 9,014.60 MWD (3) 12,580.00 96.09 24.92 5,847.45 5,725.45 8,272.61 - 3,635.43 5,978,774.87 495,310.76 0,00 9,036,17 PROJECTED to TD 0 1 1/22/2010 3:53:57PM Page 5 COMPASS 2003.16 Build 69 • 2T -29 Pre -Rig Summary DATE SUMMARY 9/4/09 PICK UP AND RIH TO PERFORATE THE 9.5' TUBING JOINT BELOW THE B KER PACKER WITH 2" MILLENIUM, DP, 6 SPF, 60 DEG PERF GUN FOR FOLLOWING SQUEEZE JOB. PERFORATIONS SHOT FROM 10079 - 10081' 9/30/09 PERFORMED SBHPS @ 10,243' RKB =3819 psi, 127 deg F. STOPS @ 10,113' =3774 psi, 8510', 6369', 4038' RKB. COMPLETE. 10/4/09 RIH W/ 2.80" DIAMOND STEP MILL. MILL OUT D NIPPLE © 10109' RKB. DRIFTED NIPPLE SEVERAL TIMES UNTIL NO MOTOR WORK WAS NOTICED. DRIFT NIPPLE DRY WITH NO PROBLEM. INSPECTION OF MILL SHOWED HEAVY WEAR DOWN TO DRIFT OF 2.77 ". WILL RUN A NEW MILL IN THE A.M. IN PROGRESS. 10/5/09 RIH W/ 2.80" MILL. DRIFT THROUGH D NIPPLE W/ NO PROBLEMS BOTH DRY & W/ MOTOR RUNNING. NO MOTOR WORK. WELL READY FOR CEMENT JOB. IN PROGRESS. 10/8/09 PUMP CEMENT SQUEEZE ESTIMATED TOC @ 10109' RKB. STAGED UP SQUEEZE PRESSURE TO 2600 PSI SURFACE PRESSURE. WATCHED FOR 60 MINUTES, LOOKED GOOD. WASHED TBG FROM 10109' RKB TO SURFACE WITH BIO ZAN & SEAWATER WHILE MAINTAINING 1:1 AT 1700 PSI WHP. TBG FREEZE PROTECTED FROM 3000' TO SURFACE. ALLOW CEMENT TO SET -UP FOR AT LEAST 72 HOURS PRIOR TO SLICKLINE TAG. (NOTE: ESTIMATE 1 BARREL SQUEEZED A WAY) 10/13/09 TAGGED CEMENT TOP © 10077' SLM. TESTED PLUG TO 1500 PSI, GOOD. TESTED TO ZERO, GOOD. COMPLETE. 12/1/09 PRE -RIG, T -POT ( PASSED ), T -PPPOT ( PASSED ), IC -POT ( PASSED ), IC -PPPOT PASSED ), MIT -OA ( PASSED ), DDT -MV ( INCONCLUSIVE DUE TO LOW T PRESSURE ), PT- MV ( PASSED) PT & DDT SSV ( PASSED ), SV ( PASSED ), PT -WV ( PASSED ), BLED T TO 0 PSI. Conoco Phillips Time Log & Summary Wellwew Web Reporting Report Well Name: 2T -29 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 12/23/2009 10:00:00 PM Rig Release: 1/21/2010 11:00:00 AM Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T ° Comment 12/23/2009 24 hr Summary Completed 1B-17, Move to 2T -29. MIRU, Start BOP testing. 00:00 15:00 15.00 0 0 MIRU MOVE MOB P Move to 2T -29. Grease injector & reel. Check all drive motors & oil levels. Replace Valves R -6, C -3 & C -8. Replace & repair packing and liner in Pump #2. 15:00 20:00 5.00 0 0 MIRU MOVE MOB P Spot drilling Sub on 2T -29 and spot Fluid sub, Rig Up Putz, line up steam 20:00 22:00 2.00 0 0 MIRU WHDBO NUND P Accept Rig @ 20:00 Nipple up BOPE 22:00 00:00 2.00 0 MIRU WHDBO BOPE P Start BOPE Test 12/24/2009 BOP test witness waived by Bob Noble. Completed BOP test and slack management. Cut 30 ft of CT to find cable. M/U pilot hole BHA. 00:00 06:00 6.00 0 0 MIRU WHDBO BOPE P BOPE Test continued. having problems gettig T2 to test. Valve grease crew on location. 06:00 08:00 2.00 0 0 MIRU WHDBO BOPE P Crew change and take over on BOPE procedure step #11. Completed BOP testing. 250 low / 4000 psi High. 08:00 10:30 2.50 0 0 SURPRI WELLPF SLPC P Clean up rig floor, set up pumps to pump down CT string. Fill CT string with Sea water. Pad operator pumped open SSV & panel. 10:30 12:00 1.50 0 0 SURPRI WELLPF SLPC P Install E -line boot and continue working on rig floor & injector. 12:00 14:00 2.00 0 0 SURPRI WELLPF SLPC P Pump slack back through CT string. Pop off and start cutting CT string. Cut 30 ft to cable. 14:00 16:30 2.50 0 0 SURPRI WELLPF SLPC P Start dressing CT connector and pressure test PDL to 2500 psi. with water. Pressure test tiger tank line then purge with Methanol & air. 16:30 18:30 2.00 0 0 SURPRI WELLPF SLPC P Change pack -off & set up to pressure test CT connector and inner valve 18:30 20:15 1.75 0 0 PROD1 WHPST PULD P P/U BHA #1 with 0.9 degree Motor and new 2.80 D331 pilot mill 20:15 22:00 1.75 0 9,950 PROD1 WHPST TRIP P RIH Pumping 1 BPM Seawater with EDC Open 22:00 22:30 0.50 9,950 10,011 PROD1 WHPST DLOG P 9950 Start tie in pass, Correct to +11, resetting to 11022'. PUW 34K, PUH to shut EDC, RIH to Tag Top of Cement Page 1 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 10,011 10,093 PROD1 WHPST MILL P 10078 TOC. Weight on bit with 200 -230 PSI motor work, ROP 20 FPH with 1200 LBS WOB 12/25/2009 Complete Pilot hole, Run Dummy whipstock, Run whipstock, TOWS @ 10208 00:00 00:45 0.75 10,093 10,109 PROD1 WHPST MILL P 10093' Milling Cement 1.4 BPM @ 2900 FS 24 FPH ROP 2.8K DH WOB 00:45 04:00 3.25 10,109 10,165 PROD1 WHPST MILL P 10109, Spike in pressure and WOB increase indicates D nipple 1.4 BPM @ 2900 FS ROP has dropped below 20 FPH 04:00 08:00 4.00 10,165 10,238 PROD1 WHPST MILL P 10165', ROP 17 FPM. Saw no clear indication of contacting casing sidewall. Tubing tail @ 10121'. Continue drilling down in good cement the whole way down. Oriented 20 deg right for pilot hole. Pumping 1.42 bpm 1.28 returns, 2900 psi, CT weight 11k, WOB 2.5, ROP 17 fph. BHP 3300, WHP 0. - IA 820, OA 580. No metal cuttings in returns 08:00 09:30 1.50 10,238 10,238 PROD1 WHPST REAM P Back ream through drilled area from 10,238 to 10,070' @ 5 fpm. No motor work. Dry run drift - smooth. P/U and tie in @ 9950' +2 ft correction. Open EDC - perform static test. BHP 2700 psi. No -flo from well. 09:30 12:30 3.00 10,238 0 PROD1 WHPST TRIP P POOH, pumping 1 bpm /EDC to P/U Dummy WS BHA. Crew change. 12:30 14:00 1.50 71 71 PROD1 RPEQPI PULD P P/U BHA# 2, Dummy WS run. D331 Mill came out a 2.79" No -go. 14:00 16:00 2.00 71 10,240 PROD1 RPEQP1TRIP P RIH with EDC closed pumping through BHA. Begin tie in @ 9970' + 12 ft correction. RIH slowly - no weight bobbles, looks clean. slow pump speed before bottom. tag lightly @ 10240' P/U weight off bottom 28K, POOH slowly until 9970' Everything is clean. 16:00 18:45 2.75 10,240 0 PROD1 RPEQP1TRIP P POOH pumping 1 bpm for BHA # 3. 18:45 19:15 0.50 0 0 PROD1 RPEQPI PULD P PJSM @ Surface, No -Flo Test, Lay down Dummy Whipstock, P/U whipstock 19:15 20:15 1.00 0 0 PROD1 RPEQPI PULD P BHA #3 M/U Whipstock with no 4 -deg kick, M/U to Coil track, Surface test tool, Open EDC 20:15 22:45 2.50 0 10,100 PROD1 RPEQP1TRIP P RIH with Whipstock 22:45 23:00 0.25 10,100 10,182 PROD1 RPEQPI DLOG P Tie in with whipstock, +13' correction, Shut EDC, RIH to set depth of 10217.7 PUW 26K 23:00 23:15 0.25 10,182 10,218 PROD1 RPEQP1TRIP P Trip in to set depth Page2of29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 23:30 0.25 10,218 10,218 PROD1 RPEQP1WPST P 10217.69 Set depth, Oriented to high side, Pumps on, good indication of tool setting @ 3800 PSI. Reduce pump rate and set down 4.5K DH WOB. Good set, trip out of well TOWS 10208'. 23:30 00:00 0.50 10,218 9,000 PROD1 RPEQP1TRIP P Trip out of well after setting whip stock 12/26/2009 Complete Milling window - No stalls, Swapped well to 9.3 PPG flo pro. TOW = 10210, BOW= 10,216.5' - 00:00 00:45 0.75 9,000 0 PROD1 RPEQPITRIP P Continue out of well after setting whipstock 00:45 01:30 0.75 0 0 PROD1 RPEQP1PULD P PJSM, Monitor well for flow. Lay down BHA #3 Whipstock setting. 01:30 02:00 0.50 0 0 PROD1 WHPST PULD P P/U BHA #4, Window milling BHA Surface test tool, open EDC 02:00 03:45 1.75 0 10,120 PROD1 WHPST TRIP P RU-I, BHA #4 2.80 Window mill, String mill, 0.6 degree motor 03:45 04:00 0.25 10,120 10,159 PROD1 WHPST DLOG P 10120', Start gamma tie in log Correct +12 ' Shut EDC, trip in to dry tag PUW =34K 04:00 04:15 0.25 10,159 10,210 PROD1 WHPST TRIP P Dry Tag @ 10210 PUH Pumps on 1.5 BPM @3350 PSI FS Feather back in to start milling 04:15 06:15 2.00 10,210 10,212 PROD1 WHPST MILL P 10210', Motor work with WOB. TOW= 10210.3 Start time milling window, No Stalls 06:15 10:15 4.00 10,212 10,214 PROD1 WHPST MILL P 10212' - WOB 1.55, Ct weight 9.7K, 1.50 bpm, returns 1.40, circ 3350 psi, WHP 10, BHP 3450. Metal fillings & cement in returns. 10:15 12:15 2.00 10,214 10,216 PROD1 WHPST MILL P P/U for weight transfer, take a small run @ bottom. Feel sitting on wear pad of BHA (no motor work). @ 10214.8' Past mid - point. Time drilling. Starting to get better weight transfer. 12:15 13:33 1.30 10,216 10,217 PROD1 WHPST MILL P Good WOB & motor work. 1.50 bpm, Circ press 3600, returns 1.39, WOB 3.8, CT weight 6K, BHP 3600. 13:33 15:15 1.70 10,217 10,227 PROD1 WHPST DRLG P Bit exiting window, smooth transition for weight transfer. CT weight 7K, WOB 1.1, BHP 3545, 1.5 bpm, circ 3500. 400 IA , 373 OA. Drill out additional 10ft of formation. No Stalls for entire window. 15:15 16:15 1.00 10,227 10,227 PROD1 WHPST REAM P Back ream window area. P/U weight 26K. Light sand /siltstone and cement in sample. First pass @ 1 fpm, clean up /down. Second/ third pass @ 4 fpm, clean up /down. Dry tag pass was clean. Bottom @ 10226'. Page 3 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 17:15 1.00 10,200 10,070 PROD1 WHPST OWFF P 20 min. static with old mud. BHP 3350 psi. 600 psi on WHP. No gain /loss - tight. Bleed off WHP - BHP 2800 psi. No flow. Open EDC - P/U 100' circulate new mud down @ 1.5 bpm. 17:15 20:00 2.75 10,070 0 PROD1 WHPST TRIP P POOH circulating clean 9.3 mud in system. 20:00 20:30 0.50 0 0 PROD1 WHPST PULD P PJSM, Check for no flow, Lay down BHA #4 Window Mill Mill came out 2.79 no go 20:30 21:15 0.75 0 0 PROD1 DRILL PULD P P/U BHA #5 with 2.55 degree motor and Bi- Center cheetah bit, good surface test, tag up set counters 21:15 23:45 2.50 0 10,115 PROD1 DRILL TRIP P Trip in hole with BHA #5 to drill build section 23:45 00:00 0.25 10,115 10,115 PROD1 DRILL DLOG P Log Gamma Tie In fora +12' Correction, Close EDC, RIH to drill 12/27/2009 Complete Build, Make up Rib Steer in Lateral BHA, Drill ahead 00:00 00:15 0.25 10,115 10,227 PROD1 DRILL TRIP P Run through window dry, tag bottom @ 10227, P/U and bring on pumps 00:15 01:00 0.75 10,227 10,280 PROD1 DRILL DRLG P 10227' Drill Ahead 1.3K WOB 1.35 BPM @ 3260 PSi FS BHP =3590 WHP =0 01:00 03:00 2.00 10,280 10,375 PROD1 DRILL DRLG P 10280' Drilling .9K WOB 1.5 BPM @ 3275PSI Free spin BHP =3620. Attempting to get Auto choke working to maintain BHP Blew down choke B and rebooted BHP now is 3715 with 100 PSI WHP 03:00 03:15 0.25 10,375 10,375 PROD1 DRILL WPRT P 10375 Wiper to window PUW =29K 1.5 BPM @ 3290 PSI FS BHP =3675 @ 100 PSI WHP 03:15 06:15 3.00 10,375 10,500 PROD1 DRILL DRLG P 10375', Drill ahead 1.44 BPM @ 3220 PSI FS BHP =3698 @ 90 PSI WHP 06:15 07:15 1.00 10,500 10,535 PROD1 DRILL DRLG P Crew Change- Phase 2 condtions. Drill ahead - CT weight 5.5K, WOB 1.83, ROP 36 fph, 1.52 bpm, returns 1.40, Circ press 3500, BHP 3740, WHP 150, ECD 12.56. Samples indicate good clean upper A -2 sand. 07:15 10:00 2.75 10,535 82 PROD1 DRILL TRIP P Complete build section, CT weight 29K, Wiper up to window. Clean through window, trap pressure 800 WHP - BHP 3700, Open EDC, POOH following Managed pressure schedule. CT © surface, trap 950 psi of WHP, stop pumping @ close EDC. 10:00 11:15 1.25 82 0 PROD1 DRILL PULD P Safety meeting and begin Undeploying BHA. Weather conditions are improving now Phase 1. BHA layed down. Break off Cheetah bit to re -run Page 4 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 13:15 2.00 0 0 PROD1 DRILL PULD P Break off Motor /Bit assembly. Lay down BHA, make up RSM in mousehole. Service injector while BHI is working on tools. Remove mouse hole (gained 24" of working room) for ease of PDL handling /making up BHA for Rib steer. 13:15 14:45 1.50 0 68 PROD1 DRILL PULD P Total of 3/4 bbl pumped in MPL in 2 hours. Deploy BHA # 6. 14:45 18:00 3.25 68 10,090 PROD1 DRILL TRIP P Open EDC -RIH following MP schedule. 18:00 18:30 0.50 10,090 10,150 PROD1 DRILL DLOG P Perform Gamma Ray Tie In +12' Correction Close EDC Wt Chk 28K PUW, continue in hole 18:30 18:45 0.25 10,150 10,535 PROD1 DRILL TRIP P RIH, Pass through window, Tight spots when ribs went through window and at 10263, 10363. High doglegs in these areas. Lost 1000 RIW didn't set down also saw WOB. 18:45 20:45 2.00 10,535 10,687 PROD1 DRILL DRLG P 10535' Drill ahead 1.4 BPM @ 3795PSI FS 6.4K RIW 1.3K WOB 20:45 22:15 1.50 10,687 10,687 PROD1 DRILL WPRT P 10687 Wiper trip to window with MAD Pass Build. Logged K1, No Correction, logged RA, @ 10215'. PUW =24K. Trip smoother then first time. WOB @ 10057. Saw nothing going through window @ 20 FPM. Continue in to drill 22:15 00:00 1.75 10,687 10,816 PROD1 DRILL DRLG P 10687, Drill Ahead 1.5 BPM @ 3680 FS BHP =3822 Wide open choke Midnight Depth 10816 12/28/2009 Drilled From 10816 to 11780, Performed Mud swap 00:00 00:15 0.25 10,816 10,835 PROD1 DRILL DRLG P 10816', Drilling ahead 00:15 01:15 1.00 10,835 10,835 PROD1 DRILL WPRT P 10835, Wiper to window 26 K PUW 1.5 BPM @ 3680 PSi FS BHP =3810 Wide open choke Came up to 10230' 01:15 03:00 1.75 10,835 10,835 PROD1 DRILL DRLG P 10835', Drilling Ahead 1.48 BPM @ 3610 PSI FS BHP =3860 ECD 12.94 03:00 04:30 1.50 10,835 10,835 PROD1 DRILL WPRT P 10987' Wiper trip to window PUW =25k 1.4 BPM @ 3730 BHP =3870 Seeing same areas 10353, 10252 -62 needing more push 04:30 06:30 2.00 10,835 11,135 PROD1 DRILL DRLG P 10835' Drill Ahead, Slack off 7k w/ 1.3K DWOB 1.4 @ 3615PSI Free spin ROP =80 FPH Page 5 of 29 Time Logs Date From To Dur S. Depth E. Depth_Phase Code Subcode T Comment 06:30 08:00 1.50 11,135 11,135 PROD1 DRILL WPRT P Wiper trip - P/U weight 29K. No weight bobbles through build section. 08:00 09:45 1.75 11,135 11,285 PROD1 DRILL DRLG P BOBD - CT weight 5K, WOB 1.5, 1.5 bpm © 4000 psi, WHP 0, BHP 3920, ECD 13.2, ROP 70. Mud © .7 % solids. Vac trucks ordered. 09:45 11:30 1.75 11,285 11,285 PROD1 DRILL WPRT P Wiper trip - CT weight off bottom 28K, roughly 2 bbls losses per hour since 06:00. 11:30 14:00 2.50 11,285 11,435 PROD1 DRILL DRLG P BOBD - CT weight 6K, WOB 1.3, ROP 70, 1.5 bpm, 4100 psi, 1.35 retums, BHP 3940, ECD 13.2, WHP 0. 14:00 16:00 2.00 11,435 11,435 PROD1 DRILL WPRT P Wiper trip, - Mud swap ( 1200 ft on system). CT weight off bottom 28K. 16:00 17:45 1.75 11,435 11,585 PROD1 DRILL DRLG P New Mud at bit - on bottom drilling - CT weight 5K, WOB 1.4, 1.5 bpm, 1.42 returns, circ press 3600psi, BHP 3800psi, WHP 80, ECD 12.81, ROP 90 fph. No losses with new mud, holding 80 psi on choke for intial mud swap. 17:45 19:30 1.75 11,585 11,585 PROD1 DRILL WPRT P Wiper trip - P/U weight off bottom 26K. Tied into RA marker +3' correction 19:30 21:30 2.00 11,585 11,735 PROD1 DRILL DRLG P 11585', Drill Ahead 1.5 BPM @ 3260 FS RIW 1K 21:30 23:15 1.75 11,735 11,735 PROD1 DRILL WPRT P 11735 Wiper to Window PUW =35k, Dragging 28K 23:15 00:00 0.75 11,735 11,780 PROD1 DRILL DRLG P 11735' Drill ahead 1.5 BPM @3650 PSI FS 4.3k Slack off with 1.2K WOB 12/29/2009 Drilled lateral from 11780' to 12480'. 00:00 01:30 1.50 11,780 11,883 PROD1 DRILL DRLG P Drilling Ahead, 60 -80 FPM 1.5 BPM © 3600 FS BHP =3800 01:30 03:00 1.50 11,883 11,883 PROD1 DRILL WPRT P Wipe to window 40K PUW 26.5 K Dragging 1.5 BPM @3600 FS 03:00 03:30 0.50 11,883 11,883 PROD1 DRILL WPRT P Wiper weight numbers - 11800 - 26K, 11300 - 24K, 10800 - 23.5K, 10300 - 23K. RIH weight 10300 - 6.5K, 10800 - 5.5K, 11300 - 5K, 11800 - 4.5K 03:30 06:30 3.00 11,883 12,028 PROD1 DRILL DRLG P BOBD - CT weight 1K, WOB 1.1, 1.46 bpm @ 3750 psi, BHP 3870, ROP 40 fph, ECD 12.9, WHP 0. Good weight transfer. 06:30 09:30 3.00 12,028 12,028 PROD1 DRILL WPRT P Slight motor stall. P/U and sticking slightly. get back on bottom - stacking weight - pull wiper trip 10 ft early. Ct weight 28K off bottom. R/A tag +3' tie in. Page 6 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:12 2.70 12,028 12,190 PROD1 DRILL DRLG P 12028' Drilling Ahead 2K Slackoff .8K WOB 1.5 BPM @ 3820 FS BHP =3980 ROP 60 -70 FPH 12:12 15:12 3.00 12,190 12,190 PROD1 DRILL WPRT P Wipe to Window 27K PUW 1.5 BPM @ 3920PSI FS BHP =4000 15:12 17:12 2.00 12,190 12,340 PROD1 DRILL DRLG P 12190 Drilling Ahead 1.5 BPM @ 3920 PSI .6K Slackoff, 1.3K WOB then went to 1.6K WOB and -1.4K surface 17:12 19:42 2.50 12,340 12,340 PROD1 DRILL WPRT P Wiper trip to window. 19:42 22:30 2.80 12,340 12,480 PROD1 DRILL DRLG P Drilling ahead, 6K RIW, 1.4 WOB, 1.4 BPM, 3970 FS, 4053 BHP, 100- 300 motor work, 50 - 70 ROP. Stacking surface weightto -10K with no WOB 22:30 00:00 1.50 12,480 12,480 PROD1 DRILL WPRT P Wiper trip to window, 40K initial PU, 35K PUW. Tie in, +5'. 12/30/2009 Drilled lateral from 12480' to 12790'. Stuck pipe during wiper trip and pumped slick diesel to get free. Ciculated out highly viscous fluid and diesel to clean up hole. 00:00 01:00 1.00 12,480 12,480 PROD1 DRILL WPRT P Continue wiper trip from 12480 to window with tie in , +5' correction. Start mud swap while running back in hole. Clean trip in hole. 01:00 03:30 2.50 12,480 12,640 PROD1 DRILL DRLG P Drilling ahead, 7K RIW, 1.4 WOB, 1.4 BPM, 3600 FS, 3862 BHP, 100- 200 motor work, 50 - 70 ROP. 03:30 06:00 2.50 12,640 12,640 PROD1 DRILL WPRT P Wiper trip to window, 38K PUW, Tie into RA marker for a +7' correction RIH to drill 06:00 09:00 3.00 12,640 12,790 PROD1 DRILL DRLG P 12640, Drill ahead 1.5 BPM @ 3465PSI FS BHP =3823 1.5K WOB 09:00 09:15 0.25 12,790 12,675 PROD1 DRILL WPRT P Wiper to window 42K PUW 1.5 BPM @ 3600 PSI FS BHP =3870 09:15 11:15 2.00 12,675 12,675 PROD1 DRILL WPRT T PU to 12675. Pulled tight, trip out pump. Unable to go down or up after working pipe, Good returns, pump bottoms up. Trap 970 PSI Surface pressure and shut down pumps. Work Pipe. Stop working pipe. Hold @ 42k, Hold @ 52K, Hold @ -10K. 11:15 13:15 2.00 12,675 12,675 PROD1 DRILL WPRT T Pump 20 bbls 110 LSRV sweep. Work pipe -10k to 55k with no success. 13:15 13:30 0.25 12,675 12,675 PROD1 DRILL SFTY T PJSM to pump Slick Diesel down coil 13:30 15:00 1.50 12,675 12,675 PROD1 DRILL WPRT T PT LRS Diesel lines to 4K, Isolate coil, open up coil to LRS, pump 50 BBIs Slick Diesel down coil. Page7of29 1 11, Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:15 0.25 12,675 12,105 PROD1 DRILL WPRT T Pumped 46 BBI into open hole, work pipe. S/d pumps and let hole relax. Open hole full of Slick diesel. Work Pipe. Pulled free, Come up 15:15 15:30 0.25 12,105 12,150 PROD1 DRILL WPRT T Packing off, returns down to 0.2 bpm. Annular pressure up to 4255. Returns down to 0.25 BPM in. Run down hole. 15:30 16:45 1.25 12,150 10,160 PROD1 DRILL WPRT T 12150. Attempt to come up above 12105. made it past no problem. Annular pressures climbing, No well head pressure. Returns down to 0.2 BPM. Suspect mud thickening /contamination. 16:45 18:00 1.25 10,160 9,000 PROD1 DRILL CIRC T In Cased Hole, Open EDC Circulate out contaminated mud / diesel. 18:00 19:18 1.30 9,000 560 PROD1 DRILL CIRC T PUH at 100 FPM and lower pump rate to 0.75 BPM. Return rate at 0.25 BPM. Continue to POOH. Highly viscous, pudding -like returns. 19:18 21:00 1.70 560 9,000 PROD1 DRILL CIRC T Clean returns, RIH and continue circulating. Following MPD tripping schedule. 21:00 21:18 0.30 9,000 9,500 PROD1 DRILL CIRC T Annular pressure climbing and returns dropping off. Reduce pump rate and continue RIH. 21:18 23:18 2.00 9,500 940 PROD1 DRILL CIRC T PUH @ 100 FPM and increase rate to 0.75 BPM. Returns at 0.3 BPM. Same highly viscous returns. 23:18 00:00 0.70 940 5,000 PROD1 DRILL CIRC P Returns cleaned up, run back in hole following tripping schedule 12/31/2009 Finish circulating out diesel, drill ahead to 12870', POOH for injector repairs. 00:00 02:00 2.00 5,000 10,125 PROD1 DRILL CIRC P Continue RIH cleaning up wellbore, 02:00 02:15 0.25 10,125 10,155 PROD1 DRILL DLOG P Tie in, +9' 02:15 04:15 2.00 10,155 12,792 PROD1 DRILL WPRT P Wiper trip to bottom. displacing some Saw some weight stacking at 12715' and at 12780, back ream. 04:15 05:15 1.00 12,792 12,840 PROD1 DRILL DRLG P Drilling ahead, 1.5 BPM, 3600 CTP, 3957 BHP, 200 psi motor work, 30K PUW, -5K RIW, 1 -1.5 WOB, 30 - 60 ROP 05:15 05:30 0.25 12,840 12,840 PROD1 DRILL WPRT P Stacking, Pull Mini Wiper up to 12600 26K PUW 3.5K RIW 1.4 BPM @ 3820PSI FS BHP =3915 05:30 06:45 1.25 12,840 12,870 PROD1 DRILL DRLG P 12840', Drill Ahead -4k Slackoff 1.3K WOB, 12859 Stacking hard to get drilling, trouble getting back to bottom after pick ups perform short wipers. 12870 drilling at -13K, 1.1k DHWOB 06:45 09:00 2.25 12,870 10,200 PROD1 DRILL WPRT P 12870', wipe to window 32K PUW 1.4 BPM @ 3600 PSI BHP =3890 Page 8 of 29 • 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 13:00 4.00 10,200 0 PROD1 DRILL TRIP T Bearing Pieces found in Injector sump, POOH to repair Injector Start Nabors down time, 9.5 billable repair hours, 5.5 non billable hours for remainder of day. 13:00 15:00 2.00 0 0 PROD1 DRILL PULD T PJSM, Undeploy BHA #6 Ribsteer 15:00 00:00 9.00 0 0 PROD1 DRILL RGRP T PJSM, Cut coil connector, Unstab Coil, Pull Stuffing Box and replace _ skates 01/01/2010 Complete injector repairs. Install coil conector. Phase 3 Suspend operations 00:00 05:30 5.50 0 0 PROD1 DRILL RGRP T Continue with injector repairs Nabors billable repair time (5.5 hrs) 05:30 07:30 2.00 0 0 PROD1 DRILL SLPC T Stab pipe into injector and install new CTC Nabors billable repair time (2 hrs) 07:30 23:30 16.00 0 0 PROD1 DRILL PULD T Field in Phase 3, Rig activities limited to essential activities only. Nabors regular day rate for weather standby 23:30 00:00 0.50 0 0 PROD1 DRILL PULD T Field in Phase 2. Pads and Access roads Phase 3. Weather trending down. Fire up air heaters Nabors regular day rate for weather standby 01/02/2010 WOW, PU BHA, RIH, Drill to TD at 12996', lay in liner running pill and swap well to 12.7 KWF 00:00 00:30 0.50 0 0 PROD1 DRILL PULD T Phase three weather Nabors regular day rate for weather standby 00:30 02:30 2.00 0 0 PROD1 DRILL SLPC T Continue with reheading coil. Crew change, pre -tour safety meeting. Nabors regular day rate for weather standby 02:30 07:30 5.00 0 0 PROD1 DRILL PULD T Phase three field wide, again... Nabors regular day rate for weather standby 07:30 09:30 2.00 0 0 PROD1 DRILL PULD T Continue with PU /Deploy drilling BHA Nabors billable repair time (2 hrs) 09:30 11:30 2.00 0 3,400 PROD1 DRILL TRIP T RIH following MPD schedule. Stop and inspect gooseneck rollers and injector alignment Nabors billable repair time (2 hrs) Page 9 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 13:15 1.75 3,400 10,130 PROD1 DRILL TRIP T 3400' started pressuring up annular with returns dropping off, Pull up hole with minimal returns. Started getting High vis contaminated mud back. PUH to 2000 to establish full return and pressure drop. RBIH for another bite. Saw no other signs of viscosified fluid. .5 Hours of billabe repair time, 1.25 hours of non - billable repair time 13:15 13:30 0.25 10,130 10,162 PROD1 DRILL DLOG T 10130, Perform Gamma tie in, +15' correction, RIH to see what we got. .25 Hours of non - billable repair time 13:30 15:00 1.50 10,162 12,870 PROD1 DRILL TRIP P RIH to Drill 15:00 16:15 1.25 12,870 12,920 PROD1 DRILL DRLG P 12868' Drill ahead 1.3 BPM @ 37250 FS BHP =3960 2.5K Slack off, 1.22 WOB Good trip to bottom RIW started dropping off @ 12600 to TD 16:15 16:30 0.25 12,920 12,920 PROD1 DRILL WPRT P 12920 to 12840 Mini Wiper PUW 35K 16:30 18:06 1.60 12,920 12,996 PROD1 DRILL DRLG P 12920 Drill Ahead 1.3 BPM @ 3535 FS BHP =3900 Pressure coming down possibly unloaded more viscous fluid 18:06 19:36 1.50 12,996 10,225 PROD1 DRILL WPRT P TD, wiper to window, 31K PUW 19:36 19:48 0.20 10,225 10,250 PROD1 DRILL DLOG P Tie in, -1' 19:48 21:18 1.50 10,250 12,996 PROD1 DRILL WPRT P Wiper to TD at 12996'. Clean trip in. 21:18 00:00 2.70 12,996 10,000 PROD1 DRILL DISP P Lay in 12.7 ppg bead -laden liner running pill in open hole, displace well to 12.7 KWF (no lubes) while POOH 01/03/2010 Ran lower section of liner and could not get deeper than 11727'. Pull liner OOH and lay down. Losing fluid, 86 Bbls for the day. 00:00 00:30 0.50 10,000 0 PROD1 DRILL DISP P Continue POOH swapping well to 12.7 KWF 00:30 01:30 1.00 0 0 PROD1 DRILL PULD P Lay down drilling BHA 01:30 02:12 0.70 0 0 COMPZ CASING PUTB P Rig up for liner job 02:12 02:30 0.30 0 0 COMPZ CASING SFTY P PJSM 02:30 05:15 2.75 0 0 COMPZ CASING PUTB P Start running slotted liner 05:15 07:00 1.75 0 0 COMPZ CASING PUTB P Make up GS and coil track to liner, surface test coil track Stab onto well 07:00 09:00 2.00 0 10,150 COMPZ CASING RUNL P RIH With lower liner section. EDC Closed 09:00 09:30 0.50 10,150 11,519 COMPZ CASING RUNL P 10150 Weight check PUW 36K. Continue in hole with liner Page 10 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 13:00 3.50 11,519 11,727 COMPZ CASING RUNL P Set down at 11519'. PUW 42k, Start working pipe to bottom in 3 -5' chunks. 13:00 16:00 3.00 11,727 6,783 COMPZ CASING RUNL T Made it as far as 11727. Started losing ground. At 11698 after 1 hour, POOH to try something else. POOH replacing coil voidage Lost 40 BBIs 12.7 ppg KWF to formation 16:00 18:30 2.50 6,783 0 COMPZ CASING RUNL T Stop and check hole fill, Line up and fill hole across top. Hole was full. Continue POOH 18:30 19:00 0.50 0 0 COMPZ CASING CIRC T Circulate 12.7 out of coil at surface 19:00 22:30 3.50 1,780 0 COMPZ CASING PUTB T Lay down slotted liner. Indexing shoe was clean. Spiral marks on liner - from running through corkscrewed tubing? 22:30 00:00 1.50 0 0 COMPZ CASING PULD T PU Drilling BHA with 0.9 motor and bicenter for cleanout run 01/04/2010 Ran drilling BHA to TD, wiper to window and lay in 9.3 ppg liner running pill and lay in 12.7 KWF to surface. Run 38 Jts. liner string 00:00 02:00 2.00 0 10,200 COMPZ CASING FCO T RIH for cleanout. Lost 22 Bbls KWF tripping in without pumping. Tried various trip speeds from 40 FPM to 100 FPM with no improvement in return rate. 02:00 04:30 2.50 10,200 10,172 COMPZ CASING DISP T Tie in, +1'. Displace well to 9.3 ppg flopro. Recovered total of 72 bbls of 12.7 KWF leaving a total of 114 bbls in the pits. Shut in well and let pressure build to a stabilized 3760 BHP at 10172' MD, thats 5764' TVD (not SSTVD) which is a 12.55 EMW. Will stick with using 12.7 ppg KWF. 04:30 05:15 0.75 10,172 12,996 COMPZ CASING FCO T RIH, pumping 0.3 BPM, maintain 3800 BHP 05:15 07:30 2.25 12,996 10,500 COMPZ CASING FCO T Wiper trip to window with tie in +1.5' correction 07:30 12:30 5.00 10,500 12,500 COMPZ CASING FCO T RBIH, condition areas as needed. Building pills for liner running 12:30 13:30 1.00 12,500 12,996 COMPZ CASING FCO T Send 23 BBIs, 9.3 Beaded pill down coil. Will be followed by 12.7 beaded, viscosified, lubricated pill in the tubing. 13:30 19:00 5.50 12,996 0 COMPZ CASING FCO T POOH laying in pill 19:00 20:00 1.00 0 0 COMPZ CASING FCO T Tag up at surface, 12.7 to surface, no flow check. Lay down drilling BHA. 20:00 22:00 2.00 0 1,248 COMPZ CASING PUTB T Rig up for liner job and run 38 Joints liner 22:00 23:00 1.00 1,248 1,248 COMPZ CASINGSVRG P Service injector Page 11 of 29 • 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 1,248 4,000 COMPZ CASING RUNL T RIH with liner at 50 FPM to reduce losses to formation 01/05/2010 Ran liner in two sections with bottom @ 12997' and top @ 10340', corrected depths. 00:00 02:15 2.25 4,000 10,200 COMPZ CASING RUNL T RIH with liner at 50 FPM to reduce losses to formation 02:15 03:45 1.50 10,200 13,002 COMPZ CASING RUNL T Weight check at window, 15K PUW, 5K RIW. Lost 16.5 Bbls while RIH to widow 03:45 05:00 1.25 13,002 11,405 COMPZ CASING RUNL P 13002, Tag bottom, PUW 32K, Run in stack 10K Surface weight. Pump on 1 BBUM 3K PSI Pull Off liner 23K. PUH to tie In TOL 11804.2 CTM 05:00 05:15 0.25 11,405 11,435 COMPZ CASING DLOG P 11405', Tie into to RA marker, Correct -5' Liner set @ 12997' corrected. TOL is 11799 Corrected Remove liner length from bit depth counter. Continue POOH filling across the top. 05:15 05:33 0.30 7,385 6,299 COMPZ CASING OWFF P Stop and flow check well. Displacement not correct.Fluid in shaker pit 12.3. No flow on well. Line up to pump down coil. Pump 12 BBIs dirty 12.7 to lay in last of clear fluid out of coil 05:33 09:03 3.50 6,299 0 COMPZ CASING RUNL P Clear fluid out of coil. Line up across top out of pit 7. 12.7 Dirty. Continue out of well 09:03 13:33 4.50 0 0 COMPZ CASING PUTB P Lay down liner running tools, PU second liner string, MU liner running BHA 13:33 16:33 3.00 0 10,215 COMPZ CASING RUNL P RIH, Wt. check at window, 27K PUW, 6K RIW 16:33 18:03 1.50 10,215 11,737 COMPZ CASING RUNL P Tag up w/ liner @ 11,749' (- 20K #). Try multiple times to get passed. Online with agitator and still no success. Losing ground after PUH several times. 18:03 18:48 0.75 11,737 11,737 COMPZ CASING RUNL P Begin circulating FP with beads down CT. Pump 20 bbls and swap to displace with FP. 18:48 19:18 0.50 11,737 11,808 COMPZ CASING RUNL P SD pumps to clean suction screen on pump. While down tried to continue running liner to bottom. Had pumped a total of 39 bbls of FP with beads and without. Liner began moving and successfully ran it to bottom @ 11808.19' 19:18 19:30 0.20 11,808 11,808 COMPZ CASING RUNL P Pump off liner and circulate 15 bbls of FP. 19:30 20:00 0.50 11,808 11,780 COMPZ CASING RUNL P Begin to POOH for tie -in. Pulling heavy -55K# @ 11780'. Continue to pump 10 more bbls. Returns @ 80% and increasing. Free. PUH to prepare for tie -in. Page 12 of 29 i 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:15 0.25 11,780 11,570 COMPZ CASING RUNL P Attempt to tie into RA marker. PUH above marker and begin to log down. Tag up and unable to RIH. Decision made to tie -into formation marker. Tie in at formation marker = 0' correction. Remove liner length from bit depth counter. 20:15 21:00 0.75 11,570 10,340 COMPZ CASING RUNL P RBIH to confirm that liner wasn't drug back up hole. Tagging up @ 10209'. TOWS. SD pumps and go right through. PU wt @ 10260' = 31 K #. Tag top of liner © 10,340' corrected depth. All good. 21:00 00:00 3.00 10,340 3,046 COMPZ CASING RUNL P Begin to POOH pumping 1.1 bpm and 3950#. POOH following press. schedule. 01/06/2010 Set anchor © 10,331' with top of billet @ 10,319'. Single slip of anchor set @ 25 deg ROHS. Rebuilt and replaced 2.375" deployment rams. 00:00 00:45 0.75 3,046 0 COMPZ CASING RUNL P At surface with BHA #11. Pumped 38 bbls while POOH. 00:45 02:30 1.75 0 0 COMPZ CASING PULD P PJSM, Pressure undeploy BHA #11. 02:30 04:30 2.00 0 0 PROD2 STK PULD P PJSM, Pressure deploy BHA #12 (aluminum billet and openhole anchor). 04:30 08:30 4.00 0 10,125 PROD2 STK TRIP P Open EDC and begin to RIH with billet and openhole anchor. Losing mud while RIH 08:30 09:00 0.50 10,125 10,150 PROD2 STK DLOG P Tie in, -6.5' correction. Close EDC. 30K PUW, 4K RIW 09:00 09:18 0.30 10,150 10,331 PROD2 STK WPST P Continue to RIH, tag liner at 10331.5', PUH and set anchor at 10331', top of billet at 10319.6', orient upper slip to 25 deg. ROHS. Pressured up to 4300 CTP to set anchor. 30K PUW. 09:18 11:30 2.20 10,331 0 PROD2 STK TRIP P POOH, .8 BPM in, .2 BPM return at 100 FPM 11:30 13:30 2.00 0 0 PROD2 STK PULD P Un- deploy anchor running BHA 13:30 17:00 3.50 0 0 PROD2 STK RGRP T Repair BOP hydralic acctuators on deployment rams due to hydraulic leaks. Nabors non - billable rig repair time (3.5 Hrs.) 17:00 18:00 1.00 0 0 PROD2 STK RGRP P Service injector and reel Nabors on the clock again. 18:00 19:30 1.50 0 0 PROD2 STK PULD P PJSM, and begin to deploy BHA #13. 19:30 20:06 0.60 0 0 PROD2 STK RGRP T Deployment rams not holding. Shut down, conduct PJSM and pull toolstring out of BOP's to inspect. * **Nabors non - billable repair time begins. Page 13 of 29 i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:06 21:36 1.50 0 0 PROD2 STK RGRP T BHI tools have been smashed by undersize deployment rams. Discovered that 2" rams were run instead of 2.375 ". Notifications were made and proper sized rams were located. Rams closed on the EDC and deformed it from 2.375" OD to 2.187" OD. 21:36 23:21 1.75 0 0 PROD2 STK RGRP T PJSM, and begin swapping out rams from 2" to 2.375 ". 23:21 00:00 0.65 0 0 PROD2 STK RGRP T Completed swapping out rams. Conduct PJSM, and prepare to pressure test (shell) and test rams on the test joint. Pressure test low /high = 250/4000#. Close rams on test joint. All good. ""Nabors non - billable repair time ends for the day. (4.5 hrs. for a total of 8 hours on the day) 01/07/2010 Completed mud swap. Tagged billet @ 10,320' and drilled off at 80 deg ROHS. Completed build section to 10,525' of lateral 2T- 29AL1. Began BOPE test. Test waived by Lou Gramaldi. 00:00 00:30 0.50 0 0 PROD2 STK RGRP T PJSM, and begin picking up BHA in preparation for deployment of BHA #14. * **Nabors non - billable repair time (0.5 hrs). 00:30 01:30 1.00 0 0 PROD2 STK PULD P Bled down pressure above deployment rams. All good. 01:30 04:15 2.75 0 10,120 PROD2 STK TRIP P Open EDC and begin to RIH with BHA #14. Pumping min rate. Losing fluid while RIH. 04:15 04:30 0.25 10,120 10,148 PROD2 STK DLOG P Tie into formation, +1' correction. Close EDC. 26K PUW, 3.5K RIW 04:30 04:45 0.25 10,148 10,322 PROD2 STK TRIP P Continue to RIH through window. Bring pumps online and begin circulating new FP down the CT. Pumps online @ 1 bpm and 3350# pump press. Getting little to no returns. Slow RIH speed and shut down pump to dry tag billet. Tag @ 10322'. Pick up off billet w/ 26K #. 04:45 05:15 0.50 10,322 10,320 PROD2 STK MILL P Begin backreaming while POOH for a BHA length (65'). RIH and slowly en •age billet. 05:15 07:00 1.75 10,320 1,300 PROD2 STK CIRC T PUH to establish circulation. Highly viscous fluid returns again. PUH to 1300' to get clean mud and full returns. 07:00 08:45 1.75 1,300 10,125 PROD2 STK CIRC T RIH following MPD tripping schedule 08:45 09:00 0.25 10,125 10,320 PROD2 STK DLOG T Tie in, +3' Page 14 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:30 3.50 10,320 10,333 PROD2 STK MILL P Tag billet at 10320', PU 27K PUW, and start time drilling at 10319.5' at 1 FPH, 1.5 BPM, 3350 CTP, 3815 BHP, 75 WHP, 0 to 300 WOB, 5K RIW. 1 FPH to 10321', 2 FPH to 10323', 3 FPH to 10324', 10 FPH to 103329', 15 FPH to 10333' 12:30 16:30 4.00 10,333 10,525 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 3600 CTP, 140 WHP, 3850 BHP, 1500 WOB and 3 -5K RIW, 51.4 ROP 16:30 19:00 2.50 10,525 0 PROD2 DRILL TRIP P POOH following new MPD schedule. 19:00 22:00 3.00 0 0 PROD2 DRILL PULD P At surface. PJSM, begin to undeploy and lay down BHA #14. Valve crew on location to service tree prior to BOP test. Flush stack with fresh water. 22:00 00:00 2.00 0 0 PROD2 DRILL BOPE P PJSM, Begin BOP test. Test was waived by AOGCC inspector Lou Gramaldi. 01/08/2010 Completed BOPE test. Deployed BHA #15 with RSM and drilled lateral 2T -29AL1 down to 11,012'. 00:00 07:30 7.50 0 0 PROD2 DRILL BOPE P Continue BOPE test and servicing injector. Displace freshwater out of CT with flo -pro. CHange stipper ellements 07:30 10:00 2.50 0 0 PROD2 DRILL PULD P PU BHA #15 with RSM and deploy 10:00 11:00 1.00 0 5,200 PROD2 DRILL TRIP P RIH following MPD tripping schedule 11:00 12:00 1.00 5,200 1,300 PROD2 DRILL TRIP T Lost returns while RIH - ran into thick, contaminated mud at 5300' MD. PUH at 100 FPM and pumping 1 BPM, .2 BPM returns with 0 WHP. 12:00 13:48 1.80 1,300 10,125 PROD2 DRILL TRIP P Return rate at 1:1, RIH following MPD tripping schedule, pumping 1 BPM 13:48 14:06 0.30 10,125 10,150 PROD2 DRILL DLOG P Tie in, +5' 14:06 14:18 0.20 10,150 10,525 PROD2 DRILL TRIP P Continue RIH 14:18 16:00 1.70 10,525 10,675 PROD2 DRILL DRLG P Drilling, 1.4 BPM, 3600 CTP, 3850 BHP, 150 WHP, 5 K RIW, 1.5K WOB, 100 -300 motor work, 50 -80 ROP ROP increased to 120 -150 16:00 17:18 1.30 10,675 10,675 PROD2 DRILL DLOG P Wiper trip, 25K PUW. MAD pass from 10515' 17:18 19:30 2.20 10,675 10,825 PROD2 DRILL DRLG P Drilling, 1.4 BPM, 3600 CTP, 3850 BHP, 100 WHP, 3 K RIW, 1.5K WOB, 100 -300 motor work, 80 -120 ROP 19:30 20:00 0.50 10,825 10,231 PROD2 DRILL WPRT P Wiper trip up to 10231'. 24K PUW. 20:00 20:30 0.50 10,231 10,825 PROD2 DRILL WPRT P Wiper trip back down to 10825'. 5K RIH wt. Page 15 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase _Code Subcode T Comment 20:30 22:15 1.75 10,825 10,975 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3600 CTP, 3870 BHP, 135 WHP, 2K RIW, 2.2K WOB, 200 -300 motor work, 45 -90 ROP. 22:15 23:00 0.75 10,975 10,230 PROD2 DRILL WPRT P Wiper trip up to 10230'. 26K PUW. PUH for tie -in. +1' correction. 23:00 23:30 0.50 10,230 10,975 PROD2 DRILL WPRT P Wiper trip back down to 10975'. 4K RIH wt. 23:30 00:00 0.50 10,975 11,012 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3500 CTP, 3850 BHP, 145 WHP, 1K RIW, 2.2K WOB, 200 -300 motor work, 85 -100 ROP. 01/09/2010 Drilled lateral 2T -29AL1 from 11,012' to 11943'. Swapped to new FloPro. 00:00 01:20 1.34 11,012 11,125 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3500 CTP free spin, 3880 BHP, 150 WHP, 500# RIW, 2.1K WOB, 300 motor work, 80 -90 ROP. 01:20 01:59 0.66 11,125 10,230 PROD2 DRILL WPRT P Wiper trip up to 10230'. 26K PUW. 01:59 02:35 0.60 10,230 11,125 PROD2 DRILL WPRT P Wiper trip back down to 11,125'. 5K RIH wt. 02:35 04:29 1.90 11,125 11,275 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3600 CTP free spin, 3890 BHP, 30 WHP, 1.5K RIW, 1.5K WOB, 100 -250 motor work, 60 -80 ROP. Have lost -26 bbls this tour. 04:29 05:14 0.75 11,275 10,225 PROD2 DRILL WPRT P Begin wiper trip up to 10225'.. 27K PUW. 05:14 05:59 0.75 10,225 11,275 PROD2 DRILL WPRT P Wiper trip back down to 11275'. 5K RIH wt. 05:59 08:53 2.90 11,275 11,425 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3650 CTP free spin, 3940 BHP, 30 WHP, 3K RIW, 1.5K WOB, 100 -250 motor work, 60 -80 ROP. 08:53 09:41 0.80 11,425 10,235 PROD2 DRILL WPRT P Wiper trip to window, 26K PUW 09:41 09:53 0.20 10,235 10,250 PROD2 DRILL DLOG P Tie in at RA, +2' 09:53 10:23 0.50 10,250 11,425 PROD2 DRILL WPRT P Wiper back to bottom, 3K RIW 10:23 12:53 2.50 11,425 11,575 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3600 CTP free spin, 3920 BHP, 25 WHP, 3K RIW, 1 - 2K WOB, 100 -300 motor work, 40 -80 ROP. 12:53 14:29 1.60 11,575 11,575 PROD2 DRILL WPRT P Wiper to window, 28K PUW. Clean trip out and in. 14:29 17:14 2.75 11,575 11,725 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3700 CTP free spin, 3920 BHP, 30 WHP, 1K RIW, 1 - 2K WOB, 100 -300 motor work, 40 -80 ROP. 17:14 18:14 1.00 11,725 10,229 PROD2 DRILL WPRT P Wiper to window, 27K PUW 18:14 19:14 1.00 10,229 11,725 PROD2 DRILL WPRT P Wiper trip back to bottom., 3K RIW. 19:14 20:44 1.50 11,725 11,875 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3700 CTP free spin, 3934 BHP, 22 WHP, 1.2K RIW, 1 -1.5K WOB, 100 -300 motor work, 90 -100 ROP. Page 16 of 29 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:44 21:59 1.25 11,875 10,224 PROD2 DRILL WPRT P Wiper trip to window, 28K PUW. Clean trip out. 21:59 22:11 0.20 10,224 10,250 PROD2 DRILL DLOG P Tie in at RA, +3' correction. 22:11 23:17 1.10 10,250 11,875 PROD2 DRILL WPRT P Wiper trip back to bottom. Make MAD pass from 10,620' to 10,650 on way back in. Swap to new mud when at 11,330'. 23:17 23:59 0.70 11,875 11,943 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3500 CTP free spin, 3955 BHP, 30 WHP, 0 RIW, 1.5K WOB, 100 -300 motor work, 70 -100 ROP. Had to increase WHP from 30 to 200 as the new mud has moved up hole. 01/10/2010 Drilled lateral 2T -29AL1 to 12,080' and upon pickup became differentially stuck @ 12,050'. Pumped 15 bbls hi -visc spacer, 20 bbls of LVT -200, followed by 15 bbls of hi -visc before pulling 65K# (several times) and cominc free. Cleaned up hole and mud system and continued drilling down to 12,387'. 00:00 00:48 0.80 11,943 12,025 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3500 CTP free spin, 3978 BHP, 245 WHP, -3K RIW, 1.7K WOB, 150 -300 motor work, 75 -95 ROP. 00:48 02:00 1.20 12,025 10,229 PROD2 DRILL WPRT P Wiper trip to window. 28K PUW. PUW spiked to 34K @ 11,880' 02:00 03:00 1.00 10,229 12,025 PROD2 DRILL WPRT P Wiper trip back to bottom. 3.2K RIH wt. Holding 270 - 320 WHP to maintain BHP, losing fluid while RIH. 03:00 03:45 0.75 12,025 12,080 PROD2 DRILL DRLG P Continue drilling. 1.4 BPM, 3400 CTP free spin, 3920 BHP, 315 WHP, -1 K RIW, 1.4K WOB, 250 -300 motor work, 95 -105 ROP. Area between 12010 - 12020 appears to be taking fluid. Had losses during previous wiper trip and now currently losing —25 bbls /hr. 03:45 05:00 1.25 12,080 12,050 PROD2 DRILL WPRT T Attempt to make short trip. PU wt = 45K. Pulling 50K, nothing. Pulled up to 12036' is max we can move. Unable to RIH past 12053'. Stacking -14K #. Still losing fluid. Reduce WHP to 170# to try and gain some returns. Unable to see any WOB. 05:00 06:00 1.00 12,050 12,050 PROD2 DRILL CIRC T Circulated 1 bottoms up. Shut down pumps and let coil relax. Pulled several times up to 60K with no luck. Attempted to RIH and stacked -15K. Still not seeing any WOB. Bring pumps BOL and continue to circulate. 06:00 09:00 3.00 12,050 12,050 PROD2 DRILL CIRC T Standby for LVT -200 to arrive from MI in PBU. Page 17 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:48 0.80 12,050 12,050 PROD2 DRILL CIRC T Pump 15 Bbls hi -vis, 20 Bbls. LVT -200, 15 Bbls. Hi -vis. Pump pressure climbing. Initially 3200 CTP at 1.4 BPM, 4200 at .8 BPM when LVT at bit. 4200 CTP, .6 BPM with 10 Bbls LVT out of the coil 09:48 12:30 2.70 12,050 9,400 PROD2 DRILL CIRC T After 10 Bbls. LVT out of coil shut in choke and shut down pump to soak for 5 min. BHP droppped to 3670 with 550 WHP. Pulled 70K twice and on third time pulled up to 68K and came free, continue PUH at 26K and start circulating. .6 BPM at 4500 CTP. Pull up to window while circdulating out LVT. Return rate went as low as .2 BPM with wide open choke, adjusted pump rate to maintain BHP at 12.7 ECD. lost 40 Bbls to formation. Returns had normal properties. 12:30 12:48 0.30 9,400 10,125 PROD2 DRILL CIRC T Circulating clean mud, 1.6 BPM at 3400 CTP, 40 WHP, 3500 BHP, 1.4 BPM returns. RIH to window 12:48 13:00 0.20 10,125 10,150 PROD2 DRILL DLOG T Tie in, +6' 13:00 14:00 1.00 10,150 12,080 PROD2 DRILL WPRT T Continue RIH, 3K RIW, 1.4 BPM in, 1 out, 3400 CTP, 3850 BHP, 300 WHP 14:00 15:00 1.00 12,080 12,161 PROD2 DRILL DRLG P Drilling, 1.4 BPM in at 3350 CTP, 150 WHP, 3870 BHP, losing about 10 Bbls /hour. 3K RIW, PUW was 27K, 1.5 WOB, 200 motor work, 80 -130 ROP 15:00 15:30 0.50 12,161 12,161 PROD2 DRILL WPRT P Short short trip to 11990', 30K PUW, still losing about 10 BPH. Stacking out when RIH at 11990' and again at 11970', PUH to 11800' and RBIH clean 15:30 16:18 0.80 12,161 12,230 PROD2 DRILL DRLG P Drilling, 1.4 BPM in at 3350 CTP, 100 WHP, 3890 BHP, losing about 10 Bbls /hour. 3K RIW, PUW was 30K, 1.5 WOB, 200 -300 motor work, 60 -100 ROP 16:18 18:45 2.45 12,230 12,230 PROD2 DRILL WPRT P Wiper trip to window. 30K PUW. All clean both directions 18:45 19:45 1.00 12,230 12,308 PROD2 DRILL DRLG P Drilling, 1.4 BPM in at 3450 CTP, 60 WHP, 3870 BHP, losing about 6 Bbls /hour, ECD = 12.99. 3K RIW, 1.8 WOB, 200 -300 motor work, 65 -90 ROP. 19:45 20:15 0.50 12,308 12,308 PROD2 DRILL WPRT P short trip up to 11800'. 34K PUW. Clean both directions. 20:15 21:00 0.75 12,308 12,348 PROD2 DRILL DRLG P Drilling, 1.4 BPM in at 3450 CTP, 60 WHP, 3900 BHP, losing about 6 Bbls /hour, ECD = 13.0. 0 RIW, 1.1 WOB, 200 -300 motor work, 65 -90 ROP. Page 18 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:30 2.50 12,348 12,348 PROD2 DRILL WPRT P Wiper trip to window. 35K PUW off bottom. Clean trip both directions. 23:30 00:00 0.50 12,348 12,387 PROD2 DRILL DRLG P Drilling, 1.4 BPM in at 3500 CTP, 15 WHP, 3860 BHP, losing about 6 Bbls /hour, ECD = 13.0. 0 RIW, 1.9 WOB, 200 -300 motor work, 65 -80 ROP. 01/11/2010 Drill down to TD @ 12,580'. Run 2 -3/8" slotted liner to bottom @ 12,580' and top liner running billet @ 11,265'. 00:00 01:00 1.00 12,387 12,460 PROD2 DRILL DRLG P Drilling, 1.4 BPM in at 3570 CTP, 11 WHP, 3860 BHP, currently maintaining 1:1, ECD = 12.95. -3K RIW, 1.9 WOB, 200 -300 motor work, 70 -80 ROP. 01:00 02:30 1.50 12,460 10,217 PROD2 DRILL WPRT P Wiper trip up to window. Clean 30K PUW. Good hole conditions. 02:30 02:48 0.30 10,217 10,246 PROD2 DRILL DLOG P tie in to RA marker, +3' correction. 02:48 03:48 1.00 10,246 12,460 PROD2 DRILL WPRT P Wiper trip back to bottom. 4K RIH wt. 03:48 04:48 1.00 12,460 12,539 PROD2 DRILL DRLG P Drilling, 1.4 BPM in at 3650 CTP, 9 WHP, 3870 BHP, currently maintaining 1:1, ECD = 12.99. -3 to -7K RIW, 2.2 WOB, 250 -300 motor work, 90 -110 ROP. 04:48 05:06 0.30 12,539 12,539 PROD2 DRILL WPRT P Saw no motor work and no WOB but were stacking -12K RIH wt. Short trip, 39K PU off bottom. A bit sticky. PU hole to 12381' but unable to RBIH. Stacking wt. Continue to POOH to 12350'. Appear to be OK now. RBIH but watching very carefully. 05:06 05:54 0.80 12,539 12,580 PROD2 DRILL DRLG P Drilling, 1.4 BPM in at 3650 CTP, 9 WHP, 3870 BHP, currently maintaining 1:1, ECD = 12.99. -3 to -7K RIW, 1.8 WOB, 250 -300 motor work, 20 -90 ROP. 05:54 08:00 2.10 12,580 10,225 PROD2 DRILL WPRT P Wiper to window. During morning call determined that this will be TD 08:00 08:12 0.20 10,225 10,250 PROD2 DRILL DLOG P Tie in, +2' correction 08:12 09:42 1.50 10,250 12,580 PROD2 DRILL WPRT P Wiper back to TD, tagged at 12580' 09:42 14:00 4.30 12,580 0 PROD2 DRILL DISP P Lay in 9.3 Ppg Flo -Pro with beads in open hole, 40 Bbls. 12.7 with beads and lubes, 12.7 with lubes to surface. Flag at 8600' EOP 14:00 15:00 1.00 0 0 PROD2 DRILL PULD P Tag up and check for no flow. Lay down drilling BHA. 15:00 15:15 0.25 0 0 COMPZ CASING PUTB P RU to run liner 15:15 17:45 2.50 0 0 COMPZ CASING PUTB P PJSM for running liner. Run 41 joints of 2 -3/8" slotted liner with a BOT liner top billet. Page 19 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 19:15 1.50 0 0 COMPZ CASING PUTB P PU safety joint. Make up Inteq's BHA and stab on well. PU to tag and confirm depth. Adjusted bit depth to 1359.48'. 19:15 21:45 2.50 0 9,961 COMPZ CASING RUNL P RIH with liner. Made several attempts to find the optimum RIH speed to prevent losses. Still looks like we're losing -40 %. Between 71C and 8K' stopped getting returns. 21:45 21:51 0.10 9,961 9,959 COMPZ CASING RUNL P Stop at flag depth of 8600' to check for depth accuracy. Flag depth showing -1 foot difference. Reset bit depth from 9960.53' to 9959.48', -1.05' correction. 28K PUW. 21:51 22:45 0.90 9,959 12,580 COMPZ CASING RUNL P Continue to RIH with liner. RIH @ 50 FPM. 7K RIH wt. Liner went all the way to bottom with plenty of weight to spare!!!! 22:45 23:00 0.25 12,580 10,205 COMPZ CASING RUNL P Bring pump online and pump off of liner. Pumping 1.4 BPM @ 4100# CTP. Stacking -5K while pumping. 29K PUW. RBIH for a few feet to confirm change of WOB from when running liner. All looks good, -1500# difference. 23:00 00:00 1.00 10,205 10,225 COMPZ CASING DLOG P Tie in to RA marker, +6' correction. 01/12/2010 POOH displacing KWF, P/U BHA # 17 with 1.1 AKO And Bi- center. RIH and getting heavy X- linked fluid. P/U to 4000' and circulate down to 10,180' with SW. Swa? to flo -pro, RIH tag, TOB @ 11,267' 00:00 01:00 1.00 10,225 9,802 COMPZ CASING CIRC P PUH to 10,192', open EDC and begin to pump "old" 12.7 ppg calcium laden fluid. Attempting to circ out 12.7 formate. Begin pumping .6 bpm @ 1450#. No returns so begin to PUH until returns. 01:00 03:00 2.00 9,802 3,800 COMPZ CASING CIRC P PUH to 9802' getting some returns but MM meter on rate out not working. Return fluid wt = 12.6 ppg. Troubleshooting MM meter. All good. Continue to POOH while pumping 1 bpm to increase returns. Getting 35% returns. 03:00 03:30 0.50 3,800 5,100 COMPZ CASING CIRC P Completed recovery of the 12.7 formate. Recovered - 85 bbls. RBIH and prep to begin circulation of the "old" 9.3 ppg FloPro. 03:30 05:00 1.50 5,100 0 COMPZ CASING RUNL P POOH for BHA swap. 05:00 06:00 1.00 0 0 COMPZ CASING PUTB P lay down liner running BHA with a dead well 06:00 06:12 0.20 0 0 PROD3 STK SFTY P PJSM for PU Drilling BHA# 17 06:12 06:42 0.50 0 0 PROD3 STK PULD P PU Drilling BHA# 17 Page 20 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:42 07:42 1.00 0 5,000 PROD3 STK TRIP P RIH 07:42 08:18 0.60 5,000 4,500 PROD3 STK CIRC P Circulate out 12.7 with 9.3 flo -pro 08:18 09:18 1.00 4,500 10,000 PROD3 STK TRIP P RIH 09:18 10:12 0.90 10,000 6,600 PROD3 STK CIRC P Circulate out 12.7 with 9.3 flo -pro 10:12 11:24 1.20 6,600 0 PROD3 STK CIRC T Started getting the "brownie mix" type returns. Really thick fluid exactly what we've seen the past few times. Slow pump rate down due to elevated pump press. Continue to circ and POOH. 11:24 12:06 0.70 0 3,000 PROD3 STK CIRC T At surface. Circ out fluid finall cleaing up. Recoverd -11 bbls of the thick mud. Filled up and overflowed shakers. RBIH pumping min rate and following the MPD schedule. 12:06 14:06 2.00 3,000 0 PRODS STK CIRC T Lost returns. Begin to POOH to achieve returns. More thick fluid. 14:06 16:06 2.00 0 0 PROD3 STK CIRC T RIH attempting to maintain returns to 7000', Losing returns continue getting thick mud back in returns. POOH with minimum pump rate trying to maintain returns. Discuss with town to perform cleanout run. Order out 290bbrls 100deg seawater. 16:06 16:48 0.70 0 2,000 PROD3 STK CIRC T RIH circulating mud, 16:30PM Sea water on location, mix Kla Gaurd into Sea Water 4 LBS /BBRL 16:48 21:48 5.00 2,000 10,000 PROD3 STK CIRC T Start pumping Sea Water around displacing out thick mud, RIH to 4000' Circulate out fluid, RIH to 6000' Circ. B/U - WHP 850 psi, BHP 2800. RIH to 8000' Circ B /U. Returns are cleaning up. RIH to 10,000 ft. POOH to 9700 & RIH down to 10,000 circ B /U. WHP 1050, BHP 3800. Circulated big slug of X- linked fluid. 21:48 22:48 1.00 10,000 10,185 PROD3 STK CIRC T Well cleaned up, Begin pumping Flo -pro down CT & tie in from 10,132' with =16 ft correction. Sit and circ. clean flo -pro around. Close EDC. 22:48 23:12 0.40 10,185 10,321 PROD3 STK TRIP P Stop pumping RIH through window, tagged first billet @ 10321' , Rotate 10 degree, sit down 3K, P/U again and try to roll pumps lightly, made it through. 23:12 00:00 0.80 10,321 11,267 PROD3 STK TRIP P Dry tag TOB @ 11267'. P/U and start pumps. 01/13/2010 Kicked off Billet from 11266' to 11276'. Continue to drill ahead. Drilled into fault & A -3 shale. Drilled additional 150 ft for data, POOH for Anchored billet assembly 00:00 04:00 4.00 11,267 11,268 PROD3 STK KOST P RIH slowly with pumps on and start K/O @ 11266'. Had 2 stalls @ 11266.2, P/U and start milling @ 11265.7' Getting Al. shaving in returns from 11266.4'. Page 21 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:30 1.50 11,268 11,276 PROD3 STK KOST P Had stall 1.5' into billet. Continue time drilling, good Al. shaving in returns. Milling ahead @ 3ft hr for 1 ft, 10 fph for 5, 20 fph for 2ft. Total of 3 stalls for Billet. 05:30 06:00 0.50 11,276 11,276 PROD3 STK KOST P PUH, offline with pumps performing dry run up /down through side track. Looks good, RIH to drill 06:00 09:00 3.00 11,276 11,416 PROD3 DRILL DRLG P Drill Ahead 40 -60 FPH, 1.5K DHWOB, 1.3 BPM in, 1.2 BPM out, 3850psi CTP, 4020 BHP, 13.4 ECD 09:00 10:30 1.50 11,416 11,416 PROD3 DRILL WPRT P Wiper trip back to window 10227', 32K PUW. 10:30 12:30 2.00 11,416 11,498 PROD3 DRILL DRLG P Drill Aead 40-60 FPH, 2 -2.25K DHWOB, 1.33 BPM in, 1.23 BPM out, 3872 CTP, 4020 BHP, 13.4 ECD. 12:30 13:00 0.50 11,498 11,500 PROD3 DRILL DRLG P Stall X 3, offline with pumps PU, 30K PUW. RBIH 13:00 14:30 1.50 11,500 11,566 PROD3 DRILL DRLG P Drill Ahead 25 -30 FPH, 1 -1.5K DHWOB, 1.36BPM in, 1.2 BPM out, 3930 CTP, 4060 BHP, 13.5 ECD 14:30 16:30 2.00 11,566 11,566 PROD3 DRILL WPRT P Wiper trip to window 10227', 30K PUW 16:30 18:30 2.00 11,566 11,716 PROD3 DRILL DRLG P Drill Ahead 50 -60 FPH, 1 -2K DHWOB, 1.33 BPM in, 1.21 BPM out, 3984 CTP, 4050 BHP. Start adding citric acid into active mud system lowering the PH. .6Lb/bbrl. Drill final 150 ft for formation data. 18:30 21:30 3.00 11,716 72 PROD3 DRILL TRIP T Wiper trip to window, circulating in lower pH mud. POOH for Billet assembly following MP schedule. 21:30 23:30 2.00 72 0 PROD3 DRILL PULD T Safety meeting & Undeploy BHA # 17. Choke B is leaking by, swap to choke A. BHA & Bit came out looking good. 1:1 on bit for re -run. Repair choke B offline (seat washed out). 23:30 00:00 0.50 0 0 PROD3 STK SFTY T P/U and set in Billet. Hold deployment safety meeting. 01/14/2010 P/U OH Anchored Billet, set © 11323', POOH P/U BHA #19, tool failure. Undeploy, P/U BHA# 20 with 1.1 AKO with re -run Bi- center. 00:00 00:30 0.50 0 73 PROD3 STK RGRP T Deploy BHA # 18. Drillers side PDL rope socket pulled out after BHA was set in rams. Hold Pre -job prior to continue next steps. Slip and cut with rope socket installation was performed earlier today. 00:30 03:00 2.50 73 73 PROD3 STK PULD T Removed PDL & continue with deployment. Service injector, gripper blocks. 03:00 06:30 3.50 0 10,116 PROD3 STK TRIP T Open EDC & RIH pumping .3 bpm following choke schedule. 06:30 06:45 0.25 10,116 10,126 PROD3 STK DLOG T Tie in depth +2 Correction Page 22 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:15 0.50 10,126 11,334 PROD3 STK TRIP T Record up and down weights before entering OH, 26K up, 4.5K down, RIH to setting depth, close EDC 07:15 07:30 0.25 11,334 11,334 PROD3 STK WPST T On depth, Set billet/OH anchor. 4500psi CTP, PUH 26K. TOB 11323'. 07:30 12:00 4.50 11,334 0 PROD3 STK TRIP T POOH, 25K CTW, 1.2BPM in, 1 BPM out, 3100psi CTP, 3860 BHP 12:00 12:45 0.75 0 0 PROD3 STK PRTS T At surface, close 2 3/8" deployment rams preparing for undeployment. pressure test PDL 1500psi, Pull test rope socket to 1000psi hydraulic psi. Good Tests 12:45 13:15 0.50 0 0 PROD3 STK SFTY T Hold PJSM for undeployment 13:15 18:15 5.00 0 0 PROD3 STK PULD T Undeploy BHA # 18, Perform function test on BOP's sceduled for the 15th. Deploy BHA # 19, change stripper rubber 18:15 19:15 1.00 0 0 PROD3 STK PULD T Power up the tool . prior to RIH and no communication with the BHA. Troubleshoot at surface. Still not communicating properly, Good comms through CT but not through BHA. Safety meeting to Undeploy 19:15 22:45 3.50 0 72 PROD3 STK PULD T Undeploy BHA and research tool. Iayed down BHA and found the short to be in the Power Comms also replaced UQC. Make up new BHA & Deploy 22:45 00:00 1.25 72 PROD3 STK TRIP T Start to RIH with EDC open pumping 1 bpm. following choke schedule 01/15/2010 KO Top of Billet © 11323', No stalls. Continue drilling lateral, hit shales @ 11360', Drill to 11784'. Spot liner pill, POOH pumping KWF. 00:00 02:00 2.00 10,000 11,323 PROD3 STK TRIP T RIh, Tie in + 2 ft correction. Window & upper billet clean. Begin pumping new Mud down CT. Dry tag TOB @ 11,323.2 02:00 05:00 3.00 11,322 11,324 PROD3 STK MILL T P/U weight off bottom, 26K - new mud at bit. Start pumping. Start time drilling from 11,321.7 ft. Circ. pressure 3350 psi, 1.4 BPM, ECD 12.9, CT weight 6.3K, BHP 3880. Good Al. cutting in returns © 11,322.3 _ continue time milling. 05:00 06:00 1.00 11,324 11,330 PROD3 STK MILL T Increase to 3 fph for 2 ft, good Al. cutting over shakers. 1.4 bpm, @ 3380 psi, WHP 140, BHP 3880, ECD 12.9, Ct weight 6 K, WOB .5 Increase to 10 fph for 5' & 20 fph for 2ft. No stalls 06:00 09:30 3.50 11,330 11,475 PROD3 DRILL DRLG T Drill Ahead 30 -50 FPH, 1.6K WHOB, 1.37 BPM in, 1.2 BPM out, 3812 CTP, 3550 psi off bottom CTP, 09:30 11:00 1.50 11,475 11,475 PROD3 DRILL DRLG T Wiper Trip back to window 10227', 32K PUW Page 23 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:15 1.25 11,475 11,532 PROD3 DRILL DRLG T Drill Ahead 30 -60 FPH, 2K WOB, 1.37 BPM in, 1.2 BPM out, 3700 on bottom CTP, 3311 off bottom CTP. 12:15 12:30 0.25 11,532 11,532 PROD3 DRILL WPRT T BHA Wiper, 27K PUW. 12:30 13:00 0.50 11,532 11,570 PROD3 DRILL DRLG T Drill Ahead 40 -50 FPH, 2K WOB, 1.3 BPM in, 1.2 BPM out. 3800 on bottom, 3400 psi off bottom. 13:00 13:15 0.25 11,570 11,570 PROD3 DRILL WPRT T BHA wiper trip 27K 13:15 13:36 0.35 11,570 11,590 PROD3 DRILL DRLG T Drill Ahead 50 FPH, 2.2K WOB, 1.4 BPM in 1.24 BPM out, 3780 CTP, 3940 BHP, 150 WHP, 13 ECD. 13:36 13:42 0.10 11,590 11,590 PROD3 DRILL WPRT T BHA wiper trip 26K 13:42 14:03 0.35 11,590 11,610 PROD3 DRILL DRLG T Drill Ahead 50 FPH, 1.7K WOB, 1.4 BPM in 1.24 BPM out, 3780 CTP, 3950 BHP, 150 WHP, 13 ECD. 14:03 14:09 0.10 11,610 11,610 PROD3 DRILL WPRT T BHA Wiper trip 25K 14:09 14:30 0.35 11,610 11,630 PROD3 DRILL DRLG T Drill Ahead 70 FPH, 1.8K WOB, 1.4 BPM in 1.24 BPM out, 3780 CTP, 3953 BHP, 148 WHP, 13 ECD. 14:30 16:30 2.00 11,630 11,630 PROD3 DRILL WPRT T Wiper trip back to window 10227', 26K PUW 16:30 20:30 4.00 11,630 11,780 PROD3 DRILL DRLG T TD lateral due to once again encounter upgly shale crossed @ 10,360' 20:30 22:30 2.00 11,780 11,784 PROD3 DRILL WPRT T Wiper trip with Tie in with +5 ft correction. RIH tag TD @ 11,784' pumping liner pill) followed by KWF 22:30 00:00 1.50 11,784 5,000 PROD3 DRILL DISP T Liner pill @ nozzle, POOH spotting. Stop & flag pipe 100 ft off setting depth @ 10,947' & 100' above window @ 9392'. Open EDC. Circ KWF while POOH following choke schedule. 01/16/2010 RIH and set liner from 11,765 to 11097'. Tag TOB @ 11097.2, Kick off Billet - No Stalls. 00:00 01:30 1.50 5,000 71 PROD3 DRILL TRIP T Continue to POOH pumping KWF. Returns coming back 12.3 - 12.5 start saving. 01:30 02:00 0.50 71 0 PROD3 DRILL SFTY T CT @ surface Monitor well for 30 minutes and have P/U liner Safety meeting. Lay down BHA. 02:00 04:00 2.00 0 0 COMPZ CASING PUTB T Bring down top drive for service & warm up. Set up rig floor for running liner. Have a safety Stand drill. 04:00 06:00 2.00 677 728 COMPZ CASING PUTB T Start picking up liner. Flow check well. Continue picking up liner. P/U Coiltrak assembly. 06:00 06:30 0.50 728 728 COMPZ CASING SFTY T Crew Change, Hold PJSM 06:30 07:45 1.25 728 728 COMPZ CASING PULD T Conitnue MU CoilTrack to Inj. 07:45 10:15 2.50 728 10,050 COMPZ CASING RUNL T RIH 10:15 11:09 0.90 10,050 10,050 COMPZ CASING DLOG T Tie into EOP flag +1 correction, PUW 25K, RIH Page 24 of 29 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:09 11:24 0.25 10,050 11,762 COMPZ CASING RUNL T On depth with liner, Online with pumps set liner /OH anchor, 4300psi sheared, Top of billet = 11095'. PUH, PUW =25K, Line up across the top to pump 12.7 Formate keeping hole full. 11:24 14:24 3.00 11,078 0 COMPZ CASING RUNL T Subtract Liner out of bit depth. POOH 14:24 15:00 0.60 0 0 COMPZ CASING CIRC T At surface, Displace 20 bbls water (1/2 drum Kla- Gaurd, 11sks KCL, 1.5 sks Flo -Vis, 2 -cups soda ash) into reel. Hold PJSM 15:00 17:30 2.50 0 0 COMPZ CASING PULD T Lay down BHA, Service injector head, increase chain and traction psi on injector head. PU/MU drilling BHA. 17:30 18:00 0.50 0 72 COMPZ CASING CIRC T Circulate 9.1 water cut flo pro displacing remaining 9.3 Flo -Pro out of CT. 18:00 22:00 4.00 72 10,130 PROD4 STK TRIP T RIH with EDC closed & not pumping. Tie in depth. Open EDC & start to circulate B/U with spacer pill to push out KWF. Start capturing fluid from 12.3 ppg, 83 bbls recovered. Close EDC RIH 22:00 23:00 1.00 10,130 11,097 PROD4 STK MILL T Dry tag TOB © 11097.8', P/U weight 25K, Start pumping @ 1.5 bpm, 3800psi, BHP 3850, CT weigth 6K, ECD 12.9. Start time milling © 11097.2' 23:00 00:00 1.00 11,097 11,100 PROD4 STK MILL T Geting good aluminum returns over shakers 11098'. 1.5 bpm, 3800 psi, BHP 3854, ECD 12.88, WHp 50, CT weight 5K. Conitnue milling Billet. 2, 3, & 10 fph. Very smooth milling, No stalls. 01/17/2010 Continue Drilling ahead as planned, perfromed Mud swap with 1350 ft drilled on system. Hit fault @ 11990'. Continue drilling ahead. 00:00 01:30 1.50 11,103 11,115 PROD4 STK MILL T Completed Billet K/O. Good Al. returns through entire billet. Auto pilot billet entire process. Zero Stalls. 01:30 02:00 0.50 11,115 11,115 PROD4 STK REAM T Back ream 25 right/25 left. Did not down -ream. Dry run looked clean. 02:00 03:00 1.00 11,115 11,265 PROD4 DRILL DRLG T Drill head from 11,116' 1.43 bpm, 3700 psi, BHP 3830, ECD 12.90, WHP 90, WOB 1.8, Ct weight 5k, ROP 100 fph. No fluid losses. 03:00 04:30 1.50 11,265 11,265 PROD4 DRILL WPRT T Wiper trip to window, P/U 26K. Clean through Billet. 04:30 06:15 1.75 11,265 11,415 PROD4 DRILL DRLG T Drilling ahead - 1.4 bpm, circ 3750psi, WHP 80, BHP 3850, ECD 12.9, CT weight 3K, WOB 1.5, ROP 95 06:15 07:45 1.50 11,415 11,415 PROD4 DRILL WPRT T Wiper trip back to window, 27K PUW. Drilling parameters show drilling shale Page 25 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 09:00 1.25 11,415 11,565 PROD4 DRILL DRLG T Drilling ahead - 1.4 bpm, circ 37000psi, WHP 100, BHP 3910, ECD 12.9, CT weight 3K, WOB 1.9, ROP 100 09:00 11:00 2.00 11,565 11,565 PROD4 DRILL WPRT T Wiper trip back to window, 27K PUW. Tie into RA marker +4 correction 11:00 12:15 1.25 11,565 11,714 PROD4 DRILL DRLG T Drilling ahead - 1.38 bpm, circ 3750psi, WHP 117, BHP 3920, ECD 12.9, CT weight 3K, WOB 1.85, ROP 100 -120. 12:15 14:30 2.25 11,714 11,714 PROD4 DRILL WPRT T Drilling show drilling shale, Wiper trip to window, 30K puw 14:30 16:30 2.00 11,714 11,865 PROD4 DRILL DRLG P Drill Ahead, 1.37 BPM in, 1.34 BPM out, 3765 CTP, 0 WHP, 3900 BHP, 13 ECD, 2K CTW, 1.8K WOB, Break through within a foot. Drill ahead 1K WOB, 50 -100 FPH Back on planned Time 16:30 18:30 2.00 11,865 11,865 PROD4 DRILL WPRT P Wiper trip back to window, 28K PUW 18:30 20:15 1.75 11,865 11,990 PROD4 DRILL DRLG P BOBD - CT weight 0, WOB 1.7, pumping 1.41 bpm @ 3900 psi, returns 1.3 bpm, WHP 0, BHP 3977, ECD 13.25, ROP 80 fph. Start pumping new mud down CT. Tool glitched twice (Gamma). 20:15 20:45 0.50 11,990 11,990 PROD4 DRILL WPRT P New mud out Bit - 200' Wiper due to CT weight stacking & getting close to 12,000 (possible fault/fracture). CT weight 30K off bottom. Swap pumps. 20:45 21:15 0.50 11,990 12,030 PROD4 DRILL DRLG P Drilling fault - CT WEIGHT -10K, WOB 1K, 145 BPM, 3800 PSI, BHP 3950, ROP 15, ECD 13.2. drilled through @ 11,998' - CT WEIGHT 1 K, WOB, 1K, ROP 100, BHP 3900, ECD 13, - Drill to 12,030 for gamma survey. No fluid losses. 21:15 23:30 2.25 12,030 12,030 PROD4 DRILL WPRT P Wiper trip - CT P/U weight 28K. + 4 correction on tie in. 23:30 00:00 0.50 12,030 12,049 PROD4 DRILL DRLG P On bottom drilling - CT weight 1 K, WOB 1.3, 1.43 BPM, CIRC 3600, BHP 3880, ECD 12.9, ROP 95. 01/18/2010 Drill ahead to 12180', Gamma failed. POOH - P/U BHA# 23 with Agitator & 2.3 AKO. Begin drilling ahead on final lateral. Total of 51 bbls lost in 24 hrs. 00:00 01:00 1.00 12,049 12,110 PROD4 DRILL DRLG P Drilling ahead - CT 2K, WOB 1.4, 1.43 BPM, CIRC 3750, BHP 3885, ECD 12.9, ROP 70. Another fault drilled @ 12043'. Rate out dropping from 1.36 to 1.25 bpm. 100' ft wiper. Little sticky on P/U weights @ 12055'. Gamma stopped working on bottom, P/U and it started to work again Page 26 of 29 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 12,110 12,150 PROD4 DRILL DRLG P Drilling - CT WEIGHT 2K, WOB 1.3, 1.48 BPM, CIRC 3850, BHP 3900, ECD 13, ROP 70, RATE OUT 1.40 BPM. No fluid losses last hour. Gamma failed again. 02:00 03:00 1.00 12,150 12,180 PROD4 DRILL DRLG P Wiper trip 500' to discuss BHA due to tool failure Gamma & Direction. Formation or BHA is not allowing us to build. Holding angle but not building @ 90 degrees. 2 bbls loss last hour. Trip back to bottom drilled another 30'. 03:00 06:00 3.00 12,180 12,180 PROD4 DRILL TRIP T POOH for BHA change. Gamma has failed & cannot build in formation. 06:00 06:30 0.50 12,180 500 PROD4 DRILL SFTY T Crew change, PJSM 06:30 08:30 2.00 500 0 PROD4 DRILL PULD T At surface, Undeploy BHA, service injector head, Inspect BHA for orientation problems due not building. Looks Good. 08:30 11:00 2.50 0 0 PROD4 DRILL PULD T MU new BHA, with 1.3 AKO and RR Razor. Deploy BHA 11:00 13:15 2.25 0 10,116 PROD4 DRILL TRIP T RIH 13:15 13:30 0.25 10,159 10,161 PROD4 DRILL DLOG T Tie in depth to gamma, +2'. Close EDC RIH 13:30 15:00 1.50 12,020 12,170 PROD4 DRILL DLOG T Madd Pass 4' /min, minimum rate 15:00 17:15 2.25 12,170 12,330 PROD4 DRILL DRLG P Drill Ahead 1.36 BPM in, 1.25 BPM out, 43 WHP, 3970CTP, 12.9 ECD, 3879 BHP, -2 CTW, 1.7 WOB, 80 FPH. Much excess drag for the first 100' or so: coil weight -10K. Cleared up once we stopping building and started turning. 17:15 19:45 2.50 12,330 12,330 PROD4 DRILL WPRT P Wiper Trip to window, 31K PUW 19:45 21:30 1.75 12,330 12,450 PROD4 DRILL DRLG P Drill Ahead 1.3 BPM in, 1.3 BPM out, 2K WOB, -4K CTW, 3830 CTP, 0 WHP, 12.9 ECD, 40 -50FPH 21:30 00:00 2.50 12,450 12,450 PROD4 DRILL WPRT P Wiper trip to window. 13 bbls lost during wiper. 01/19/2010 TD well @ 12586. M/U and run 2497.5 feet of liner to TD. Circulate out KWF BOL =12583 TOL= 10085.5 00:00 00:30 0.50 12,450 12,450 PROD4 DRILL WPRT P Wiper 00:30 03:00 2.50 12,450 12,580 PROD4 DRILL DRLG P BOBD - CT weight 2K, WOB 1.7, 1.40 BPM, 3900 PSI, BHP 3880, ECD 12.96, ROP 50. Drill to TD of well. 03:00 06:00 3.00 12,580 12,580 PROD4 DRILL WPRT P Wiper trip to window, tie in +7 ft correction. P/U weight off bottom 35K. 06:00 07:00 1.00 12,580 12,587 PROD4 DRILL WPRT P Tag bottom. TD at 12,587' MD. Start pumping liner bead pill followed by KWF. 07:00 11:00 4.00 12,587 71 PROD4 DRILL TRIP P POOH spotting liner beads & KWF. Page 27 of 29 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 71 71 PROD4 DRILL SFTY P 30 Minute flo -test. No -flo, hold safety meeting to pull BHA. 11:30 12:30 1.00 0 0 PROD4 DRILL PULD P Lay down BHA 12:30 14:00 1.50 0 0 COMPZ CASING SVRG P Bring down Top drive and let it warm up. Service Injector while waiting on Top Drive. Perform Safety joint drill. 14:00 18:00 4.00 0 0 COMPZ CASING PUTB P Begin P/U liner assembly 18:00 19:00 1.00 0 2,541 COMPZ CASING PUTB P Crew change, PJSM, P/U coil track And M/U to liner 19:00 21:45 2.75 2,541 10,144 COMPZ CASING RUNL P Run in hole with liner 21:45 22:45 1.00 10,144 12,583 COMPZ CASING RUNL P Stop and correct @ 7600 EOP Flag @ 10144Bit. -3 foot correction. RIH with liner 8K RIW 22:45 23:00 0.25 12,583 12,562 COMPZ CASING RUNL P Tag bottom, PUW =43k. RBIH and release liner. TOL= 10085.5. PUH 23:00 00:00 1.00 12,562 10,065 COMPZ CASING CIRC P Pump High Vis pill followed by seawater trying to get one for one Remove liner from depth counters, 10065.3 01/20/2010 POOH after releaseing liner. Pump High vis sweep to recover KWF, Set BPV. Blow down Coil. Prep for reel swap 00:00 01:15 1.25 10,065 2,100 COMPZ CASING CIRC P Pump High Vis pill followed by seawater to recover formate KWF. Recovered 73 bbls. POOH. Note: Lost only 24 bbl K- formate this time (14 bbl to formation, 10 bbl interface) as opposed to —85 bbl last time. Difference was due to pumping at slower rate. 01:15 03:15 2.00 2,100 2,100 COMPZ CASING FRZP P PJSM, Heat diesel 80 to 100 degrees, Pump 30 bbls F/P into well, 03:15 05:45 2.50 2,100 71 COMPZ CASING RUNL P Continue out of well 05:45 06:15 0.50 71 71 COMPZ CASING SFTY P Crew change & Undeploy safety meeting 06:15 07:45 1.50 71 0 COMPZ CASING PULD P Undeploy BHA 07:45 10:45 3.00 0 0 DEMOB WHDBO CIRC P Prepare fluid lines and tree for purge and setting BPV 10:45 13:45 3.00 0 0 DEMOB WHDBO MPSP T Prepare to P/U lubricator - had some fitting that need repaired. 13:45 14:45 1.00 0 0 DEMOB WHDBO MPSP P P/U BPV lubricator, pressure test and prepare to set valve. Had problems getting off the BPV due to by -pass lever leaking on Lubricator. Dumped Methanol above PBV & diesel is below due to well freeze protect. Page 28 of 29 • 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 16:45 2.00 0 0 DEMOB WHDBO CTOP P Start setting up to purge CT with Air/foam plug. Inject two stages of foam into reel. Build up pressure in CT string and purge with compressor. Repeat. Only 22 bbl of 30 bbl recovered. Rig down iron and lines. 16:45 19:00 2.25 0 0 DEMOB WHDBO SFTY P Crew going in for Safety Stand up & hand over. 19:00 20:15 1.25 0 0 DEMOB WHDBO CTOP P Night crew travel to rig. Pre tower meeting including N2 Reel blowdown 20:15 21:15 1.00 0 0 DEMOB WHDBO CTOP P Rig up N2, Cool Down, Blow down reel to Tiger Tank, Bleed off coil 21:15 00:00 2.75 0 0 DEMOB WHDBO CTOP P Remove UQC, Cut off coil connector, Remove pressure bulkhead and collector Remove inner reel iron Prep coil for internal grapple connector and instal. Rig up pull back cable. 01/21/2010 Rig Release @ 11:00 AM. 00:00 09:00 9.00 0 0 DEMOB WHDBO CTOP P Continue with reel swap. 09:00 11:00 2.00 0 DEMOB WHDBO NUND P ND BOP'S & MP line off Tree. Rig released at 1100 hrs for move to 31 pad. Page 29 of 29 • 0 / -., \',, r 'l l, ' r , (I;;\ `::, f 11 i L i ,c, \\ ii ( ,,,, ) e a / SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. V. Cawvey CT Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -29AL1 ConocoPhillips Alaska, Inc. Permit No: 209 -137 Surface Location: 522' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Bottomhole Location: 1844' FNL, 2188' FWL, Sec. 35, T12N, R8E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -drill the above referenced service well. The Permit is for a new wellbore segment of existing well Kuparuk River Unit 2T -29A, Permit No. 2091360, API No. 50- 029 - 20222 -01. Production should continue to be reported as a function of the original AOI 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). ' cerely, /P Daniel T. Seamount, Jr. / /� Chair DATED this / f day of November, 2009 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RECEIVED • STATE OF ALASKA 1 NOV I 0 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage la. Type of Work: 1b. Proposed Well Class: Development - Oil ❑ Service - Winj 111 • 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 2T - 29AL1 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 12695' • TVD: 5872' ' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation Number): Surface: 522' FSL, 556 FWL, Sec. 1, T11 N, R8E, UM • ADL 25569, 25548 • Kuparuk River Oil Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2394' FSL, 1706' FWL, Sec. 35, T12N, R8E, UM 2667, 2662 12/28/2009 ' Total Depth: 9. Acres in Property: 14. Distance to 1844' FNL, 2188' FWL, Sec. 35, T12N, R8E, UM 2560 Nearest Property: 3837' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: - 122 feet 15. Distance to Nearest Well Open Surface: x - 498945 • y - 5970503 • Zone 4 GL Elevation above MSL: 80.7 feet to Same Pool: 2T -23 , 1120' 16. Deviated wells: Kickoff depth: 10420 . ft. 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 96.5° deg Downhole: 3822 psig • Surface: 3200 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 - 3/8" 4.7# L - 80 ST - L 1185' 11510' 5898' 12695' 5872' 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) 10570' 6082' cement 0 10101' 10472' 6007' Casing Length Size Cement Volume MD TVD Conductor /Structural 80' 16" 210 sx AS 1 121' 121' Surface 4118' 9 -5/8" 790 sx AS III, 700 sx CI G 4159' 2878' Intermediate Production 10516' 7" 200 sx Class G 10557' 6072' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 10208'- 10224', 10246- 10259', 10265' - 10278' 5806- 5815', 5832'- 5842', 5847-5857' 20. Attachments: Property Plat ❑ BOP Sketch Ei Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: i ' do q/ D 22. I hereby certify that the foregoing is true and correct. Contact Jill Lo g @ 263 - 4093 Printed Name Von Cawvey @ 265 -6306 Title CT Drilling Manager Signature Phone u " 3 Date ,i/9 / ,y Commission Use Only / Permit to Drill / API Num : Permit Approv See cover letter Number: /i � _ 76 50- /6)3 �ZZ.' ?-7-2 Date: // /67 �,/' for other requirements v Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed ethane, gas hydrates, or gas contained in shales: f 4/060 Psi 6F e s-f— Samples req'd: Yes ❑ No Li ' Mud log req'd: Yes ❑ No Er Other:, ZSoo 1° s ` nK n 4,41. - S - F 1 H2S measures: Lr Yes "No ❑ Directional svy req'd: Yes No ❑ /' Q Gx-:" J `"" A/0 445 /` / APPROVED BY THE COMMISSION / / vi 7 DATE: aell COMMISSIONER Form 10-401 (R 7/2009) This permit is valid for 24 months Pap a d = a proval 20 AAC 25.005(g)) Submit in Duplicate �' « /r170? /,moo, � 1. ,� BAKER HUGHES INTEQ ConocoPhillips(Alaska) Inc. • Kuparuk River Unit Kuparuk 2T Pad ( 2T -29 Plan 6, 2T -29AL1 C -�� Plan: Plan 6 Baker Hughes INTEQ Planning Report • 29 October, 2009 NOV ConocoPhilhi s p Alaska R ■ Baker Hughes INTEQ *-' MOMS Baker Hughes INTEQ Planning Report COnOCO dIhpS INTEQ Alaska Company: "" ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2T -29 Project: Kuparuk River Unit 1VD Reference: 2T -29 update © 122.00ft (2T -29) • Site: Kuparuk 2T Pad MD Reference: 2T -29 update @ 122.00ft (2T -29) Wells ` : ` . 2T -29 North Reference: True Welber. Plan 6, 2T -29AL1 Suivey Calculation Method: Minimum Curvature Design: Plan 6 Database: EDM 2003.16 Single User Db Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor • Site Kuparuk 2T Pad Site Position: Northing: 5,970,382.43 ft Latitude: 70° 19' 49.129 N From: Map Easting: 498,944.93 ft Longitude: 150° 0' 30.807 W f -D Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° � 2T -29 (7 ) Well Position +NI -S 0.00 ft Northing: 5,970,502.58 ft . Latitude: 70° 19' 50.311 N +E/ W 0.00 ft Easting: 498,944.66 ft • Longitude: 150° 0' 30.815 W �. ---:: Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 80.70ft . --- - WeSbore Plan 6, 2T -29AL1 r - 2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ( °) (nT) BGGM 1/4/2010 17.20 79.76 57,350 Design , Plan 6 0 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,420.00 Vertical Section: Depth From (TVD) " + . +E/-W Direction " (I - (ft) (ft) (0) 41.30 0.00 0.00 20.00 10/29/2009 11 :14 :05AM Page 2 COMPASS 2003.16 Build 71 rI Baker Hughes INTEQ '+►-' M ON IS Baker Hughes INTEQ Planning Report COn000PhiIIpS INTEQ Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2T -29 Project. Kuparuk River Unit TVD Reference: 2T -29 update @ 122.00ft (2T -29) Site: Kuparuk 2T Pad MD Reference: 2T -29 update © 122.00ft (2T -29) Wets: 2T -29 North Reference: True Welbore: Plan 6, 2T -29AL1 Survey Calculation Method: Minimum Curvature Design: Plan 6 Database: EDM 2003.16 Single User Db Survey Toc4 Program Date From To (ft) (ft) Survey (Wepbore) Tool Name Description 50.00 10,199.00 2T -29 Gyro (2T -29) GYD - CT - CMS Gyrodata cont.casing m/s • 10,199.00 10,420.00 Plan 5 (Plan 5, 2T -29A) MWD MWD - Standard 10,420.00 12,695.00 Plan 6 (Plan 6, 2T- 29AL1) MWD MWD - Standard Planned Survey � .;, MD . Inc Azi 'MOSS WS EMI Northing Easdng DLeg V. Sec TFace --- (ft) (") (°) , - (ft) (ft) (ft) (ft) (ft) ( ° 1tOOM (ft) (°) (-- - 10,420.00 91.46 292.49 5,757.19 6,287.65 - 4,525.39 5,976,790.24 494,420.61 0.00 4,360.69 0.00 JJ �.. �. KOP - ..--v. 10,440.00 94.93 294.50 5,756.07 6,295.61 - 4,543.70 5,976,798.20 494,402.30 20.00 4,361.90 30.00 a 2 10,470.00 96.45 300.33 5,753.10 6,309.35 - 4,570.18 5,976,811.94 494,375.82 20.00 4,365.75 75.00 I End of 20 Deg110O' DLS 10,500.00 94.53 310.70 5,750.22 6,326.67 - 4,594.45 5,976,829.27 494,351.55 35.00 4,373.73 100.00 10,570.00 89.60 334.72 5,747.66 6,381.92 - 4,636.49 5,976,884.51 494,309.53 35.00 4,411.27 101.00 4 10,600.00 89.61 345.22 5,747.86 6,410.07 - 4,646.75 5,976,912.66 494,299.28 35.00 4,434.21 90.00 10,670.00 89.67 9.72 5,748.31 6,479.47 - 4,649.81 5,976,982.05 494,296.22 35.00 4,498.38 89.93 0 5 10,700.00 89.86 20.22 5,748.43 6,508.41 - 4,642.07 5,977,010.99 494,303.97 35.00 4,528.22 89.00 10,730.00 90.05 30.72 5,748.45 6,535.45 - 4,629.19 5,977,038.03 494,316.85 35.00 4,558.04 88.96 End of 35 DegM00' DLS 10,800.00 90.20 39.12 5,748.30 6,592.80 - 4,589.15 5,977,095.36 494,356.89 12.00 4,625.62 89.00 10,900.00 90.40 51.12 5,747.77 6,663.23 - 4,518.43 5,977,165.78 494,427.62 12.00 4,716.00 89.02 10,910.00 90.42 52.32 5,747.70 6,669.43 - 4,510.58 5,977,171.97 494,435.47 12.00 4,724.50 89.08 7 10,990.00 86.07 60.88 5,750.16 6,713.40 - 4,443.90 5,977,215.93 494,502.15 12.00 4,788.63 117.00 8 11,000.00 86.07 59.68 5,750.84 6,718.34 - 4,435.24 5,977,220.87 494,510.81 12.00 4,796.24 -90.00 10/29/2009 11 :14 :05AM Page 3 COMPASS 2003.16 Build 71 BAntill Baker Hughes INTEQ MOM Baker Hughes INTEQ Planning Report COnOCOPhilliPS INTEQ Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 2T-29 Project: Kuparuk River Unit TVD Reference: 2T-29 update © 122.00ft (2T-29) Site: Kuparuk 2T Pad MD Reference: 2T-29 update © 122.00ft (2T-29) Weft: 2T-29 North Reference: True WelMore: Plan 6, 2T-29AL1 Survey Calculation Method: Minimum Curvature Design: Plan 6 Database: EDM 2003.16 Single User Db Planned Survey MD Inc Azi IVDSS PUS EIW Northing Eroding DLeg V. Sec TFace (ft) : :r) r}. (ft) (ft) (ft) (ft) (ft) (1100ft) (ft) r) 11,100.00 86.18 47.65 5,757.63 6,777.34 -4,355.01 5,977,279.86 494,591.04 12.00 4,879.12 -89.92 4 , 11,140.00 86.26 42.84 5,760.26 6,805.44 -4,326.67 5,977,307.94 494,619.38 12.00 4,915.21 -89.10 ,---- 9 11,200.00 86.92 35.66 5,763.84 6,851.79 -4,288.80 5,977,354.28 494,657.25 12.00 4,971.72 -85.00 11,290.00 87.99 24.90 5,767.85 6,929.31 -4,243.53 5,977,431.80 494,702.52 12.00 5,060.05 -84.57 10 CD 11,300.00 87.99 26.10 5,768.20 6,938.33 -4,239.23 5,977,440.82 494,706.83 12.00 5,070.00 90.00 ,-- 11,370.00 88.02 34.51 5,770.64 6,998.68 -4,203.96 5,977,501.15 494,742.10 12.00 5,138.77 89.96 ,..:. 11 ..„ 11,400.00 87.96 30.91 5,771.69 7,023.90 -4,187.76 5,977,526.37 494,758.30 12.00 5,168.01 -91.00 noramo 11,500.00 87.82 18.90 5,775.39 7,114.37 -4,145.76 5,977,616.83 494,800.32 12.00 5,267.39 -90.87 11,540.00 87.79 14.10 5,776.92 7,152.69 -4,134.41 5,977,655.13 494,811.67 12.00 5,307.28 -90.43 12 11,600.00 88.06 21.30 5,779.09 7,209.77 -4,116.20 5,977,712.21 494,829.89 12.00 5,367.15 88.00 11,700.00 88.57 33.29 5,782.04 7,298.44 -4,070.44 5,977,800.86 494,875.65 12.00 5,466.11 87.74 11,710.00 88.63 34.49 5,782.29 7,306.74 -4,064.87 5,977,809.16 494,881.23 12.00 5,475.82 87.39 13 • 11,800.00 88.84 23.69 5,784.28 7,385.25 -4,021.19 5,977,887.66 494,924.91 12.00 5,564.54 -89.00 11,880.00 89.06 14.09 5,785.75 7,460.84 -3,995.32 5,977,963.23 494,950.79 12.00 5,644.41 -88.76 14 11,900.00 89.15 16.49 5,786.06 7,480.13 -3,990.05 5,977,982.52 494,956.06 12.00 5,664.34 88.00 12,000.00 89.59 28.48 5,787.17 7,572.35 -3,951.88 5,978,074.73 494,994.24 12.00 5,764.06 87.96 12,070.00 89.91 36.88 5,787.47 7,631.22 -3,914.12 5,978,133.58 495,032.01 12.00 5,832.29 87.83 15 12,100.00 90.35 33.30 5,787.40 7,655.76 -3,896.87 5,978,158.12 495,049.25 12.00 5,861.25 -83.00 12,200.00 91.79 21.39 5,785.53 7,744.41 -3,851.03 5,978,246.75 495,095.11 12.00 5,960.23 -83.01 12,250.00 92.49 15.42 5,783.66 7,791.79 -3,835.26 5,978,294.13 495,110.88 12.00 6,010.16 -83.23 16 10/29/2009 11:14:05AM Page 4 COMPASS 2003.16 Build 71 R " Baker Hughes INTEQ ✓ mom Baker Hughes INTEQ Planning Report Conocor-hillips INTEQ Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2T -29 Project: Kuparuk River Unit TVD Reference: 2T -29 update @ 122.00ft (2T -29) Site: Kuparuk 2T Pad MD Reference: 2T -29 update © 122.00ft (2T -29) Welt 2T -29 North Reference: True Wellbore: Plan 6, 2T -29AL1 Survey Calculation Method: Minimum Curvature Design; Plan 6 Database: EDM 2003.16 Single User DI) Planned Survey MD Inc Azi TVDSS NIS ENV Northing Easting DL.eg V. Sec TFace (ft) (") (1 (ft) (ft) (ft) (ft) (t) ( °rtalft) (ft} C) 12,300.00 92.89 21.42 5,781.31 7,839.16 - 3,819.49 5,978,341.49 495,126.66 12.00 6,060.06 86.00 . 12,400.00 93.60 33.41 5,775.63 7,927.62 - 3,773.60 5,978,429.94 495,172.55 12.00 6,158.88 86.28 — 17 „_ 12,500.00 94.77 21.44 5,768.30 8,015.98 - 3,727.74 5,978,518.28 495,218.42 12.00 6,257.59 -84.00 .M .....,. 12,550.00 95.28 15.44 5,763.92 8,063.21 - 3,712.00 5,978,565.50 495,234.17 12.00 6,307.36 -84.88 1 ° 18 12,600.00 95.46 21.46 5,759.24 8,110.41 - 3,696.25 5,978,612.70 495,249.92 12.00 6,357.10 88.00 ° °.;'-' . 12,695.00 95.63 32.91 5,750.03 . 8,194.37 - 3,653.12 5,978,696.65 495,293.06 12.00 6,450.75 88.56 > TD at 12695.00 - 2-3/8" 1 III 10/29/2009 11:14 :05AM Page 5 COMPASS 2003.16 Build 71 Hughes INTE *-` r Baker Hug Q r� NYgNEs Baker Hughes INTEQ Planning Report ConocoPhillips INTEQ Alaska Company: ConocoPhillips(Alaska) inc. Local Co- ordinate Reference: Well 2T -29 Pr*** Kuparuk River Unit TVD Reference: 2T -29 update © 122.00ft (2T -29) Site: Kuparuk 2T Pad MD Reference: 2T -29 update © 122.00ft (2T -29) Weil: 2T-29 North Reference: True Welibore: Plan 6, 2T - 29AL1 Survey Calculation Method: Minimum Curvature Design: Plan 6 Database: EDM 2003.16 Single User Db Targets Target Name bitlrniss target Dip Angle: Dip Dlr. TVD +NI-S +E/-W Northing Easting - Shape (°) (1 (ft) (ft) (ft) (R) (ft) Latitude Longitude • 2T - 29AL1 t4.5 0.00 0.00 5,882.00 6,801.22 - 4,312.40 5,977,303.73 494,633.65 70° 20' 57.188 N 150° 2' 36.837 W - - plan misses target center by 13.41ft at 11145.75ft MD (5882.64 TVD, 6809.67 N, - 4322.80 E) - Point °) 2T -29AL1 t1.5 0.00 0.00 5,879.61 6,268.27 - 4,483.50 5,976,770.86 494,462.49 70° 20' 51.945 N 150° 2' 41.828 W plan misses target center by 46.15ft at 10420.00ft MD (5879.19 TVD, 6287.65 N, -4525.39 E) .- - Point CI ) 2T -29AL1 fault 1 (cop 0.00 0.00 122.00 6,481.74 - 3,958.32 5,976,984.23 494,987.65 70° 20' 54.047 N 150° 2' 26.485 W - plan misses target center by 5775.27ft at 10990.00ft MD (5872.16 TVD, 6713.40 N, - 4443.90 E) *sm7) - Polygon e"= Point 1 122.00 6,481.74 - 3,958.32 5,976,984.23 494,987.65 Point 2 122.00 6,773.65 - 4,590.44 5,977,276.19 494,355.63 2T -29AL1 t7.5 0.00 0.00 5,909.23 7,634.59 - 3,922.32 5,978,136.96 495,023.81 70° 21' 5.386 N 150° 2' 25.450 W - plan misses target center by 8.62ft at 12068.41ft MD (5909.47 TVD, 7629.94 N, - 3915.07 E) - Point 2T -29AL1 t2.5 0.00 0.00 5,870.00 6,415.66 - 4,580.88 5,976,918.24 494,365.14 70° 20' 53.394 N 150° 2' 44.676 W - plan misses target center by 64.48ft at 10582.67ft MD (5869.74 TVD, 6393.58 N, - 4641.45 E) - Point 2T -29AL1 t3.5 0.00 0.00 5,870.00 6,648.69 - 4,465.77 5,977,151.24 494,480.27 70° 20' 55.687 N 150° 2' 41.316 W - plan misses target center by 43.29ft at 10936.02ft MD (5869.83 TVD, 6684.82 N, - 4489.61 E) - Point • 2T -29AL1 fault 2 (cop 0.00 0.00 122.00 6,878.78 - 3,812.35 5,977,381.21 495,133.66 70° 20' 57.953 N 150° 2' 22.225 W - plan misses target center by 5783.54ft at 11178.44ft MD (5884.63 TVD, 6834.59 N, - 4301.74 E) - Polygon Point 1 122.00 6,878.78 - 3,812.35 5,977,381.21 495,133.66 Point 2 122.00 6,837.60 - 4,740.43 5,977,340.17 494,205.66 2T -29AL1 NEW Polyg 0.00 0.00 122.00 6,063.63 - 4,577.33 5,976,566.25 494,368.64 70° 20' 49.932 N 150° 2' 44.566 W - plan misses target center by 5756.26ft at 10500.00ft MD (5872.22 TVD, 6326.67 N, - 4594.45 E) - Polygon Point 1 122.00 6,063.63 - 4,577.33 5,976,566.25 494,368.64 Point 2 122.00 6,332.60 -4,895.41 5,976,835.24 494,050.63 Point 3 122.00 6,671.68 - 4,611.45 5,977,174.24 494,334.61 Point 4 122.00 7,224.81 - 4,259.52 5,977,727.27 494,686.58 Point 5 122.00 8,364.02 - 3,737.69 5,978,866.29 495,208.52 10/29/2009 11 :14 :05AM Page 6 COMPASS 2003.16 Build 71 R / Baker Hughes INTEQ . `Iv = MOMS Baker Hughes INTEQ Planning Report ConocoPhilhhps INTEQ Fuca Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2T -29 Project: Kuparuk River Unit TVD Reference: 2T -29 update @ 122.00ft (2T -29) Site: Kuparuk 2T Pad MD Reference: 2T -29 update © 122.00ft (2T -29) Well: 2T -29 North Reference: True Wellbore: Plan 6, 2T -29AL1 Survey Calculation Method: Minimum Curvature Design: Plan 6 Database: EDM 2003.16 Single User Db Point 6 122.00 8,150.05 - 3,468.62 5,978,652.31 495,477.53 Point 7 122.00 6,740.76 - 4,235.43 5,977,243.26 494,710.60 Point 8 122.00 6,399.68 - 4,496.39 5,976,902.25 494,449.62 Point 9 122.00 6,274.69 - 4,360.35 5,976,777.26 494,585.63 Point 10 122.00 6,063.63 - 4,577.33 5,976,566.25 494,368.64 • 2T -29AL1 t6.5 0.00 0.00 5,899.00 7,153.77 -4,137.30 5,977,656.22 494,808.78 70° 21' 0.656 N 150° 2' 31.726 W -.� - plan misses target center by 3.07ft at 11540.16ft MD (5898.93 TVD, 7152.84 N, - 4134.37 E) - Point " " 2T -29AL1 t5.5 0.00 0.00 5,892.00 6,987.75 - 4,225.16 5,977,490.22 494,720.90 70° 20' 59.023 N 150° 2' 34.291 W ° - plan misses target center by 11.74ft at 11349.84ft MD (5891.94 TVD, 6981.84 N, - 4215.02 E) "" - Point 2T -29AL1 t8.5 0.00 0.00 5,872.00 8,193.90 - 3,689.51 5,978,696.18 495,256.67 70° 21' 10.888 N 150° 2' 18.654 W -° - plan misses target center by 30.81ft at 12678.01ft MD (5873.69 TVD, 8180.02 N, - 3662.05 E) -- 7,* - Point ...;.> Casing Points Measured . " " Vertical Casing Hole Depth Depth Diameter Diameter #(# (ft) Name ( ") r) 4,159.00 9 5/8" 9 -5/8 12 -1/4 12,695.00 5,872.03 2 -3/8" 2 -3/8 3 • 10/29/2009 1 1:14:05AM Page 7 COMPASS 2003.16 Build 71 Baker Hughes INTEQ �� .. NUONIS Baker Hughes INTEQ Planning Report COnOC I INTEQ Alaska C ompany: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 2T -29 Projecf Kuparuk River Unit TVD Reference: 2T -29 update © 122.00ft (2T -29) She: Kuparuk 2T Pad MD Reference: 2T -29 update @ 122.00ft (2T -29) Welt 2T -29 North Reference: True Wellbore: Plan 6, 2T -29AL1 Survey Calculation Method: Minimum Curvature Design: Plan 6 Database: EDM 2003.16 Single User Db Plan Annotations Measured Vertical Local Coordinates DePth Depth > : +N/-s +E!-W (ft} (ft# (ft) (ft) Comment 10,420.00 5,879.19 6,287.65 - 4,525.39 KOP II 10,440.00 5,878.07 6,295.61 - 4,543.70 2 •—°"! 10,470.00 5,875.10 6,309.35 - 4,570.18 End of 20 Deg /100' DLS 10,570.00 5,869.66 6,381.92 - 4,636.49 4 10,670.00 5,870.31 6,479.47 - 4,649.81 5 10,730.00 5,870.45 6,535.45 - 4,629.19 End of 35 Deg /100' DLS 10,910.00 5,869.70 6,669.43 - 4,510.58 7 ';,,.., 10,990.00 5,872.16 6,713.40 - 4,443.90 8 11,140.00 5,882.26 6,805.44 - 4,326.67 9 '' 11,290.00 5,889.85 6,929.31 - 4,243.53 10 11,370.00 5,892.64 6,998.68 - 4,203.96 11 11,540.00 5,898.92 7,152.69 - 4,134.41 12 11,710.00 5,904.29 7,306.74 - 4,064.87 13 11,880.00 5,907.75 7,460.84 - 3,995.32 14 12,070.00 5,909.47 7,631.22 - 3,914.12 15 12,250.00 5,905.66 7,791.79 - 3,835.26 16 12,400.00 5,897.63 7,927.62 - 3,773.60 17 12,550.00 5,885.92 8,063.21 - 3,712.00 18 12,695.00 5,872.03 8,194.37 - 3,653.12 TD at 12695.00 ill Checked By: Approved By: Date: 10/29/2009 11 :14 :05AM Page 8 COMPASS 2003.16 Build 71 'Y1niitliato Tn1e 1 th WELLBORE DETAILS: Plan 6, 2T -29AL1 REFERENCEMFORMRTI N Project: Kuparuk River Unit Mapelt NOM .21.74' nall Site: Kuparuk2T Pad Magnet Feld Parent Wellbore: Plan 5, 2T -29A Coo 198M'�RBIB`Bn`e We12L29,TrueNo4r BAKER '.✓ Well: 2T -29 Strew., 57639.7an Vertical(M)Reference: MeanSeaLeve O IP Mod e t .91' Tie on MD: 10420.00 Wellborc: Plan 6, 2T -29AL1 ion (/s)Raterence: Sol- (o.00N, o.oOt� V ��� P lan: Plan 6 (2T-29/Plan 6, 2T- 29AL1) Mod et Sad MeasuredDepm Rekrenm: 2T-29igd6e ©122.001(T -99) Calculation Whorl MininumCovaure INTEQ 8600 . 2T29AL1 t8.5 WELL DETAILS: 2T -29 8400 Ground Level: 80.70 20L29RPw 4, ■ -29AL I411- TD at 12615.00 +NI-S +01-W Northing Easting Latittude Longitude Slot 0.00 0.00 5970502.58 498944.66 70° 19' 49,225 N 150° 0' 42.037 W 8200 _ 2 29/Plan 6, r -29AL 1 SECTION DETAILS ANNOTATIONS 8000 Sec MD Inc Azi ssTVD 411 -S +E/-W DLeg TFace VSec Target Annotation 7800 2 =zvAL v.9 18 1 10420.00 91.46 29249 5757.19 6287.65 -4525.39 0.00 0.00 4360.69 KOP ` 1,r 2 10440.00 94.93 294.50 575607 6295.61 -4543.70 20.00 30.00 4361.90 2 3 10470.00 96.45 300.33 5753.10 6309.35 - 4570.18 20.00 75.00 4365.75 End of 20 0eg /100'DLS 7600 / 16 4 10570.00 89.60 334.72 5747.66 6381.92 -4635.49 35.00 100.00 4411.27 4 5 10670.00 89.67 9.72 5748.31 6479.47 -4649.81 35.00 90.00 4498.38 5 7400 I 6 10730.00 90.05 30.72 5748.45 6535.45 -4629.19 35.00 89.00 4558.04 End of35Deg1100'DLS 0 0 2T 9AL106.5 l � 7 10910.00 90.42 52.32 5747.70 6669.43 -4510.58 12.00 89.00 4724.50 7 Ni7200 2T 2° - t t5 5 14 • , 8 10990.00 86.07 60.88 575 6713.40 -4443.90 12.00 117.00 4788.63 8 9 11140.00 86.26 42.84 5760.26 6805.44 -432667 12.00 270.00 4915.21 9 13 2T - 29AL1 fault 2 10 11290.00 87.99 24.90 5767.85 6929.31 - 4243.53 12.00 275.00 5060.05 10 S4 ' 7000: 2T z9ALl64.5 11 11370.00 88.02 34.51 5770.64 6998.68 -4203.96 12.00 90.00 5138.77 11 0O J 1. - • 12 11540.00 87.79 14.10 5776.92 7152.69 -4134.41 12.00 269.00 5307.28 12 • 6800" V 13 11710.00 88.63 34.49 5782.29 7306.74 -4064.87 12.00 88.00 5475.82 13 ^ 2T - .9AL1 3.5 ►� 14 11880.00 89.06 14.09 5785.75 7460.84 - 3995.32 12.00 271.00 5644.41 14 C � tl I 2T - 25AL1 Exult I 15 12070.00 89.91 36.88 5787.47 7631.22 - 3914.12 12.00 88.00 583229 15 '5 6600 . - '" '(3 16 12250.00 9249 15.42 5783.66 7791.79 - 3835.26 12.00 277.00 6010.16 16 0 5 I i �� 17 12400.00 93.60 33.41 5775.63 7927.62 - 3773.60 12.00 86.00 6158.88 17 w) 6400' 7f 2941.1 a 9. - 18 12550.00 95.28 15.44 5763.92 8063.21 - 371200 12.00 276.00 6307.36 18 • ' . �� 2T 19 19 12695.00 95.63 3291 5750.03 8194.37 -3653.12 1200 88.00 6450.75 TD at 12695.00 6200 • OP • . ,- �"� 6000 End oC20 Deg/U 1 1 LS 5800 �-�-�+ -5600 -5400 -5200 -5000 ID i -4b a tk?- �UI R4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 i West(- )/East( +) (200 ft/in) 552 ' 558 _ 1 1.111111111 1.111■■ • 0 5640 'aim11.1 2T29Maa 4, 1 29AL _ 1 5700 ",0 =� - '- 2T -23AL1 15.5 2T -:9AL1 16.5 • 5760 n - --- - - - -- / .4 - , • • I Q ■' .1 .111 ' ' 7 0 10 II 12 17 18 2 C -29AL 1 18.5 ° • v 5821 pfd of • 3 i Deg/100' DL 8 2 2T- 29T'lan 6, 2T-29AL1 • 5880 '� , � 11 " = -" 21-29AL t7.5 i .1 H 5940 111iiiiE .2.) 6060 ° y 61L ,____ r m 4260 4320 4380 4440 4500 4560 4620 4680 4740 4800 4860 4920 4980 5040 5100 5160 5220 5280 5340 5400 5460 5520 5580 5640 5700 5760 5820 5880 5940 6000 6060 6120 6180 6240 6300 6360 6420 6480 6540 6600 Vertical Section at 20.00° (60 ft/in) ■ Azimcthe to True North WELLBORE DETAILS: Plan 6, 2T -29AL1 REFERENCE INFORMATION >.'" R Project: Kuparuk River Unit Magnetic North: 21.74° Site: Kuparuk 2T Pad Magnefic Field Parent Wellbore: Plan 5, 2T -29A Co- ordinate (HIE) Reference Well 2T -29, True North BAKER g T e on : MD 104 20.00 Vertical TVD Reference. 27.29 u ate 122.00ft (2T -29 ) Well: 2T -29 so-en the s 78 0 s.7snT ( ) � @ Wellbore: Plan 6, 2T -29AL1 o ri el ° B le:80.01 Section (VS) Reference: Slot- (0.00N, 0.00E) ConoeoPhiliips Plan: Plan 6 (2T -29 /Plan 6, 2T-29AL1) M le 80819 Measured Depth Reference 2T -29 update @ 122.500 (2T -29) HUGHES Calculation Method: Minimum Curvature 9800 I -_ - -_ � ������������� _.� I : 1111111.111111 9600 : -. __ _._. I I � }} I i � I i .` 9400 .�:" 9200 0 I t I I ■ 9000 - —' 1 — - -- . 1111111 ssoo \I � I shoo \ — • T 2 F T I I i I ��21,1�h � a ' "I.-29A 1 1) _� I � - - �s, ` `p, _2 i n "�' I 8200_ I ' . 1 — _._. _ ." 8400 —� I i - _ � 2T 6, 229ALi t 2 i I / O9Z 8000 ( I. C 7800 E , J $OD f 7600 I -� � 7aoo \ 11- N G) o - .7200A ter. -.. t 7000 800 I I ._ _.. __ ,, 6600 . _. _ , - 6400 . — __-+ 29/21129 — 1 6200 —i-- _. � ) -_ _ . _.. � , :.t� 1 _ - --- . 60,1- i I _ • 6000 _ 2T-4012T-40 1 j �I ... \ •15.'''''' ' 5800 rss t �, j —I r , \ \I \ , 5600 ( �80(� — , 5400 �.. , a - _. I - - - - -- . _.:. _. _ I 5200 I. !.: _ " ;� � - - - -- ', I I 4800 �— �� I = - 4600 N � 1 1 � '., ?� j JY ) ICI -8000 -7800 -7600 -7400 -7000 - 00 -6600 -6400 -6200 -6000 I L), j 1 — - \ -1000 4400, — 2T -291P1 s z A 00 -7200 7000 68 - - 00 -5800 -5600 -5400 -5200 -5000 - 4800 -4600 -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 2T -29 update @ 122.00ft (2T -29) West( -) /East( +) (200 ft/in) • Conoc P h i l l i s p Alaska RECEIVED P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 NOV 1 0 2009 November 6, 2009 itiaskE Oil & Gas cons. Commission Anchorage Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill three lateral sidetracks out of Kuparuk Well 2T -29 (PTD# 195 -075) using the coiled tubing drilling rig, Nabors CDR2 -AC. Work is scheduled to begin on 2T -29 as early as mid - December 2009. The CTD objective is to drill three lateral sidetracks (2T -29A, 2T -29A L1, and 2T -29A L1 -01) that will serve as injection wells into the A2 & A3 - sands across faults into unsupported areas. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 2T -29A, 2T -29A L1, and 2T -29A L1 -01 — Proposed Schematic — BOP Schematic — Detailed Summary of Operations — Directional Plans — Quarter Mile Injection Review If you have any questions or require additional information please contact me at 907 - 263 -4093. Sincerely, Jill Lon: IQI Coiled ubing Drilling Engineer 11 • • Permit to Drill Summary of Operations KRU 2T -29A, 2T -29A L1, and 2T -29A L1 -01 Lateral Coiled Tubing Drilling Overview: Existing well 2T -29 is a 3.5" single completion with no history of annular communication issues. The well currently injects into the A3 and A2 sands and potentially supports wells 2T -23 and 2T-40. The purpose of the 2T -29 CTD sidetracks will be to improve injection support to the aforementioned producing patterns and CTD producer 2T -27A by extending injection across faults into unsupported areas. This will be achieved by drilling three laterals: 2T -29A, 2T- 29AL1, and 2T- 29AL1 -01. A cement plug was pumped into the 2T -29 motherbore on October 8, 2009, isolating the existing perforations. A 2.80" pilot hole will then be drilled on the high -side of the 7" casing allowing for the setting of a mechanical whipstock. The first lateral, 2T -29A, will be drilled south into the A2 sand to support 2T-40. The lateral will kick off the ' whipstock at 10,208' MD in the A3 sand. The lateral will land in the base of the A2 pay then slowly invert to crest in the upper A2 pay. The wellbore will then drop down through the A2 pay, crossing a single fault and reaching total depth in the base of the A2 pay at the planned depth of 13,065' MD. The lateral will be completed with a 2.375 ", 4.7 ppf, slotted liner with an aluminum billet placed at 10,420' MD that will serve as the kick off point for • 2T- 29AL1. The second lateral, 2T- 29AL1, will be drilled north into the A2 sand to support 2T -27A and 2T -23. This lateral is • planned to kick off of the aluminum billet set in 2T -29A at —10,420' MD. The lateral will be drilled north in the A2 crossing two large faults and significant down dip. The last 500' drilled will be inverted to crosscut the A2 section and reach the planned total depth at 12,695' MD. The lateral will be completed with a 2.375 ", 4.7 ppf, slotted liner with a liner top aluminum billet placed at 11,510' MD for the kick off point for 2T- 29AL1 -01. The third lateral, 2T- 29AL1 -01, will be drilled north into the A3 sand to support 2T -27AL1 and 2T -23. The lateral is planned to kick off of the aluminum billet set in 2T -29AL1 at —11,510' MD. The kickoff point is in the A2 sand and the well will invert north into the A3 sand and drill horizontally to the planned total depth point at 12,779' MD. No fault crossings are planned in this lateral, as the kickoff point is past the second and final fault crossing. The lateral will be completed with a 2.375 ", 4.7 ppf, slotted liner with a liner top placed at —10,113' MD in the 2T -29 motherbore tubing tail. The drill -in fluid for all laterals will be Flo -Pro xanthan -based polymer with potassium chloride. The managed pressure drilling technique will be applied to manage bottomhole pressure, thereby minimizing hole stability problems and reducing mud cost. Page 1 of 5 DUPLICATE 11 /6/2009 • Permit to Drill Summary of Operations Cont. KRU 2T -29A, 2T- 29AL1, & 2T- 29AL1 -01 Operational Outline Pre -Rig Work 1. Mill out the 2.75" D- nipple to 2.80" with a left hand motor- done 2. Tag fill and obtain a SBHP survey- done 3. Lay in cement plug in the 7" casing annulus below the tubing tail (NOTE: kickoff point target depth is 10280')- done 4. Mill out cement & cement sheath in tubing down to the tubing tail- done 5. Tag top of cement- done 6. Prepare wellsite for rig arrival Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. Window Milling a. Mill a 2.80" pilot hole in the cement below the tubing tail to 10260' MD . b. Drift pilot hole for whipstock c. Set mechanical whipstock at 10208' MD with 0° high side orientation d. Mill 2.80" window at 10208' 3. 2T -29A Lateral a. Drill 2.70" x 3" bi- center lateral to the south at a TD of 13065' MD • b. Run the 2645' of 2 slotted liner from TD to 10420'. An open -hole aluminum billet will be placed at 10420'. 4. 2T -29A L1 Lateral • a. Kick off of the open -hole aluminum billet at 10420' MD at a tool face setting of -30 right of high side t� b. Drill 2.70" x 3" bi- center lateral to the south at a TD of 12695' MD 9 c. Run the 1185' of 2%" slotted liner from TD to 11510'. An open -hole aluminum billet will be placed at 11510'. 5. 2T -29A L1 -01 Lateral a. Kick off of the open -hole aluminum billet at 11510' MD at a high side tool face setting. b. Drill 2.70" x 3" bi- center lateral to the south at a TD of 12779' MD c. Run the -2666' of 2 %" slotted liner from TD up into the tubing at 10113' MD. The liner top will be completed with a 2 -5/8" deployment sleeve with 5' seals. 6. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Post - Rig Work 1. Obtain SBHP 2. Flowback to tanks for well cleanup 3. Begin injection r'" Page 2 of 5 11/6/2009 • • Permit to Drill Summary of Operations Cont. KRU 2T -29A, 2T- 29AL1, & 2T- 29AL1 -01 Mud Program • Chloride -based Biozan brine (9.6 ppg) for milling operations, and chloride -based Flo -Pro mud ( -10.0 ppg) for drilling operations. • There is not a SCSSV installed in 2T -29 so the well must be loaded with overbalanced fluid prior to running the 2%" slotted liner. Disposal: • No annular injection on this well. • Class 11 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 Liner Liner Liner Liner Liner Details Other Details Top Btm Top Btm MD MD SSTVD SSTVD 2T -29A 10420 13065 5756 5748 2 ", 4.7 #, L -80, Aluminum billet ST -L slotted 2T - 29A L1 11510 12695 5776 5750 2%", 4.7 #, L -80, Aluminum billet ST -L slotted 2%", 4.7 #, L -80, Top of liner will have a 2T - 29A L1 - 10113 12779 5621 5733 ST -L slotted 2-5/8" deployment sleeve with 5' seals Existing Completion Details: Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.58 H-40 Welded 0 78 0 79 1640 630 Surface 9 5 / 8 " 40 L -80 BTC 0 4159 0 2878 5750 3090 Casing 7" 26 L -80 BTC 0 10557 0 6072 7240 5410 Tubing 3 %2 " 9.3 L -80 ABM -EUE 0 10120 0 5748 10160 10540 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 4000 psi. Maximum potential surface pressure is 3200 psi assuming a gas gradient to surface based on the most recent bottom hole pressure measurement which was 3822 psi at 5721' TVDSS on September 30, 2009. Since being shut -in on February 20, 2009, the maximum surface tubing pressure seen during well service events was 2700 psi on February 27, 2009. The last well service event prior to cementing (October 5, 2009) showed a surface tubing pressure of 1450 psi. • The annular preventer will be tested to 250 psi and 2500 psi. ' i t rs. 1 t o "r Page 3 of 5 11/6/2009 • Permit to Drill Summary of Operations Cont. KRU 2T -29A, 2T- 29AL1, & 2T- 29AL1 -01 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 2T -29 A 2946' 2T -29 A L1 3837' 2T -29 A L1 -01 4348' • Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset Well 2T -29 A 1260' 2T -02 2T -29 A L1 1120' 2T -23 2T -29 A L1 -01 1028' 2T -23 Logging MWD directional, resistivity, and gamma ray will be run over the entire open - hole sections. . Quarter Mile Injection ection Review � Two existing wellbores are within a quarter mile of the planned 2T -29 laterals: 2T -02 and 2T -23. 2T -02 2T -02 is a single injector in the Kuparuk A sands with perforations in the A2 and A3 sands. The minimum distance (i.e. closest proximity) from any of the 2T -29 laterals to the wellbore trajectory in the 2T -02 wellbore is 1268 ft. Cement evaluation not necessary since this well is already serving as an injector. 2T -23 2T -23 is a single producer in the Kuparuk A sands with perforations in the A2 and A3 sands. The minimum distance (i.e. closest proximity) from any of the 2T -29 laterals to the wellbore trajectory in the 2T -23 wellbore is 1015 ft. Note: Needs cement evaluation. Also, the cement isolation, packer location, or annular integrity of 2T -29 will not be affected by this proposed CTD sidetracking operation. Hazards • If the first whipstock does not hold due to cement deterioration, there is room to set a second whipstock. In order to minimize the potential for this problem though, motor work and rate will be reduced when running through the pilot hole. • In order to reduce the reservoir pressure seen while drilling, 2T -29 has been shut -in since February 2009. • Wells at Drillsite 2T have a history of subsidence at an average rate of 3.7" /year. 2T -29 has a recorded • subsidence depth of 28 ". Downhole diagnostics were run and indicate that any buckling is minimal and does not currently prevent CTD access. • The maximum H level on the 2T pad is 700 ppm measured on 1/11/09 at 2T -24. 2T -14 is -470' to the . north of 2T -29. All H monitoring equipment will be operational. H measurements in the offset producers are as follows: 2T -23 (65 ppm on 01/11//09); 2T-40 (50 ppm on 01/11//09) n , I! ! °E Page 4 of 5 11/6/2009 • . Permit to Drill Summary of Operations Cont. KRU 2T -29A, 2T- 29AL1, 8 2T- 29AL1 -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 2T -29 does not have a SCSSV, so the well must be loaded with overbalanced 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. Reservoir pressure at the KOP is currently estimated to be 3,763 psi (10208' MD/ 5695' TVDSS). Milling and Drilling Conditions Pumps On Pumps off Mud weight 10 ppg 10 ppg Hydrostatic 2961 psi 2961 psi Annular Friction 919 psi 0 psi Surface Choke 33 psi 951 psi TOTAL 3913 psi 3913 psi EMW 13.2 ppg 13.2 ppg *Assume annular friction is 90 psi /1000 ft at 1.5 bpm Reservoir Pressure Wells 2T -23 and 2T-40 are the closest offset producing wells in the A -sand intervals. They are also the target producing wells for this CTD injection patterns. The most recent static bottom hole pressure readings in each well are as follows: Well name Pressure (psi) SSTVD of Est. Measured Date EMW (ppg) 2T -23 3591 5666 Aug -05 12.2 2T-40 2162 5722 Oct -08 7.3 ' Page 5 of 5 �" "( ` 11/6/2009 • • Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator Riser Annular() Blind / Shear 2" Pipe / Slip (CT) Pump into Lubricator I ���� J ■ above BHA rams QI <' 'i ∎ ' - 1 Choke 1 2 -3/8" Pipe / Slip (BHA) Choke Equalize Manifold X4 2 -3/8" Pipe / Slip (BHA) Kill .jC > \ > <I> — • 1 ► 1 r 8 Blind / Shear 2" Pipe / Slip (CT) Choke 2 1 Swab Valves Wing Valves J L ' v Tree Flow Cross 1 E g Surface Safety Valve BOPE: 7- 1/16 ", 5M psi, TOT Choke Line: 2- 1/16 ", 5M psi Master Valve Kill Line: 2- 1/16 ", 5M psi Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union u PI inATF: 1 2T -29 Proposed CTD Sidetrack 3-1/7 Cam. DS nipple @ 518' MD 3.1/7 9.38 L -80 ABMEUE erd Tubng to surface 16' 6271H-40 shoe a 121' MD i 3-12' Cam. MMM gas S8 mandrels @ 10.040 9-518" 40# L-80 shoe U II 3-12" Cameo W-1 selective lancing nipple @ 10085' MD (2.817 in ID) Baker 949-3 permanent packer @ 10093' MD (3.25" ID) • _ - 3-12 . " Cam D landing nipple *10107 MD (2.75" min ID, No-Go) 3-1/7 tubing tall a 10121' MD i i, 23/8 . 4.7# STL liner top 10113 5' ■and k 7 I KCp 510208' MD I q 41. \\ 3-3/16• •Sot hole 481) lock ,.,,,� � � A. I2T- 29AL1 -01 TO 12779' and (north A3 sand) A3 sand Perk I ' y¢, : �s. 1 1 � 1 . 10208' - 10221' . -...+– ^7 r•¢• y \ i —I— __i i ,. _ . I � mm ✓� t I2T 294 TDf3065'md (south A2 send) jf ` k� � % " r r q3 � � f K A2 sand da �" ,, - 12T•29AL1 TO 5 12895' and (north A2 sand) I F ri 10246 -10257 v.:. � ;y A2 sand perk r:`; Lest kg 10407 10285' - 10276' T`: RKB (913/08) il Aluminum billet ®10420' and Aluminum [Met i. 11510' and 7 L-80 shoe _.. ' - 10557' MD • KRU 2T-29AL1 — Area of Review ' W.SA1 iI nT 3t.7 —J A , ... ':2 _ Only wells KRU 2T -02 and 2T -23 ■ % ', appear to open the Kuparuk � KRU 2? --27A reservoirs within the Area of Review \ T -29AL l 2T-30 !1 2T —L8 t-E000 a \ VAIN �' 2T - 217 ! 2T -20 • �G ,` , • --9 ti 2T -27 .,ea° / T-26 RU T -40 , 2T -217, 1000 f ��aaoo -rood 1 T)). l �m . • � � � � '�r T7���e 1 A .9 r 1i : 2�0 , * °- 7T- 20$PB1 Art �YY► �., . jk f rte r ago . 9' ' 2 0 4 1 I / // / e . ft .ip ,, , ...„, -.ME \ \ ,. \ . 1 - / t' '" ' - hop I L '/ f /CO , „ —1---leg 0-2447-.., \ '• — kl:i ' 411 1 I .. t -?car -- - "i. # . -• s 1. � rill _� -_,_ ,___ - - �'` _ -...' Ilp.Kid„ ' ' ' 0 ' �.�4_` ---..1 :-i°pp Depth increments annotated along well paths —�',, ' '! °;_,t 1 Represent True Vertical Depth Subsea (TVDss) AOGCC SFD 11/12/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME Kuparuk River Unit 2T -29AL1 PTD# 2091370 Development X Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: Kuparuk River POOL: Kuparuk River Oil Pool Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well Kuparuk River Unit 2T -29A, Permit No. 2091360, X (If last two digits in API No. 50- 029 - 20222 -01. Production should continue to be API number are reported as a function of the original API number stated above. between 60 -69) PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 ti ',e Field & Poo KUPARUK RIVER, KUPARUK RIV OIL - 4901 : - .. k - Pool 490100 Well Name: KUPARUK RIV UNIT 2T -29AL1 Program SER Well bore seg 0 PTD#: 2091370 Company CONOCOPHILLIPS ALASKA INC. Initial Class/Type SER / PEND GeoArea 890 __- Unit 11160 On /Off Shore On Annular Disposal ❑ Administration 11 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 025569; top productive interval and TD in ADL 025548 3 Unique well name and number Yes ,4 Well located in a defined pool Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 6 Well located proper distance from other wells Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 2 miles 7 Sufficient acreage available in drilling unit Yes from an external property line where ownership or landownership changes. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 11/12/2009 114 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes Area Injection Order No. 2B 15 All wells within 1/4 mile area of review identified (For service well only) Yes KRU 2T -29, KRU 2T -23 16 Pre- produced injector: duration of pre- production less than 3 months (For service well only) No Well will be cleaned up, but not pre- produced. 17 Nonconven. gas conforms to AS31,05.030( -D) NA 18 Conductor string provided NA Conductor set in 2T -29 Engineering 1 19 Surface casing protects all known USDWs NA Surface casing set in 2T -29 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casings cemented to GL 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 2T -29 122 CMT will cover all known productive horizons No OH slotted liner completion - - 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with Steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 309 -287 26 Adequate wellbore separation proposed Yes Proximity analysis performed. No issues. 27 If diverter required, does it meet regulations NA Wellhead already in place. BOPs installed. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure= 3822 psi (12.8 ppg) Will drill with 1Oppg mud using MPD (managed pressure drilling) GLS 11/17/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 3200psi Will test BOP to 4000 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes 1 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on 2T pad. Rig has alarms and sensors. 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR complete. All wells within 1 /4mi cemented in Kuparuk zone. 1 35 Permit can be issued w/o hydrogen sulfide measures No H2S => 50 ppm has been measured in 2T -Pad wells. Measures must be taken. Geology 136 Data presented on potential overpressure zones Yes Expected reservoir pressure is up to 12.5 ppg EMW; will be drilled with 10.0 ppg mud using Appr Date 1 37 Seismic analysis of shallow gas zones NA a coiled- tubing rig and managed pressure drilling techniques. SFD 11/12/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Co�oner: Date Commissioner Date 0
