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Home My WebLink About213-021DATA SUBMITTAL COMPLIANCE REPORT 3/2/2017 Permit to Drill 2130210 Well Name/No. KUPARUK RIV UNIT 1G-1013 Pf1-p Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21003-02-00 MD 10543 TVD 6583 Completion Date 4/1/2013 Completion Status 1-0I1- Current Status 1-0I1- UIC No REQUIRED INFORMATION Mud Log No Z Samples No V/11' Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR / Res Well Log Information: Log/ Interval Electr Data Digital Dataset Type Med/Frmt Number Name Rpt Comments Directional Survey ED C Las 22540 See Notes Log Directional Survey Report & PB1 + disc ' 22601 Induction/Resistivity Log 6300 22601 Induction/Resistivity Log Production Profile + Graphics tiff, las 22601 Induction/Resistivity ED C Pdf 22601 Gamma Ray Log MD Multiple Propagation Resistivity Gamma Ray 22603 Induction/Resistivity Log 22603 Induction/Resistivity Log Realtime Log 22603 Induction/Resistivity ED C Pdf 22603 Gamma Ray ED C 22893 Digital Data ED C 22893 Digital Data ED C 22893 Digital Data ED C 22893 Digital Data (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 8625 10543 Open 4/8/2013 Directional Survey Report & PB1 + disc ' 6050 6300 Open 5/10/2013 Production Profile + Graphics tiff, las 2 Col 7481 10540 Open 5/14/2013 MD Multiple Propagation Resistivity Gamma Ray e Realtime Log 5 Col 7481 10540 Open 5/14/2013 MD Multiple Propagation Resistivity Gamma Ray ' P Realtime Log 5 Col 7481 10540 Open 5/14/2013 TVD SS Multiple Propagation Resistivity Gamma P Ray Realtime Log 7481 10540 Open 5/14/2013 MPR/GR 1:600,1:240 MD & TVD + Graphics pdf, meta, tif, txt, tap, tiff 2 Col,j481 0 8940 Open 5/14/2013 MD Multiple Propagation Resistivity Gamma Ray Realtime Log 5 Col 7481 8940 Open 5/14/2013 MD Multiple Propagation Resistivity Gamma Ray• P Realtime Log 5 Col 7481 8940 Open 5/14/2013 TVD SS Multiple Propagation Resistivity Gamma ? Ray Realtime Log 7481 8940 Open 5/14/2013 MPR/GR 1:600,1:240 MD & TVD + Graphics pdf, meta, tif, txt, tap, tiff -19 6149 6/19/2013 Electronic Data Set, Filename: 1 G - 10B MFC40 10JUN13 Main.LAS 5879 6148 6/19/2013 Electronic Data Set, Filename: 1G- 10B_MFC40_10JUN 13_Repeat.LAS 6/19/2013 Electronic File: 1G- 10B_MFC40_10JUN 13_img.tiff 6/19/2013 Electronic File: CONOCOPHILLIPS_1 G_10B_MFC_report.pdf AOGCC Page 1 of 3 Thursday, March 02, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/2/2017 Permit to Drill 2130210 Well Name/No. KUPARUK RIV UNIT 1G-1013 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21003-02-00 MD 10543 TVD 6583 Completion Date 4/1/2013 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 22893 Digital Data 6/19/2013 Electronic File: 1G 106 MFC CENTERED.cmi ED C 22893 Digital Data 6/19/2013 Electronic File: 1G 1013 MFC CENTERED.wvd ED C 22893 Digital Data 6/19/2013 Electronic File: 1G_10B_MFC_CENTERED.wvp ED C 22893 Digital Data 6/19/2013 Electronic File: 1G 106 MFC UNCENTERED.cmi ED C 22893 Digital Data 6/19/2013 Electronic File: 1G_ 106_ MFC_UNCENTERED.wvd ED C 22893 Digital Data 6/19/2013 Electronic File: 1G — G_106_ MFC _UNCENTERED.wvp Log 22893 Log Header Scans 0 0 2130210 KUPARUK RIV UNIT 1G -10B LOG HEADERS Log 22896 Log Header Scans 0 0 2130210 KUPARUK RIV UNIT 1G -10B LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report (D Production Test Information YY//�J Geologic Markers/Tops o Y COMPLIANCE HISTORY Completion Date: 4/1/2013 Release Date: 2/25/2013 Description Directional / Inclination Data V Mud Logs, Image Files, Digital Data //`Y //(9 Core Chips Y / Mechanical Integrity Test Information Y t A Composite Logs, Image, Data File` Y 1�� Core Photographs Y / A Daily Operations Summary G Cuttings Samples \ Y / NA Laboratory Analyses Y /6) Date Comments AOGCC Page 2 of 3 Thursday, March 02, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/2/2017 Permit to Drill 2130210 Well Name/No. KUPARUK RIV UNIT 1G-1013 Operator CONOCOPHILLIPS ALASKA INC MD 10543 TVD 6583 Completion Date 4/1/2013 Completion Status 1-0I1- Current Status 1-011- Comments: -OILComments: Compliance Reviewed By: Date: API No. 50-029-21003-02-00 UIC No AOGCC Page 3 of 3 Thursday, March 02, 2017 cti S-11. PROACTIVE DIACINOSTIC SERVICES, INC. To: AOGCC WELL LOG TRANSMITTAL Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 AUG 0 6 2013 AOGCC -2-k3-02,c 2-Z�T4k RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) LeakPointTm Survey 2) Signed Print Name: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 12 -Jun -13 1G -10B 1 CD Date : 50-029-21003-02 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(&MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Archi ves\Di stribution\Transmittal S heets\ConowPhi II ips_Transmit docx STATE OF ALASKA ALA, OIL AND GAS CONSERVATION COMI. ,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon F_ Repair w ell w Plug Perforations Perforate _ Other I Alter Casing 'rW Pull Tubing;, Stimulate - Frac j Waiver Time Extension Change Approved Program i"'"" Operat. Shutdown Stimulate - Other iRe-enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory) 213-021-0 3. Address: 6. API Number: _ Stratigraphic Service P. O. Box 100360, Anchorage, Alaska 99510 , 50-029-21003-02 ' 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25640 1G -10B ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): caliper Kuparuk River Field / Kuparuk River Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 10540. feet Plugs (measured) 6189 true vertical 6583 feet Junk (measured) none Effective Depth measured 7526 feet Packer (measured) 5980, 6149, 6168 true vertical 6543 feet (true vertical) 5159, 5311, 5329 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 116 116 SURFACE 2313 10.75 2350 2185' PRODUCTION 6255 7 6290 5441' TIEBACK LINER 5952 5.5 5976' 5155' RECEIVED LINER A 1764 3.5 7906 6641' LINER B 1379 2.375 10540 6583' JUL 16 2013 Perforation depth: Measured depth: slots from 9173'-10539' /� OGCC True Vertical Depth: 6516'-6489' A VC Tubing (size, grade, MD, and TVD) 3.5, L-80, 5930 MD, 5114 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 5980 MD and 5159 TVD PACKER - BAKER C-2 ZXP LINER PACKER @ 6149 MD and 5311 TVD NIPPLE - CAMCO 'DS' NIPPLE @ 529 MD and 529 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory ,f —' Development r�i Service i" Stratigraphic ( - 16. Well Status after work: Oil -% - Gas F,... WDSPL F Daily Report of Well Operations XXX�� GSTOR F_WINJ � WAG � GINJ i SUSP SPLUG F__ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313-167 Contact Brett Packer (a) 265-6845 Email J. Brett. Packer(a)-conocophillips.com Printed Name Brett Packer Title Wells Engineer Phone: 265-6845 Date Signature %� 'If 'elftb Form 10-404 Revised 10/2012 RBI'AAS JUL 2 3 20t Submit Original Only SURFACE, A 37-2,350 KUP Casing Description WINDOW BL2 String 0... 4 String ID ... 3.000 Top (ftKB) 7,482.0 Set Depth (f... Set Depth (TVD'... 7,490.0 6,503.4 IG -10B ConocQPhillips I Well Attributes GAS LIFT, 2,858 Casing Description LINER A String 0... 3 1/2 Max Angle & MD TD AizlSka If1C Wellbore APIIUWI Field Name ___ Well Sfatus Incl (°) MD (ftKB) Act Elm (ftKB) _ 500292100302 KUPARUK RIVER UNIT PROD 100.99 7,870.70 10,540.0 3/16/2013 Comment H2S (ppm) Date Annotation End Date KB-Grd (k) Rig Release Date SSSV: NIPPLE 24B $/14/2012 Last WO: 6/162013 31.1$ 9/7/19$3 Well Cdnti'MULTIPLE LATERALS -1-:620201 3 1 2 4623 PM Schematic -actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date _-- = Mandrel Details Last Tag: SLM 6,739.0 12/18/2012 Rev Reason: WORKOVER 24.39 PACKER osborl 6/20/2013 ._ CaSln Strl�$ 4.437 GAS LIFT, 5,383 N... Top (ftKB) (ftKB) 1°) Make Model (in) Sam Type Type (in) 6,155.5 5,317.0 24.30 HANGER BAKER HMC HYDRAULIC LINER HANGER HANGER, 22 Casing Description String 0... String to ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... _ String Top Thrd 4.000 CONDUCTOR 16 15.063 39.0 116.0 116.0 62.58 H40 WELDED LINERB Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 37.1 2,350.3 2,180.0 45.50 K-55 BUTT Cg Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Nomi... NIPPLE,5,867 7 6.276 35.1 6,290.0 5,440.2 26.00 K-55 BTC 7N ID (in) 9,161.5 ost S/T'A' 96.72 BILLET I Anchored Billet 1.000 asing Description String 0.String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd LOCATOR, 5'912 Tubing Description TUBING WO 2013 r7CPZDUCTION String Wt... 9.30 ROD SCAB LINER 51/2 4.95975.6 Completion Details 5,154.4 15.50 L-80 BTCSC SEAL ASSY, 5.912 Top Depth (TVD) Top ]net iner Details Nomi... Top (ftKB) (ftKB) (°) Item Description Comment conlDucroR, 39-116Ta�f]Top ID (in) Depth -15.60 HANGER TUBING HANGER 2.922 529.4 529.3 1.87 NIPPLE CAMCO 2.875"'DS' NIPPLE (TVD) Top Incl 2.875 5,866.8 5,057.3 27.37 NIPPLE NIPPLE, 529 2.813 Top (ftKB) (ftKB) (°) Item Description 5,911.7 5,097.4 Comment BAKER LOCATOR SURFACE, A 37-2,350 6,099.6 5,266.2 25.11 NIPPLE 2.75" CAMCO'D' NIPPLE w/RHC PLUG Casing Description WINDOW BL2 String 0... 4 String ID ... 3.000 Top (ftKB) 7,482.0 Set Depth (f... Set Depth (TVD'... 7,490.0 6,503.4 String Wt... String ... String Top Thrd GAS LIFT, 2,858 Casing Description LINER A String 0... 3 1/2 String ID ... 2.992 Top (ftK8) 6,142.3 Set Depth (f... Set Depth (TVD) ._ 7,906.0 6,641.2 String Wt... 93.00 String ... L-80 String Top Thrd ABM -BTC Liner Details 8,144 6,101.0 5,267.5 25.09 CATCHER 2.74" JUNK CATCHER (OAL=88") _ 6,189.0 5,347.6 23.82 PLUG 2.69" SPECIAL CLEARANCE WRP 5/2/2013 0, 7,482.0 6,496.2 25.27 WHIPSTOCK WHIPSTOCK, ORIENTED 140 DEGREES 3/16/2013 Top Depth PRODUCTION GAS LIFT, 4,434 (TVDt Top (ftKB) (ftKB) Top net V) Item Description Comment CMT SOZ, Nami... ID (in) 7,318-7,330 6,142.3 5,305.0 24.49 TIEBACK BAKER TIEBACK SLEEVE 5.250 _-- = Mandrel Details 6,149.2 5,311.3 24.39 PACKER BAKER C-2 ZXP LINER PACKER CMT SOZ, 73667374 S... (TVD) Incl OD Valve Latch Size 4.437 GAS LIFT, 5,383 N... Top (ftKB) (ftKB) 1°) Make Model (in) Sam Type Type (in) 6,155.5 5,317.0 24.30 HANGER BAKER HMC HYDRAULIC LINER HANGER 0.0 6/162013 7.482-7'490 4.375 0.0 6/162013 6,162.1 5,323.1 24.21 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String... Siring Top Thrd GAS uPT• 5,813 LINERB 23/8 1.995 9,161.5 10,540,0 6,583.4 4.70 L-80 STL Liner Details Top Depth (TVD) Top Incl Nomi... NIPPLE,5,867 Top(ftKB) (ftKB) (°) Item Description Comment ID (in) 9,161.5 6,611.9 96.72 BILLET I Anchored Billet 1.000 Tubing Strings LOCATOR, 5'912 Tubing Description TUBING WO 2013 String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... 31/2 2.992 22.0 5,930.4 5,114.1 String Wt... 9.30 String... L-80 String Top Thrd IBTM-SCC Completion Details SEAL ASSY, 5.912 Top Depth (TVD) Top ]net Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 22.0 22.0 -15.60 HANGER TUBING HANGER 2.922 529.4 529.3 1.87 NIPPLE CAMCO 2.875"'DS' NIPPLE 2.875 5,866.8 5,057.3 27.37 NIPPLE HES 2.812"'X' NIPPLE 2.813 5,911.7 5,097.4 26.73 LOCATOR BAKER LOCATOR 3.000 PER, 5,965 5,912.5 5,098.1 26.72 SEAL ASSY BAKER 80-40 GBH -22 PRODUCTION SEAL ASSEMBLY 3.000 PROD SCAB LINER, 245.976 - Tubing Description STACK PACKER String 0... String ID ... 3 1/2 2.992 Top (ftKB) Set Depth (f... Set Depth (TVD) ... 5,965.1 6,168.3 5,328.7 String Wt... 9.30 1 String ... L-80 String Top Thrd EUE8rdMOD BUSHING.5979 Completion Details 'ACKER, 5,980 Top Depth (TVD) Top Ind Noml... Top (ftKB) '1111121)(°) Item Description Comment ID (in) 5,965.1 5,145.0 26.28PER BAKER PBR - pinned to shear @40K 4.000 5,978.8 5,157.3 26.16 BUSHING Crossover 3-12" EUE boxxTCll pin 2.992 5.980.3 5.158.6 26.15 PACKER BAKER PREMIER PACKER - Dinned to set at 3500 Dsi 3.000 NIPPLE, 6,103 6,099.6 5,266.2 25.11 NIPPLE 2.75" CAMCO'D' NIPPLE w/RHC PLUG 2 6,143.1 5,305.8 24.48 LOCATOR BAKER LOCATOR 2 6,143.9 5,306.5 24.47 SEAL ASSY BAKER GBH -22 SEAL ASSEMBLY 2 1LOCATOR, able luut Other In Hole Wireline retrievs., valves, pumps, fish, etc.) CAT6.143 CATCHER, Top Depth _ 6,101 (TVD) Top Incl SEAL ASSY, Top (ftKB) (ftKB) (°) Description Comment Run Date ID 8,144 6,101.0 5,267.5 25.09 CATCHER 2.74" JUNK CATCHER (OAL=88") 5/4/2013 0. 6,189.0 5,347.6 23.82 PLUG 2.69" SPECIAL CLEARANCE WRP 5/2/2013 0, 7,482.0 6,496.2 25.27 WHIPSTOCK WHIPSTOCK, ORIENTED 140 DEGREES 3/16/2013 PLUG, 6,189 PRODUCTION Post Srr'A', L� 35-6,290 CMT SOZ, _ 7,318-7,330 CMT SOZ, 7,330-7,340 CMT SOZ. _-- = Mandrel Details 7352-7366 _ i Top Depth Top Port CMT SOZ, 73667374 S... (TVD) Incl OD Valve Latch Size TRO Run WHIPSTOCK, N... Top (ftKB) (ftKB) 1°) Make Model (in) Sam Type Type (in) (psi) Run Date Cc 7,482 WINDOW BL2, 1 2,858.4 2,599.3 37.28 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 6/162013 7.482-7'490 2 4,434.1 3,849.3 36.48 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 6/162013 LINER A. J 6.142-7.906 SLOTS, 9,17310,539 LINER B, 9,162-10.540 TD (1G -10a). 10,540 ConocoPhillips Aarxsw.InC. Notes: Well Conflor MULTIPLE LATERALS -1G100 6202013124623 PM Schematic - Ag6 I HANGER, 22 ,.. KUP Top (TVD) I Bt. (TVD) Btm (ftKBI (ftKB) (ftKI3 Zone Date NIPPLE, 5,867 LOCATOR, 5,912 PER, 5,965 PRODSCAB LINER, 24-5.976 BUSHING, 5,979 PACKER, 5, 980 NIPPLE. 6.100 LOCATOR, 6,143 CATCHER, 6101 SEAL ASSY, 6.144 PLUG, 6,189 PRODUCTION Post S/r'N, 35-6,290 CMT SOZ, 7,318-7,330 CMT SOZ, 7.330.7.340 CMT SGZ, 7,352-7,358 CMT SOZ, 7366-7,374 WHIPSTOCK, 7 482 WINDOW BL2, 7,482-7,490 LINER A, J L 6.142-7.906 SLOTS, 9,173-10,539 LINER B, 9,162-10,540 TD (1G -10B). 10,540 1G -10B KB-Grd (R) Rig Release Dab 31.18 9!7/1983 Shot Dene (sh... Type Comment 32.0 SLOTS Slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends Notes: General & Safety Ll I End Date - Annc CONoucTOR, 9/28/1996 NOTE: WELL SIDETRACKED to A' & WORKOVER 39-11fi ---"" 9/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE. 529 ' [ - 4/2/2013 NOTE: WELL SIDETRACKED TO'B', BL1, BL2 (BL2 C SURFACE, 37-2,350 GAS LIFT, 2,858 GAS LIFT, 4,434 GAS LIFT, NIPPLE, 5,867 LOCATOR, 5,912 PER, 5,965 PRODSCAB LINER, 24-5.976 BUSHING, 5,979 PACKER, 5, 980 NIPPLE. 6.100 LOCATOR, 6,143 CATCHER, 6101 SEAL ASSY, 6.144 PLUG, 6,189 PRODUCTION Post S/r'N, 35-6,290 CMT SOZ, 7,318-7,330 CMT SOZ, 7.330.7.340 CMT SGZ, 7,352-7,358 CMT SOZ, 7366-7,374 WHIPSTOCK, 7 482 WINDOW BL2, 7,482-7,490 LINER A, J L 6.142-7.906 SLOTS, 9,173-10,539 LINER B, 9,162-10,540 TD (1G -10B). 10,540 1G -10B KB-Grd (R) Rig Release Dab 31.18 9!7/1983 Shot Dene (sh... Type Comment 32.0 SLOTS Slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends 1 G-1 OB Pre -Rig Well Work Summary DATE SUMMARY 4/9/2013 DRIFT TBG W/2.69" GAUGE RING AND TAG DEPLOYMENT SLEEVE @ 7465' RKB; MEASURE BHP @ 7450' RKB ( 2975 psi) . E -LINE UP NEXT FOR WRP. 5/2/2013 COMPLETED SETTING WEATHERFORD 2.69" SPECIAL CLEARANCE WRP. CORRELATED TO TUBING TALLY AND SET WRP MID -ELEMENT @ 6190' CMIT WRP PASSED (See attached report) 5/4/2013 SET CATCHER ON WRP @ 6189' RKB; PULLED DV @ 6095' RKB. READY FOR BPV ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 1G-10 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 6/6/2013 6:00:00 AM Rig Release: 6/17/2013 12:00:00 AM Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T Comment 6/04/2013 24 hr Summary Move camp from 2H to 1G. Begin moving modules to 1G. Working with 2 Sals due to bridge outage. 06:00 12:00 6.00 MIRU MOVE RUNL P Blow down steam and water lines. Disconnect service lines and prep modules to move. 12:00 00:00 12.00 MIRU MOVE MOB P Move camp, boiler, motors, pumps and pits from 2H-10 to 1G-10. Move with 2 Sals due to Kuparuk river bridge outage. 6/05/2013 Move rig from 2H-10 to 1 G -10B. Spot sub base over well and spot modules. 00:00 01:00 1.00 MIRU MOVE MOB P PJSM, mobilize pump room and pits to 1G pad 01:00 01:30 0.50 MIRU MOVE MOB P Pull pipe sheds to corner of 2H pad and wait for road to be matted. 01:30 03:30 2.00 MIRU MOVE MOB P Pull sub off 2H-10 and spot on pad. (wait on drilling support to mat culverts) 03:30 04:00 0.50 MIRU MOVE MOB P Mobilize pipe sheds to 1G pad. 04:00 11:15 7.25 MIRU MOVE MOB P Pipe shed had to stop at CPF-2 while drilling support laid mats and change out. 11:15 13:00 1.75 MIRU MOVE MOB P Cont. mobilizing pipe sheds to 1G pad. 13:00 21:00 8.00 MIRU MOVE MOB P Move sub base to 1G -10B. 21:00 22:30 1.50 MIRU MOVE MOB P Spot sub over well 1 G -10B. 22:30 00:00 1.50 1 1 MIRU MOVE MOB I P I Spot pits. 6/06/2013 Cont spotting modules and rig up. Accept rig @ 6:00 hours. R/U tiger tank and hardline. Pull BPV and circ out freeze protect with 9.6 ppg brine. OWFF and set BPV. N/D tree and N/U BOPE. 00:00 05:30 5.50 MIRU MOVE MOB P PJSM, spot pits, pumps, motors, boiler and pipe shed modules. SIMOPS, work on rig acceptance checklist. 05:30 06:00 0.50 MIRU MOVE RURD P PJSM, work on rig acceptance checklist. Calibrate and test gas alarms. Rig accepted @ 6:00 hours. 06:00 07:30 1.50 MIRU MOVE RURD P Load brine into pits. 07:30 09:30 2.00 MIRU MOVE RURD P Mobilize rock washer from 2H pad to 1 G-1 OB and rig up. 09:30 13:45 4.25 MIRU MOVE RURD P Rig up tiger tank, choke house and hardline. Rig up scaffolding in cellar. 13:45 14:30 0.75 MIRU WHDBO RURD P Rig up to pull BPV. SIMOPS, repair handrail in cellar. 14:30 16:15 1.75 MIRU WHDBO SEQP P PJSM, pull BPV with lubricator as per CIW rep. Page 1 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:15 17:00 0.75 MIRU WHDBO RURD P PJSM, Rig up to circulate kill weight fluid. 17:00 17:15 0.25 MIRU WHDBO PRTS P Pressure test lines to 250/2000 PSI. 17:15 18:45 1.50 MIRU WHDBO OTHR T CIW rep closed SSV on tree, after closing SSV would not open. Valve shop replaced barrel on SSV and opened the valve. 18:45 20:15 1.50 MIRU WHDBO KLWL P PJSM, circulate out diesel freeze protect. Pumped 260 bbls of 9.6 ppg brine with 253 bbls returned. Pumped @ 4 BPM, ICP= 150 PSI, FCP= 650 PSI. 20:15 20:45 0.50 MIRU WHDBOOWFF P Monitor well, static. 20:45 21:15 0.50 MIRU WHDBO SEQP P R/D lines, set BPV and test BPV to 1000 PSI for 10 minutes. 21:15 21:45 0.50 MIRU WHDBO RURD P R/D scaffolding and circ hoses in cellar. 21:45 23:15 1.50 MIRU WHDBO NUND P PJSM, N/D tree and N/U adapter flange. 23:15 00:00 0.75 MIRU WHDBO NUND P N/U BOPE. 6/07/2013 Cont testing BOPE to 250/3500 PSI with 3-1/2" and 4" test joint. Jeff Jones AOGCC rep waived withness of test. R/U and attempt to pull hanger, no go. R/U E -line and RI w/ string shot. POOH w/ E -line and M/U RCT cutter, RIH and cut tubing @ 6125'. 00:00 01:45 1.75 MIRU WHDBO NUND P PJSM, Cont to N/U BOPE. SIMOPS, cut riser to length. 01:45 04:00 2.25 MIRU WHDBO NUND P PJSM, Change lower rams from 2-7/8" X 5" VBR to 3-1/2" X 6" VBR. 04:00 04:15 0.25 MIRU WHDBO SFTY P Hold PJSM on rigging up and testing ROPE. 04:15 05:15 1.00 MIRU WHDBO BOPE P Rig up to test BOPE. 05:15 12:30 7.25 MIRU WHDBO BOPE P Test BOPE to 250/3500 PSI for 5 minutes each. Test #1: Top pipe rams, CV 1,12,13,14 and manual kill. Test #2: Upper IBOP, HCR kill, CV 9 and 11. Test #3: Lower IBOP, CV 5, 8 and 10. Test#4: Dart valve, CV4,6 and 7. Test #5: Floor valve and CV 2. Test #6: HCR choke and 4" kill line demco. Test #7: Manual choke. Test #8: Annular preventer. Test #9: Lower pipe rams. Test #10: Blind rams and CV 3. Tested with 3-1/2" and 4" test joint. Accumulator test: System pressure= 3000 PSI, pressure after closing= 1700 PSI, 200 PSI attained after 53 sec., full pressure after 209 sec. Nitrogen 5 bottle avg.= 1950 PSI. AOGCC rep Jeff Jones witness of the test. 12:30 13:00 0.50 MIRU WHDBO BOPE P Rig down BOP testing equipment. 13:00 13:15 0.25 COMPZ RPCOM SEQP P Pull BPV and test dart. 13:15 14:15 1.00 COMPZ RPCOM OWFF P Monitor well, static. SIMOPS, R/U landing joint and BOLD's Page 2 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:15 18:00 3.75 6,150 6,150 COMPZ RPCOM OTHR P Attempt to pull tubing, P/U to 149K (80% yield) work pipe several times with no success. Notified HES E -line to make RCT cut. Cont to work tubing while waiting on E -line. 18:00 19:00 1.00 6,150 6,150 COMPZ RPCOM RURD P PJSM, R/D drill pipe and M/U 3-1/2" tubing pups as landing joint w/ XO on top. Set string in 20K tention. 19:00 20:00 1.00 6,150 6,150 COMPZ RPCOM RURD P PJSM, Rig up HES E -line. 20:00 21:45 1.75 6,150 6,150 COMPZ RPCOM ELOG P RIH w/ string shot on E -line. Fired string shot @ 6125', mid joint. Observed E -line string weight drop off 125 lbs when shot was fired and collars appeared to be .5' higher on the CCL, indicating possible pipe movement. 21:45 22:15 0.50 6,150 6,150 COMPZ RPCOM ELOG P POOH with E -line. 22:15 22:45 0.50 6,150 6,150 COMPZ RPCOM OTHR P Break off E -line tools. Attempt to pull tubing, pulled 149K three times. No movement. 22:45 00:00 1.25 6,150 6,150 ICOMPZIRPCOM RURD P R/U HES E -line and change out tools, M/U RCT cutter. 6/08/2013 Cut tubing w/ RCT @ 6125', POOH and R/D HES E -line. Pull hanger and rev circ, POOH L/D 3-1/2" completion. M/U BHA #1 and RIH, engage fish @ 6119' and pull free. POOH w/ fish and L/D 00:00 01:45 1.75 6,150 6,150 COMPZ RPCOM ELOG P PJSM, R/U HES E -line RCT cutter. 01:45 02:30 0.75 6,150 6,125 COMPZ RPCOM ELOG P RIH with RCT on E -line. Cut tubing @ 6125', mid joint. Observed tubing jump and when POOH w/ E -line the collars where 4' higher. 02:30 04:30 2.00 6,125 6,125 COMPZ RPCOM ELOG P POOH with E -line and R/D HES E -line. 04:30 05:00 0.50 6,125 6,125 COMPZ RPCOM PULL P Pull hanger to rig floor, P/U 80K. Rig up power tongs, lay down tubing hanger and pup. OWFF. 05:00 05:45 0.75 6,125 6,125 COMPZ RPCOM CIRC P Rig up and reverse circulate 2 tubing volumes. Pump @ 5 BPM= 500 PSI. 05:45 11:45 6.00 6,125 0 COMPZ RPCOM PULL P PJSM, L/D 3-1/2" completion. L/D 190 joints, 2 pups, 5 GLM's, 1 DS nipple and 14.12' cut joint. 11:45 12:00 0.25 0 0 COMPZ RPCOM RURD P PJSM, R/D tubing tools and C/O elevators. 12:00 12:45 0.75 0 0 COMPZ RPCOM PULD P P/U Baker tools from overshot. 12:45 14:00 1.25 0 313 COMPZ RPCOM PULD P PJSM, M/U BHA#1, overshot as per Baker rep. 14:00 18:15 4.25 313 6,072 COMPZ RPCOM TRIP P RIH picking up 4" drill pipe f/ 313' to 6072'. P/U= 132K, S/0= 93K, ROT= 108K. Actual displacement= 38.47 bbls, Calculated displacement= 38.76 bbls. 18:15 18:45 0.50 6,072 6,119 COMPZ RPCOM FISH P Wash down f/ 6072' to 6119', pump @ 3 BPM= 200 PSI. Page 3 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:45 19:15 0.50 6,119 6,119 COMPZ RPCOM FISH P Tag top of fish @ 6119', observed 400 PSI pump pressure increase. Set down 10K, swallow fish down to 6125'. Pull 10K over, set down 15K. P/U two times @ 40K over pull and fire jars. Jar @ 50K over pull two times. Pull 60K over and fish pulled free. 19:15 19:30 0.25 6,119 6,059 COMPZ RPCOM PULD P P/U a single and stand back. Obtain SPR's @ 6059' with 9.6 ppg brine. 19:30 20:15 0.75 6,059 6,059 COMPZ RPCOM CIRC P CBU X 2 @ 5 BPM=500 PSI, observed small amount of gas @ BU 20:15 21:00 0.75 6,059 6,059 COMPZ RPCOM OWFF P Blow down and monitor well, static. 21:00 22:45 1.75 6,059 315 COMPZ RPCOM TRIP P PJSM, POOH f/ 6059' to 315', monitor well @ collars. 22:45 23.45 1.00 315 0 COMPZ RPCOM TRIP P Stand back BHA in derrick. Actual displacement= 40.46 bbls, Calculated displacement= 38.07 bbls. Recovered fish. 6/09/2013 Lay down fish. Make up clean out assembly. RIH to 6169'. CBU 2x. POOH to 6126'. Reverse circulate. POOH 3 stand and make ujp Storm Packer. RIH two stand and set storm packer. Test storm packer to 1000 psi. N/D BOPE and tubing spool. Nipple up new tubing spool and BOPE. 00:00 01:00 1.00 0 0 COMPZ RPCOM PULD P Lay down seal assembly and nipple 01:00 01:30 0.50 0 0 COMPZ RPCOM OTHR P Clear rig floor and bring Baker mills and magnets to the floor 01:30 03:00 1.50 0 363 COMPZ RPCOM PULD P Make up BHA 03:00 05:30 2.50 363 6,122 COMPZ RPCOM TRIP P RIH with clean out assembly to 6122'. Obtain perameters @ 20 rpm, Torque = 3.5 k ft -lbs, P/U = 135k, S/O = 94k. Actual bbl displacement 38.9 bbl calc 37.2 bbl 05:30 05:45 0.25 6,122 6,132 COMPZ RPCOM WASH P Break circulation and was to 6169.5', tag bottom of SBE. POOH to 6132 05:45 06:15 0.50 6,132 6,132 COMPZ RPCOM CIRC P CBU two times 06:15 07:00 0.75 6,132 6,167 COMPZ RPCOM CIRC P RIH to 6167' and reverse circulate 30 bbl at 2 bpm 07:00 08:00 1.00 6,167 6,126 COMPZ RPCOM CIRC P POOH to 5934' and reverse circulate 225 bbl at 7 bpm 1000 psi 08:00 08:15 0.25 6,126 5,934 COMPZ RPCOM TRIP P POOH to 5934' 08:15 10:30 2.25 5,934 6,136 COMPZ RPCOM PACK P Make up Storm Packer and RIH two stands. Set storm packer and release. Test storm packer to 1000 psi for 15 minutes. Muleshoe at 6136' P/U = 130k, S/O = 92K 10:30 13:00 2.50 6,136 6,136 COMPZ RPCOM NUND P N/D BOPE 13:00 15:00 2.00 6,136 6,136 COMPZ RPCOM NUND P N/D tubing spool, adapter flange and spacer spool 15:00 17:00 2.00 6,136 6,136 COMPZ RPCOM NUND P Install new pack -off in Mcevoy Type S-3 casing spool and install on top of existing Gen 13M casing spool 17:00 18:30 1.50 6,136 6,136 COMPZ RPCOM PRTS T Pump packing into new casing spool. Unable to test pack -off. Wait on new fitting for testing. Page 4 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:30 20:30 2.00 6,136 6,136 COMPZ RPCOM PRTS P Test packoffto 250/3000 psi for test minutes each test 20:30 23:00 2.50 6,136 6,136 COMPZ RPCOM NUND P Nipple up adapter flange and BOPE 23:00 00:00 1.00 6,136 6,136 COMPZ RPCOM NUND P Clear cellar and modify bell nipple 6/10/2013 Finish testing new casing spool. Retrieve storm packer. Nipple down bell nipple and rig up shooting flange. Rig up E -line and run gyro and caliper from 6124 to surface. Rig down E -line. Rig down shooting flange. 00:00 02:00 2.00 6,136 6,136 COMPZ RPCOM NUND P Rig up and test casing spool to 250/3000 psi 02:00 02:15 0.25 6,136 6,136 COMPZ RPCOM RURD P Install bell nipple 02:15 04:15 2.00 6,136 6,136 COMPZ RPCOM BOPE P Attempted to test lower VBR's with 5-1/2" test joint no test. 04:15 05:15 1.00 6,136 6,136 COMPZ RPCOM PULL P M/U storm packer retrieving tool. RIH engage storm packer and release same. POOH and L/D storm packer 05:15 07:45 2.50 6,136 363 COMPZ RPCOM TRIP P Monitor well. POOH. CAcic displacement 37.5 bbl, actual displacement 39.6 bbl 07:45 09:00 1.25 363 0 COMPZ RPCOM PULD P Lay down BHA 09:00 09:30 0.50 0 0 COMPZ RPCOM OTHR P Clear and clean rig floor 09:30 11:30 2.00 0 0 COMPZ RPCOM NUND P N/D bell nipple and nipple up shooting flange. Spot wireline unit. Load pipeshed with 5-1/2" casing 11:30 13:00 1.50 0 0 COMPZ RPCOM RURD P Rig up E -line tools 13:00 17:00 4.00 0 0 COMPZ RPCOM SRVY P Run gyro from surface to 6142' 17:00 18:00 1.00 0 0 COMPZ RPCOM PULD P L/D gyro tools and pick up caliper log 18:00 22:15 4.25 0 0 COMPZ RPCOM SRVY P Run caliper log from 6147' to surface 22:15 22:45 0.50 0 0 COMPZ RPCOM RURD P R/D a -line tools and lay down 22:45 00:00 1.25 0 0 COMPZ RPCOM NUND P Nipple down shooting flange D6/11/2013 C/O Upper and lower rams and test w/ 5-1/2" jt. Troubleshoot upper rams and replace seals, complete testing. R/U and run 5-1/2" tieback liner to 4868' MD. 00:00 00:45 0.75 0 0 COMPZ WHDBO RURD P PJSM- N/U Riser boot and nipple 00:45 03:00 2.25 0 0 COMPZ WHDBO RURD P PJSM and C/O Lower rams to 2-7/8" x 5" VB, C/O Upper rams to 3-1/2" x 6" VB. 03:00 04:45 1.75 0 0 COMPZ WHDBO BOPE P R/U 3-1/2" test jt w/ McEvoy test plug, could not get test plug to seat. Notified Cameron rep -calling town to verify correct test plug. 04:45 06:15 1.50 0 0 COMPZ WHDBO SLPC P Slip and cut 65' of drilling line. 06:15 08:00 1.75 0 0 COMPZ WHDBO SVRG T R/U test equip, test lower 2-7/8" x 5" VBR's and Upper 3-1/2" x 6" VBR's w/ 3.5" test jt 250/3000 psi charted 5 min ea. R/D 3-1/2" test jt and R/U 5-1/2" test jt. Attempt to test Upper VBR's with 5-1/2" test joint, could not get good test. Decision made to inspect 3-1/2" x 6" rams. Page 5 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08:00 09:00 1.00 0 0 COMPZ WHDBO BOPE P I Lubricate rig 09:00 12:00 3.00 0 0 COMPZ WHDBO BOPE T PJSM- Open upper ram doors, inspect rams, close doors. P/U 5-1/2" test jt and observe rams close around test jt. Fill test jt, observed rams leaking. Shut down and contact supervisor and Hydril rep in town. 12:00 13:15 1.25 0 0 COMPZ WHDBO BOPE T Continue to troubleshoot rams, decision made to re -open upper doors and C/O rams seals w/ new. 13:15 15:30 2.25 0 0 COMPZ WHDBO BOPE T PJSM and C/O upper ram seals. 15:30 17:30 2.00 0 0 COMPZ WHDBO BOPE T Test 5-1/2" test jt t/ 250/3000 psi 5 min ea on chart. Re -test w/ 3-1/2" jt Upper rams t/ 250/3000 psi 5 min on chart. 17:30 18:15 0.75 0 0 COMPZ WHDBO RURD P PJSM and R/D BOP testing equipment. 18:15 19:15 1.00 0 0 COMPZ RPCOM RURD P PJSM and R/U to run 5-1/2" tie -back casing string. 19:15 00:00 4.75 0 4,868 COMPZ RPCOM RNCS P Run 5-1/2" tie -back liner per detail t/ 4868' MD. (P/U=100k, S/0=75k) Calc disp=26.64 bbl, Actual disp=23.8 bbl. 6/12/2013 RIH with 5-1/2" liner and 3-1/2" tail, located and spaced 3' out. Tested liner 2500 psi, attempted to test IA, failed x 3. Decide to POOH w/ 5-1/2" and 3-1/2" to run leak detection log. R/U and RIH w/ eline. 00:00 02:00 2.00 4,868 6,158 COMPZ RPCOM RNCS P PJSM and continue RIH w/ 5-1/2" liner and 3-1/2" tailpipe/ seal assy to 6158' MD, P/U=125k, S/0=85k. Calc disp=9 bbl, Actual disp=8.7 bbl. 02:00 03:00 1.00 6,158 6,173 COMPZ RPCOM HOSO P M/U XO and head pin, R/U to cement line and break circ @ 1 bpm 120 psi. Slack off and observe pressure increase t/ 300 psi as seals enter @ 6161' MD. S/D and bleed pressure to 0, S/O to 6173' MD and tag, set do 20k, repeat procedure x 3 to verify seals enter at 6161' MD RKB, no-go @ 6173' MD RKB- 12 foot engaged. 03:00 04:00 1.00 6,173 6,173 COMPZ RPCOM HOSO P Call Engineer to verify seal engagement and set depths, measured old seals and reviewed original tally. Decide to pick up to neutral wt plus 3 ft, leaving two sets of seals fully engaged. 04:00 05:15 1.25 6,173 6,169 COMPZ RPCOM PRTS P Space out w/ bottom of seal assy @ 6168.5' MD. Test casing and seals t/ 2500 psi 5 min, bleed off to 0. R/U and attempt test on 7" x 5-1/2" IA,x 3/. Could not get test, bled off f/ 2700 psi t/ 2442 psi 10 minutes. Call engineer. Page 6 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:15 10:30 5.25 6,169 6,169 COMPZ RPCOM SVRG T Monitor well and WOO. Prep cellar for N/D BOP. Clean rig, fuel cold starts, check hydraulic fluid and sercive jacking units. Decision made to POOH with liner and tailpipe/ seal assy to detect leak/ establish barrier. 10:30 11:30 1.00 6,169 6,169 COMPZ RPCOM RURD X PJSM and R/U csg equipment, prep pipe shed t/ L/D 5-1/2" tubing. P/U thread protectors to rig floor. 11:30 16:45 5.25 6,169 147 COMPZ RPCOM PULL X PJSM and POOH, laying down 5-1/2" Liner f/ 6168.5' MD t/ 147' MD. Calc fill=33.84, Actual fill 38.84 bbl. 16:45 17:30 0.75 147 0 COMPZ RPCOM PULL X Lay down Seal bore ext, sliding sleeve, 3-1/2" jt, 'D' Nipple, 3-1/2" jt, Locator and seal assy. 17:30 18:00 0.50 0 0 COMPZ RPCOM RURD X Clean and clear rig floor 18:00 19:45 1.75 0 0 COMPZ RPCOM NUND X PJSM and nipple up shooting flange for eline work. 19:45 20:00 0.25 0 0 COMPZ RPCOM RURD X P/U tools in cellar, clean and clear from N/U shooting flange. 20:00 22:15 2.25 0 0 COMPZ RPCOM RURD X Spot HES Eline unit at slide, re -head cable, load tools in pipe shed and bring to floor. 22:15 22:30 0.25 0 0 COMPZ RPCOM SFTY X PJSM w/ HES Eline crew on picking up tools, rigging up and running leak detection log. 22:30 00:00 1.50 0 0 COMPZ RPCOM RURD X P/U tools from slide, and R/U wireline. 6/13/2013 Complete Eline Archer leakpoint run, found anomaly at 6122' MD. Mobilize additional tools and P/U modified tieback string, RIH with seals, Packer, SBE and 5-1/2" casing t/ 1373' MD. 00:00 01:00 1.00 0 300 COMPZ RPCOM RURD X PJSM and continue rigging up Eline tools. PT pressure equipment to 3000 psi. 01:00 02:00 1.00 300 6,165 COMPZ RPCOM ELOG X RIH w/ Archer Leakpoint detection tool 02:00 09:00 7.00 6,165 300 COMPZ RPCOM ELOG X RIH t/ 6165' MD, pressure up to 3000 psi, holding for leak detection log, pulling up hole @ 30 fph. Detected temp signature at 6122' and parked tool. No accoustic signal, casing leak is intermittant. Bled to 0 psi 10 min then 1000 psi, lost 100 psi 10 min, no accoustic signal. 2000 psi lost 100 psi 10 min, same. Pressure 2200 psi, and continue logging, leak intermittant. Best guess 6122' MD leak. 09:00 09:30 0.50 300 300 COMPZ RPCOM SVRG X Wait on orders, clean and service rig. 09:30 10:15 0.75 300 300 COMPZ RPCOM PRTS X R/U Lubricator and test casing t/ 2700 psi 30 min on chart, good test. 10:15 11:30 1.25 300 0 COMPZ RPCOM RURD X R/D Eline. 11:30 12:00 0.50 0 0 COMPZ RPCOM RURD X Clean and clear rig floor, R/U to N/D shooting flange. 12:00 14:45 2.75 0 0 COMPZ RPCOM RURD X PJSM and N/D shooting flange, N/U Riser. Page 7 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:45 15:00 0.25 0 0 COMPZ RPCOM RURD X Clean up tools in cellar 15:00 18:45 3.75 0 0 COMPZ RPCOM SVRG X Mobilize packer from Deadhorse to rig. Work on Drawworks MP -2's, replace wheel on iron roughneck. Clean and prep liner string, install new seal rings in 5-1/2" casing and 3-1/2" tubing. 18:45 19:30 0.75 0 0 COMPZ RPCOM RURD X R/U tongs, load packer in shed. 19:30 21:45 2.25 0 0 COMPZ RPCOM OTHR X Wait on tools / clean rig. Required slickline to come and install RHC plug in 'D' nipple for packer setting, also waiting for 10' 3-1/2" EUE pup to arrive on location for packer placement. 21:45 00:00 2.25 0 1,373 COMPZ RPCOM RNCS X PJSM and P/U Seal assy, 3-1/2" EUE, 'D' Nipple, Baker Premier Packer (pinned 3.5K), sliding sleeve, SBE and 5-1/2" 15.5# csg t/ 1373' MD. Calc disp 7.1 bbl, Actual disp 7.1 bbl. P/U=50k, S/0=48k. 6/14/2013 Continue RIH, w/ 5-1/2" casing, space out and reverse in inhibited brine. Set packer and PT csg/ann. Shear out PBR and set on depth. N/D BOP and set slips, cut casing. N/U and test tubing spool. N/U flange & BOP, R/U t/ test BOPE breaks, could not set test plug due ID of flange. N/D and wait on flange. 00:00 03:45 3.75 1,373 6,135 COMPZ RPCOM RNCS X PJSM, Continue RIH w/ 5-1/2 Csg from 1373' MD to 6135' MD, P/U=125k, S/O 85k, Actual = 28.7 bbls, Calculated = 29.6 bbls 03:45 05:30 1.75 6,135 6,170 COMPZ RPCOM RNCS X RIH to 6170' MD tag bottom, space out, L/D 2 joints, P/U 9.82, 9.84, 8.71 pup joints, P/U full joint + 7.81 pup joint, slack off tag bottom. 05:30 06:00 0.50 6,170 6,139 COMPZ RPCOM HOSO X PJSM, R/U Circ Eqpt, Break circulation @ .7 bpm, 100 psi, slack off saw presure increase as seals entered SB, Cont pressure up to 500 psi, shut down pumps holding pressure, bleed off pressure. Slack off to no go @ 6170' MD, Press up to 500 psi seals holding, bleed off to 0 psi, POOH to 6139' MD. 06:00 07:15 1.25 6,139 6,139 COMPZ RPCOM RNCS P PJSM, R/U Rev. Circ. 9.6 ppg inhibited brine down 5" x 7" Annulus @ 3 bpm, 800 psi, pump 55 bbls, followed by 15 bbls clean brine. 07:15 09:30 2.25 6,139 6,167 COMPZ RPCOM PRTS P Set casing on depth, Pressure up to 4000 psi and set packer, test casing for 30 minutes. record on chart. bleed to 0 psi, R/U test 5.5 x 7" Annulus to 3000 psi for 30 minutes, recorded on chart. 09:30 09:45 0.25 6,167 6,167 COMPZ RPCOM HOSO P Pressure up csg to 1000 psi, shear out of PBR, saw shear @ 145k up weight. top of 3-1/2 SB @ 5914' MD, P/U 110k. 09:45 10:30 0.75 6,167 6,167 COMPZ RPCOM OWFF P Monitor Well, BD Kill and Choke line. R/D Circ lines. Flush stack. Page 8 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:30 11:30 1.00 6,167 6,167 COMPZ RPCOM NUND P PJSM, N/D BOP 11:30 12:00 0.50 6,167 0 COMPZ RPCOM RNCS P Set Emergency Slips, Slackoff blocks. 12:00 13:15 1.25 0 0 COMPZ RPCOM RNCS P Suck fluid out of langing joint, R/U wachs cutter. cut csg. 13:15 13:45 0.50 0 0 COMPZ RPCOM RNCS P L/D landing joint, break pup joint, L/D cut joint. 19.79'. 13:45 16:30 2.75 0 0 COMPZ RPCOM NUND P PJSM, N/D drlg spool, N/U tubing spool, energize seal. PT primary, secondary & flange break, 250 psi low, 3000 psi high for 10 minutes, witness, move dbl IA valve to tubing spool. 16:30 18:30 2.00 0 0 COMPZ RPCOM NUND P PJSM, N/U adapter flange and BOPE. 18:30 19:30 1.00 0 0 COMPZ RPCOM RURD P PJSM, R/U to test, BOPE, Attempt to set test plug, landing high in adapter flange. 19:30 20:30 1.00 0 0 COMPZ RPCOM NUND T PJSM, N/D BOPE, verified ID of adapter flange 6.375", N/D adapter flange. 20:30 00:00 3.50 0 0 COMPZ RPCOM EQRP T Clean and clear cellar area, wait on adapter flange. Prepare and mark completion string and jewelry, verify tally. Clean rig and prepare for move. Located adapter flange in Deadhorse, enroute. 6/15/2013 N/U adapter and test breaks. P/U 3-1/2" completion and RIH t/ 587'. POOH to change X nipple arrangement and test BOPE. Test BOP's and RIH w/ 3-1/2" completion per program. Space out and disp to 9.6 ppg Inhibited brine. 00:00 03:30 3.50 0 0 COMPZ RPCOM RURD T PJSM, N/U adapter flange & BOPE, choke line. 03:30 04:00 0.50 0 0 COMPZ RPCOM BOPE P R/U test all breaks on BOPE 250 psi low, 3500 psi High, recorded on chart, R/D Test equipment, set bell nipple. 04:00 04:30 0.50 0 0 COMPZ RPCOM RURD P Clear rig floor. R/U casing equipment. 04:30 06:15 1.75 0 587 COMPZ RPCOM RCST P PJSM, RIH w/ 3-1/2 tubing per running order to 587' MD, fill - Actual 2 bbls, calculated 1.9 bbls. 06:15 06:30 0.25 587 0 COMPZ RPCOM PULL X Decision made to POOH L/D tbg for reconfigure of Tubing / X nipple / Tubing space out. 06:30 08:00 1.50 0 0 COMPZ RPCOM RURD X PJSM, R/U tongs POOH L/D tbg. 08:00 08:15 0.25 0 0 COMPZ RPCOM RURD X Clear Rig floor. 08:15 09:00 0.75 0 0 COMPZ RPCOM RURD P PJSM, R/U test equipment. Page 9 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 12:00 3.00 0 0 COMPZ RPCOM BOPE P Test BOPE 250 psi Low, 3500 psi High: Test #1 - top pipe rams, CV -1, 12, 13, 14, manual kill line valve; Test #2 - Upper IBOP, HCR Kill, CV -9, 11; Test #3 - Lower IBOP, CV -5,8,10; Test #4 - Dart valve, CV -4,6,7; Test #5 - Floor Valve, CV -2; Test #6 - HCR Choke Valve, 4" kill line, HCR Kill. (Jeff Turkington W/ AOGCC waived witness of BOPE test) 12:00 13:45 1.75 0 0 COMPZ RPCOM BOPE P PJSM, Continue BOPE test, Test #7 - Manual Choke Valve, HCR Kill; Test #8 - Annular Preventer; Test #9 - Blind Rams, Valve 3; Test #10 - Test Lower Rams; System Pressure 2900 psi, Pressure after Closed 1700 psi, 200 psi attained in 47 seconds, full pressure attained in 208 seconds, Nitrogen bottles at 2050 psi. Tested with 3.5" test joint, 250 psi low / 3500 psi high. Jeff Turkington w/ AOGCC Waived witness of test. 13:45 14:15 0.50 0 0 COMPZ RPCOM RURD P R/D Test eqpt, B/D choke and kill lines, clean and clear rig floor, hang rig tongs. 14:15 14:30 0.25 0 0 COMPZ RPCOM RURD P R/U to run 3.5" tbg. 14:30 21:00 6.50 0 5,900 COMPZ RPCOM RCST P PJSM, Run 3.5" tbg completion per detail., Establish parameters, P/U 80k, S/O 63k. Calculated= 18.4 bbls, Act = 18.14 bbls. 21:00 22:15 1.25 5,900 5,872 COMPZ RPCOM RCST P Remove bell guide for X -O's spacing, M/U Circ head on joint # 185 with 100 psi tbg pressure and wash down to locate, M/U Circ Head on joint # 186, RIH w/ 100 psi on tubing to locate top of SBE @ 5916' MD with 150 psi increase. R/D Circ eqpt, P/U joint #187 and tag no-go @5939' MD, L/D jts 187, 186,185. 22:15 22:30 0.25 5,872 5,872 COMPZ RPCOM RURD P R/U to reverse Circulate Inhibited Brine. 22:30 00:00 1.50 5,872 5,872 COMPZ RPCOM CIRC P PJSM, Reverse Circ 125 bbls 9.6 inhibited brine @ 3 bpm, 375 psi, flush lines w/ 10 bbls clean brine. 36/16/2013 PT tubing, 3-1/2" IA and 5-1/2" Annulus, sheer out SOV. Set BPV, PT, N/D BOPE, N/U Tree, test and FP. Clean pits, L/D DP, release Rig @ 24:00. 00:00 01:15 1.25 5,872 0 COMPZ RPCOM RNCS P PJSM, R/D Circ Lines, P/U Joint 187 for space out, RIH, M/U Hanger & Landing Joint, land tubing, RILDS, P/U=80k, S/O=63k. Page 10 of 11 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:15 03:30 2.25 0 0 COMPZ RPCOM PRTS P R/U Test tubing to 2500 psi for 30 minutes (record on chart), bleed pressure to 1500 psi, pressure up on 3-1/2" x 5-1/2" IA to 2500 psi for 30 minutes (record on chart), bleed IA to 0 psi, R/U to test 5-1/2" x 7" annulus to 1500 psi for 15 min (record on chart), ramp up 3-1/2" x 5-1/2" IA to 2500 psi, shear SOV, bleed off to 0 psi. 03:30 04:00 0.50 0 0 COMPZ RPCOM OWFF P Monitor well for 30 minutes. (static) 04:00 04:15 0.25 0 0 COMPZ RPCOM RURD P R/D Circ lines, back out landing joint. 04:15 04:45 0.50 0 0 COMPZ RPCOM SEQP P Set BPV, test from below to 1000 psi for 10 min (record on chart). 04:45 06:15 1.50 0 0 COMPZ WHDBO NUND P PJSM, N/D BOPE & adapter flange. Install test dart. 06:15 09:00 2.75 0 0 COMPZ WHDBO NUND P N/U adapter flange & tree, test hanger seals & adapter flange to 250 psi low and 5000 psi high, test tree to 250 psi low and 5000 psi high. 09:00 09:30 0.50 0 0 COMPZ WHDBO RURD P R/D Test equipt, pull test dart & BPV. 09:30 10:00 0.50 0 0 COMPZ WHDBO RURD P PJSM, R/U Circulating lines. 10:00 11:00 1.00 0 0 COMPZ WHDBO FRZP P PJSM, w/ Little Red, Freeze protect 11:00 12:00 1.00 0 0 COMPZ WHDBO FRZP P U-Tube well, R/D Little Red Services, Set Mouse hole. 12:00 13:00 1.00 0 0 COMPZ WHDBO RURD P PJSM, Set BPV, B/D and R/D Circ lines, secure cellar and tree. 13:00 13:45 0.75 0 0 DEMOB MOVE PULD P PJSM, L/D 4" DP via mousehole. 13:45 14:30 0.75 0 0 DEMOB MOVE SVRG P PJSM, install bell guide on top drive, inspect saver sub. 14:30 19:00 4.50 0 0 DEMOB MOVE PULD P PJSM, Continue L/D DP via mousehole, SIMOPS unload pipeshed. 19:00 21:00 2.00 0 0 DEMOB MOVE SLPC P PJSM, Slip and Cut drilling line, 234'. 21:00 21:30 0.50 0 DEMOB MOVE SVRG P Service Rig 21:30 00:00 2.50 DEMOB MOVE DMOB P Remove all casing equipt from rig floor, clean rockwasher, cleanout secondary containment from around the rig. R/D site control and envirovac. Rig release @ 24:00 hrs. Page 11 of 11 1 G-1 OB Post -Rig Well Work Summary DATE SUMMARY 6/24/2013 HAD SCAFFOLD RE -CONSTRUCTED. W/O BPV TO BE PULLED. IN PROGRESS. 6/25/2013 ASSIST VLV CREW WITH BPV. PULLED SOV @ 5813' RKB & SET DV. OPENED CMU @ 5946' RKB. CIRC'D OUT 200 BBLS DSL DOWN TBG & UP 7" ANN (OA) CLOSED CMU @ 5946' RKB. LRS TO MIT OA TO 2500 PSI. IN PROGRESS. 6/26/2013 PULLED DV & SET OV @ 5813' RKB. PULLED DVs & SET GLVs @ 5383', 4434' & 2858' RKB; PULLED CATCHER, BALL & ROD & RHC PLUG BODY @ 6099' RKB; ATTEMPT PULL JUNK CATCHER AND ENCOUNTERED FILL. IN PROGRESS. 6/27/2013 PULLED CATCHER & WRP (MISSING RUBBER ELEMENTS) @ 6189' RKB. GAUGE TBG W/2.66" GAUGE RING DOWN TO 7465' RKB. JOB COMPLETE. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 17, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper (MFC): 1G-IOB Run Date: 6/10/2013 2 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1G -10B Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21003-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: Signed: v WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch Record/ String Shot Record: IG-1OB Run Date: 6/7/2013 June 10, 2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1G-lOB Digital Data in LAS format, Digital Log Image file 50-029-21003-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: c Signed: THE STATE Alaska GIR and Gas 01ALASKA cc�.n&elcvadai-k cGinlrussiGi-I GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Brett Packer Wells Engineer I ConocoPhillips Alaska, Inc. 3 �— P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1G-1OB Sundry Number: 313-167 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner S-/� DATED this 3 1 day of May, 2013. Encl. STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMi ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon _ Plug for Redrill 1"""" Perforate New Pool r"''" Repair well { . Change Approved Program f Suspend ("'" Plug Perforations F- Perforate "' Pull Tubing fv- . Time Extension F- Operational Shutdown j`"F Re-enter Susp. Well "" Stimulate Alter casing � •Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ;�o Exploratory F- Stratigraphic - Service ("mm 213-021-0- 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21003-02 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes F No (*I 1G -10B• 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25640. Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 10540 6489 7526' 6543' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 116' 116' SURFACE 2313 10.75 2350' 2185' PRODUCTION 6255 7 6290' 5441' LINER 1764 3.5 7906' 6868' LINER B 1379 2.375 10540' 6489' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): . slots from 9173-10539' 6516-6489' 3.5 L-80 6151 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER C-2 ZXP LINER PACKER MD=6149 TVD=5311 NIPPLE - CAMCO DS LANDING NIPPLE MD= 523 TVD=523 12. Attachments: Description Summary of Proposal jr 13. Well Class after proposed work: Detailed Operations Program f- BOP Sketch F_ Exploratory )- Stratigraphic f- Development • Service f- 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/11/2013 Oil l;i - Gas F_ WINJ I GINJ ("' WDSPL F_ Suspended F- WAG F Abandoned 16. Verbal Approval: Date: 16. Commission Representative: GSTOR [_ SPLUG I- 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Email: J. Brett. Packeraconocophillips.com Printed Name Brett Packer _ Title: Wells Engineer > Signature �� till Phone: 265-6845 Date Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3/ Plug Integrity " BOP Test ( Mechanical Integrity Test (` ' Location Clearance ) `W Other. l -r-5 �- 7'�' _?P 0G /l 5 '- RBDMS MAY 31 iKJ Spacing Exception Required? Yes ❑ No ( Subsequent Form Required: APPROVED BY Approved by:I NE T I Date: r, r,. .. r• r . ............ .... ...... ..... —11 ...... OR0- is d 1 /2 12) �✓� /' Submit Form and Attachments in Duplicate ��Nb ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 3, 2013 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: A®GCC ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Producer 1G-1OB (PTD# 213-021). 1G-IOB was recently sidetracked with coiled tubing (previously 1G-IOA). Several weeks prior to CTD spudding, a surface casing leak was discovered at 858' MD, thus a loss of one of our barriers. ConocoPhillips policy requires two barriers from any energized fluid to produce a well, and we consider our lift gas to be an energized fluid, therefore, we cannot bring this well online with lift gas until we address the barrier issue. This well has fairly low reservoir pressure and will likely will not flow on its own or will freeze off; it requires artificial lift for sustained production. The proposed workover plans are to pull the existing 3-1/2" tubing, install an inner 5-1/2" casing string, and run a new 3-1/2" completion. Gas lift will be through the 3-1/2" x 5-1/2" annulus and with competent 5-1/2" & 7" casing strings, we will have restored our two barriers. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells I G- l OB Rig Workover Pull 3 �/2" Tubing, Install 5-1/2" Inner Csg String, Run New 3 '/2" Completion (PTD #: 213-021) Current Status:.IG-IOB was recently sidetracked with coiled tubing (previously IG-IOA). Several weeks prior to CTD spudding, a surface casing leak was discovered at 858' MD, thus a loss of one of our barriers. This well requires artificial lift for sustained production, therefore it will remain SI until we can restore a 2nd barrier. Scope of Work: Pull the existing 3-1/2" tubing, install an inner string of 5-1/2" casing, and run a new 3-1/2" completion. General Well info: Well Type: Producer MPSP: 2,073 psi using current SBHP and 0.1 psi/ft gradient. Reservoir Pressure/TVD: 2,724 psi / 6,508' TVD (8.1 ppg) from Panex gauges on 3/1/13. Wellhead type/pressure rating: CIW Gen 1 (Retrofitted), 7-1/16" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -IA passed on 3/4/13. MIT -OA failed due to leak at 858' MD. Earliest Estimated Start Date: July 11, 2013 Production Engineer: Dana Glessner / David Lagerlef Workover Engineer: Brett Packer (265-6845 / j.brett.packer@cop.com) Pre -Rig Work 1. RU Slickline: a. RIH w/ dual Panex gauges to 7450' MD for 30 min. SBHP. Pull up hole to 7335' MD for 15 min. gradient stop. 2. RU E -line: a. RIH and set a WRP in the 3-1/2" liner at 6,190' MD. (mid joint of first full joint below the SBE) 3. CMIT TxIA to 3,000 psi. 4. RU Slickline: a. Set catcher sub on top of WRP at 6190' MD. b. Pull DV from GLM #5 at 6,095' MD, leave pocket open. 5. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Kill Well. ND tree, NU BOPE & test. 3. POOH laying down tubing. 4. RIH w/ cleanout assy. and cleanout down to PBR. 5. On TOH, set a storm packer @ —100' MD w/ drillpipe hanging below. PT storm packer. 6. ND BOP stack, ND tubing head. Install new 5-1/2" casing spool on top of existing CIW Gen 1 3M casing head. NU BOP stack on top of new casing head. PT BOP breaks against the storm packer. (3,000 psi Max WP of casing head) 7. Pull storm packer and continue POOH laying down drillpipe. 8. RU E -line: RIH w/ caliper & gyro. Log from PBR back to surface. 9. MU 5-1/2" inner casing string and RIH to just above the PBR. I G- l OB Rig Workover Pull 3 �/2" Tubing, Install 5-1/2" Inner Csg String, Run New 3 %2" Completion (PTD #: 213-021) ---Procedure Continued --- 10. Circulate corrosion inhibited 9.6 ppg NaCl into the 5-1/2" x 7" annulus. 11. Sting into PBR, space out 4 feet off bottom. PT 5-1/2" x 7" annulus to 500 psi to verify seals are engaged. 12. ND BOP & lift. Install 5-1/2" emergency slips & land 5-1/2" casing in slips. RU Wachs cutter and cut 5-1/2" casing. Remove excess casing & set BOP stack aside. 13. Install casing packoff & new tubing head. Test packoffs. NU BOP stack to tubing head. PT breaks against WRP set in the 3-1/2" liner. PT the 5-1/2" x 7" annulus. 14. RIH w/ new 3-1/2" gas lift completion to just above the SBE, engage the SBE until fully located, space out 7 feet off bottom, mark the pipe and pull out of the PBR. 15. Space out w/ pups, MU hanger. Circulate well full of corrosion inhibited brine. Land the hanger, RILDS. 16. PT the tubing & IA, shear the SOV. 17. Install two-way check, ND BOPE, NU and test tree. Pull two-way check. 18. Freeze protect through the SOV, set BPV. 19. RDMO. Post -Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Open CMU, circulate diesel into 5-1/2" x 7" annulus. Close CMU. PT 5-1/2" x 7" annulus. Pull SOV from GLM #5, run GLD, pull catcher sub, pull WRP. 4. Turn well over to operations/CTD. ConocoPhillips Alaska, Inc ... Well Conf 'MULTIPLE LATERALS - 1G108 41220/32:39:48 PM KUP 1G-106 Wellbore AP W WI Field Name Well Status Incl (°)c MD (ftKB) Act Bt (RKB) :. 500292100302 KUPARUK RIVER UNIT PROD 10,540.0 Comment H25 (ppm) oele Annotation End Date KB-Grd (R) Rig Release Date SSSV: NIPPLE 240 8/14/2012 Last WO: 31.18 9/7/1983 SMematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: SLM Rev Reason: SIDETRACK/LATERALS osborl 4/2/2013 Casin Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WL.. String ... String Top Thrd HANGER, 26 CONDUCTOR 16 15.063 39.0 116.0 62.58 H-40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Third SURFACE 10314 9.950 37.1 2,350.3 45.50 K-55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String... String Top Thrtl PRODUCTION 7 6.276 35.1 6,290.0 26.00 K-55 BTC Post S/r'A' Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Third WINDOW BL2 4 3.000 7,482.0 7,490.0 Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... t.String String W.. String ... ng Top Third RA 31/2 2.992 6,142.3 7,906.0 920 L-80 ABM -BTC i l?Etails Top Depth (TVD) Top Incl Nomi... CONDUCTOR, Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 39-116 6,142.3 TIEBACK BAKER TIEBACK SLEEVE 5250 6,149.2 PACKER BAKER C-2 ZXP LINER PACKER 4.437 NIPPLE, 523 6,155.5 HANGER BAKER HMC HYDRAULIC LINER HANGER 4.375 6,162.1 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Third LINER 23/8 1.995 9,161.5 10,540.0 4.60 L-80 STL Liner Details Top Depth SURFACE, (TVD) Top Incl I Nomi... 37-2,350 Top (ftKB) (ftKB) Rem Description Comment ID (in) 9,161.5 BILLET I Anchored Billet 1.000 GAS LIFT, 2,396 1 uning Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WL.. String ... String Top Third TUBING 31/2 2.992 26.0 6,151.1 9.30 J-55 ABM-EUE GAS LIFT Com ietion Details Top Depth (TVD) Top Incl Nomi... GAS LIFT, TO (ftKB) (ftKB) (°) Item Description Comment ID (in) 4'242 26.0 HANGER CAMERON GEN IV HANGER 3.500 523.0 NIPPLE CAMCO DS LANDING NIPPLE 2.812 GAS gl756 6,141.1 NIPPLE CAMCO D NIPPLE NO GO (MILLED OUT TO 2.89'3/9/2013) 2.800 6,148.1 LOCATOR BAKER GBH -22 LOCATOR SHOULDERS UP ON LINER TIE BACK 3.000 6,150.2 SEALS BAKER SEAL ASSEMBLY- SEALS EXTEND INTO LINER SBE (SEALS 3.000 24.5' OAL) GAS LIFT, 6,095 -- Other In Hole Wireline retrievable pluqs, valves pumps, fish, etc. Top Depth (TVD) Topincl Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) NIPPLE, 6,141 7,482.01 1WHIPSTOCK WHIPSTOCK, ORIENTED 140 DEGREES 3;16/2013 Perforations & Slots Shot Top (TVD) Btm(TVD) Dens LOCATOR,Top(ftKB) Btm (RKB) (RKB) MKS) Zone Date (sh- Type Comment 6.148 - 9,173.0 10,539.0 3/25/2013 32.0 SLOTS Slotted pipe- 0.125'x2.5"@4 circumferential adjacent rows, 3' SEALS, 6,150 centers staggered 18 deg, 3' _ non -slotted ends PRODUCTION Post Sr' 'A', 35-6290 CMT SOZ, 7,318-7,330 CMT SOZ, 7,330.7,340 CMT SOZ, 7,352-7,358 CMT SOZ, 7.366.7,374 WHIPSTOCK, 7,482 WINDOW BL2, 7,482-7,490 IS I (RKB I Incl I I OD I Valve I Latch I Size ITRORunI I I N- Too (ftK81 1 ) (°) Make Model lin) Sery Tvpe Tvoe (in) (psi) Run Date Com LINER A, / L 6.142-7,906 SLOTS, 9,173-10,539 LINER B. 9,162-10,540 I TD (1 G-1011), 10,540 Ferguson, Victoria L (DOA) From: Allsup -Drake, Sharon K <Sharon.K.Allsup-Drake@conocophill ips.com> Sent: Friday, May 31, 2013 1:10 PM To: Ferguson, Victoria L (DOA) Cc: Chan, Paul (Petrotechnical Resources of Alaska) Subject: RE: 1G-10 sundry These are the permit to drill but we submitted a sundry for the workover in question on April 4, 2013 which we have not received back yet. Thank you for your help. Sharon From: Ferguson, Victoria L (DOA)[mailto:victoria.ferguson@alaska.gov] Sent: Friday, May 31, 2013 1:08 PM To: Allsup -Drake, Sharon K Cc: Chan, Paul (Petrotechnical Resources of Alaska) Subject: [EXTERNAL]RE: IG -10 sundry 1G -10A, 1G -10B, 1G-10BL1 and 1G-10BL2 were couriered to you on 2/26/2013. From: Allsup -Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillips.com] Sent: Friday, May 31, 2013 11:03 AM To: Ferguson, Victoria L (DOA) Cc: Chan, Paul (Petrotechnical Resources of Alaska) Subject: 1G-10 sundry Victoria — The workover on 1G -10B is now expected to start the week of June 10, 2013, due to the preceding workovers taking less time than estimated, thereby accelerating the 1G -10B workover start date. The order of the workovers did not change to accelerate the start date. Can you please ensure that we receive the approved sundry no later than the week of June 3, 2013? On a separate note, as part of the workover operations, the well head components are being changed out, and the new casing spool is rated to 31VI psi, therefore, we will only be testing the BOPE breaks to 3000 psi until we nipple up the 5M psi tubing spool, at which time we will be testing all the BOPE breaks to 3500 psi. If you have any questions, please feel free to contact either me or Paul Chan at 263-4759. Thank you, Sharon WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: WRP Setting Record: IG-IOB Run Date: 5/2/2013 �F17- '111 E MAY 10 2013 0 May 6, 2013 2s3- o zk 2252AO The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com &G -10B Digital Data in LAS format, Digital Log Image file 50-029-21003-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew. cook@halliburton. com Date: �J �� Signed:0'" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: ✓ „ 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPIL Other ❑ No. of Completions: Service ❑ StratigraphicTest❑ 2. Operator Name: ✓ 5. Date Comp., Susp., V 12. Permit to Drill Number: / ConocoPhillips Alaska, Inc. orAband.: April 1, 2013 213-021 / 3. Address: 6. Date Spudded: 13. API Number: j P. O. Box 100360, Anchorage, AK 99510-0360 March 18, 2013 50-029-21003-02 4a. Location of Well (Governmental Section): / 7. Date TO Reached: J 14. Well Name and Number: Surface: 386' FSL, 793' FWL, Sec. 29, T12N, R1 OE, UM March 24, 2013 1G -10B & 1G-10BPB1 Top of Productive Horizon: 8. KB (ft above MSL): 94' RKB 15. Field/Pool(s): ✓ 994' FSL, 1234' FEL, Sec. 29, T12N, R10E, UM GL (ft above MSL): 63' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + ND): ,. 1978' FNL, 1593' FEL, Sec. 29, T12N, R10E, UM 10540' MD / 6583' TVD Kupuruk River Oil Pool . 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): V 16. Property Designation: Surface: x-540572 y- 5981035 Zone- 4 10543' MD / 6583' TVD ADL 25640 11. SSSV Depth (MD + TVD): 17. Land Use Permit: TPI: x-543820 y- 5981661 Zone- 4 Total Depth: x- 543441 - 5983967 Zone -4 nipple @ 523' MD / 523' TVD 2571 18. Directional Survey: Yes ❑ 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) 1668' MD / 1599' 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 7481' MD / 6495' 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 39' 116' 39' 116' 24" 212 sx CS II 10.75" 45.5# K-55 37' 2350' 37' 2185' 13.5" 930 sx AS III, 250 sx AS 1 7" 26# K-55 35' 6290' 35' 5441' 8.75" 850 sx Class G, 250 sx AS I 2.375" 4.7# L-80 9161.5' 10540' 6612' 6583' 3" slotted liner 24. Open to production or injection? Yes ❑✓ 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" 6151' 6149' MD / 5305' TVD slotted liner from 9173'-10539' MD 6610'-6583' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. a�P�Li TtOC ` Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ #' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED V iFlEii none -- ,APR 3 0 2013 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) shut-in Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZEGAS-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 n + Sidewall Cores Acquired? Yes ❑ No 21 - 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. NONE Form 10-407 Revised 10/2012Rg®MS MAY 1 20 CONTINUED ON REVERSE // r � /�/ �� Submit original only �\�a\ \-)3 29. GEOLOGIC MARKERS (List all formations and ma,. . ocountered): 30. FORMATION TESTS NAME MD TVD Well tested? 1-1 Yes O No • If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top ground surface ground surface Permafrost - Bottom 1668' 1599' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk A4 7624' 6624' N/A 1G-10BPB1 total depth 8940' Formation at total depth: Kuparuk A4 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional surveys 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. C. Contact: Kai Starck @ 263-4093 Email: Kai. Starck(a)conocophillips.com Printed Name Lamar Gantt Title: Coiled Tubing Drilling Supervisor Z % Signature ji'y� Phone 263-4021 Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 PRODUCTION Post SrT *A', 35-6290 CMT SOZ, 7,318-7,330 CMT SOZ, 7,330-7,340 CMT SOZ, 7.352-7.358 CMT SOZ, 7,366-7,374 WHIPSTOCK, 7,482 WINDOW SL2, 7,482-7,490 " Is...I I (TVD) I Incl 1 1 1 OD I I Valve I Latch I Size TRORunI I I Make LINER A, A 6,142.7,906 SLOTS, 9,173-10,539 LINER B. 9,162-70.540 TD (1G-100), 10,540 KUP Liner Details 1G -10B COfIOCOP�I1��IpS SURFACE, 37-2,350 Max An le & MD TD Naslra If1C mmli eld Name 9,161.51 Well Status Incl t°) MD (ftKB) Act Btm (RKB) GAS LIFT, 2.396 �, Tubing Strings KUPARUK RIVER UNIT PROD 10,540.0 cos LI FT. 3,6fi5 Comment H2S tppm) Date Annotation End Date KB-Grd (ft) Rig Release Dat Top (ftKB) (RKB) C Item Description Comment ID I SSSV: NIPPLE 240 8/14/2012 LaSIWO: 31.18 917/1983 Well Conf' MULTIPLE LATERALS- I UPS 4122013239'48 PM. Schematic-Adua1 Annotation Depth (ftKB) End Date Annotation 6,150.2 SEALS BAKER SEAL ASSEMBLY - SEALS EXTEND INTO LINER SBE (SEALS 3.( Last Mod ... End Data 24.5' OAL) Last Tag: STM Other In Hole Wireline retrievable Rev Reason: SIDETRACWLATERALS osborl 4/2/2013 Top Depth Casing Strincts (TVD) Casing Description String 0... String ID ... Top (ftKB) Set Depth(f... Set Depth (ND) ... String Wt... String... String Top Thrd HANGER, 26 CONDUCTOR 16 15.063 39.0 1 16 .0 62.58 H40 WELDED -,. Casing Description String 0... String ID ... Top (ftKB) Set Depth If Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 37.1 2,350.3 45.50 K-55 BUTT Shot Casing Description String C... String to ... Top (110(13) Set Depth If... Set Depth (TVD) String Wt... String... String Top Thrd Btm (TVD) PRODUCTION 7 6.276 35.1 6,290.0 26.00 K-55 BTC Top (ftKB) Post S/T'A' (ftKB) I (ftKB) Zone Date (sh^ Type Casing Description String 0... String ID ... Top (ftKB) Set Depth If... Set Depth (ND) ... String Wt.. String ... String Top Thrd 3/25/2013 WINDOW BL2 4 3.000 7,482.0 7,490.0 Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SEALS.6,1W - LINER 31/2 2.992 6,142.3 7,906.0 9.20 L-80 I ABM -BTC Liner Details centers staggered 18 deg, 3' non -slotted ends Top Depth (ND) Topincl Nomi CONDUCTOR, Top (ftKB) (RKB) (°) Item Description Comment ID (in 39-116 6,142.3 TIEBACK BAKER TIEBACK SLEEVE 5.2E 6,149.2 PACKER BAKER C-2 ZXP LINER PACKER 4.43 NIPPLE. 523 .......__ _...__...._....__.... ._....__.......__ _- PRODUCTION Post SrT *A', 35-6290 CMT SOZ, 7,318-7,330 CMT SOZ, 7,330-7,340 CMT SOZ, 7.352-7.358 CMT SOZ, 7,366-7,374 WHIPSTOCK, 7,482 WINDOW SL2, 7,482-7,490 " Is...I I (TVD) I Incl 1 1 1 OD I I Valve I Latch I Size TRORunI I I Make LINER A, A 6,142.7,906 SLOTS, 9,173-10,539 LINER B. 9,162-70.540 TD (1G-100), 10,540 LINERB 23/8 1.995 9,161.5 10,540.0 4.60 L-80 STL Liner Details Top Depth SURFACE, 37-2,350 Top (ftKB) (TVD) (RKB) Top incl (') Noi Rem Description Comment ID 9,161.51 JBILLET lAnchored Billet 1.1 GAS LIFT, 2.396 �, Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... Shing... String Top 7hn TUBING 31/2 2.992 26.0 6,151.1 9.30 J-55 ABM-EUE cos LI FT. 3,6fi5 compfetion Details Top Depth (ND) Top Incl Nor GAS LIFT, Top (ftKB) (RKB) C Item Description Comment ID I 4.242 26.0 HANGER CAMERON GEN IV HANGER 3.! 523.0 NIPPLE CAMCO DS LANDING NIPPLE 2.! GAS al756 6,141.1 NIPPLE CAMCO D NIPPLE NO GO (MILLED OUT TO 2.80" 3/9/2013) 2.t 6,148.1 LOCATOR BAKER GBH -22 LOCATOR SHOULDERS UP ON LINER TIE BACK 3.( 6,150.2 SEALS BAKER SEAL ASSEMBLY - SEALS EXTEND INTO LINER SBE (SEALS 3.( GAS LIFT, 24.5' OAL) 6'095 Other In Hole Wireline retrievable pjugs, valves pumps, fish etc. Top Depth (TVD) Top incl Top (ftKB) (ftKB) i°) Description Comment Run Date ID I 7,482.01 1 WHIPSTOCK WHIPSTOCK, ORIENTED 140 DEGREES 3/16/2013 NIPPLE, 6,141 Perforations & Slots Shot Top (ND) Btm (TVD) Dens LOCAfi11Q Top (ftKB) 2tm(ftK13) (ftKB) I (ftKB) Zone Date (sh^ Type Comment 9,173.0 10,539.0 3/25/2013 32.0 SLOTS Slotted pipe -0.125'W.5"@4 circumferential adjacent rows, 3" SEALS.6,1W - centers staggered 18 deg, 3' non -slotted ends PRODUCTION Post SrT *A', 35-6290 CMT SOZ, 7,318-7,330 CMT SOZ, 7,330-7,340 CMT SOZ, 7.352-7.358 CMT SOZ, 7,366-7,374 WHIPSTOCK, 7,482 WINDOW SL2, 7,482-7,490 " Is...I I (TVD) I Incl 1 1 1 OD I I Valve I Latch I Size TRORunI I I Make LINER A, A 6,142.7,906 SLOTS, 9,173-10,539 LINER B. 9,162-70.540 TD (1G-100), 10,540 CTD 16" 62# H-40 shoe @ 116' 0-3/4" 45.5# J-55 hoe @ 2350' MD 7" 26# K-55 shoe @ �I� 6290' MD C -sand perfs (sgz'd) 7,318' - 7,374' MD Seal -Bore Deployment Sleeve @ 7465' MD 1G-10BL2 (A4 sourthwest) TD @ 10,020' MD A -sand perfs (sqz'd) 7,614' - 7,644' MD 3-1/2" 9.2# L-80 shoe @ 7,906' MD — 1/2" Camco DS nipple @ 523' RKB 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Camco FMHO gas lift mandrels @ 2396', 3665', 42421, 4756' RKB 3-1/2" Camco MMM gas lift mandrel @ 6095' RKB 3-1/2" Camco DS landing nipple @ 6141' RKB (2.812" min ID) Baker 3-1/2" GBH -22 seal assembly @ 6150' RKB (3" ID) Baker ZXP liner top packer (616149' RKB Baker 80-40 SBE (129length with 4 KD seal bore) Seal -Bore Deployment sleeve Cad 7465' Baker 3-1/2" Monobore Wipsto`ck @ 7482' KOP from 3-1/2" monobore whipstock @ 1 G-10B-PB1 Anchored Billet @ 8650' 1 G-106 (A4 Northwest) TD @ 10,542' MD' ,_1Liner Top Billet—_ - @ 7900' Liner Top Billet 1G-10BL1 (A3 Northwest) TD @ 10,392' MD 1 G-1 OA Well Work Summary DATE SUMMARY 1/26/2013 TAGGED @ 7765' SLM. MEASURED BHP @ 7300' RKB: 2630 PSI. GAUGED TBG TO 2.79" TO 6141' RKB. DRIFTED WITH 17.3'x 2.625" DUMMY WHIPSTOCK TO 6770' SLM. SET 2.75" CA -2 PLUG @ 6141' RKB; PT TBG AGAINST PLUG & DRAW DOWN TESTED, PASSED. IN PROGRESS. 1/27/2013 SET AVA CATCHER ON PLUG @ 6141' RKB. PULLED GLVs FROM 4755', 3664', &2396' RKB. SET DVs @ SAME. ATTEMPTED PULL OV @ 6095' RKB. IN PROGRESS. 1/28/2013 PULLED OV @ 6095' RKB. LOADED WELL WITH 185 BBL DSL TAKING RETURNS OFF IA TO PRODUCTION. COMBO MIT T x IA 2500 PSI, PASSED. SET DV @ 6095' RKB. MIT IA 2500 PSI, PASSED. PULL AVA CATCHER @ 6141' RKB. IN PROGRESS. 1/29/2013 PULLED CA -2 PLUG @ 6141' RKB. READY FOR E -LINE. 1/31/2013 PERFORMED CALIPER SURVEY WITH 24 -ARM MIT. LOGGED FROM 7650' TO SURFACE. 2/1/2013 PERFORMED GYRO SURVEY WITH GYRODATA GYRO TOOLS. LOGGED SURVEY FROM 7600' TO SURFACE. 2/15/2013 (PRE -CTD): RIG WORK- T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED). SV (PASSED), SSV (PASSED), MV (INCONCLUSIVE). IN PROGRESS. 2/16/2013 (PRE -CTD) MITOA (DID NOT CATCH PRESSURE), PT & DDT ON SV (PASSED), SSV (PASSED), MV (PASSED), RE-ENERGIZE OC PO "Y" SEAL 2/17/2013 (PRE -CTD): RIG WORK - SCLD (SUSPECTED TO BE -858') 2/27/2013 SET CATCHER @ 2505' SLM. PULLED DV @ 2396' RKB & REPLACED WITH OV. PULLED CATCHER. READY FOR DHD. 2/28/2013 (PRE -CTD) OA NFT- FAILED WOULD NOT BLEED TO OPSI. 3/1/2013 PERFORMED RADIAL CEMENT BOND LOG AND SBHP WITH PRESSURE MEMORY GAUGE. FOUND GOOD CEMENT BOND OVER ZONE OF INTEREST AT 7300'- 7600'. FOUND ESTIMATED TOP OF CEMENT @ 6160'. SBHPS FOUND 2723 PSI AND 160 DEGF AT 7500'. 2682 PSI AND 159 DEGF AT 7386' 3/2/2013 (AC EVAL) OA DD TEST- FAILED ON GAS PASSES W/O GAS 3/3/2013 SET 2.75" D CAT SV @ 6141' RKB. PULLED OV @ 2396' RKB. CIRC'D OUT 85 BBL DSL. SET DV @ 2396' RKB. ATTEMPTED MIT TBG 2500 PSI.. OPERATIONS SUSPENDED FOR HIGH WINDS. IN PROGRESS. 3/4/2013 MIT IA 2500 PSI, PASSED. TESTED TBG AGAINST HOLEFINDER 2500 PSI, PASSED. PULLED CAT SV @ 6141' RKB. READY FOR CTU. 3/7/2013 Pumped 15 bbl 15.8 ppg class "G" neat, squeezed 9 bbls to perfs 7,318 -ft to 7,644 -ft RKB, achieved 1200 psi squeeze pressure, washed tubing down to 7,240 -ft, POOH jetting tubing, freeze protect, trapped 500 psi at surface. Stand back CTU for night. 3/8/2013 Weather delayed start. Conduct weekly BOP test 250/4,000 psi. Remove snow from surface lines and equipment. Job in progress. 3/9/2013 Milled "D" nipple out to 2.80". Tagged TOC at 7,370 -ft CTMD, 52 -ft below top perf. Established injection rate of 1,050 psi at .5 bpm. Return in AM for repeat cement job. 3/10/2013 Pumped 10 bbl 15.8 ppg class "G" neat, squeezed '3 bbls to perfs 7,318 -ft to 7,370 -ft RKB, achieved 1200 psi squeeze pressure, washed tubing down to 7,200 -ft, POOH jetting tubing, freeze protect, trapped 500 psi at surface. Stand back CTU for night. 3/11/2013 Milled cement in liner from 7,181 -ft to 7,510 -ft with 2.7" x 3" Bi -center mill. Test tubing to 1,200 psi. RDMO. Ready for Slickline. 3/12/2013 TAG TOC @ 7503' SLM / -7526' RKB. MITT TO 1475 PSI ( PASS) . DRIFT TO TAG DEPTH WITH DMY WHIPSTOCK DRIFT. READY FOR E -LINE TO SET WHIPSTOCK. 3/15/2013 Set 3 1/2" Baker Monobore Whipstock with TOWS at 7482' at an orientation of 140 ROHS ConocoPhiliips Time Log & Summary WeRview Web Repo+7rng Report Well Name: 1G-10 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 3/17/2013 12:00:00 PM Rig Release: 4/1/2013 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 3/16/2013 24 hr Summary RDMO from 1 H-19, move rig to 1 G-10 18:00 00:00 6.00 MIRU MOVE MOB P Move rig from 1 H-19 to 1G-10 3/17/2013 Mobilize rig from 1H-19 to 1G-10. Spot rig & RU. Start BOPE testing at 12:OOpm. State Waived witness by John Crisp. Rig Accept 12:OOpm 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Mobilize rig from 1H pad to 1G pad. Tarp down and plywood around wellhead, Spot rig modules. 06:00 12:00 6.00 0 0 MIRU MOVE MOB P RU Putz, berm up around cellar, RU interconnect, steam, landings, load pits 11.8ppg completion fluid, 13.1 ppg Formate and used 9.6ppg FP. Spot tiger tank, RU hardline to rig from tiger tank. 12:00 22:00 10.00 0 0 MIRU WHDBO BOPE P Perform initial BOPE 250/4,000 psi, annular 2,500 psi. John Crisp (AOGCC) waived witness of test @ 15:45. Rig Accept: 12:00 22:00 00:00 2.00 0 0 MIRU WHDBO BOPE P BOPE test complete with 0 failures. Continue operations servicing Bowen connections on stack, Riser and PDL's, PT PDL's and Tiger tank line. 3/18/2013 PU/MU/RIH BHA 1. Displace well to 9.6ppg used FP. Dry tag TOWS 7481'. Mill window including rat hole down to 7501'. Backream window. POOH 00:00 02:00 2.00 0 0 MIRU WHDBO BOPE P Continue operations servicing Bowen connections on stack, Riser and PDL's, Fill reel with H2O, PT tiger tank liner and inner reel valve, stripper. 02:00 05:00 3.00 0 0 MIRU WHDBO BOPE P Pull BPV. Debris on top BPV. 05:00 05:59 0.99 0 0 MIRU WHDBO BOPE P Pressure test PDL's, Inspect CTC, and CT. Service injector head and reel. 05:59 05:59 0.01 0 0 SLOT WELLPF DISP P 05:59 06:14 0.25 0 0 PROD1 WHPST SFTY P Crew change, PJSM 06:14 07:59 1.75 0 0 PROD1 WHPST PULD P PU/MU BHA1, surface test, open EDC. 07:59 08:59 1.00 0 0 PROD1 WHPST TRIP T RIH w/ milling assembly, counter issue, troubleshoot problem. 08:59 11:08 2.15 0 7,450 PROD1 WHPST TRIP P RIH with BHA #1, log tie-in, -17.5' correction, continue in hole. Page 1 of 13 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:08 12:08 1.00 7,450 7,481 PROD1 WHPST CIRC P _ Swap over to 9.6 ppg mud. Close EDC, weight check 34K, RIH to tag WS, PU 34K. RBIH, stall. 12:08 13:53 1.75 7,481 7,482 PROD1 WHPST MILL P Start time milling as per well plan, tool face 140R, pumping 1.44 bpm @ 3,880 psi, BHP 4,410 psi, DHWOB .SK. 13:53 20:05 6.20 7,482 7,488 PROD1 WHPST MILL P Start auto -driller milling, 1.44 bpm @ 3,882 psi, BHP 4,450 psi, DHWOB= 1.4K. 20:05 22:05 2.00 7,488 7,501 PROD1 WHPST DRLG P Start drilling rathole to 8,501'. 1.44 bpm @ 3,750, BHP 4,450 psi, DNWOB=2.4K. 22:05 23:59 1.90 7,501 7,476 PROD1 WHPST REAM P Make several reaming passes. 1 pass up and down at 140 TF. Additional passes 170 TF, 110 TF up, all passes down at 140 TF. 3/19/2013 Finished milling 2.80 OD window, Displace well to 9.5ppg Flo -Pro. POOH. Undeployed Milling BHA. M/U Build section BHA with a 2.3° AKO motor with a bi-center bit. RIH 00:00 00:30 0.50 7,476 7,500 PROD1 WHPST REAM P 2 additional reaming passes at 140 TF up and down milling off consistent motorwork at 7481'= TOWS. Two additional passes milled off area. PU above TOWS 00:30 00:45 0.25 7,475 7,500 PROD1 WHPST REAM P Drift window without pumps, holding MP. Window looked good. 00:45 02:30 1.75 7,500 0 PROW WHPST TRIP P POOH following MP schedule 02:30 02:45 0.25 0 0 PROD1 WHPST SFTY P At surface, PJSM 02:45 04:30 1.75 0 0 PROD1 WHPST PULD P Undeploy BHA 1 04:30 05:15 0.75 0 0 PROD1 WHPST PULD P LD BHA 05:15 06:00 0.75 0 0 PROD1 DRILL PULD P Deploy BHA 2 06:00 06:30 0.50 0 0 PROD1 DRILL SFTY P Crew change PJSM 06:30 07:30 1.00 0 0 PROD1 DRILL PULD P Cont. to Deploy 07:30 08:00 0.50 62 7,140 PROD1 DRILL TRIP P RIH, w/EDC open 08:00 08:15 0.25 7,140 7,140 PROD1 DRILL DLOG P Tie in depth to K1 minus 18.5' correction 08:15 09:15 1.00 7,140 7,500 PROD1 DRILL TRIP P RIH, Drift window with build BHA. Drift good, PUH above window 09:15 10:30 1.25 7,500 7,501 PROW DRILL TRIP P Displace well to 9.5ppg FP 10:30 17:15 6.75 7,501 7,618 PROD1 DRILL DRLG P RIH Drill ahead, 1.5bpm, 3950 ctp, 44 wh , 3962 bhp, 16k ctw 17:15 17:30 0.25 7,618 7,150 PROD1 DRILL WPRT P Rework directional plan. Out of spec surveys. Tuff drilling. Pull wiper trip early DD reowrk directional plan. Shoot surveys to compare. PU to K1 marker to tie in depth. 17:30 17:45 0.25 7,150 7,178 PROD1 DRILL DLOG P Log Tie into the K1 marker correction of - 5ft. RIH and Log RA marker 7487' (7481' TOWS) 17:45 18:30 0.75 7,178 7,618 PROD1 DRILL WPRT P Wiper back in hole RIW 17 8k Page 2of13 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:30 00:00 5.50 7,618 7,759 PROM DRILL DRLG P 7618'- BOBD 1.48bpm at 3800psi, BHP 3959, WHP 31, Coil Surface Weight + 15k, IA 631, OA 33 3/20/2013 Finished landing the build section at 801 Oft. POOH. Undeployed build BHP, Deployed the B lateral BHA with Rib Steer. RIH 00:00 01:30 1.50 7,759 7,790 PROW DRILL DRLG P OBD 1.48bpm at 3800psi, BHP 4028, WHP 43, 16k coil surface Weight, IA 696, OA 35 01:30 01:45 0.25 7,790 7,500 PROM DRILL WPRT P 7790ft - Wiper up to the bottom of window 01:45 02:00 0.25 7,500 7,790 PROM DRILL WPRT P 7500ft - Wiper back in hole RIW 18k 02:00 04:30 2.50 7,790 7,940 PROD1 DRILL DRLG P 7790ft - BOBD 1.40bpm at 3750psi, BHP 4022, WHP 46, 16k coil surface weight, IA 701, OA 35 04:30 05:45 1.25 7,940 7,572 PROM DRILL WPRT P Wiper up to 7573ft PUW 38k 05:45 06:15 0.50 7,572 7,940 PROM DRILL WPRT P Wiper back in hole RIW 18k 06:15 10:15 4.00 7,940 8,010 PROD1 DRILL DRLG P BOBD 1.49 bpm, 4.35 ctp, Stacking WOB at 7955', sticky PU 42k for BHA wiper. Cont. drilling 10:15 12:15 2.00 8,010 0 PROM DRILL TRIP P Land Build section. POOH 12:15 12:45 0.50 0 0 PROD1 DRILL SFTY P At surface. PJSM 12:45 14:15 1.50 0 0 PROM DRILL PULD P Undeploy BHA 14:15 15:15 1.00 0 0 PROM DRILL SVRG P Service injector head, reel L/W, MP choke, and stripper. 15:15 16:45 1.50 0 0 PROD1 DRILL PULD P Deploy BHA 3 16:45 18:00 1.25 69 7,165 PROM DRILL TRIP P RIH 18:00 18:15 0.25 7,165 7,190 PROM DRILL DLOG P Tie into the K1 correction of - 20ft. 18:15 19:00 0.75 7,190 8,010 PROD1 DRILL TRIP P Continue tripping in hole. RIW 18k 19:00 20:30 1.50 8,010 8,160 PROM DRILL DRLG P OBD 1.43bpm at 3750psi, BHP 3998, WHP 31, 15k coil surface weight, OP 75fph, IA 154, OA 45 20:30 20:45 0.25 8,160 8,020 PROM DRILL WPRT P Wiper trip up to start Madd Pass 20:45 21:30 0.75 8,020 7,500 PROD1 DRILL DLOG P Start Madd Pass from 8020ft - 7500ft 21:30 22:00 0.50 7,500 8,160 PROM DRILL WPRT P Wiper back in hole. RIW 18 22:00 23:45 1.75 8,160 8,310 PROM DRILL DRLG P 8160ft - BOBD 1.41 bpm at 3636psi, BHP 4000, WHP 39, 14k coil surface weight. IA 502, OA 47 23:45 00:00 0.25 8,310 8,141 PROM DRILL WPRT P Wiper trip to window. PUW 34k 3/21/2013 Drilled the "B" lateral until we inadvertantly faulted through the A5/A6 into the B1. Drilled further for Geo's. Decide to POOH for anchored billet. 00:00 00:30 0.50 8,141 8,310 PROM DRILL WPRT P Continue wiper trip 00:30 02:30 2.00 8,310 8,460 PROM DRILL DRLG P OBD 1.40bpm at 3650psi, BHP 4109, WHP 116,13k surface coil weight, 1.8wob, ROP 70fph, IA 582, OA 48 02:30 03:00 0.50 8,460 7,505 PROD1 DRILL WPRT P Wiper up to the window for a tie in. PUW 38 Page 3 of 13 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:00 03:15 0.25 7,505 7,526 PROD1 DRILL DLOG P Tie into RA marker correction of - 2.5ft. 03:15 03:45 0.50 7,526 8,460 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k 03:45 05:45 2.00 8,460 8,610 PROD1 DRILL DRLG P BOBD 1.41 bpm at 3650psi, BHP 4091, WHP 113, WOB 1.6k, ROP 85 fph, 14k coil surface weight, IA 572, OA 48 05:45 06:30 0.75 8,610 8,610 PROD1 DRILL WPRT P Wiper trip 500' . PUW 37k 06:30 09:45 3.25 8,610 8,760 PROD1 DRILL DRLG P Drill Ahead 1.45 bpm, 4013 ctp, 4084 bhp, 74 whp, 14k ctw 09:45 10:15 0.50 8,760 8,000 PROD1 DRILL WPRT P Wiper trip 750'. PUW 10:15 10:30 0.25 8,000 8,760 PROD1 DRILL WPRT P RBIH 10:30 15:30 5.00 8,760 8,910 PROD1 DRILL DRLG P Drill Ahead 1.43 bpm, 4000 ctp, 50 whp, 4130 bhp, 13k ctw. Start preparing for mud swap. Multiple faulting into an uncertain formation. Possibly the A5/A6 8890'. Cont. drilling for data to wiper trip 8010'. 15:30 16:15 0.75 8,910 7,907 PROD1 DRILL WPRT P Wiper trip 38K weight break back to 32k, PUH slowly. Trucks on location pits ready Swap out mud system. 16:15 17:00 0.75 7,907 8,910 PROD1 DRILL WPRT P Wiper back in hole to drill ahead to search for fault. 17:00 20:00 3.00 8,910 8,940 PROD1 DRILL DRLG P BOBD 1.45bpm at 3830psi, BHP 4145, WHP 253, WOB 2.7k, ROP 10-15fph, 12k coil surface weight. 20:00 22:30 2.50 8,940 0 PROD1 DRILL TRIP T POOH 22:30 22:45 0.25 0 0 PROD1 DRILL SFTY T Tag up and space out for Undeploying drilling BHA. PJSM. SIMOPS w/changing out reel motor 22:45 00:00 1.25 0 0 PROD1 DRILL PULD T Start Undeploying BHA 3/22/2013 POOH, Undeployed drilling BHA (RSM). Replace reel motor. M/U and RIH with anchored billet and set TOB at 8650ft 00:00 01:30 1.50 0 0 PROD1 STK PULD T M/U and deploy BHA# 4 Aluminum Anchored Billet 01:30 02:30 1.00 0 0 PROD1 STK CTOP T Finish replacing and test new reel motor. ***** Nabors Reel Motor Swap out ***Nabors on 1 hour Rig Repair Rate*** 02:30 03:15 0.75 0 0 PROD1 STK SVRG P Service INJH at surface. 03:15 03:45 0.50 0 0 PROD1 STK PULD T Finish deploying BHA 03:45 06:30 2.75 0 7,150 PROD1 STK TRIP T RIH with Anchored Billet 06:30 06:45 0.25 7,150 7,150 PROD1 STK DLOG T Tie into K1 correction of -20'. Close EDC. Weight check. 34k puw. 06:45 07:30 0.75 7,150 8,662 PROD1 STK TRIP T Cont RIH Page 4 of 13 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:30 07:45 0.25 8,662 8,662 PROD1 STK WPST T Billet on depth 8662. PU string weight. Online with pumps setting OH anchored billet with single slip at 160 ROHS, 8650 TOB. 3800 psi 07:45 09:45 2.00 8,662 0 PROD1 STK TRIP T POOH 09:45 10:00 0.25 0 0 PROD1 STK SFTY T At surface. PJSM 10:00 11:30 1.50 0 0 PROD1 STK PULD T Undeploy BHA 4 11:30 12:00 0.50 0 0 PROD1 STK BOPE T PU test joint, function test BOPE 12:00 12:30 0.50 0 0 PROD1 STK SFTY T Nabors Crew change. PJSM 12:30 14:30 2.00 0 0 PROD1 STK PULD T Deploy BHA 5 14:30 16:30 2.00 72 7,150 PROD1 STK TRIP T RIH 16:30 16:45 0.25 7,150 7,178 PROD1 STK DLOG T Tie in depth to K1 marker correction of - 20.5'. 16:45 17:30 0.75 7,178 8,653 PROD1 STK TRIP T RIH 17:30 18:00 0.50 8,653 8,653 PROD1 STK TRIP T Dry tag TOB at 8652.5ft. PUW 36k 18:00 20:30 2.50 8,653 8,655 PROD1 STK MILL T Start time milling 20:30 21:00 0.50 8,655 8,690 PROD1 DRILL DRLG T Drilling Ahead 21:00 21:15 0.25 8,690 8,640 PROD1 DRILL WPRT T Dry drift billet area clean 21:15 21:30 0.25 8,640 8,690 PROD1 DRILL WPRT T Wiper back in hole past billet 21:30 23:00 1.50 8,690 8,790 PROD1 DRILL DRLG T OBD 1.40bpm at 3650psi, BHP 4134, WHP 158, WOB 1.5k, ROP 90fph, 14k coil surface weight, IA 217, OA 52 23:00 23:15 0.25 8,790 8,665 PROD1 DRILL WPRT T Wiper up to the bottom of billet 8665ft 23:15 23:30 0.25 8,665 8,790 PROD1 DRILL WPRT T Wiper back on bottom. RIW 18k 23:30 00:00 0.50 8,790 8,857 PROD1 DRILL DRLG T BOBD 1.40bpm at 3650psi, BHP 4110, WHP 130, WOB 1.8k, ROP 91fph, 13k coil surface weight, IA 249, OA 53 3/23/2013 Drilled "B" lateral section as per plan 00:00 01:30 1.50 8,857 8,940 PROD1 DRILL DRLG T OBD 1.40bpm at 3650psi. BHP 4104, WOB 2.3k, ROP 40fph 01:30 01:45 0.25 8,940 8,665 PROW DRILL WPRT P Wiper up to the bottom of billet 01:45 02:00 0.25 8,665 8,940 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k 02:00 04:30 2.50 8,940 9,090 PROD1 DRILL DRLG P BOBD 1.40bpm at 3650psi, BHP 4107, WHP 121, WOB 1.6k, ROP 88fph, IA 303, OA 53 04:30 05:00 0.50 9,090 7,510 PROD1 DRILL WPRT P Wiper to the window for tie in. PUW 34k 05:00 05:15 0.25 7,510 7,525 PROD1 DRILL DLOG P Tie into the RA marker correction of - 4ft 05:15 05:45 0.50 7,525 9,090 PROD1 DRILL WPRT P Wiper back in hole. RIW 18k 05:45 07:15 1.50 9,090 9,169 PROD1 DRILL DRLG P BOBD 1.4bpm at 3650psi, BHP 4113psi Page 5of13 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:15 08:00 0.75 9,170 8,780 PROD1 DRILL WPRT P Wiper trip back to 8780'(390'). early for Geo. 32k puw. stay below billet. 08:00 08:15 0.25 8,780 9,170 PROD1 DRILL WPRT P RBIH 08:15 10:30 2.25 9,170 9,320 PROD1 DRILL DRLG P Drill ahead 1.5 bpm, 4262 ctp, 92 whp, 4138 bhp, 14k ctw 10:30 11:15 0.75 9,320 8,686 PROM DRILL WPRT P Wiper trip back to Billet 8686'. 33k uw. 634' 11:15 11:30 0.25 8,686 9,320 PROM DRILL WPRT P RBIH 40fpm 11:30 13:45 2.25 9,320 9,470 PROM DRILL WPRT P Drill Ahead 1.5 bpm, 4300 ctp, 89 whp, 4194 bhp, 10k ctw. 13:45 14:45 1.00 9,470 7,487 PROM DRILL WPRT P Wiper trip back to window 33k puw 14:45 15:00 0.25 7,487 7,487 PROD1 DRILL DLOG P Log RA marker, -8' correction 15:00 16:00 1.00 7,487 9,470 PROM DRILL WPRT P RBIH 16:00 17:30 1.50 9,470 9,620 PROM DRILL DRLG P Drill Ahead 1.5 bpm, 4340 ctp, 111 whp, 4185 bhp, 13k ctw 17:30 18:00 0.50 9,620 9,000 PROM DRILL WPRT P Wiper trip, PUW 33 18:00 18:30 0.50 9,000 9,620 PROM DRILL WPRT P Wiper back in hole. RIW 15k 18:30 20:30 2.00 9,620 9,775 PROD1 DRILL DRLG P BOBD - 1.44bpm at 3927psi, BHP 4223, WHP 135, WOB 2.6k, ROP 70fph 20:30 21:00 0.50 9,770 8,700 PROM DRILL WPRT P Wiper up to 8700ft, PUW 36k 21:00 21:30 0.50 8,700 9,770 PROM DRILL WPRT P Wiper back in hole. RIW 16k 21:30 23:00 1.50 9,770 9,935 PROM DRILL DRLG P BOBD - 1.44bpm at 3961 psi, BHP 4695, WHP 131, ROP 100fph, IA 564, OA 54 23:00 00:00 1.00 9,935 7,715 PROM DRILL WPRT P Wiper up to window for tie in. PUW 35k 3/24/2013 Drilled "B" Lateral to TD 10543ft. Pulled a wiper to the swab. 00:00 00:15 0.25 7,715 7,510 PROD1 DRILL WPRT P Continue wiper from 9935ft. 00:15 00:30 0.25 7,510 7,570 PROM DRILL DLOG P Tie into RA marker correction of - 45ft 00:30 00:45 0.25 7,570 7,440 PROM DRILL WPRT P Pull up into the casing and replace Injector head. 00:45 01:00 0.25 7,440 7,440 PROD1 DRILL SVRG P Replace Injector head counter 01:00 01:15 0.25 7,440 7,510 PROM DRILL WPRT P RBIH to tie in. 01:15 01:30 0.25 7,510 7,528 PROD1 DRILL DLOG P Tie into RA marker. no correction 01:30 02:30 1.00 7,528 9,935 PROM DRILL WPRT P Contiue wiper in hole. RIW 18k 02:30 04:45 2.25 9,923 10,085 PROW DRILL DRLG P BOBD - 1.40bpm at 3900psi, BHP 4218, WHP 66, WOB 1.6k, ROP 100fph 04:45 05:15 0.50 10,085 9,000 PROM DRILL WPRT P Wiper up to 9000'. PUW 34k 05:15 06:00 0.75 9,000 10,085 PROM DRILL WPRT P Wiper back in hole. RIW. 06:00 06:30 0.50 10,085 10,117 PROM DRILL DRLG P Drill ahead 1.46 bpm, 4326 ctp, 211 whp, 4329 bhp, 7k ctw 06:30 06:39 0.15 10,117 10,117 PROD1 DRILL WPRT P Depth counter stopped working PU of bottom, found loose wire. Reset depth to CTES. RBIH Page 6 of 13 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:39 06:48 0.15 10,117 10,132 PROD1 DRILL DLOG P Ream down 150 fph, logging hole data, 06:48 07:48 1.00 10,132 10,235 PROD1 DRILL DRLG P Cont drilling 1.45 bpm, 4315 ctp, 214 whp, 4307 bhp, 7-9k ctw. 07:48 09:03 1.25 10,235 10,235 PROD1 DRILL WPRT P Wiper trip back to 8925'. 35k PUW 09:03 11:03 2.00 10,235 10,385 PROD1 DRILL DRLG P Drill ahead 1.45 bpm, 4300 ctp, 210 whp, 4308 bhp, 9k ctw. Monitor depth tracking on BHI counter with CTES counter. Exact match. cont drilling. Pump low/high sweeps. 11:03 12:15 1.20 10,385 10,385 PROD1 DRILL WPRT P Wiper trip 500' chasing sweeps. 33k PUW 12:15 15:00 2.75 10,385 10,543 PROD1 DRILL DRLG P Drill ahead. 15:00 18:30 3.50 10,543 72 PROD1 DRILL WPRT P pump sweep, TD lateral @ 10543'. 33k off btm. Wiper up to the swabs. 18:30 20:00 1.50 72 7,150 PROD1 DRILL WPRT P Wiper back in hole 20:00 20:15 0.25 7,150 7,180 PROW DRILL DLOG P Tie into the K1 correction of- 13ft. 20:15 22:00 1.75 7,180 10,540 PROD1 DRILL WPRT P Continue wiper in hole. 22:00 22:15 0.25 10,540 10,540 PROD1 DRILL TRIP P Tag TD at 10540ft, PUH and Paint EOP flagYellow at 8999.9ft. 22:15 00:00 1.75 10,540 5,190 PROW DRILL TRIP P POOH laying in 11.8ppg completion fluid with alpine beads up to window. Paint EOP flag White at 5899.8ft. 3/25/2013 Ran liner in B lateral to 10,540' setting the anhored billet at 9159'. kicked off billet, started drilling BL1 lateral. 00:00 01:15 1.25 5,190 72 PROW DRILL TRIP P Continue POOH 01:15 01:30 0.25 72 72 PROD1 DRILL SFTY P OOH, Check well for flow. PJSM for LD drilling tools. 01:30 02:00 0.50 72 0 PROD1 DRILL PULD P Laydown BHA 02:00 02:15 0.25 0 0 PROD1 DRILL SVRG P Tighten reel bolts on reel saddles. Prep Rigfloor for running liner. 02:15 02:45 0.50 0 100 COMPZ CASING PUTB P M/U "B" liner 02:45 03:00 0.25 100 100 COMPZ CASING SFTY P BOPE Drill with rig crew. Drill Time 1 min 32sec. 03:00 05:00 2.00 100 1,440 COMPZ CASING PUTB P Continue M/U "B" liner assy. 05:00 08:00 3.00 1,440 10,540 COMPZ CASING RUNL P RIH - with 41 jts of slotted liner for "B" lateral completion with Anchored billet. Open EDC. See first flag 7340' -13', close EDC. CIH, see second flag 100' off BTM, good. Tag up @ 10540. Pull up for pick up wt, 40.5k. Run back down, 10539.38, 2.4 k WOB. Pressure up coil to 4000 psi, shear running tool. Pick -off, 35k liner gone. 08:00 10:45 2.75 10,540 0 COMPZ CASING RUNL P POOH pumping mininum rate down coil to keep hole full. 10:45 11:30 0.75 0 0 COMPZ CASING PUTB P Tagged up. Watch for no flow. Conduct PJSM for BHA change out. Page 7 of 13 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:30 15:30 4.00 0 0 PROD2 STK SVRG P Service injector, replace pack offs. Chanhe out checjs. Coil has a flat spot just above the coil connector. Decide to cut coil to just above flat spot & re -head. 15:30 16:15 0.75 0 0 PROD2 STK PULD P Pre -Job, Pu drilling BHA. 16:15 18:15 2.00 72 7,140 PROD2 STK TRIP P RIH 18:15 18:30 0.25 7,140 7,140 PROD2 STK DLOG P Log K-1, for a -13' correction. 18:30 19:45 1.25 7,140 7,452 PROD2 STK CIRC P RIH to just above window 7452'. Pump 9.5 flo-pro drilling down coil circulating & recovering the completion fluid. 19:45 20:15 0.50 7,452 9,160 PROD2 STK TRIP P Close EDC, RIH 20:15 22:30 2.25 9,160 9,170 PROD2 STK KOST P Tag TOB @ 9160'. Kick off billet, time milling, Have several stalls. Pick up 100' & try again. apperars to be slip sticking. 22:30 23:30 1.00 9,170 9,195 PROD2 DRILL DRLG P Drill Ahead 1.38bpm at 3759psi. BHP 4632 23:30 23:45 0.25 9,195 9,150 PROD2 DRILL WPRT P PUH and drift billet area. 23:45 00:00 0.25 9,150 9,195 PROD2 DRILL WPRT P RBIH - Billet area clean 3/26/2013 Drilled 9195 to 10225', Swapped mud @ 10225 00:00 01:15 1.25 9,195 9,325 PROD2 DRILL DRLG P BOBD - 1.40bpm at 4015psi, BHP 4173, WHP 47, WOB 1.5, ROP 01:15 01:30 0.25 9,325 9,180 PROD2 DRILL WPRT P Wiper up to bottom of billet 9170ft 01:30 01:45 0.25 9,180 9,325 PROD2 DRILL WPRT P Wiper back in hole. RIW 16k 01:45 03:30 1.75 9,325 9,475 PROD2 DRILL DRLG P BOBD 1.43bpm at 3923psi. BHP 4131, WHP 39, WOB 1.5k ROP 100fph 03:30 04:00 0.50 9,475 9,180 PROD2 DRILL WPRT P Wiper to the billet PUW 34k 04:00 04:30 0.50 9,180 9,475 PROD2 DRILL WPRT P Wiper back in hole. RIW 15k 04:30 06:15 1.75 9,475 9,625 PROD2 DRILL DRLG P BOBD - 1.40bpm at 3960psi, BHP 4160, WHP 38, CTW 11k 06:15 07:15 1.00 9,625 7,510 PROD2 DRILL WPRT P Wiper up for a tie in. PUW 36k 07:15 07:30 0.25 7,510 7,550 PROD2 DRILL DLOG P Tie into RA marker correction of + 1' 07:30 08:30 1.00 7,550 9,625 PROD2 DRILL WPRT P Wiper back in hole. RIW 16k 08:30 11:00 2.50 9,625 9,775 PROD2 DRILL DRLG P BOBD - 1.40bpm at 3923psi, BHP 4054, WHP 40, CWT 12k 11:00 11:30 0.50 9,775 8,700 PROD2 DRILL WPRT P Wiper up hole. PUW 36k 11:30 12:00 0.50 8,700 9,775 PROD2 DRILL WPRT P Wiper back in hole. RIW 12:00 14:00 2.00 9,775 9,925 PROD2 DRILL DRLG P BOBD - 1.40bpm at 3963, BHP 4109, WHP 40, CTW 12k, IA 457, OA 63 14:00 14:30 0.50 9,925 8,700 PROD2 DRILL WPRT P Wiper up hole. PUW 36k 14:30 15:30 1.00 8,700 9,925 PROD2 DRILL WPRT P Wiper back in hole. RIW 15k Page 8 of 13 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:30 17:18 1.80 9,925 10,075 PROD2 DRILL DRLG P BOBD - 1.4bpm at 3964psi, BHP 4220 , WHP 110, IA 485 , OA 64 17:18 20:12 2.90 10,075 10,075 PROD2 DRILL WPRT P Wiper to window with tie in, PUW=35K no correction at tie in 20:12 22:54 2.70 10,075 10,225 PROD2 DRILL DRLG P 10075', Drill Ahead, 1.4 BPM @ 3750 PSi FS, BHP=4220 22:54 00:00 1.10 10,225 9,732 PROD2 DRILL WPRT P 10225 wiper to 9200', Swap Mud. Midni ht 9732 RIH 3/27/2013 TD well @ 10393', Wiper to swab, Pump liner Pill and 12.2 Completion fluid. Run Lower BL1 liner 10392 to 8540 00:00 00:18 0.30 9,732 10,225 PROD2 DRILL WPRT P Continue wiper from 10225' 00:18 02:54 2.60 10,225 10,392 PROD2 DRILL DRLG P 10225', Drill Ahead, 1.44 BPM @ 4050 PSi FS, (New Mud), BHP=4200 02:54 06:30 3.60 10,392 0 PROD2 DRILL WPRT P 10392', Call TD, Pump 10-10 sweeps and chase to swab valves. PUW=35K 06:30 08:00 1.50 0 7,150 PROD2 DRILL WPRT P RIBIH, continue wiper in hole. 08:00 08:15 0.25 7,150 7,181 PROD2 DRILL DLOG P Tie into the K1 marker correction of 0 ft. 08:15 10:00 1.75 7,181 10,392 PROD2 DRILL WPRT P RIH 10:00 13:00 3.00 10,393 0 PROD2 DRILL TRIP P Confirm TD 10393', POOH laying in 11.8ppg completion fluid with alpine beads. Paint EOP flag at 8471.72' Yellow.5571.78' White. 13:00 13:30 0.50 0 0 PROD2 DRILL SFTY P Conduct PJSM for laying down drilling BHA while flow checking well. 13:30 14:15 0.75 0 0 PROD2 DRILL PULD P LD Drilling BHA 14:15 14:45 0.50 0 0 PROD2 DRILL SVRG P Service top drive and prep rig floor for liner ops 14:45 15:00 0.25 0 0 COMPZ CASING SFTY P Conduct PJSM for M/U liner 15:00 15:30 0.50 0 0 COMPZ CASING PUTB P M/U 59 jts of slotted liner - BOPE drill while tripping in with tubing drill time was 2mins 45sec. 15:30 16:00 0.50 0 189 COMPZ CASING PUTB P Rabbit failed to go through pipe. Switch out joint, and try and retrieve rabbit. 16:00 19:00 3.00 189 1,896 COMPZ CASING PUTB P continue M/U liner, Make up to coil and surface test. Strip on well 19:00 19:45 0.75 1,896 1,896 COMPZ CASING RGRP T Working CTES Issues to ensure coil fatigue operational 19:45 21:21 1.60 1,896 7,395 COMPZ CASINGTRIP P Trip in well 21:21 21:27 0.10 7,395 7,399 COMPZ CASING DLOG P Tie in to EOP flag for -13.2, PUW=39K 21:27 22:15 0.80 7,399 8,985 COMPZ CASING TRIP P RIH with liner 22:15 22:21 0.10 8,985 9,000 COMPZ CASING DLOG P Tie in to K1 Marker, for no correctiom 22:21 23:03 0.70 9,000 10,392 COMPZ CASINGTRIP P Continue in with liner, No correction at lower flag drive by 23:03 00:00 0.95 10,392 7,744 COMPZ CASINGTRIP P Tag @ 10392„ PUW=45Kwith liner, set back down, Pumps on @ 1.25 BPM, PUW=38K. Liner released POOH Page 9 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 3/28/2013 24 hr Summary Complete running BL1 Liner BOL=10392, TOL=7901, Complete full BOPE Test. Test witnes waived By Bob Nobel, AOGCC 00:00 02:00 2.00 7,744 41 COMPZ CASING TRIP P Continue out of well Paint EOP flags @ 7700 and 6700 02:00 02:36 0.60 41 0 COMPZ CASING PULD P �At surface, Flow check well, PJSM lay down BHA on dead well 02:36 04:00 1.40 0 630 COMPZ CASING PUTB P PJSM, Start making up BI -1 Upper liner section, Ported bullnose, 20 jts slotted liner and anchored billet. Held Safety joint drill 3 Minutes good test 04:00 06:00 2.00 630 630 COMPZ CASING PULD P P/U, M/U, and scribe BHI tools onto liner assy. 06:00 08:00 2.00 630 7,401 COMPZ CASING RUNL P RIH - w/20jts of slotted and anchored billet. IA 0, OA 61 08:00 08:15 0.25 7,401 7,401 COMPZ CASING DLOG P Correct to EOP Flag correction of - 14'. 08:15 08:45 0.50 7,401 8,140 COMPZ CASING RUNL P Continue RIH with liner 08:45 09:00 0.25 8,140 8,154 COMPZ CASING DLOG P Gamma tie into RA marker correction of + 2'. 09:00 09:15 0.25 8,154 8,541 COMPZ CASING RUNL P Continue in hole with upper liner section 09:15 11:00 1.75 8,541 0 COMPZ CASING RUNL P POOH circulating pipe displacement. 11:00 11:15 0.25 0 0 COMPZ CASING SFTY P Conduct PJSM - L/D liner running tools while performing a flow check. 11:15 12:15 1.00 0 0 COMPZ CASING PULD P Blow down and L/D BHI and BOT BHA. 12:15 13:15 1.00 0 0 COMPZ CASING PULD P R/D liner running eqiupment. 13:15 14:45 1.50 0 0 PROD3 DRILL BOPE P Prep to start BOP tesing. 14:45 15:30 0.75 0 0 PROD3 DRILL BOPE P Conduct PJSM - BOPE Testing - grease tree 15:30 23:00 7.50 0 0 PROD3 DRILL BOPE P Start BOPE testing, Test witness waived b Bob Nobel, AOGCC 23:00 23:48 0.80 0 0 PROD3 DRILL PULD P PJSM, P/U BHA #10 Drill By BHA with .7° motor, Hyc Bicenter with test cutters 23:48 00:00 0.20 0 0 PROD3 DRILL SVRG P Tool in hole, servicing injector 3/29/2013 Trip in and Kick off liner top Billet @ 7897, Drill ahead to 8960 00:00 00:30 0.50 0 72 PROD3 STK PULD P Make up coil to BHA and surface test 00:30 02:24 1.90 72 7,155 PROD3 STK TRIP P Trip in in casing, EDC Open 02:24 02:36 0.20 7,155 7,192 PROD3 STK DLOG P Log K1 for -14' 02:36 03:48 1.20 7,192 7,450 PROD3 STK CIRC P Swap well back to 9.5 PPG Flo Pro 03:48 04:06 0.30 7,450 7,898 PROD3 STK TRIP P Close EDC, PUW=34.6K, Trip in to find billet, Clean trip through window, Dry tag billet @ 7897.56 04:06 04:54 0.80 7,898 7,897 PROD3 STK MILL P PUH, Bring pumps on @ 1.4 BPM@ 4000 PSI FS, BHP=4047, See DHWOB and diff press @ 7897.0 04:54 05:30 0.60 7,897 7,900 PROD3 STK MILL P Stacking out, Pick up and reset, Milling Billet. Seem to be off of billet. Page 10 of 13 'rime Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:30 06:00 0.50 7,900 7,940 PROD3 DRILL DRLG P Drilling Ahead 06:00 06:15 0.25 7,940 7,885 PROD3 DRILL WPRT P PUH and dry drift billet area. 06:15 06:30 0.25 7,885 7,940 PROD3 DRILL WPRT P RIH past billet clean. 06:30 07:15 0.75 7,940 8,040 PRODS DRILL DRLG P Drilling Ahead 1.41 bpm at 4030psi. BHP 4041, WHP 4, WOB 1.4k, ROP 130fph. IA 24, OA 65 07:15 07:45 0.50 8,040 7,530 PROD3 DRILL WPRT P Wiper up to 7530', PUW 33k 07:45 08:15 0.50 7,530 8,040 PROD3 DRILL WPRT P Wiper back in hole. RIW 18k 08:15 09:30 1.25 8,040 8,190 PROD3 DRILL DRLG P BOBD - 1.41 bpm at 4030psi, BHP 4030, WHP 5. 09:30 10:00 0.50 8,190 7,530 PRODS DRILL WPRT P Wiper up to 7530ft. PUW 33k 10:00 10:30 0.50 7,530 8,190 PROD3 DRILL WPRT P Wiper back in hole. RIW 18k 10:30 11:30 1.00 8,190 8,340 PRODS DRILL DRLG P BOBD - 1.41 bpm at 4030psi. BHP 4032, WHP 5, IA 73, OA 66. 11:30 12:00 0.50 8,340 7,510 PRODS DRILL WPRT P Wiper up to tie into the RA marker 12:00 12:15 0.25 7,510 7,551 PROD3 DRILL DLOG P Tie into RA marker correction of + 1' 12:15 12:45 0.50 7,551 8,340 PROD3 DRILL WPRT P Wiper back in hole. RIW 16k 12:45 14:00 1.25 8,340 8,490 PROD3 DRILL DRLG P BOBD - 1.43bpm at 4051 psi, BHP 4117, WHP 91, WOB 1.5k, ROP 14:00 14:30 0.50 8,490 7,915 PRODS DRILL WPRT P Wiper up to 7930'. PUW 33k 14:30 15:00 0.50 7,915 8,490 PROD3 DRILL WPRT P Wiper back in hole. RIW 16k 15:00 16:00 1.00 8,490 8,640 PRODS DRILL DRLG P BOBD - 1.40bpm at 4060psi. BHP 4037, WHP 20, IA 170, OA 66 16:00 16:30 0.50 8,640 7,915 PRODS DRILL WPRT P Wiper up to 7930'. PUW 33k 16:30 17:15 0.75 7,915 8,640 PRODS DRILL WPRT P Wiper back in hole. RIW 16k 17:15 18:15 1.00 8,640 8,773 PRODS DRILL DRLG P BOBD 1.36bpm at 4053', BHP 4121, WHP 92, WOB 1.6k, ROP 140fph. 18:15 18:21 0.10 8,773 8,773 PROD3 DRILL WPRT P Lost pump prime starting sweeps down hole. PUH then stacked out on way back in 18:21 19:15 0.90 8,773 8,773 PRODS DRILL WPRT P Stuck just off bottom, Able to maintain full circulation, Work pipe. Circulate sweeps around to surface 19:15 19:27 0.20 8,773 8,773 PRODS DRILL WPRT P Work Pipe, Trap pressure and let pipe hole relax, Pull free at 59K 19:27 20:21 0.90 8,773 7,510 PROD3 DRILL WPRT P Wipe to window 20:21 20:27 0.10 7,510 7,526 PRODS DRILL DLOG P Log RA Marker for -.5' correction 20:27 20:57 0.50 7,526 8,773 PROD3 DRILL WPRT P Wiper trip back to bottom 20:57 22:27 1.50 8,773 8,925 PRODS DRILL DRLG P 8773 Drill ahead, 1.4 BPM @ 3700 PSI FS, BHP=4080 22:27 23:39 1.20 8,925 8,925 PROD3 DRILL WPRT P Wiper to Billet 7990, PUW=34K 23:39 00:00 0.35 8,925 8,960 PROD3 DRILL DRLG P 8925', Drill Ahead, 1.4 BPM @ 3740 PSi FS, BHP=4110 3/30/2013 Drilled 8960 to 9840 00:00 01:12 1.20 8,960 9,075 PRODS DRILL DRLG P Drill ahead 1.4 BPM @ 3750PSI FS, BHP=4140 Page 11 of 13 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:12 02:30 1.30 9,075 91075 PRODS DRILL WPRT P Wiper to 7940, PUW=35K 02:30 04:30 2.00 9,075 9,225 PRODS DRILL DRLG P 9075', Drill ahead, 1.44 BPM @ 3900 PSI FS, BHP=4140, RIW-16K New mud at bit @ 9178, 1445' on old s stem .6% DS 04:30 05:30 1.00 9,225 7,510 PRODS DRILL WPRT P 9225 wiper to window with tie in. PUW=34K, BHP=4130, WHP=115 05:30 05:45 0.25 7,510 7,525 PRODS DRILL DLOG P Tie into RA marker NO correction. 05:45 06:30 0.75 7,525 9,225 PRODS DRILL WPRT P Wiper back in hole. RIW 15k 06:30 07:30 1.00 9,225 9,375 PRODS DRILL DRLG P BOBD - 1.48bpm at 4085psi, BHP 4142, WHP 109, IA 511, OA 69 07:30 08:15 0.75 9,375 8,000 PRODS DRILL WPRT P Wiper up to 7930', PUW 34k 08:15 09:00 0.75 8,000 9,375 PRODS DRILL WPRT P Wiper back in hole. RIW 09:00 13:30 4.50 9,375 9,525 PRODS DRILL DRLG P 9375ft - BOBD 1.40bpm at 3950psi. BHP 4130, WHP 92, IA 588, OA 70 13:30 14:00 0.50 9,525 8,350 PRODS DRILL WPRT P Wiper up hole, PUW 33 14:00 14:30 0.50 8,350 9,525 PRODS DRILL WPRT P Wiper back in hole. RIW 16 14:30 17:54 3.40 9,525 9,675 PRODS DRILL DRLG P BOBD - 1.46bpm at 3960psi, BHP 4130, WHP 66, IA 634, OA 70 17:54 19:00 1.10 9,675 7,510 PRODS DRILL WPRT P Wiper up hole. PUW 33k 19:00 19:06 0.10 7,510 7,526 PRODS DRILL DLOG P Log tie into RA marker for no correction 19:06 20:12 1.10 7,526 9,675 PRODS DRILL WPRT P Wiper back in hole. RIW 20:12 22:06 1.90 9,675 9,825 PRODS DRILL DRLG P 9675', Drill ahead, 1.4 BPM @ 3790 PSI FS, BHP=4160 22:06 23:48 1.70 9,825 9,825 PRODS DRILL WPRT P Wiper to billet 7925', PUW=33K 23:48 00:00 0.20 9,825 9,840 PRODS DRILL DRLG P 9825', Drill Ahead, 1.4 BPM @ 3800 PSI FS, BHP=4230 03/31/2013 TD well @ 10020', Condition Hole, run BL2 liner to bottom TOL=7465, BOL=10020 00:00 02:12 2.20 9,840 9,975 PRODS DRILL DRLG P 9840', Drill ahead 02:12 04:12 2.00 9,975 9,975 PRODS DRILL WPRT P 9975', Wiper to billet 7925', PUW=32K, BHP=4200, Clean trip out and in 04:12 05:30 1.30 9,975 10,020 PRODS DRILL DRLG P 9975', Drill Ahead, 1.4 BPM @ 3850 PSI FS, BHP=4137 05:30 08:30 3.00 10,020 72 PRODS DRILL WPRT P Pump 10x10, TD BL2 lateral 10020ft. Wiper to the swab. PUW 33 08:30 10:00 1.50 72 7,150 PRODS DRILL WPRT P At surface. RBIH to tie into the K1. 10:00 10:15 0.25 7,150 7,168 PRODS DRILL DLOG P Tie into the K1 correction of minus 2'. 10:15 11:45 1.50 7,168 10,020 PRODS DRILL WPRT P Continue tripping in hole to confirm TD10020ft 11:45 15:00 3.25 10,020 0 PRODS DRILL TRIP P PUH laying in 11.8ppg completion fluid with 2ppb alpine beads, Paint EOP Flags @ 7300 & 4800' 15:00 15:45 0.75 0 0 PRODS DRILL PULD P Conduct PSJM to UD Drilling BHA. 15:45 16:21 0.60 0 0 COMPZ CASING PULD P PJSM, Prep floor to run liner Page 12 of 13 'Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:21 19:45 3.40 0 2,554 COMPZ CASING PUTB P M/U BHA #11, Non ported bullnose, 76 Jts 2 3/8" slotted, 5 jts 2 3/8" solid, and long deployment sleeve 19:45 20:45 1.00 2,554 2,598 COMPZ CASING PULD P R/D floor from liner running, P/U Coil track, M/U to liner, M/U to coil and surface test tool 20:45 22:09 1.40 2,598 7,398 COMPZ CASING TRIP P Trip in with liner, EDC closed 22:09 22:15 0.10 7,398 7,398 COMPZ CASING DLOG P Tie into 4300' EOP flag for -11.4' correction, PUW=38K 22:15 22:51 0.60 7,398 9,680 COMPZ CASING TRIP P Continue in well, clean trip through window 22:51 23:03 0.20 9,680 9,705 COMPZ CASING DLOG P Log K1 marker for +5' correction, BOT counter has quit working after starting in hole continue to bottom 23:03 23:57 0.90 9,705 10,020 COMPZ CASING TRIP P Run liner to bottom, PUW=56K, Can get numbers to work out between CTS and injector counter, Pump on @ 1.4 BPM @ 4K PSI, PUW=35K. Trip up hole to confirm tie in, remove liner length from counters 2554.37' 23:57 00:00 0.05 7,130 7,145 COMPZ CASING DLOG P 7130 log tie into K1 correction of + 5ft D4/01/2013 Land liner, Roll well to seawater and Freeze protect to 2500'. Set BPV, flush rig RDMO 00:00 00:06 0.10 7,145 7,165 COMPZ CASING DLOG P Tieing into K1 marker for -1', BOL=10020, TOL=7465, 00:06 00:12 0.10 7,165 7,450 COMPZ CASING TRIP P RBIH to circulate seawater around 00:12 01:12 1.00 7,450 7,450 DEMOB WELLPF CIRC P Roll well to seawater, recover Bromide completion fluid 01:12 02:36 1.40 7,450 2,500 DEMOB WELLPF TRIP P POOH on seawater, PUW=33.5K 02:36 03:00 0.40 2,500 2,500 DEMOB WELLPF FRZP P Freeze protect well with Diesel 03:00 03:48 0.80 2,500 30 DEMOB WELLPF TRIP P Open EDC, POOH chasing diesel out of coil with seawater 03:48 06:00 2.20 30 0 DEMOB WELLPF PULD P At surface, PJSM, PUD BHA # 11, Liner running tools 06:00 06:15 0.25 0 0 DEMOB WHDBO NUND P Conduct PJSM with FMC and rig crew for setting BPV. 06:15 08:45 2.50 0 0 DEMOB WHDBO NUND P Set BPV 3inch Type H 08:45 09:00 0.25 0 0 DEMOB WHDBO NUND P Conduct PJSM - swapping coil over to fresh water and flushing surface lines. 09:00 11:45 2.75 0 0 DEMOB WHDBO NUND P Conduct PJSM - RDMO 11:45 12:00 0.25 0 0 DEMOB WHDBO NUND P XXXXX RIG RELEASE 12:00 NOON XXXX Page 13 of 13 ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1G Pad 1G -10B 50-029-21003-02 Baker Hughes INTEQ Definitive Survey Report 03 April, 2013 WE as BAKER HUGHES -' ConocoPhillips or its affiliates RAN ConocoPhillips BAKER Definitive Survey Report GMS Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Project: Kuparuk River Unit TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Well: 1G -1D North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G -1D 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 1G-10 Well Position +N/ -S 0.00 ft Northing: 5,981,034.77ft Latitude: 70° 21'32.824 N +E/ -W 0.00 ft Easting: 540,572.19ft Longitude: 149° 40' 13.660 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft j Wellbore 1G-108 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2012 4/30/2013 15.66 79.95 57,363 Design 1G -10B Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,625.16 Vertical Section: Depth From (TVD) +N/ -S +El -W Direction (ft) (ft) (ft) (°) 94.17 0.00 0.00 350.00 Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 95.17 6,295.17 Boss Gyro (1G-10) BOSS -GYRO Sperry -Sun BOSS gyro multishot 10/6/1983 6,390.00 7,422.00 MWD (1G -10A) MWD MWD - Standard 9/5/1996 7,481.00 8,625.16 1G-10BPB1 (1G-10BPB1) MWD MWD - Standard 3/19/2013 3/21/2013 8,652.00 10,505.32 1G-10B(lG-10B) MWD MWD - Standard 3/22/2013 3/24/2013 4/3/2013 4:09:56PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates F/ jI p C®nocoPhsllips Definitive Survey Report HUGHES Alaska Company: Conoco Ph illips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Project: Kuparuk River Unit TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +Ef•W Northing Easting DUS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (°1100') Surve Tool Name Y Annotation (ft) (ft) (ft) 8,625.16 91.26 340.23 6,620.85 6,526.68 1,066.12 2,678.97 5,982,115.28 543,245.08 2.93 584.73 MWD (3) TIP 8,652.00 92.36 340.54 6,620.01 6,525.B4 1,091.39 2,669.96 5,962,140.50 543,235.94 4.26 611.18 MWD (4) KOP 8,685.80 89.75 343.54 6,619.38 6,525.21 1,123.53 2,659.54 5,962,172.58 543,225.34 11.76 644.64 MWD (4) 8,715.91 68.99 346.03 6,619.71 6,525.54 1,152.56 2,651.64 5,962,201.58 543,217.29 6.65 674.62 MWD (4) " 8,750.88 87.91 350.03 6,620.66 6,526.49 1,186.77 2,644.39 5,982,235.73 543,209.85 11.84 709.55 MWD (4) 8,780.83 86.62 352.85 6,622.09 6,527.92 1,216.35 2,639.94 5,982,265.28 543,205.24 10.34 739.45 MWD (4) 8,611.04 66.87 355.33 6,623.81 6,529.64 1,246.35 2,636.84 5,962,295.26 543,201.97 6.24 769.53 MWD (4) 8,840.37 86.87 358.61 6,625.41 6,531.24 1,275.59 2,635.29 5,982,324.49 543,200.27 11.17 798.60 MWD (4) 8,870.84 88.77 2.61 6,626.57 6,532.40 1,306.03 2,635.61 5,982,354.93 543,200.43 14.52 828.52 MWD (4) 8,900.42 90.40 6.01 6,626.76 6,532.61 1,335.52 2,637.84 5,9B2,384.43 543,202.49 12.75 857.17 MWD (4) 8,930.65 90.95 9.46 6,626.43 6,532.26 1,365.47 2,641.90 5,982,414.39 543,206.40 11.56 885.96 MWD (4) 8,960.64 90.12 7.50 6,626.15 6,531.98 1,395.13 2,646.33 5,982,444.07 543,210.66 7.10 914.40 MWD (4) 8,991.63 91.66 4.51 6,625.66 6,531.49 1,425.94 2,649.57 5,982,474.90 543,213.73 10.85 944.18 MWD (4) I 9,020.60 93.29 2.96 6,624.41 6,530.24 1,454.82 2,651.45 5,982,503.79 543,215.46 7.76 972.30 MWD (4) 9,050.54 94.12 0.65 6,622.46 6,528.31 1,484.68 2,652.39 5,982,533.65 543,216.24 B.18 1,001.54 MWD (4) 9,080.70 I 94.58 357.57 6,620.19 6,526.02 1,514.74 2,651.93 5,982,563.71 543,215.61 10.30 1,031.23 MWD (4) 9,110.31 I 95.60 354.79 6,617.56 6,523.39 1,544.17 2,649.96 5.,982,593.12 543,213.49 9.97 1,060.55 MWD (4) 9,140.71 96.55 352.56 6,614.34 6,520.17 1,574.21 2,646.64 5,982,623.14 543,210.00 7.86 1,090.71 MWD (4) 9,170.59 96.80 349.51 6,610.87 6,516.70 1,603.52 2,642.02 5,982,652.42 543,205.22 10.24 1,120.38 MWD (4) 9,200.98 97.11 346.92 6,607.19 6,513.02 1,633.05 2,635.86 5,962,681.91 543,198.90 6.52 1,150.53 MWD (4) (, 9,230.19 98.22 344.54 6,603.29 6,509.12 1,661.11 2,628.73 5,982,709.93 543,191.62 8.92 1,179.40 MWD (4) 9,260.44 98.47 345.32 6,598.90 6,504.73 1,690.01 2,620.94 5,982,738.78 543,163.68 2.68 1,209.21 MWD (4) 9,285.38 97.30 347.17 6,595.46 6,501.31 1,714.00 2,615.07 5,982,762.74 543,177.68 8.72 1,233.86 MWD (4) 9,315.38 96.27 350.11 6,591.94 6,497.77 1,743.20 2,609.20 5,982,791.91 543,171.65 10.32 1,263.64 MWD (4) 9,340.54 95.29 352.07 6,589.40 6,495.23 1,767.93 2,605.33 5,962,616.61 543,167.64 8.67 1,288.66 MWD (4) .f 9,370.66 94.36 354.27 6,586.87 6,492.70 1,797.73 2,601.76 5,982,846.39 543,163.91 7.91 1,318.63 MWD (4) 9,400.51 93.17 357.01 6,584.91 6,490.74 1,627.43 2,599.50 5,982,876.07 543,161.49 9.99 1,348.27 MWD (4) 9,430.51 92.39 358.51 6,583.45 6,489.28 1,857.37 2,598.32 5,982,906.00 543,160.16 5.63 1,377.95 MWD (4) 9,460.64 93.07 0.23 6,582.02 6,487.85 1,887.46 2,597.99 5,982,936.09 543,159.66 6.13 1,407.65 MWD (4) 9,490.55 92.49 3.12 6,580.57 6,486.40 1,917.32 2,598.87 5,982,965.95 543,160.37 9.84 1,436.90 MWD (4) 4/3/2013 4:09:56PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates Fins ConocoPhillips Definitive Survey Report HUGHES Aas� Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Project: Kuparuk River Unit TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 Database: EDM Alaska Prod v16 Survey i a MD Inc Azi TVD TVDSS +N/ -S +EI -W Map Map DLS Vertical (ft) (°)' (°)' Ift1 (ft) (ft) (ft) Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ff) (rt) 9,520.62 92.15 6.26 6,579.35 6,485.18 1,947.26 2,601.32 5,982,995.90 543,162.67 10.49 1,465.96 MWD (4) 9,550.67 92.24 8.33 6,578.20 6,484.03 1,977.04 2,605.14 5,983,025.70 543,166.32 6.89 1,494.63 MWD (4) - 9,580.66 92.27 11.36 6,577.02 6,482.85 2,006.56 2,610.26 5,983,055.25 543,171.28 10.10 1,522.81 MWD (4) 9,610.66 91.44 13.41 6,576.05 6,481.88 2,035.85 2,616.69 5,983,084.56 543,177.55 7.37 1,550.54 MWD (4) 9,640.46 90.80 16.06 6,575.46 6,481.29 2,064.66 2,624.27 5,983,113.41 543,184.97 9.15 1,577.59 MWD (4) 9,670.40 90.56 18.58 6,575.10 6,480.93 2,093.24 2,633.18 5,983,142.03 543,193.73 8.45 1,604.19 MWD (4) ) 9,700.44 89.54 20.74 6,575.07 6,480.90 2,121.53 2,643.29 5,983,170.37 543,203.68 7.98 1,630.29 MWD (4) 9,730.36 87.54 23.59 6,575.83 6,481.66 2,149.22 2,654.57 5,983,198.13 543,214.81 11.63 1,655.61 MWD (4) 9,760.67 87.48 24.47 6,577.15 6,482.98 2,176.88 2,666.90 5,983,225.85 543,226.99 2.91 1,680.70 MWD (4) 9,790.78 86.90 27.50 6,578.63 6,484.46 2,203.91 2,680.07 5,983,252.95 543,240.02 10.23 1,705.04 MWD (4) 9,820.75 87.15 30.31 6,580.18 6,486.01 2,230.11 2,694.54 5,983,279.22 543,254.34 9.40 1,728.32 MWD (4) 9,850.72 87.76 33.50 6,581.51 6,487.34 2,255.52 2,710.36 5,983,304.72 543,270.02 10.83 1,750.60 MWD (4) 9,880.58 87.45 31.21 6,582.76 6,488.59 2,280.72 2,726.33 5,983,330.00 543,285.85 7.73 1,772.65 MWD (4) 9,910.75 87.94 27.86 6,583.98 6,489.81 2,306.94 2,741.18 5,983,356.30 543,300.56 11.21 1,795.90 MWD (4) 9,940.55 89.02 24.48 6,584.77 6,490.60 2,333.68 2,754.32 5,983,383.10 543,313.55 11,90 1,819.94 MWD (4) 9,971.93 88.34 21.34 6,585.49 6,491.32 2,362.57 2,766.53 5,983,412.06 543,325.61 10.24 1,846.27 MWD (4) 10,000.63 88.28 17.67 6,586.34 6,492.17 2,389.61 2,776.11 5,983,439.14 543,335.04 12.78 1,871.24 MWD (4) 10,030.75 88.59 14.93 6,587.16 6,492.99 2,418.50 2,784.56 5,983,468.08 543,343.33 9.15 1,898.23 MWD (4) 10,061.46 89.30 11.78 6,587.73 6,493.56 2,448.37 2,791.65 5,983,497.99 543,350.26 10.51 1,926.41 MWD (4) 10,090.85 89.05 9.96 6,588.15 6,493.98 2,477.23 2,797.19 5,983,526.87 543,355.65 6.18 1,953.87 MWD (4) 10,120.39 88.53 5.94 6,588.77 6,494.60 2,506.47 2,801.28 5,983,556.13 543,359.58 13.79 1,981.96 MWD (4) i 10,150.64 88.74 1.93 6,589.49 6,495.32 2,536.64 2,803.36 5,983,586.30 543,361.49 13.27 2,011.30 MWD (4) d 10,180.68 90.03 359.59 6,589.82 6,495.65 2,566.67 2,803.76 5,983,616.34 543,361.72 8.89 2,040.81 MWD (4) iI 10,215.60 91.07 1.56 6,589.48 6,495.31 2,601.58 2,804.11 5,983,651.25 543,361.89 6.38 2,075.13 MWD (4) 10,250.44 90.52 4.53 6,589.00 6,494.83 2,636.37 2,805.96 5,983,686.04 543,363.55 8.67 2,109.07 MWD (4) 10,280.72 92.15 8.20 6,588.29 6,494.12 2,666.45 2,809.31 5,983,716.13 543,366.74 13.26 2,138.11 MWD (4) 10,310.47 91.16 10.24 6,587.43 6,493.26 2,695.80 2,814.08 5,983,745.51 543,371.34 7.62 2,166.18 MWD (4) 10,345.35 89.88 12.92 6,587.12 6,492.95 2,729.96 2,821.08 5,983,779.70 543,378.16 8.51 2,198.61 MWD (4) (( 10,380.65 90.37 13.94 6,587.04 6,492.87 2,764.30 2,829.28 5,983,814.08 543,386.17 3.21 2,231.00 MWD (4) u 10,405.64 90.64 15.65 6,586.82 6,492.65 2,788.46 2,835.66 5,983,838.27 543,392.42 6.93 2,253.69 MWD (4) 10,435.51 90.80 17.76 6,586.44 6,492.27 2,817.06 2,844.24 5,983,866.92 543,400.85 7.08 2,280.37 MWD (4) 4/3/2013 4:09:56PM Page 4 COMPASS 2003.16 Build 69 4/3/2013 4:09:56PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates F/i2 ConocoPhil ips Definitive Survey Report HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Project: Kuparuk River Unit TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 Database: EDM Alaska Prod v16 Survey MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (ft) Northing (ft) Easting Section (°/100') Survey Tool Name Annotation (ft) (ft) (ft) 10,460.35 91.72 20.29 6,585.90 6,491.73 2,840.54 2,852.34 5,983,890.44 543,408.82 10.84 2,302.08 MWD (4) 10,485.37 91.69 22.29 6,585.15 6,490.98 2,863.84 2,861.42 5,983,913.78 543,417.77 7.99 2,323.45 MWD (4) 10,505.32 91.90 23.83 6,584.53 6,490.36 2,882.18 2,869.23 5,983,932.17 543,425.48 7.79 2,340.16 MWD (4) 10,543.00 91.90 23.83 6,583.28 6.489.11 2,916.63 2,884.44 5,983,966.70 543,440.51 0.00 2,371.45 PROJECTED to TO 4/3/2013 4:09:56PM Page 5 COMPASS 2003.16 Build 69 Conoc6Phiffips Alaska ConocoPhill ips(Alaska) Inc. Kuparuk River Unit Kuparuk 1G Pad 1 G-10BPB1 50-029-21003-70 Baker Hughes INTEQ Definitive Survey Report 03 April, 2013 Few a I BAKER HUGHES 4/3/2013 4:11:42PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates F/FAI ConocoPhillips ER BAKER Definitive Survey Report UGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Project: Kuparuk River Unit TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 Database: EDM Alaska Prod v16 Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level I Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1G-10 Well Position +N/ -S 0.00 ft Northing: 5,981,034.77ft Latitude: 70° 21'32.824 N +EI -W 0.00 ft Easting: 540,572.19ft Longitude: 149° 40' 13.660 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1G-10BPB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength C) (1) (nT) BGGM2012 4/30/2013 15.66 79.95 57,363 Design 1G-10BPB1 m .. Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,422.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (ft) (ft) (ft) 94.17 0.00 0.00 350.00 Survey Program Date From To Survey Survey I (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 9 95.17 t 6,295.17 Boss Gyro (1G-10) BOSS -GYRO Sperry -Sun BOSS gyro multishot 10/6/1983 6,390.00 7,422.00 MWD (1G -10A) MWD MWD - Standard 9/5/1996 7,481.00 8,900.10 1G-10BPB1 (1G-10BPB1) MWD MWD - Standard 3/19/2013 3/21/2013 4/3/2013 4:11:42PM Page 2 COMPASS 2003.16 Build 69 GonocoPhillips or its affiliates F/hI ConocoPhilli s BAKW Definitive Survey Report HUQfifeS Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Project: Kuparuk River Unit ND Reference: 1G-10A: @ 94.17ft (1G-10A:) Site: Kuparuk 1G Pad MD Reference: 1G-10A: @ 94.17ft (1G-10A:) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W DLS (ft) (') o O (ft) (ft)' (ft) (ft) Northing Fasting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 7,422.00 29.39 116.50 6,443.80 6,349.63 666.44 3,234.90 5,981,718.66 543,803.11 0.82 94.58 MWD (2) TIP 7,481.00 28.87 114.72 6,495.34 6,401.17 654.02 3,260.80 5,981,706.38 543,829.07 1.71 77.86 MWD (3) KOP s 7,510.41 22.35 141.00 6,521.93 6,427.76 646.68 3,270.81 5,981,699.09 543,839.12 44.04 68.88 MWD (3) 7,540.46 19.26 181.00 6,550.16 6,455.99 637.23 3,274.33 5,981,689.67 543,842.70 47.44 58.97 MWD (3) 7,570.31 18.12 223.00 6,578.56 6,484.39 628.88 3,271.07 5,981,681.30 543,839.48 44.33 51.31 MWD (3) 7,600.25 32.87 224.00 6,605.51 6,511.34 619.58 3,262.20 5,981,671.95 543,830.66 49.28 43.69 MWD (3) 7,630.57 45.55 227.02 6,628.96 6,534.79 606.23 3,248.51 5,981,658.52 543,817.05 42.28 32.92 MWD (3) 7,660.55 59.55 221.67 6,647.15 6,552.98 589.19 3,232.00 5,961,641.40 543,800.63 48.77 19.00 MWD (3) 7,690.47 73.22 218.25 6,659.11 6,564.94 568.20 3,214.47 5,981,620.32 543,783.22 46.86 1.38 MWD (3) 7,720.58 I 86.38 214.64 6,664.43 6,570.26 544.41 3,196.92 5,981,596.43 543,765.80 45.26 -19.00 MWD (3) 7,750.36 97.32 210.44 6,663.47 6,569.30 519.34 3,180.93 5,981,571.28 543,749.94 39.31 -40.91 MWD (3) 7,780.28 98.59 222.61 6,659.32 6,565.15 495.59 3,163.34 5,981,547.44 543,732.49 40.53 -61.25 MWD (3) 6 7,810.26 99.78 238.04 6,654.50 6,560.33 476.75 3,140.64 5,981,528.48 543,709.89 50.96 -75.86 MWD (3) @ 7,840.47 100.43 253.78 6,649.17 6,555.00 464.65 3,113.58 5,981,516.23 543,682.90 51.33 -83.08 MWD (3) g 7,870.70 100.99 268.53 6,643.52 6,549.35 460.09 3,084.32 5,981,511.52 543,653.66 47.97 -82.49 MWD (3) 9$9$9$€ 7,900.50 99.71 284.90 6,638.13 6,543.96 463.52 3,055.31 5,981,514.78 543,624.64 54.20 -74.08 MWD (3) 7,935.34 95.28 298.53 6,633.57 6,539.40 476.28 3,023.31 5,981,527.37 543,592.58 40.61 -55.95 MWD (3) 7,960.34 86.90 305.41 6,633.09 6,538.92 489.50 3,002.14 5,981,540.47 543,571.34 43.35 -39.26 MWD (3) P i� 7,991.20 88.13 319.08 6,634.44 6,540.27 510.18 2,979.38 5,981,561.03 543,548.46 44.43 -14.94 MWD (3) 8,021.30 88.53 326.84 6,635.32 6,541.15 534.17 2,961.27 5,981,584.92 543,530.22 25.80 11.84 MWD (3) 8,051.46 89.94 327.74 6,635.72 6,541.55 559.55 2,944.97 5,981,610.21 543,513.79 5.55 39.66 MWD (3) '. 8,081.40 91.32 327.86 6,635.39 6,541.22 584.88 2,929.02 5,981,635.45 543,497.70 4.63 67.38 MWD (3) 8,111.46 92.09 328.31 6,634.49 6,540.32 610.39 2,913.13 5,981,660.87 543,481.68 2.97 95.25 MWD (3) 8,141.72 92.36 329.42 6,633.32 6,539.15 636.27 2,897.50 5,981,686.66 543,465.91 3.77 123.45 MWD (3) 8,171.33 92.06 330.51 6,632.18 6,538.01 661.88 2,882.69 5,981,712.19 543,450.96 3.82 151.25 MWD (3) 8,200.40 91.17 330.29 6,631.36 6,537.19 687.15 2,868.34 5,981,737.38 543,436.48 3.15 178.63 MWD (3) 8,230.75 91.23 329.47 6,630.72 6,536.55 713.39 2,853.11 5,981,763.54 543,421.11 2.71 207.12 MWD (3) 8,260.50 91.17 329.38 6,630.10 6,535.93 739.00 2,837.98 5,981,789.06 543,405.84 0.36 234.96 MWD (3) 8,290.41 90.80 328.47 6,629.59 6,535.42 764.61 2,822.54 5,981,814.59 543,390.27 3.28 262.87 MWD (3) 8,320.58 91.50 329.66 6,628.98 6,534.61 790.49 2,807.04 5,981,840.37 543,374.63 4.58 291.04 MWD (3) 4/3/2013 4:11:42PM Page 3 COMPASS 2003.16 Build 69 4/3/2013 4:11:42PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates (/jll ConocoPhillips Definitive Survey Report H ER HES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Project: Kuparuk River Unit TVD Reference: 1G-10A: @ 94.17ft (1G-10A:) Site: Kuparuk 1G Pad MD Reference: 1G-10A: @ 94.17ft (1G-1DA:) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +El-W Northing Eastin DLS on Section (it) (1) 1°) (ft) (ft) (it) (ft) (°1100') Survey Tool Name Annotation i (ft) (ft) (ft) 6,350.42 92.58 330.32 6,627.92 6,533.75 816.31 2,792.12 5,981,866.11 543,359.57 4.24 319.06 MWD (3) 8,380.69 92.95 331.59 6,626.46 6,532.29 842.74 2,777.44 5,981,892.46 543,344.75 4.37 347.64 MWD (3) 8,410.49 93.19 332.87 6,624.86 6,530.69 869.07 2,763.58 5,981,918.71 543,330.75 4.36 375.98 MWD (3) 8,440.46 91.23 333.71 6,623.71 6,529.54 895.82 2,750.12 5,981,945.39 543,317.14 7.11 404.66 MWD (3) 8,470.41 3 90.40 334.85 6,623.26 6,529.11 922.80 2,737.12 5,981,972.29 543,304.00 4.71 433.48 MWD (3) 8,500.55 90.80 336.27 6,622.96 6,528.79 950.24 2,724.66 5,981,999.66 543,291.39 4.B9 462.67 MWD (3) 8,530.60 91.04 337.24 6,622.48 6,528.31 977.84 2,712.80 5,982,027.20 543,279.38 3.32 491.92 MWD (3) 8,560.43 91.10 338.86 6,621.92 6,527.75 1,005.59 2,701.65 5,982,054.80 543,268.08 5.43 521.09 MWD (3) u 6,590.27 90.71 339.37 6,621.45 6,527.28 1,033.38 2,691.01 5,982,082.61 543,257.30 2.15 550.39 MWD (3) g 8,625.16 91.26 340.23 6,620.85 6,526.68 1,066.12 2,678.97 5,982,115.28 543,245.08 2.93 584.73 MWD (3) 8,660.25 92.70 340.64 6,619.64 6,525.47 1,099.16 2,667.22 5,982,148.26 543,233.16 4.27 619.31 MWD (3) 8,690.21 93.29 341.55 6,618.08 6,523.91 1,127.47 2,657.53 5,982,176.51 543,223.31 3.62 648.86 MWD (3) 8,720.50 92.92 342.93 6,616.43 6,522.27 1,156.27 2,648.31 5,982,205.26 543,213.93 4.71 678.83 MWD (3) 8,750.59 94.46 344.17 6,614.50 6,520.33 1,185.07 2,639.60 5,982,234.00 543,205.27 6.57 708.67 MWD (3) 1 8,780.31 94.46 344.83 6,612.19 6,518.02 1,213.62 2,631.88 5,982,262.51 543,197.20 2.21 738.16 MWD (3) 8,810.31 94.55 345.79 6,609.83 6,515.66 1,242.55 2,624.30 5,982,291.40 543,189.46 3.20 767.97 MWD (3) 8,840.04 97.45 347.84 6,606.72 6,512.55 1,271.33 2,617.56 5,982,320.14 543,182.56 11.92 797.49 MWD (3) 8,870.01 96.86 349.33 6,602.99 6,508.82 1,300.48 2,611.67 5,982,349.25 543,176.52 5.31 827.21 MWD (3) 8,900.10 95.10 349.67 6,599.86 6,505.69 1,329.91 2,606.22 5,982,378.64 543,170.91 5.96 857.14 MWD (3) 8,940.00 95.10 349.67 6,596.31 6,502.14 1,369.00 2,599.09 5,982,417.70 543,163.57 0.00 896.88 PROJECTED to TD a 4/3/2013 4:11:42PM Page 4 COMPASS 2003.16 Build 69 - a Fe is BAKER Date: HUGHES April 3, 2013 To: Christine Mahnken AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Letter of Transmittal Carl Ulrich / Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1G-1013 l 3 .� o -�, l 1G-10BLI t3 Z 2 1G-10BL2 1G-10BPB1 Z 1 � LV 1 (4) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of retu m '1 r Michael Soper, Baker Hughes, Project Engineer Michael. Soper@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl .Ulrich ,BakerHughes.com a 2. k 3 _ 02` ConocoPhillips Alaska ConocoPhiIli ps(Alaska) Inc. Kuparuk River Unit Kuparuk 1G Pad 1G -10B 50-029-21003-02 Baker Hughes INTEQ //a I Definitive Survey Report N{Kl6HES 03 April, 2013 ConocoPhillips ConocoPhillips or its affiliates NA al Definitive Survey Report BAKER Alaska HUGHES Company: Conoco Ph illips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Project: Kuparuk River Unit TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 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 1G-10 Well Position +N/ -S 0.00 ft Northing: 5,981,034.77ft Latitude: 70° 21'32.824 N +E/ -W 0.00 ft Easting: 540,572.19ft Longitude: 149° 40' 13.660 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1G-106 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (% (I (nT) BGGM2012 4/30/2013 15.66 79.95 57,363 Design .�.a �1G-1O13 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,625.16 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction --� (tt) (ft) (R) (°) 94.17 0.00 0.00 350.00 Survey Program Date From To Survey Survey (ft) tff) Survey (Wellbore) Tool Name Description Start Date End Date 95.17 6,295.17 Boss Gyro (1G-10) BOSS -GYRO Sperry -Sun BOSS gyro multishot 10/6/1983 6,390.00 7,422.00 MWD (1G -10A) MWD MWD - Standard 9/5/1996 7,481.00 8,625.16 1G-10BPB1 (1G-10BPB1) MWD MWD - Standard 3/19/2013 3/21/2013 8,652.00 10,505.32 1G-10B(1G-1OB) MWD MWD - Standard 3/22/2013 3/24/2013 4/3/2013 4:09:56PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates • ConocoPhillips BA BAKER Definitive Survey Report HUGHES UGHES Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: IG -10 Project: Kuparuk River Unit TVD Reference: 1 G-1 OA: @ 94.17ft (1 G-1 OA:) Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 Database: EDM Alaska Prod v16 Survey MD Inc Azi TVD TVDSS +(ft) +E / -W Map Map DLS Vertical ~ ({O (°) (°) O O O (ft)) Northing Easting (1100') Section Survey Tool Name Annotation (ft) (ft) O 8,625.16 91.26 340.23 6,620.85 6,526.68 1,066.12 2,678.97 5,982,115.28 543,245.08 2.93 584.73 MWD (3) TIP 8,652.00 92.36 340.54 6,620.01 6,525.84 1,091.39 2,669.96 5,982,140.50 543,235.94 4.26 611.18 MWD (4) KOP 8,685.80 89.75 343.54 6,619.38 6,525.21 1,123.53 2,659.54 5,982,172.58 543,225.34 11.76 644.64 MWD (4) 8,715.91 88.99 346.03 6,619.71 6,525.54 1,152.58 2,651.64 5,982,201.58 543,217.29 8.65 674.62 MWD (4) 8,750.88 87.91 350.03 6,620.66 6,526.49 1,186.77 2,644.39 5,982,235.73 543,209.85 11.84 709.55 MWD (4) k 8,780.83 86.62 352.85 6,622.09 6,527.92 1,216.35 2,639.94 5,982,265.28 543,205.24 10.34 739.45 MWD (4) t 8,811.04 86.87 355.33 6,623.81 6,529.64 1,246.35 2,636.84 5,982,295.26 543,201.97 8.24 769.53 MWD (4) 8,840.37 86.87 358.61 6,625.41 6,531.24 1,275.59 2,635.29 5,982,324.49 543,200.27 11.17 798.60 MWD (4) 8,870.84 88.77 2.61 6,626.57 6,532.40 1,306.03 2,635.61 5,982,354.93 543,200.43 14.52 828.52 MWD (4) 8,900.42 90.40 6.01 6,626.78 6,532.61 1,335.52 2,637.84 5,982,384.43 543,202.49 12.75 857.17 MWD (4) 8,930.65 90.95 9.46 6,626.43 6,532.26 1,365.47 2,641.90 5,982,414.39 543,206.40 11.56 885.96 MWD (4) 8,960.64 90.12 7.50 6,626.15 6,531.98 1,395.13 2,646.33 5,982,444.07 543,210.66 7.10 914.40 MWD (4) 8,991.63 91.66 4.51 6,625.66 6,531.49 1,425.94 2,649.57 5,982,474.90 543,213.73 10.85 944.18 MWD (4) 9,020.60 93.29 2.96 6,624.41 6,530.24 1,454.62 2,651.45 5,982,503.79 543,215.46 7.76 972.30 MWD (4) } 9,050.54 94.12 0.65 6,622.48 6,528.31 1,484.68 2,652.39 5,982,533.65 543,216.24 8.18 1,001.54 MWD (4) 9,080.70 94.58 357.57 6,620.19 6,526.02 1,514.74 2,651.93 5,982,563.71 543,215.61 10.30 1,031.23 MWD (4) 9,110.31 95.60 354.79 6,617.56 6,523.39 1,544.17 2,649.96 5,982,593.12 543,213.49 9.97 1,060.55 MWD (4) 9,140.71 96.55 352.58 6,614.34 6,520.17 1,574.21 2,646.64 5,982,623.14 543,210.00 7.88 1,090.71 MWD (4) �. 9,170.59 96.80 349.51 6,610.87 6,516.70 1,603.52 2,642.02 5,982,652.42 543,205.22 10.24 1,120.38 MWD (4) 9,200.98 97.11 346.92 6,607.19 6,513.02 1,633.05 2,635.86 5,982,681.91 543,198.90 8.52 1,150.53 MWD (4) 9,230.19 98.22 344.54 6,603.29 6,509.12 1,661.11 2,628.73 5,982,709.93 543,191.62 8.92 1,179.40 MWD (4) 9,260.44 98.47 345.32 6,598.90 6,504.73 1,690.01 2,620.94 5,982,738.78 543,183.68 2.68 1,209.21 MWD (4) 9,285.38 97.30 347.17 6,595.48 6,501.31 1,714.00 2,615.07 5,982,762.74 543,177.68 8.72 1,233.86 MWD (4) )_ 9,315.38 96.27 350.11 6,591.94 6,497.77 1,743.20 2,609.20 5,982,791.91 543,171.65 10.32 1,263.64 MWD (4) 9,340.54 95.29 352.07 6,589.40 6,495.23 1,767.93 2,605.33 5,982,816.61 543,167.64 8.67 1,288.66 MWD (4) i 9,370.66 94.36 354.27 6,586.87 6,492.70 1,797.73 2,601.76 5,982,846.39 543,163.91 7.91 1,318.63 MWD (4) 9,400.51 93.17 357.01 6,584.91 6,490.74 1,827.43 2,599.50 5,982,876.07 543,161.49 9.99 1,348.27 MWD (4) 9,430.51 92.39 358.51 6,583.45 6,489.28 1,857.37 2,598.32 5,982,906.00 543,160.16 5.63 1,377.95 MWD (4) 9,460.64 93.07 0.23 6,582.02 6,487.85 1,887.46 2,597.99 5,982,936.09 543,159.66 6.13 1,407.65 MWD (4) 9,490.55 92.49 3.12 6,580.57 6,486.40 1,917.32 2,598.87 5,982,965.95 543,160.37 9.84 1,436.90 MWD (4) 4/3/2013 4 09 56PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates BAKER BA ConocoPhillips Definitive Survey Report NUER Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1G Pad Well: 1G-10 Wellbore: 1G-10 Design: 1G-10 Survey Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: IG -10 1G -10A: @ 94.17ft (1G -10A:) 1G -10A: @ 94.17ft (1G -10A:) True Minimum Curvature EDM Alaska Prod 06 MD Inc Azi TVD TVDSS +N! -S +E/ -W Map Map DLS Vertical (ft) (ft) (ft) Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 9,520.62 92.15 6.26 6,579.35 6,485.18 1,947.26 2,601.32 5,982,995.90 543,162.67 10.49 1,465.96 MWD (4) 9,550.67 92.24 8.33 6,578.20 6,484.03 1,977.04 2,605.14 5,983,025.70 543,166.32 6.89 1,494.63 MWD (4) 9,580.66 92.27 11.36 6,577.02 6,482.85 2,006.56 2,610.26 5,983,055.25 543,171.28 10.10 1,522.81 MWD (4) 9,610.66 91.44 13.41 6,576.05 6,481.88 2,035.85 2,616.69 5,983,084.56 543,177.55 7.37 1,550.54 MWD (4) 9,640.46 90.80 16.06 6,575.46 6,481.29 2,064.66 2,624.27 5,983,113.41 543,184.97 9.15 1,577.59 MWD (4) 9,670.40 90.58 18.58 6,575.10 6,480.93 2,093.24 2,633.18 5,983,142.03 543,193.73 8.45 1,604.19 MWD (4) 9,700.44 89.54 20.74 6,575.07 6,480.90 2,121.53 2,643.29 5,983,170.37 543,203.68 7.98 1,630.29 MWD (4) 9,730.36 87.54 23.59 6,575.83 6,481.66 2,149.22 2,654.57 5,983,198.13 543,214.81 11.63 1,655.61 MWD (4) 9,760.67 87.48 24.47 6,577.15 6,482.98 2,176.88 2,666.90 5,983,225.85 543,226.99 2.91 1,680.70 MWD (4) 9,790.78 86.90 27.50 6,578.63 6,484.46 2,203.91 2,680.07 5,983,252.95 543,240.02 10.23 1,705.04 MWD (4) 9,820.75 87.15 30.31 6,580.18 6,486.01 2,230.11 2,694.54 5,983,279.22 543,254.34 9.40 1,728.32 MWD (4) 9,850.72 87.76 33.50 6,581.51 6,487.34 2,255.52 2,710.36 5,983,304.72 543,270.02 10.83 1,750.60 MWD (4) 9,880.58 87.45 31.21 6,582.76 6,488.59 2,280.72 2,726.33 5,983,330.00 543,285.85 7.73 1,772.65 MWD (4) 9,910.75 87.94 27.86 6,583.98 6,489.81 2,306.94 2,741.18 5,983,356.30 543,300.56 11.21 1,795.90 MWD (4) 9,940.55 89.02 24.48 6,584.77 6,490.60 2,333.68 2,754.32 5,983,383.10 543,313.55 11.90 1,819.94 MWD (4) 9,971.93 88.34 21.34 6,585.49 6,491.32 2,362.57 2,766.53 5,983,412.06 543,325.61 10.24 1,846.27 MWD (4) 10,000.63 88.28 17.67 6,586.34 6,492.17 2,389.61 2,776.11 5,983,439.14 543,335.04 12.78 1,871.24 MWD (4) 10,030.75 88.59 14.93 6,587.16 6,492.99 2,418.50 2,784.56 5,983,468.08 543,343.33 9.15 1,898.23 MWD (4) 10,061.46 89.30 11.78 6,587.73 6,493.56 2,448.37 2,791.65 5,983,497.99 543,350.26 10.51 1,926.41 MWD (4) 10,090.85 89.05 9.98 6,588.15 6,493.98 2,477.23 2,797.19 5,983,526.87 543,355.65 6.18 1,953.87 MWD (4) 10,120.39 88.53 5.94 6,588.77 6,494.60 2,506.47 2,601.28 5,983,556.13 543,359.56 13.79 1,981.96 MWD (4) 10,150.64 88.74 1.93 6,589.49 6,495.32 2,536.64 2,803.36 5,983,586.30 543,361.49 13.27 r 2,011.30 MWD (4) 10,180.68 90.03 359.59 6,589.82 6,495.65 2,566.67 2,803.76 5,983,616.34 543,361.72 8.89 2,040.81 MWD (4) 10,215.60 91.07 1.56 6,589.48 6,495.31 2,601.58 2,804.11 5,983,651.25 543,361.89 6.38 2,075.13 MWD (4) 10,250.44 90.52 4.53 6,589.00 6,494.83 2,636.37 2,805.96 5,983,686.04 543,363.55 8.67 2,109.07 MWD (4) 10,280.72 92.15 8.20 6,588.29 6,494.12 2,666.45 2,809.31 5,983,716.13 543,366.74 13.26 2,138.11 MWD (4) 10,310.47 91.16 10.24 6,587.43 6,493.26 2,695.80 2,814.08 5,983,745.51 543,371.34 7.62 2,166.18 MWD (4) 10,345.35 89.88 12.92 6,587.12 6,492.95 2,729.96 2,821.08 5,983,779.70 543,378.16 8.51 2,198.61 MWD (4) 10,380.65 90.37 13.94 6,587.04 6,492.87 2,764.30 2,829.28 5,983,814.08 543,386.17 3.21 2,231.00 MWD (4) 10,405.64 90.64 15.65 6,586.82 6,492.65 2,788.46 2,835.66 5,983,838.27 543,392.42 6.93 2,253.69 MWD (4) 10,435.51 90.80 17.76 6,586.44 6,492.27 2,817.06 2,844.24 5,983,866.92 543,400.85 7.08 2,280.37 MWD (4) 4/3/2013 4:09:56PM Page 4 COMPASS 2003.16 Build 69 IV-' ConocoPhill ConocoPhillips or its affiliates WFAI Definitive Survey Report BA yaps GHES Company: ConocoPhill ips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Project: Kuparuk River Unit TVD Reference: 1G-10A: @ 94.17ft (1G-10A:) Site: Kuparuk 1G Pad MD Reference: 1G-10A: @ 94.17ft (1G-10A:) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 Database: EDM Alaska Prod v16 Survey MD Inc Azi TVD TVDSS +N/-S Map +E/-W Map DLVertical S O O O (ft) Northing Easting ('/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 10,460.35 91.72 20.29 6,585.90 6,491.73 2,840.54 2,852.34 5,983,890.44 543,408.82 10.84 2,302.08 MWD (4) 10,485.37 91.69 22.29 6,585.15 6,490.96 2,863.84 2,861.42 5,983,913.78 543,417.77 7.99 2,323.45 MWD (4) 10,505.32 91.90 23.83 6,584.53 6,490.36 2,882.18 2,869.23 5,983,932.17 543,425.48 7.79 2,340.16 MWD (4) 10,543.00 91.90 23.83 6,583.28 6,489.11 2,916.63 2,884.44 5,983,966.70 543,440.51 0.00 2,371.45 PROJECTED to TD 1 4/3/2013 4:09:56PM Page 5 COMPASS 2003.16 Build 69 p ConocoPhillips Alaska ConocoPhill ips(Alaska) Inc. Kuparuk River Unit Kuparuk 1G Pad 1G-10BPB1 50-029-21003-70 Baker Hughes INTEQ Definitive Survey Report 03 April, 2013 F&A a I BAKER HUGHES ee►� ConocoPhillips or its affiliates FINA11 ConocoPhillips Definitive Survey Report ��Es Alaska (ft) Survey (Wellbore) Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1G-10 Boss Gyro (1 G-10) Project: Kuparuk River Unit TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) MWD (1G -10A) Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) 1G-10BPB1 (1G-10BPB1) Well: 1G-10 North Reference: True Wellbore: 1G-10 Survey Calculation Method: Minimum Curvature Design: 1G-10 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 1G-10 Well Position +N/ -S 0.00 ft Northing: 5,981,034.77ft Latitude: 70° 21' 32.824 N +E/ -W 0.00 ft Easting: 540,572.19ft Longitude: 149° 40' 13.660 W Position Uncertainty 0.00 it Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1G-10BPB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (I (nT) BGGM2012 4/30/2013 15.66 79.95 57,363 Design 1'G-10BPB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,422.00 Vertical Section: Depth From (TVD) +N/ -S (ft) (ft) 94.17 0.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) 95.17 6,295.17 Boss Gyro (1 G-10) 6,390.00 7,422.00 MWD (1G -10A) 7,481.00 8,900.10 1G-10BPB1 (1G-10BPB1) Tool Name BOSS -GYRO MWD MWD +E/ -W (ft) 0.00 Description Sperry -Sun BOSS gyro multishot MWD - Standard MWD - Standard Direction 350.00 Survey Start Date 10/6/1983 9/5/1996 3/19/2013 Survey End Date 3/21/2013 4/3/2013 4:11:42PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips 29.39 Alaska Company: Conoco Phillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 1G Pad Well: 1G-10 Wellbore: 1G-10 Design: 1G-10 Survey 32.87 MD Inc Az (ft) (1) (°) 7,422.00 29.39 116.50 7,481.00 28.87 114.72 7,510.41 22.35 141.00 7,540.46 19.26 181.00 7,570.31 18.12 223.00 7,600.25 32.87 224.00 7,630.57 45.55 227.02 7,660.55 59.55 221.67 7,690.47 73.22 218.25 7,720.58 86.38 214.64 7,750.38 97.32 210.44 7,780.28 98.59 222.61 7,810.26 99.78 238.04 7,840.47 100.43 253.78 7,870.70 100.99 268.53 7,900.50 99.71 284.90 7,935.34 95.28 298.53 7,960.34 86.90 305.41 7,991.20 88.13 319.08 8,021.30 88.53 326.84 8,051.46 89.94 327.74 8,081.40 91.32 327.86 8,111.46 92.09 328.31 8,141.72 92.36 329.42 8,171.33 92.06 330.51 8,200.40 91.17 330.29 8,230.75 91.23 329.47 8,260.50 91.17 329.38 8,290.41 90.80 328.47 8,320.58 91.50 329.66 ConocoPhillips or its affiliates Definitive Survey Report +N1 -S Local Co-ordinate Reference: 1G-10 TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) MD Reference: 1G -10A: @ 94.17ft(1G-10A:) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska Prod v16 TVD TVDSS +N1 -S (ft) (ft) (S) 6,443.80 6,349.63 666.44 6,495.34 6,401.17 654.02 6,521.93 6,427.76 646.68 6,550.16 6,455.99 637.23 6,578.56 6,484.39 628.88 6,605.51 6,511.34 619.58 6,628.96 6,534.79 606.23 6,647.15 6,552.98 589.19 6,659.11 6,564.94 568.20 6,664.43 6,570.26 544.41 6,663.47 6,569.30 519.34 6,659.32 6,565.15 495.59 6,654.50 6,560.33 476.75 6,649.17 6,555.00 464.65 6,643.52 6,549.35 460.09 6,638.13 6,543.96 463.52 6,633.57 6,539.40 476.28 6,633.09 6,538.92 489.50 6,634.44 6,540.27 510.18 6,635.32 6,541.15 534.17 6,635.72 6,541.55 559.55 6,635.39 6,541.22 584.88 6,634.49 6,540.32 610.39 6,633.32 6,539.15 636.27 6,632.18 6,538.01 661.88 6,631.36 6,537.19 687.15 6,630.72 6,536.55 713.39 6,630.10 6,535.93 739.00 6,629.59 6,535.42 764.61 6,628.98 6,534.81 790.49 Map Map +E/ -W Northing (ft) (ft) 3,234.90 5,981,718.66 3,260.80 5,981,706.38 3,270.81 5, 981, 699.09 3,274.33 5,981,689.67 3,271.07 5,981,681.30 3,262.20 5,981,671.95 3,248.51 5, 981, 658.52 3,232.00 5,981,641.40 3,214.47 5,981,620.32 3,196.92 5,981,596.43 3,180.93 5,981,571.28 3,163.34 5,981,547.44 3,140.64 5,981,528.48 3,113.58 5,981,516.23 3,084.32 5,981,511.52 3,055.31 5, 981, 514.78 3,023.31 5, 981, 527.37 3,002.14 5,981,540.47 2,979.38 5,981,561.03 2,961.27 5,981,584.92 2,944.97 5,981,610.21 2,929.02 5,981,635.45 2,913.13 5,981,660.87 2,897.50 5,981,686.66 2,882.69 5,981,712.19 2,868.34 5,981,737.38 2,853.11 5, 981, 763.54 2,837.98 5,981,789.06 2,822.54 5,981,814.59 2,807.04 5,981,840.37 Map Vertical Easting DLS Section Survey Tool Name (ft) (°/100') (ft) 543,803.11 0.82 94.58 MWD (2) 543,829.07 1.71 77.86 MWD (3) 543,839.12 44.04 68.88 MWD (3) 543,842.70 47.44 58.97 MWD (3) 543,839.48 44.33 51.31 MWD (3) 543,830.66 49.28 43.69 MWD (3) 543,817.05 42.28 32.92 MWD (3) 543,800.63 48.77 19.00 MWD (3) 543,783.22 46.86 1.38 MWD (3) 543,765.80 45.26 -19.00 MWD (3) 543,749.94 39.31 -40.91 MWD (3) 543,732.49 40.53 -61.25 MWD (3) 543,709.89 50.96 -75.86 MWD (3) 543,682.90 51.33 -83.08 MWD (3) 543,653.66 47.97 -82.49 MWD (3) 543,624.64 54.20 -74.08 MWD (3) 543,592.58 40.81 -55.95 MWD (3) 543,571.34 43.35 -39.26 MWD (3) 543,548.46 44.43 -14.94 MWD (3) 543,530.22 25.80 11.84 MWD (3) 543,513.79 5.55 39.66 MWD (3) 543,497.70 4.63 67.38 MWD (3) 543,481.68 2.97 95.25 MWD (3) 543,465.91 3.77 123.45 MWD (3) 543,450.96 3.82 151.25 MWD (3) 543,436.48 3.15 178.63 MWD (3) 543,421.11 2.71 207.12 MWD (3) 543,405.84 0.36 234.96 MWD (3) 543,390.27 3.28 262.87 MWD (3) 543,374.63 4.58 291.04 MWD (3) Annotation TIP KOP Nag BA HUGHES 4/3/2013 4:11:42PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1G Pad Well: 1G-10 Wellbore: 1G-10 Design: 1G-10 Survey MID inc (ft) (') 8,350.42 92.58 8,380.69 92.95 8,410.49 93.19 8,440.46 91.23 8,470.41 90.40 8,500.55 90.80 8,530.60 91.04 8,560.43 91.10 8,590.27 90.71 8,625.16 91.26 8,660.25 92.70 8,690.21 93.29 8,720.50 92.92 8,750.59 94.46 8,780.31 94.46 8,810.31 94.55 8,840.04 97.45 8,870.01 96.86 8,900.10 95.10 8,940.00 95.10 Azi 330.32 331.59 332.87 333.71 334.85 336.27 337.24 338.86 339.37 340.23 340.64 341.55 342.93 344.17 344.83 345.79 347.84 349.33 349.67 349.67 ConocoPhillips or its affiliates rias Definitive Survey Repoli +E/_yy BAKER HUGHES Local Co-ordinate Reference: 1G-10 Vertical ND Reference: 1G -10A: @ 94.17ft (1G -10A:) (ft) MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Easting North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska Prod v16 TVD TVDSS +N/ -S +E/_yy Map Map DLS Vertical (ft) (ft) (ft) (ft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) (ft) 6,627.92 6,533.75 816.31 2,792.12 5,981,866.11 543,359.57 4.24 319.06 MWD (3) 6,626.46 6,532.29 842.74 2,777.44 5,981,892.46 543,344.75 4.37 347.64 MWD (3) 6,624.86 6,530.69 869.07 2,763.58 5,981,918.71 543,330.75 4.36 375.98 MWD (3) 6,623.71 6,529.54 895.82 2,750.12 5,981,945.39 543,317.14 7.11 404.66 MWD (3) 6,623.28 6,529.11 922.80 2,737.12 5,981,972.29 543,304.00 4.71 433.48 MWD (3) 6,622.96 6,528.79 950.24 2,724.66 5,981,999.66 543,291.39 4.89 462.67 MWD (3) 6,622.48 6,528.31 977.84 2,712.80 5,982,027.20 543,279.38 3.32 491.92 MWD (3) 6,621.92 6,527.75 1,005.51 2,701.65 5,982,054.80 543,268.08 5.43 521.09 MWD (3) 6,621.45 6,527.28 1,033.38 2,691.01 5,982,082.61 543,257.30 2.15 550.39 MWD (3) 6,620.85 6,526.68 1,066.12 2,678.97 5,982,115.28 543,245.08 2.93 584.73 MWD (3) 6,619.64 6,525.47 1,099.16 2,667.22 5,982,148.26 543,233.16 4.27 619.31 MWD (3) 6,618.08 6,523.91 1,127.47 2,657.53 5,982,176.51 543,223.31 3.62 648.86 MWD (3) 6,616.43 6,522.27 1,156.27 2,648.31 5,982,205.26 543,213.93 4.71 678.83 MWD (3) 6,614.50 6,520.33 1,185.07 2,639.80 5,982,234.00 543,205.27 6.57 708.67 MWD (3) 6,612.19 6,518.02 1,213.62 2,631.88 5,982,262.51 543,197.20 2.21 738.16 MWD (3) 6,609.83 6,515.66 1,242.55 2,624.30 5,982,291.40 543,189.46 3.20 767.97 MWD (3) 6,606.72 6,512.55 1,271.33 2,617.56 5,982,320.14 543,182.56 11.92 797.49 MWD (3) 6,602.99 6,508.82 1,300.48 2,611.67 5,982,349.25 543,176.52 5.31 827.21 MWD (3) 6,599.86 6,505.69 1,329.91 2,606.22 5,982,378.64 543,170.91 5.96 857.14 MWD (3) 6,596.31 6,502.14 1,369.00 2,599.09 5,982,417.70 543,163.57 0.00 896.88 PROJECTED to TD Annotation 4/3/2013 4:11:42PM Page 4 COMPASS 2003.16 Build 69 CD3 - C21 2 WASUKU BAKER PRINT DISTRIBUTION LIST NVGNES COMPANY ConocoPhillips, Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 1G -10B RUN NUMBER (mandatory, FIELD Kuparuk BH SALESMAN Anyanwu, Okechukwu (OKEY) (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) STATE Alaska PAGE (mandatory,i OF LOG DATE: March 25, 2013 TODAYS DATE: 5/10/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips, Alaska Inc. HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 0 4 4 4 4 4 4 1 ConocoPhillips Alaska, Inc. r 1 NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 3 BP 1 1 Petrotechnical Data Center, MB33 David Douglas 900 East Benson Blvd Anchorap,e, Alaska 99508 4 Chevron / KRU REP 1 1 Glenn Fredrick 3800 Center Point Drive, Suite 100 Anchorage, Alaska 99503 5 Brandon Tucker, NRT 1 State of Alaska; DNR, Div. of Oil and Gas 550 W. 7th Ave, Suite 800 Anchorage, Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 CD FIELD FINAL (digital / I# LOGS LOGS image) FILM # OF PRINTS # Ur PHIN i 5 # OF COPIES OF COPIES 4 4 4 4 4 4 1 ConocoPhillips Alaska, Inc. r 1 NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 3 BP 1 1 Petrotechnical Data Center, MB33 David Douglas 900 East Benson Blvd Anchorap,e, Alaska 99508 4 Chevron / KRU REP 1 1 Glenn Fredrick 3800 Center Point Drive, Suite 100 Anchorage, Alaska 99503 5 Brandon Tucker, NRT 1 State of Alaska; DNR, Div. of Oil and Gas 550 W. 7th Ave, Suite 800 Anchorage, Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 VAC 2 2G U Z� BAKER PRINT DISTRIBUTION LIST HUGHES FIELD FINAL COMPANY ConocoPhillips, Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) LOGS LOGS WELL NAME 1G-10BPBI RUN NUMBER (mandatory; # OF PRINTS # Ur h'HIN 16 FIELD Kuparuk BH SALESMAN Anyanwu, Okechukwu (OKEY) (mandatory), (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory)-ndatoryi STATE Alaska PAGE OF (mandatory) LOG DATE: March 22, 2013 TODAYS DATE: 5/10/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips, Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 4 1 ConocoPhillips Alaska, Inc. NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 1 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 3 BP 1 1 Petrotechnical Data Center, MB33 David Douglas 900 East Benson Blvd Anchorage, Alaska 99508 4 Chevron / KRU REP 1 1 Glenn Fredrick 3800 Center Point Drive, Suite 100 Anchorase. Alaska 99503 5 Brandon Tucker, NRT 1 State of Alaska; DNR, Div. of Oil and Gas 550 W. 7th Ave, Suite 800 Anchorage, Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 CD FIELD FINAL (digital / I# LOGS LOGS image) FILM # OF PRINTS # Ur h'HIN 16 # OF COPIES OF COPIES 1 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 3 BP 1 1 Petrotechnical Data Center, MB33 David Douglas 900 East Benson Blvd Anchorage, Alaska 99508 4 Chevron / KRU REP 1 1 Glenn Fredrick 3800 Center Point Drive, Suite 100 Anchorase. Alaska 99503 5 Brandon Tucker, NRT 1 State of Alaska; DNR, Div. of Oil and Gas 550 W. 7th Ave, Suite 800 Anchorage, Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Lamar Gantt Coiled Tubing Drilling Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1G-IOB ConocoPhillips Alaska, Inc. Permit No: 213-021 Surface Location: 386' FSL, 793' FWL, SEC. 29, T12N, R10E, UM Bottomhole Location: 2147' FNL, 1570' FEL, SEC. 29, T12N, RIOE, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P Foerster Chair DATED this day of February, 2013. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED FEB 15 2013 ,AOGCC 1a. Type of Work: 1 b. Proposed Well Class: Development - Oil ❑✓ Service - Winj ❑ Single Zone ❑ 1c. Specify if well is proposed for: Drill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply Multiple Zone ❑ E]E:1Lateral Coalbed Gas Gas Hydrates ❑ �❑� I- Redrill Reentry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: ✓ Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 1G -10B 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 10380', TVDSS: 6493' • Kuparuk River Field 4a. Location of Well (Governmental Section): T Property Designation (Lease Number): Surface: 386' FSL, 793' FWL, Sec. 29, T1 2N, R1 OE, UM ADL 25640 • Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1760' FSL, 1827' FEL, Sec. 29, T12N, R10E, UM 2571 3/18/2013 Total Depth: 9. Acres in Property: 14. Distance to 2147' FNL, 1570' FEL, Sec. 29, T1 2N, R1 OE, UM 2560. Nearest Property: 11245' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 94 feet 15. Distance to Nearest Well Open Surface: x- 5405721 y- 5981035 - Zone- 4, GL Elevation above MSL: 31 feet to Same Pool: 1G-07, 748' 16. Deviated wells: Kickoff depth: 7482 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 104° deg Downhole: 3907 psig • Surface: 3383 psig 18. Casino Pro ram: Specifications Top - Setting Depth - Bottom Cement Quantity, r . or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS(including stage data 3" 2.375" 4.7# L-80 ST -L 1465' 8935' 6582' 10380' 6493' 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) 7906 6864 none 1 7815 6789 none Casing Length Size Cement Volume MD TVD Conductor/Structural 77' 16" 116' 116' 212 sx CS II Surface 2313' 10.75 2350' 2185' 930 sx AS III, 250 sx AS I Intermediate Production 6255' 7" 6290' 5441' 850 sx Class G, 250 sx AS I Liner 1764' 3.5" 7906' 6868' 396 sx Class G Perforation Depth MD (ft): Perforation Depth TVD (ft): 7318-7340, 7352-7358, 7366-7374, 7614-7644 6354-6373, 6384-6389, 6396-6403, 6613-6639 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21. Verbal Approval: Commission Representative: Date: ��jj 22. 1 hereby certify that the foregoing is true and correct. Contact Kai Starck @ 263-4093 /' Email Kai. Starck conoco III com Printed Name Lamar Title Coiled Tubing Drilling Supervisor \Gantt Signature �+, r:� Phone: 263-4021 Date d / Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: �'� 0 �) 50- Q�C� -�� 0�3 - �'� _ �j� Date: (�' (� ! for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other:1 p f e S l f� i� ��s Samples req'd: Yes ❑ No Mud log req'd: Yes❑ No 1-12S measures: Yes No Directional svy req'd: Yes [j No ❑ Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No � U P RO�/E BY THE —7 _ Approved by: OM ISE t ?' . ONIMI ION Date: Z: — 3 Form 10-401 (Rev' ed 10/20'(2) This permit is v li f r;4 &nthtfromjbe date -of approval (20 AAC 25.005(8)) G ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 14, 2013 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVED FEB 15 2013 AOGCC ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete 1G-1013, 1G- 10BL1 and 1G-1061_2 from Kuparuk well 1G -10A (PTD#196-140). Coiled tubing drilling (CTD) operations are scheduled to begin March 18, 2013 using the Nabors CDR2-AC rig. Producer 1 G-1 OB is part of a development concept to increase throughput in an unswept A -sand pattern. The planned 1 H-1 9A injector to the east will increase sweep efficiency to this new producer. Prior to commencing CTD operations all of the original A and C -sand perforations will be squeezed. There will be a cement plug left at 7510' above the A -sand perforations. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A and C -sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 7482' MD. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. - Drilling program summary - Permit to Drill application forms for 1 G-1 OB, 1 G-1061_1 and 1 G-10BL2 - Directional plans for 1 G-1013, 1 G-10BL1 and 1 G-1061-2 - Current wellbore schematic - Proposed wellbore schematic after CTD operations - 10-403 to plug perforations in the 1G -10A If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, U a,� Kai Starck ConocoPhillips Alaska Coiled Tubing Drilling Specialist Kuparuk CTD Laterals NA60RS ALASKA 1G -10B, 1 G-10BL1 and 1 G-10BL2 �r Application for Permit to Drill Document NC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)).................................................................................................................. 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)) ..................................... .......................................................................................................... !. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3))................................................................................................................................................ 2 4. Drilling Hazards Information and Reservoir Pressure................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4))................................................................................................................................................ 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(6))................................................................................................................................................. 2 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))................................................................................................................................................. 3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8))................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9))................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(10))............................................................................................................................................... 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))............................................................................................................................................... 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))............................................................................................................................................... 4 13. Proposed Drilling Program............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(13))............................................................................................................................................... 4 Summaryof Operations...................................................................................................................................................4 PressureDeployment of BHA.......................................................................................................................................... 5 LinerRunning.................................................................................................................................................................. 6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))............................................................................................................................................... 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))..................................................................................................................................................... 6 16. Quarter Mile Injection Review (for injection wells only) .................... Error! Bookmark not defined. (Requirements of 20 AAC 25.402)........................................................................................................... Error! Bookmark not defined. 17. Construction of Injection Wells......................................................... Error! Bookmark not defined. (Requirements of 20 AAC 25.412)............................................................................................................................................................ Attachment 1: Directional Plans for 3C -11A, 3C-11AL1................................................................................................. 6 Attachment 2: Current Well Schematic for 3C-11........................................................................................................... 6 Attachment 3: Proposed Well Schematic for 3C-11 CTD Laterals.................................................................................. 6 0 R I G I P,% L Page 1 of 6 February 14, 2013 PTD Application for KRU 1G -10B, BL1, BL2 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) There are three proposed laterals described in this document: KRU 1G-1015, 1G-1061-1 and 1G-10131-2. 1G - 10A. The B sidetrack will be drilled off the motherbore and the BL1 and BL2 laterals will be drilled off the B sidetrack. All three will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The 1 G-1 OB sidetrack is planned to target the Kuparuk A4 sand to north of the existing well. The 1 G-1061-1 lateral is planned to target the Kuparuk A3 sand to the north of the existing well. The 1 G-1061_2 lateral is planned to target the A4 sand to the southwest of the existing well. See the attached 10-401 forms for surface and subsurface coordinates of each of the 1G-10 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4000 psi. Using a maximum potential formation pressure of 4022 psi, the maximum potential surface pressure is 3383 - psi assuming a gas gradient of 0.1 psi/ft. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The latest 1 G-1 OA SBHP taken 1/13 was 2630 psi for an 8.1 EMW from the C3/C4 and the A4/A5 sands. The 1G -10B and BL1 laterals will be approaching 1G-07 producer which had the latest SBHP in October 2012 showing 2557 psi for the A sand, 7.5 EMW. 1 H-03 water injector to the east has a current BHP of 3907; 12.1 EMW and is the highest pressure in the area. It is not expected that pressures as high as 1 H-03 will be encountered during the drilling operations due to offset distance. Using the 1H-03 formation pressure as the maximum possible in 1G -10B, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3383 psi.. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled and there has been no gas or MI injection in the area Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected downhole risk in the 1 G-1 OB laterals is hole stability due to interbedded shales and silts in the A -sand. We will mitigate hole instability by maintaining a minimum ECD target of 11.8 ppg EMW at the window while drilling the CTD laterals, as well as using mud additives that minimize chemical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Each of the 1G-1013 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Page 2 of 6 0 I G I aiLL February 14, 2013 PTD Application for KRU 1G-1013, BL1, BL2 New Completion Details Existing Casing/Liner Information Category Liner Liner Liner Liner Top Lateral Name Top MD Btm Top Btm Liner Details (ppf) MD SSTVD SSTVD MD 1G -10B 8930' 10,380' 6582' 6594' 2'/", 4.7#, L-80, ST -L slotted liner; 62 H-40 Welded 39' 116' aluminum billet on to 1G-10BL1 7895' 10,400' 6640' 6624' 2'/", 4.7#, L-80, ST -L slotted liner; K-55 BTC 37.1' 2350' 0' aluminum billet on to 1G-10BL2 7470' 10,100' 6482' 6554' 2%" 4.7#, L-80, ST -L slotted liner; BTC 35.1' 6290' 0' 5441' De to ment sleeve on to Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 39' 116' 0' 116' Surface 10-3/4 45.5 K-55 BTC 37.1' 2350' 0' 2185' 3580 2090 Casing 7" 26 K-55 BTC 35.1' 6290' 0' 5441' 4980 4320 Liner 3%" 9.3 L-80 IBT 6142' 7906' 5305' 6868' 10,160 10,530 Tubing3%" 9.3 J-55 AMB - EUE 26 6151' 0' 1 5315' 6990 7400 7. Diverter System Information (Requirements of 20 AA 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AA 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based Biozan brine or used drilling mud (-9.5 ppg) — Drilling operations: Chloride -based Flo -Pro Flo Vis mud (9.5 ppg). This mud weight alone will hydrostatically overbalance formation pressure in the 1G -10A motherbore. MPD practices described below will increase the overbalance to enhance shale stability. — Completion operations: The well will be loaded with 11.8 ppg sodium bromide completion fluid in order to maintain pressure over -balance while picking up liner. — Emergency Kill Weight fluid: Two well bore volumes (-200 bbl) of 12 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing pressure over- balance to the formation. In the 1G-10 laterals we will target a constant BHP of 11.8 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Page 3 of 60 % I cli I �"t il 1+ February 14, 2013 PTD Application for KRU 1G-1013, BL1, BL2 Pressure at the 1G -10B Window (7482' MD, 6393' TVD) Usinq MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 1G-10 was originally completed in 1984 as a C1 -sand producer. In 1996 it was sidetracked and 1 G-1 OA was an A -sand producer until 1999 when the C3 and C4 intervals were perforated and stimulated with a small fracture treatment. The well continued as an A and C sand dual producer until October 2012 when it was shut in due to low productivity and freezing issues. The C -sand perforations will be cement squeezed with a cement plug left over the A -sand perforations. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A - sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 7482' MD. A mechanical whipstock will be placed in the 3%" liner at the planned kickoff point. The 1G -10B sidetrack will exit the 3%" casing at 7482' MD and target the A4 sand to the north of the existing well with a 2918' lateral. The hole will be completed with a 23/" slotted liner to the TD of 10,380' MD with an aluminum billet at 8930' MD. The 1 G-10BL1 lateral will kick off from the aluminum billet at 8930' MD and will target the A3 sand north of the existing well with a 1465' lateral. The hole will be completed with a 23/" slotted liner to the TD of 10,400' MD with an aluminum billet at 7895' MD. Page 4 of 6 ORIU1 �"'! I February 14, 2013 Pumps On 1.5 bpm) Pumps Off A -sand Formation Pressure 8.1 2692 psi 2692 psi Mud Hydrostatic 9.5 3158 psi 3158 psi Annular friction i.e. ECD, 0.090psi/ft) 711 psi 0 psi Mud + ECD Combined 3869 psi 3158 psi (no choke pressure) (overbalanced (overbalanced 1231psi) 466psi) Target BHP at Window 11.8 3923 psi 3923 psi Choke Pressure Required to Maintain Target BHP 54 psi 765 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 1G-10 was originally completed in 1984 as a C1 -sand producer. In 1996 it was sidetracked and 1 G-1 OA was an A -sand producer until 1999 when the C3 and C4 intervals were perforated and stimulated with a small fracture treatment. The well continued as an A and C sand dual producer until October 2012 when it was shut in due to low productivity and freezing issues. The C -sand perforations will be cement squeezed with a cement plug left over the A -sand perforations. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A - sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 7482' MD. A mechanical whipstock will be placed in the 3%" liner at the planned kickoff point. The 1G -10B sidetrack will exit the 3%" casing at 7482' MD and target the A4 sand to the north of the existing well with a 2918' lateral. The hole will be completed with a 23/" slotted liner to the TD of 10,380' MD with an aluminum billet at 8930' MD. The 1 G-10BL1 lateral will kick off from the aluminum billet at 8930' MD and will target the A3 sand north of the existing well with a 1465' lateral. The hole will be completed with a 23/" slotted liner to the TD of 10,400' MD with an aluminum billet at 7895' MD. Page 4 of 6 ORIU1 �"'! I February 14, 2013 PTD Application for KRU 1G-1013, BL1, 131_2 The 1 G-10BL2 lateral will kick off from the aluminum billet at 7895' MD and will target the A4 sand southwest of the existing well with a 2200' lateral. The hole will be completed with a 2'/" slotted liner to the TD of 10,100' MD with a liner top deployment sleeve at 7470' MD, inside the 3%2" liner. Pre -CTD Work 1. MIRU slickline. Dummy all GLMs. 2. MIRU a -line, perform CBL 3. OPTIONAL- Pending results of CBL - MIRU e -line, perforate 3-1/2" liner at 7480-7490. To ensure good cement isolation at the window from the C1. 4. Perform injectivity test into open A & C -sand perfs. 5. MIRU coiled tubing. Cement squeeze the open perforations and lay in cement in the 3-1/2" liner, leaving the cement top in the 3-1/2" liner at 7290'. 6. Coiled tubing. Mill 2.75" Camco D nipple at 6141' to 2.80" 7. Mill cement from 7290' to 7510' with a bi-center bit. This will leave a cement plug 100' above the A -sand perforations. 1P fA 8. MIRU slickline. Run whipstock dummy inside 3%" liner. -/4-a 9. Prep site for Nabors CDR2-AC, including setting BPV 5,v,c1ry 313-()V ftS f f� 4-000 P S S Rig Work l g o� ct 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2 Hrs 1"' 2. 1G -10B Sidetrack (A4 sand, North) e- a. Set whipstock at 7482' MD with 140 ROHS orientation b. Mill 2.80" window through 3%" liner C. Drill 2.70" x 3" bi-center lateral to TD of 10,380' NID �,7-� d. Run 2'/" slotted liner with an aluminum billet from TD up to 8930' 2 13 _ 02 i 3. 1 G-10BL1 Lateral (A3 sand, north) a. Kick off of the aluminum billet at 8930' MD b. Drill 2.70" x 3" bi-center lateral to TD of 10,400' MD C. Run 23/" slotted liner with an aluminum billet from TD up to 7895' MD 4. 1G-10BL2 Lateral (A4 sand, south) a. Kick off of the aluminum billet at 7895' MD b. Drill 2.70" x 3" bi-center lateral to TD of 10,100' MD C. Run 2'/" slotted liner with an aluminum billet from TD up to 7470' MD inside the 3%" liner 5. Freeze protect. Set BPV, ND BOPE. 6. RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV Obtain static BHP, Install gas lift valves Put well on production Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. 0 ri I ' , ', L February Page 5 of 6 14, 2013 PTD Application for KRU 1G-1013, 131-1, 131_2 — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize_ internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Liner Running — Fluid of sufficient density to over -balance the formation will be used to provide well control. See the "Drilling Fluids" section for more details. — While running 23/" slotted liner, a joint of 23/" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 23/" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1 R Pad Class IJ disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — There are no other affected owners — Please see attached directional plans for each lateral. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to nearest property line and nearest well in the same pool. Lateral Name Directional Plan Distance to Unit Boundary Distance to Nearest Well Nearest Well 1G -10B 11 11,245' 748' 1 G-07 1 G-10BL1 04 11,150' 744' 1 G-07 1G-10BL2 05 10,665' 1865' 1G-11 Attachment 1: Directional Plans for 1G -10B, 1G-10BL1 and 1G-10BL2 Attachment 2: Current Well Schematic for 1G -10A Attachment 3: Proposed Well Schematic for 1G -10B CTD Laterals Page 6 of 6 0 R I � a I February 14, 2013 CD _- 1G -10A Proposed CTD Sidetrack 16" 62# H-40 shoe @ 116' 10-3/4" 45.5# J-55 shoe @ 2350' MD 7" 26# K-55 shoe @ 6290' MD C -sand perfs (sgz'd) 7,31 S' - 7,374' MD 1 G-1 OBI -2 (A4 sourthwest) TD @ 10,100' MD A -sand perfs (sgz'd) 7,614' - 7,644' MD 3-1/2" 9.2# L-80 shoe @ 7,906' MD 1/2" Camco DS nipple @ 523' RKB /2" 9.3# L-80 ELIE 8rd Tubing to surface Camco FMHO gas lift mandrels @ 2396', 3665', 4242', 4756' 12" Camco MMM gas lift mandrel @ 6095' RKB 3-1/2" Camco DS landing nipple @ 6141' RKB (2.812" min ID) Baker 3-1/2" GBH -22 seal assembly @ 6150' RKB (3" ID) liner top packer @ 6149' RKB liner hanger @ 6156' RKB EO SBE (12 length with 4" ID seal bore) Cement Plug at 7510' ;OP from 3-1/2" ionobore whipstock @ 482' M D G-1 OB (A4 Northwest) -- TD @ 10,400' MD 1G-10BL1 (A3 Northwest) TD @ 10,400' MD ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1G Pad 1G-10 1G -10B Plan: 1 G-10B_wp11 Standard Planning Report 12 February, 2013 0 S I C- I AL BAKER HUGHES ConocoPhillips Alaska Database: EDM Alaska Prod v16 Company: ConocoPhill ips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1G Pad Well: 1G-10 Wellbore: 1G -10B Design: 1 G-10B_wpl 1 ConocoPhillips or its affiliates Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1G-10 Mean Sea Level 1G -10A: @ 94 17f (1G -10A:) True Minimum Curvature 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 WEAI BAKER HUGHES Site Kuparuk 1G Pad Site Position: Northing: 5,981,540.78ft Latitude: 700 21' 37.826 N From: Map Easting: 540,089.12ft Longitude: 149'40'27.705 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.31 ° Well 1G-10 1G-10B_wp11 Well Position +N/ -S 0.00 ft Northing: 5,981,034.77 ft Latitude: 70° 21'32.824 N +E/ -W 0.00 ft Easting: 540,572.19 ft Longitude: 149° 40' 13.660 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 1G-106 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BG G M2011 12/31/2012 16.00 79.98 57,385 Design 1G-10B_wp11 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,422.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 350.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (ft) (°) (1 (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,422.00 29.39 116.50 6,349.63 666.44 3,234.90 0.00 0.00 0.00 0.00 7,482.00 28.86 114.69 6,402.05 653.82 3,261.23 1.71 -0.88 -3.02 -121.82 7,502.00 27.06 118.08 6,419.71 649.66 3,269.63 12.00 -8.99 16.96 140.00 7,572.00 18.75 197.06 6,485.47 631.00 3,280.62 42.00 -11.87 112.82 140.00 7,768.11 100.00 217.19 6,577.77 500.68 3,198.32 42.00 41.43 10.27 20.00 7,960.00 101.37 299.50 6,534.88 465.78 3,030.75 42.00 0.71 42.89 80.00 8,030.00 91.32 327.34 6,527.00 513.18 2,980.90 42.00 -14.36 39.77 108.00 8,100.00 89.50 334.10 6,526.50 574.19 2,946.69 10.00 -2.60 9.66 105.00 8,300.00 90.20 342.07 6,527.03 759.59 2,872.11 4.00 0.35 3.98 85.00 8,400.00 90.55 338.09 6,526.37 853.59 2,838.04 4.00 0.35 -3.98 275.00 8,600.00 98.43 336.69 6,510.74 1,037.50 2,761.45 4.00 3.94 -0.70 350.00 8,795.00 92.43 341.69 6,492.30 1,218.83 2,692.57 4.00 -3.08 2.57 140.00 9,245.00 87.73 359.08 6,491.69 1,660.69 2,617.72 4.00 -1.04 3.86 105.00 9,645.00 90.42 14.85 6,498.20 2,056.40 2,666.07 4.00 0.67 3.94 80.50 9,945.00 90.41 26.85 6,496.01 2,336.23 2,772.66 4.00 0.00 4.00 90.00 10,380.00 90.39 9.45 6,492.93 2,747.99 2,907.65 4.00 0.00 -4.00 270.00 2/1212013 12.26:38PM Page 2 COMPASS 2003.16 Build 69 0 flll� I kIAl ConocoPhillips or its affiliates Has ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1G Pad Well: 1G-10 Wellbore: 1G -10B Design: 1G-10B_wp11 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1G-10 Mean Sea Level 1G -10A: @ 94.17ft (1G -10A:) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (ft) (1) (1) (ft) (ft) (ft) (ft) (1/100ft) (°) (ft) (ft) 7,422.00 29.39 116.50 6,349.63 666.44 3,234.90 94.58 0.00 0.00 5,981,718.66 543,803.11 TIP 7,482.00 28.86 114.69 6,402.05 653.82 3,261.23 77.58 1.71 -121.82 5,981,706.18 543,829.51 KOP 7,500.00 27.24 117.72 6,417.93 650.09 3,268.83 72.59 12.00 140.00 5,981,702.49 543,837.12 7,502.00 27.06 118.08 6,419.71 649.66 3,269.63 72.03 12.00 137.32 5,981,702.07 543,837.93 Start 42 DLS 7,572.00 18.75 197.06 6,485.47 631.00 3,280.62 51.74 42.00 140.00 5,981,683.47 543,849.02 4 7,600.00 30.06 205.06 6,510.93 620.31 3,276.32 41.96 42.00 20.00 5,981,672.75 543,844.78 7,700.00 71.57 213.96 6,572.81 555.34 3,237.46 -15.28 42.00 12.68 5,981,607.58 543,806.27 7,768.11 100.00 217.19 6,577.77 500.68 3,198.32 -62.31 42.00 6.66 5,981,552.72 543,767.43 5 7,800.00 102.04 230.68 6,571.65 478.19 3,176.66 -80.70 42.00 80.00 5,981,530.11 543,745.90 7,900.00 103.85 273.79 6,548.19 449.10 3,086.31 -93.66 42.00 82.59 5,981,500.53 543,655.72 7,960.00 101.37 299.50 6,534.88 465.78 3,030.75 -67.58 42.00 92.70 5,981,516.91 543,600.07 6 8,000.00 95.80 315.54 6,528.87 489.80 2,999.52 -38.50 42.00 108.00 5,981,540.76 543,568.72 8,030.00 91.32 327.34 6,527.00 513.18 2,980.90 -12.25 42.00 110.41 5,981,564.03 543,549.97 Start 10 DLS 8,100.00 89.50 334.10 6,526.50 574.19 2,946.69 53.78 10.00 105.00 5,981,624.86 543,515.43 Start 4 DLS 8,200.00 89.85 338.09 6,527.07 665.59 2,906.17 150.83 4.00 85.00 5,981,716.03 543,474.43 8,300.00 90.20 342.07 6,527.03 759.59 2,872.11 249.32 4.00 84.98 5,981,809.83 543,439.85 9 8,400.00 90.55 338.09 6,526.37 853.59 2,838.04 347.80 4.00 -85.00 5,981,903.63 543,405.28 10 8,500.00 94.49 337.39 6,521.98 946.02 2,800.20 445.40 4.00 -10.00 5,981,995.85 543,366.95 8,600.00 98.43 336.69 6,510.74 1,037.50 2,761.45 542.22 4.00 -10.03 5,982,087.11 543,327.70 11 8,700.00 95.35 339.27 6,498.74 1,129.51 2,724.23 639.29 4.00 140.00 5,982,178.91 543,289.99 8,795.00 92.43 341.69 6,492.30 1,218.83 2,692.57 732.76 4.00 140.31 5,982,268.05 543,257.85 12 8,800.00 92.37 341.89 6,492.09 1,223.58 2,691.01 737.70 4.00 105.00 5,982,272.78 543,256.27 8,900.00 91.33 345.75 6,488.85 1,319.55 2,663.17 837.05 4.00 105.01 5,982,368.59 543,227.91 9,000.00 90.29 349.61 6,487.44 1,417.21 2,641.84 936.93 4.00 105.13 5,982,466.13 543,206.05 9,100.00 89.24 353.47 6,487.85 1,516.11 2,627.14 1,036.88 4.00 105.19 5,982,564.94 543,190.82 9,200.00 88.20 357.34 6,490.09 1,615.74 2,619.13 1,136.39 4.00 105.17 5,982,664.51 543,182.27 9,245.00 87.73 359.08 6,491.69 1,660.69 2,617.72 1,180.90 4.00 105.09 5,982,709.45 543,180.62 13 9,300.00 88.09 1.25 6,493.70 1,715.65 2,617.88 1,234.99 4.00 80.50 5,982,764.40 543,180.48 9,400.00 88.76 5.19 6,496.44 1,815.43 2,623.49 1,332.29 4.00 80.42 5,982,864.21 543,185.55 9,500.00 89.44 9.13 6,498.02 1,914.62 2,635.96 1,427.80 4.00 80.31 5,982,963.45 543,197.48 9,600.00 90.12 13.08 6,498.41 2,012.73 2,655.22 1,521.07 4.00 80.25 5,983,061.65 543,216.20 9,645.00 90.42 14.85 6,498.20 2,056.40 2,666.07 1,562.20 4.00 80.24 5,983,105.38 543,226.82 14 9,700.00 90.42 17.05 6,497.79 2,109.27 2,681.19 1,611.64 4.00 90.00 5,983,158.33 543,241.65 9,800.00 90.42 21.05 6,497.06 2,203.77 2,713.82 1,699.04 4.00 90.02 5,983,252.99 543,273.76 9,900.00 90.41 25.05 6,496.33 2,295.77 2,752.97 1,782.84 4.00 90.05 5,983,345.19 543,312.41 9,945.00 90.41 26.85 6,496.01 2,336.23 2,772.66 1,819.27 4.00 90.07 5,983,385.75 543,331.88 15 10,000.00 90.41 24.65 6,495.61 2,385.76 2,796.55 1,863.90 4.00 -90.00 5,983,435.41 543,355.50 211212013 12:26:38PM Page 3 COMPASS 2003.16 Build 69 IV-, ConocoPhillips or its affiliates Hall ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1G Pad Well: 1G-10 Wellbore: IG -10B Design: 1 G-10B_wpl 1 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Well 1G-10 Mean Sea Level 1G -10A: @ 94.17ft (1G -10A:) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Nl-S +El -W Section Rate Azimuth Northing Easting (ft) (°) (°1 (ft) (ft) (ft) (ft) (°1100ft) l°) (ft) (ft) 10,100.00 90.41 20.65 6,494.90 2,478.03 2,835.05 1,948.08 4.00 -90.02 5,983,527.87 543,393.50 10,200.00 90.40 16.65 6,494.19 2,572.75 2,867.03 2,035.81 4.00 -90.04 5,983,622.76 543,424.96 10,300.00 90.40 12.65 6,493.49 2,669.48 2,892.32 2,126.68 4.00 -90.07 5,983,719.61 543,449.72 10,380.00 90.39 9.45 6,492.93 2,747.99 2,907.65 2,201.33 4.00 -90.10 5,983,798.20 543,464.62 TD at 10380.00 2/12/2013 12:26:38PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates FUS ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 G Pad Well: 1G-10 Wellbore: IG -1013 Design: 1 G-10B_wp 11 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Shape (1) (1) (ft) (ft) (ft) Well 1G-10 Mean Sea Level 1 G-1 OA: @ 94 17ft (1 G-1 OA ) True Minimum Curvature Northing Easting (ft) (ft) Latitude Longitude 1G-10B_T1 0.00 0.00 6,519.00 992.83 2,729.92 5,982,042.28 plan misses target center by 46.77ft at 8570.42ft MD (6514.78 TVD, 1010.57 N, 2772.99 E) Point 1G -106_T5 0.00 0.00 6,496.00 2,847.20 2,876.99 5,983,897.23 plan misses target center by 103.89ft at 10380.00ft MD (6492.93 TVD, 2747.99 N, 2907.65 E) Point 1G-10B_Faultl 0.00 0.00 0.00 992.84 2,728.92 5,982,042.28 plan misses target center by 6378.12ft at 7422.00ft MD (6349.63 TVD, 666.44 N, 3234.90 E) Rectangle (sides W1,000.00 H1.00 D0.00) 1G -10B Fault3 0.00 0.00 0.00 1,984.42 2,638.29 5,983,033.25 plan misses target center by 6498.39ft at 9543.57ft MD (6498.33 TVD, 1957.53 N, 2643.52 E) Rectangle (sides W1,000.00 H1.00 D0.00) 1G -10B T3 0.00 0.00 6,487.00 1,389.34 2,643.06 5,982,438.27 plan misses target center by 4.14ft at 8972.51ft MD (6487.64 TVD, 1390.22 N, 2647.05 E) Point 1G -1013_T4 0.00 0.00 6,500.00 1,984.42 2,638.29 5,983,033.25 plan misses target center by 10.54ft at 9568.96ft MD (6498.41 TVD, 1982.42 N, 2648.52 E) Point 1G-10B_Fault2 0.00 0.00 0.00 1,339.34 2,642.79 5,982,388.27 plan misses target center by 6412.58ft at 7422.00ft MD (6349.63 TVD, 666.44 N, 3234.90 E) Rectangle (sides W1,000.00 H1.00 D0.00) 1G -10B T2 0.00 0.00 6,485.00 1,340.39 2,633.79 5,982,389.27 plan misses target center by 23.82ft at 8926.68ft MD (6488.30 TVD, 1345.46 N, 2656.84 E) Point 1G-1013 CTD Polygon_S 0.00 0.00 0.00 919.18 3,217.58 5,981,971.27 plan misses target center by 6354.68ft at 7422.00ft MD (6349.63 TVD, 666.44 N, 3234.90 E) Polygon Point 1 0.00 919.18 3,217.58 5,981,971.27 Point 0.00 607.07 1,868.75 5,981,651.89 Point 3 0.00 -981.33 1,485.19 5,980,061.59 Point 0.00 -1,193.00 2,102.12 5,979,853.29 Point 5 0.00 -47.78 2,240.28 5,980,999.12 Point 0.00 174.20 2,290.48 5,981,221.35 Point 0.00 542.94 3,465.59 5,981,596.42 Point 8 0.00 919.31 3,217.58 5,981,971.40 1G-1013 CTD Polygon_N 0.00 0.00 0.00 919.14 3,224.58 5,981,971.27 plan misses target center by 6354.67ft at 7422.00ft MD (6349.63 TVD, 666.44 N, 3234.90 E) Polygon Point 1 0.00 919.14 3,224.58 5,981,971.27 Point 0.00 542.69 3,486.59 5,981,596.28 Point 0.00 337.28 2,999.43 5,981,388.26 Point 0.00 1,299.42 2,247.51 5,982,346.21 Point 5 0.00 3,082.22 2,695.13 5,984,131.24 Point 0.00 2,891.45 3,208.16 5,983,943.27 Point 0.00 1,914.61 2,970.89 5,982,965.25 Point 0.00 1,095.35 2,816.48 5,982,145.25 Point 0.00 919.14 3,224.58 5,981,971.27 543,296.42 70° 21'42.583 N 149° 38'53.834 W 543,433.43 70° 22'0.820 N 149° 38' 49.512 W 543,295.42 70° 21'42.583 N 149° 38' 53.863 W 543.199.43 70° 21'52.336 N 149° 38'56.503 W I 543,207.42 700 21'46.483 N 149° 38'56.370 W 543,199.43 70° 21'52.336 N 149° 38' 56.503 W 543,207.42 70° 21'45.991 N 149° 38'56.378 W 543,198.42 70° 21'46.002 N 149° 38' 56.641 W 543,784.42 70° 21'41.857 N 149° 38'39.575 W 543,784.42 542,437.44 542, 062.52 542,680.53 542,812.47 542,861.46 544,034.44 543,784.42 543.791.42 70° 21'41.857 N 149° 38'39.370 W 543,791.42 544,055.44 543,569.45 542,812.40 543,250.32 543,764.32 543,532.37 543,382.41 543,791.42 2/1212013 12:26:38PM Page 5 COMPASS 2003.16 Build 69 1VP-1 ConocoPhillips or its affiliates rias ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project Kuparuk River Unit Site: Kuparuk 1 G Pad Well: 1G-10 Wellbore: 1G -10B Design: 1 G-10B_wp11 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1G-10 Mean Sea Level 1 G-1 OA: @ 94.17ft (1 G-1 OA:) True Minimum Curvature Casing Points Measured Vertical Local Coordinates Casing Hole Depth Depth +E/ -W Diameter Diameter (ft) (ft) Name (") (") 111.17 17.00 16" 16 24 2,345.17 2,081.53 10 3/4" 10-3/4 13-1/2 6,296.17 5,351.69 7" 7 8-1/2 10,380.00 6,492.93 2 3/8" 2-3/8 3 Formations Measured Vertical Dip Depth Depth Dip Direction (ft) (ft) Name Lithology (1) (�) 6,581.00 1G -10B Landing 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (ft) (ft) (ft) (ft) Comment 7,422.00 6,349.63 666.44 3,234.90 TIP 7,482.00 6,402.05 653.82 3,261.23 KOP 7,502.00 6,419.71 649.66 3,269.63 Start 42 DLS 7,572.00 6,485.47 631.00 3,280.62 4 7,768.11 6,577.77 500.68 3,198.32 5 7,960.00 6,534.88 465.78 3,030.75 6 8,030.00 6,527.00 513.18 2,980.90 Start 10 DLS 8,100.00 6,526.50 574.19 2,946.69 Start4 DLS 8,300.00 6,527.03 759.59 2,872.11 9 8,400.00 6,526.37 853.59 2,838.04 10 8,600.00 6,510.74 1,037.50 2,761.45 11 8,795.00 6,492.30 1,218.83 2,692.57 12 9,245.00 6,491.69 1,660.69 2,617.72 13 9,645.00 6,498.20 2,056.40 2,666.07 14 9,945.00 6,496.01 2,336.23 2,772.66 15 10,380.00 6,492.93 2,747.99 2,907.65 TD at 10380.00 2/12/2013 12:26:38PM Page 6 COMPASS 2003.16 Build 69 ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-10 1G -10B 1 G-10B_wp11 Travelling Cylinder Report 12 February, 2013 0 R I G I Ik tL WA led &I BAKER HUGHES ConocoPhillips or its affiliates FGk® ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1G-10 Project: Kuparuk River Unit TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Site Error: 0.00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: 0.0aft Output errors are at 1.00 sigma Reference Wellbore 1G -10B Database: EDM Alaska Prod v16 Reference Design: 1G-10B_wp11 Offset TVD Reference: Offset Datum Reference 1G-10B_wp11 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,422.00 to 10,380.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,228.58ft Error Surface: Elliptical Conic Survey Tool Program Date 2/11/2013 Measured From To Depth Depth (ft) (ft) Survey (Wellbore) Tool Name Description 95.17 6,295.17 Boss Gyro (1 G-10) BOSS -GYRO Sperry -Sun BOSS gyro multishot 6,390.00 7,422.00 MWD (1G -10A) MWD MWD - Standard 7,422.00 10,380.00 1G-10B_wp11 (1G -10B) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name No -Go 111.17 111.17 16" 16 24 2,345.17 2,175.70 10 3/4" 10-3/4 13-1/2 6,296.17 5,445.86 7" 7 8-1/2 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) Kuparuk 1G Pad 1 G-07 - 1 G-07 - 1 G-07 Out of range 1 G-09 - 1 G-09 - 1 G-09 Out of range 1 G-10 - 1 G-10 - 1 G-10 7,438.41 7,500.00 328.18 112.08 219.33 Pass - Major Risk 1G -10 -1G -10A -1G -10A 7,475.00 7,475.00 0.00 1.44 -1.41 FAIL - Major Risk 1G-10 - 1G-10BL1 - 1G-10BL1_wp04 8,950.00 8,950.00 0.24 1.21 -0.91 FAIL - Minor 1/10 1G-10 - 1G-10BL2 - 1G-10BL2_wp05 7,900.00 7,900.00 0.08 1.16 -0.75 FAIL - Major Risk 1G-1 1 - 1G-1 1 - 1G-1 1 Out of range 1 G-12 - 1 G-12 - 1 G-12 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2112/2013 8:42:06AM Page 2 of 9 COMPASS 2003.16 Build 69 0 r? I I N I �' I i(IJ i I 'SAL_ ConocoPhillips ConocoPhillips or its affiliates rias Travelling Cylinder Report BAKER Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1 G Pad MD Reference: Site Error: 0.00ft North Reference: Reference Well: 1G-10 Survey Calculation Method: Well Error: 0.00ft Output errors are at Reference Wellbore 1G -10B Database: Reference Design: 1 G-10B_wp11 Offset ND Reference: HUGHES Well 1G-10 1G -10A: @ 94.17ft(1G-10A:) 1G -10A: @ 94.17ft (1G -10A:) True Minimum Curvature 1.00 sigma EDM Alaska Prod v16 Offset Datum Offset Design Kuparuk 1 G Pad - 1 G-10 - 1 G-10 - 1 G-10 offset site Error: 0.00 it Survey Program: 100 -BOSS -GYRO Rule Assigned: Major Risk Offset Well Error: 0.0011 Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Tootface+ Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N15 +E/ -W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) (ft) (ft) (ft) 7,438.41 6,458.11 7,500.00 6,521.49 34.78 6.10 4.59 983.32 3,282.11 0.65 328.18 112.08 219.33 Pass - Major Risk, CC, ES, SF 7,464.28 6,480.71 7,525.00 6,542.05 34.80 6.27 4.99 986.61 3,295.95 0.65 336.68 112.95 227.02 Pass - Major Risk 7,487.88 6,501.38 7,550.00 6,562.47 34.82 6.44 5.55 989.99 3,309.97 0.65 345.12 113.78 234.93 Pass - Major Risk 7,504.91 6,516.48 7,575.00 6,582.75 34.83 6.60 6.66 993.45 3,324.17 0.65 353.90 114.33 243.94 Pass - Major Risk 7,517.06 6,527.55 7,600.00 6,602.89 34.83 6.77 8.33 996.99 3,338.55 0.65 363.38 114.97 254.26 Pass - Major Risk 7,530.00 6,539.64 7,625.00 6,622.91 34.84 6.95 10.30 1,000.62 3,353.08 0.65 373.70 115.79 265.54 Pass - Major Risk 7,540.00 6,549.12 7,650.00 6,642.83 34.84 7.13 12.26 1,004.38 3,367.71 0.65 384.88 116.77 277.77 Pass - Major Risk 7,550.00 6,558.66 7,675.00 6,662.65 34.84 7.31 14.35 1,008.25 3,382.45 0.65 396.94 117.38 291.11 Pass - Major Risk 7,556.26 6,564.65 7,700.00 6,682.37 34.84 7.49 16.29 1,012.24 3,397.29 0.65 409.85 118.18 305.25 Pass - Major Risk 7,563.76 6,571.81 7,725.00 6,701.97 34.84 7.68 18.34 1,016.33 3,412.26 0.65 423.62 119.12 320.48 Pass - Major Risk 7,570.00 6,577.75 7,750.00 6,721.44 34.84 7.87 20.34 1,020.51 3,427.38 0.65 438.18 119.94 336.58 Pass - Major Risk 7,572.00 6,579.64 7,775.00 6,740.77 34.84 8.06 22.04 1,024.76 3,442.64 0.65 453.57 120.66 353.22 Pass - Major Risk 7,580.00 6,587.14 7,800.00 6,759.98 34.83 8.24 23.73 1,029.10 3,458.04 0.65 469.69 120.23 372.06 Pass - Major Risk 7,580.00 6,587.14 7,825.00 6,779.11 34.83 8.34 25.15 1,033.49 3,473.52 0.65 486.52 120.62 390.82 Pass - Major Risk 7,584.49 6,591.28 7,850.00 6,798.25 34.83 8.44 26.58 1,037.87 3,489.00 0.65 503.93 120.36 411.22 Pass - Major Risk 7,590.00 6,596.28 7,875.00 6,817.39 34.83 8.54 27.95 1,042.25 3,504.48 0.65 521.92 119.88 432.44 Pass - Major Risk 7,590.00 6,596.28 7,900.00 6,836.53 34.83 8.64 29.11 1,046.63 3,519.96 0.65 540.34 120.33 451.98 Pass - Major Risk 7,590.00 6,596.28 7,925.00 6,855.66 34.83 8.74 30.20 1,051.02 3,535.43 0.65 559.27 120.78 471.96 Pass - Major Risk 7,594.92 6,600.67 7,950.00 6,874.80 34.83 8.83 31.34 1,055.40 3,550.91 0.65 578.56 120.38 493.80 Pass - Major Risk 7,600.00 6,605.10 7,970.00 6,890.11 34.83 8.91 32.23 1,058.91 3,563.29 0.65 594.32 119.84 512.00 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2112/2013 8:42:06AM Page 3 of COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates Has ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1G-10 Project: Kuparuk River Unit ND Reference: 1G -10A: @ 94.17ft (1G -10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Site Error: 0,00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1G -10B Database: EDM Alaska Prod v16 Reference Design: 1G-110B_wpl1 Offset ND Reference: Offset Datum Offset Design Kuparuk 1 G Pad - 1G -10 -1G -10A -1G -10A offset site Error: 0 00 e Survey Program: 95 -BOSS -GYRO, 6390 -MWD Rule Assigned: Major Risk Offset Well Error: 0 00 It Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toofface+ Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth -NIS +E/ -W Hole Srze Centre Distance Deviation (ft) (ft) (try (R) (ft) (ff) (°) (ft) (it) (ft1 (ft) (ft) (it) 7,425.00 6,446.42 7,425.00 6,446.42 0.00 0.00 13.52 665.79 3,236.22 0.50 0.00 0.55 -0.55 FAIL - Major Risk, CC 7,450.00 6,468.23 7,450.00 6,468.23 0.04 0.04 13.42 660.42 3,247.19 0.50 0.00 1.00 -0.98 FAIL - Major Risk 7,475.00 6,490.09 7,475.00 6,490.09 0.07 0.09 13.33 655.24 3,258.16 0.50 0.00 1.44 -1.41 FAIL - Major Risk, ES, SF 7,499.99 6,512.09 7,500.00 6,511.99 0.10 0.13 66.95 650.24 3,269.13 0.50 0.35 1.87 -1.41 FAIL - Major Risk 7,524.52 6,534.49 7,525.00 6,533.94 0.12 0.17 73.59 645.42 3,280.09 0.50 3.34 2.28 1.26 Pass - Major Risk 7,547.30 6,556.09 7,550.00 6,555.89 0.14 0.21 76.95 640.74 3,291.10 0.50 10.64 2.65 8.26 Pass - Major Risk 7,567.39 6,575.27 7,575.00 6,577.83 0.15 0.26 78.92 636.18 3,302.18 0.50 21.68 2.98 19.06 Pass - Major Risk 7,585.19 6,591.92 7,600.00 6,599.76 0.16 0.30 78.96 631.74 3,313.33 0.50 35.60 3.24 32.74 Pass - Major Risk 7,600.00 6,605.10 7,625.00 6,621.68 0.18 0.34 77.26 627.40 3,324.54 0.50 51.48 3.45 48.39 Pass - Major Risk 7,613.96 6,616.81 7,650.00 6,643.60 0.19 0.39 75.59 622.96 3,335.72 0.50 68.88 3.64 65.59 Pass - Major Risk 7,625.25 6,625.70 7,675.00 6,665.50 0.20 0.44 74.14 618.38 3,346.86 0.50 87.53 3.79 84.07 Pass - Major Risk 7,634.90 6,632.81 7,700.00 6,687.40 0.21 0.48 72.95 613.67 3,357.96 0.50 107.17 3.92 103.58 Pass - Major Risk 7,643.15 6,638.52 7,725.00 6,709.29 0.22 0.53 71.98 608.87 3,369.05 0.50 127.63 4.05 123.92 Pass - Major Risk 7,650.00 6,642.99 7,750.00 6,731.17 0.23 0.59 71.15 604.04 3,380.13 0.50 148.78 4.18 144.97 Pass - Major Risk 7,656.33 6,646.88 7,775.00 6,753.04 0.24 0.64 70.47 599.18 3,391.23 0.50 170.48 4.30 166.59 Pass - Major Risk 7,660.00 6,649.03 7,800.00 6,774.91 0.25 0.69 69.84 594.30 3,402.33 0.50 192.65 4.41 188.69 Pass - Major Risk 7,666.27 6,652.52 7,825.00 6,796.76 0.26 0.74 69.40 589.40 3,413.43 0.50 215.15 4.52 211.14 Pass - Major Risk 7,670.00 6,654.48 7,850.00 6,818.61 0.27 0.79 68.97 584.48 3,424.54 0.50 237.98 4.62 233.92 Pass - Major Risk 7,673.96 6,656.47 7,875.00 6,840.46 0.27 0.83 68.61 579.55 3,435.65 0.50 261.06 4.70 256.97 Pass - Major Risk 7,680.00 6,659.30 7,900.00 6,862.31 0.28 0.88 68.39 574.63 3,446.76 0.50 284.40 4.79 280.29 Pass - Major Risk 7,680.00 6,659.30 7,906.00 6,867.55 0.28 0.89 68.29 573.45 3,449.42 0.50 290.00 4.81 285.88 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/12/2013 8:42:06AM Page 4 of COMPASS 2003.16 Build 69 0 R" 11 G I N -i (% L ConocoPhillips or its affiliates NitI ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Reference Site: Kuparuk 1G Pad Site Error: 0.00ft Reference Well: 1G-10 Well Error: 0.00ft Reference Wellbore 1G-1013 Reference Design: 1G-10B_wpl l Local Co-ordinate Reference: Well 113-10 TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) MD Reference: 1G -10A: @ 94.17ft (1G -10A:) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM Alaska Prod v16 Offset TVD Reference: Offset Datum Offset Design KuparuklGPad- 1G-10-1G-10BLi-1G-10BL1_wp04 offset Site Error 000ft Survey Program: 95 -BOSS -GYRO, 6390 -MWD, 7422 -MWD, 8930 -MWD Rule Assigned: Minor 1/10 Offset Well Error: 0.00 8 Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toofface+ Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NIS +E/ -W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) l°l lh) (ft) (ft) (ft) (ft) Ift) 8,950.00 6,582.09 8,950.00 6,582.29 0.15 0.16 -159.35 1,368.17 2,651.55 0.65 0.24 1.21 -0.91 FAIL - Minor 1/10, CC, ES, SF 8,974.97 6,581.79 8,975.00 6,582.83 0.35 0.23 -158.39 1,392.51 2,645.90 0.65 1.24 1.61 -0.10 FAIL - Minor 1/10 8,999.90 6,581.61 9,000.00 6,584.14 0.54 0.32 -157.46 1,416.83 2,640.25 0.65 3.02 1.97 1.46 Pass - Minor 1/10 9,024.75 6,581.54 9,025.00 6,586.21 0.75 0.42 -156.54 1,441.10 2,634.61 0.65 5.56 2.32 3.79 Pass - Minor 1/10 9,049.55 6,581.58 9,050.00 6,588.66 0.96 0.52 -156.41 1,465.41 2,629.35 0.65 8.34 2.63 6.39 Pass - Minor 1/10 9,074.38 6,581.74 9,075.00 6,591.10 1.17 0.64 -157.11 1,489.88 2,624.84 0.65 10.85 2.90 8.74 Pass - Minor 1/10 9,099.22 6,582.01 9,100.00 6,593.54 1.38 0.75 -158.27 1,514.48 2,621.08 0.65 13.10 3.13 10.87 Pass - Minor 1110 9,124.09 6,582.39 9,125.00 6,595.98 1.61 0.88 -159.77 1,539.17 2,618.08 0.65 15.09 3.35 12.77 Pass - Minor 1/10 9,148.97 6,582.89 9,150.00 6,598.40 1.84 1.00 -161.61 1,563.95 2,615.84 0.65 16.86 3.52 14.48 Pass - Minor 1/10 9,173.86 6,583.50 9,175.00 6,600.81 2.06 1.14 -163.79 1,588.79 2,614.36 0.65 18.42 3.66 16.02 Pass - Minor 1110 9,198.78 6,584.22 9,200.00 6,603.21 2.29 1.28 -166.33 1,613.67 2,613.64 0.65 19.81 3.75 17.43 Pass - Minor 1110 9,223.72 6,585.06 9,225.00 6,605.60 2.53 1.43 -169.23 1,638.55 2,613.68 0.65 21.05 3.81 18.74 Pass - Minor 1/10 9,248.67 6,586.01 9,250.00 6,607.64 2.76 1.57 -171.91 1,663.46 2,614.30 0.65 21.92 3.83 19.68 Pass - Minor 1/10 9,273.53 6,586.94 9,275.00 6,609.03 3.00 1.72 -174.01 1,688.40 2,615.30 0.65 22.21 3.83 20.01 Pass - Minor 1/10 9,298.41 6,587.81 9,300.00 6,609.75 3.23 1.88 -175.82 1,713.35 2,616.68 0.65 21.98 3.83 19.79 Pass - Minor 1/10 9,323.31 6,588.61 9,325.00 6,609.82 3.46 2.04 -177.55 1,738.29 2,618.44 0.65 21.22 3.83 18.98 Pass - Minor 1/10 9,348.20 6,589.34 9,350.00 6,609.22 3.70 2.20 -179.41 1,763.19 2,620.58 0.65 19.91 3.82 17.57 Pass - Minor 1/10 9,373.07 6,589.99 9,375.00 6,607.95 3.93 2.38 178.31 1,788.03 2,623.10 0.65 18.06 3.83 15.54 Pass - Minor 1/10 9,397.95 6,590.57 9,400.00 6,606.36 4.16 2.55 175.06 1,812.80 2,626.06 0.65 16.04 3.83 13.22 Pass - Minor 1/10 9,422.88 6,591.08 9,425.00 6,605.17 4.40 2.72 170.42 1,837.51 2,629.65 0.65 14.64 3.81 11.42 Pass - Minor 1/10 9,447.85 6,591.51 9,450.00 6,604.42 4.64 2.89 164.73 1,862.14 2,633.85 0.65 13.96 3.81 10.35 Pass - Minor 1/10 9,472.86 6,591.88 9,475.00 6,604.11 4.88 3.07 158.82 1,886.67 2,638.66 0.65 14.03 3.84 10.21 Pass - Minor 1/10 9,497.92 6,592.16 9,500.00 6,604.13 5.12 3.23 154.80 1,911.17 2,643.66 0.65 14.47 3.85 10.70 Pass - Minor 1/10 9,523.03 6,592.38 9,525.00 6,604.23 5.36 3.39 155.11 1,935.80 2,647.93 0.65 14.46 3.84 10.74 Pass - Minor 1/10 9,548.10 6,592.52 9,550.00 6,604.41 5.60 3.54 159.77 1,960.55 2,651.46 0.65 13.91 3.84 10.14 Pass - Minor 1110 9,573.07 6,592.59 9,575.00 6,604.68 5.85 3.70 169.66 1,985.39 2,654.23 0.65 13.07 3.84 9.26 Pass - Minor 1/10 9,597.85 6,592.58 9,600.00 6,605.02 6.09 3.87 -174.09 2,010.30 2,656.24 0.65 12.53 3.84 9.32 Pass - Minor 1/10 9,622.37 6,592.50 9,625.00 6,605.44 6.33 4.05 -152.78 2,035.27 2,657.50 0.65 13.29 3.86 9.72 Pass - Minor 1/10 9,646.67 6,592.35 9,650.00 6,605.91 6.56 4.24 -133.54 2,060.24 2,658.49 0.65 15.91 3.87 12.49 Pass - Minor 1/10 9,670.98 6,592.17 9,675.00 6,606.39 6.80 4.44 -121.03 2,085.18 2,660.20 0.65 19.46 3.88 18.81 Pass - Minor 1110 9,695.27 6,592.00 9,700.00 6,606.86 7.04 4.65 -112.80 2,110.05 2,662.68 0.65 23.29 3.89 22.64 Pass - Minor 1110 9,719.55 6,591.82 9,725.00 6,607.33 7.28 4.87 -107.08 2,134.83 2,665.92 0.65 27.11 3.89 26.46 Pass - Minor 1 A 0 9,743.81 6,591.64 9,750.00 6,607.80 7.52 5.08 -102.87 2,159.51 2,669.91 0.65 30.78 3.88 30.14 Pass - Minor 1/10 9,768.06 6,591.46 9,775.00 6,608.27 7.76 5.30 -99.63 2,184.05 2,674.65 0.65 34.24 3.86 33.59 Pass - Minor 1/10 9,792.30 6,591.29 9,800.00 6,608.74 8.00 5.52 -97.05 2,208.43 2,680.15 0.65 37.44 3.84 36.79 Pass - Minor 1110 9,816.53 6,591.11 9,825.00 6,609.20 8.23 5.73 -94.93 2,232.64 2,686.38 0.65 40.36 3.80 39.71 Pass - Minor 1110 9,840.76 6,590.93 9,850.00 6,609.68 8.47 5.95 -93.17 2,256.64 2,693.35 0.65 43.00 3.81 42.35 Pass - Minor 1110 9,864.97 6,590.76 9,875.00 6,610.19 8.70 6.17 -91.73 2,280.42 2,701.05 0.65 45.35 3.84 44.70 Pass - Minor 1/10 9,889.17 6,590.58 9,900.00 6,610.74 8.93 6.39 -90.55 2,303.95 2,709.47 0.65 47.41 3.85 46.77 Pass - Minor 1/10 9,913.37 6,590.41 9,925.00 6,611.33 9.16 6.61 -89.59 2,327.21 2,718.60 0.65 49.19 3.87 48.54 Pass - Minor 1/10 9,937.57 6,590.23 9,950.00 6,611.96 9.39 6.82 -88.84 2,350.19 2,728.44 0.65 50.67 3.88 50.02 Pass - Minor 1/10 9,962.88 6,590.05 9,975.00 6,612.63 9.59 7.04 -89.77 2,372.85 2,738.98 0.65 51.68 3.89 51.03 Pass - Minor 1/10 9,988.69 6,589.86 10,000.00 6,613.33 9.76 7.25 -91.92 2,395.18 2,750.20 0.65 51.65 3.89 51.01 Pass - Minor 1/10 10,014.43 6,589.68 10,025.00 6,614.07 9.91 7.46 -94.74 2,417.15 2,762.09 0.65 50.60 3.88 49.96 Pass - Minor 1/10 10,040.07 6,589.50 10,050.00 6,614.83 10.03 7.65 -98.09 2,438.99 2,774.23 0.65 49.00 3.87 48.35 Pass - Minor 1/10 10,065.69 6,589.31 10,075.00 6,615.60 10.16 7.81 -101.40 2,461.18 2,785.72 0.65 47.72 3.86 47.07 Pass - Minor 1/10 10,091.31 6,589.13 10,100.00 6,616.36 10.28 7.97 -104.60 2,483.71 2,796.53 0.65 46.77 3.84 46.13 Pass - Minor 1/10 10,116.91 6,588.95 10,125.00 6,617.12 10.42 8.14 -107.65 2,506.56 2,806.64 0.65 46.15 3.81 45.50 Pass - Minor 1/10 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/12/2013 8:42:06AM Page 5 of 9 COMPASS 2003.16 Build 69 0 R 1`1 N' " I ki" - -110-1 ConocoPhillips or its affiliates FeAa. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1G Pad Site Error: 0.00ft Reference Well: 1G-10 Well Error: 0.00ft Reference Wellbore 1G -10B Reference Design: 1G-10B_wp11 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 1G-10 1G -10A: @ 94.17ft (1G -10A:) 1G -10A: @ 94.17ft (1G -10A:) True Minimum Curvature 1 00 sigma EDM Alaska Prod v16 Offset Datum Offset Design KuparuklGPad- 1G-10-1G-10BL1-1G-1061-1_wp04 Offset Site Error: 0.0011 Survey Program: 95 -BOSS -GYRO, 6390 -MWD, 7422 -MWD. 8930 -MWD Rule Assigned: Minor 1/10 Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toofface+ Offset Wellbore Centre Casing • Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/ -S +E/ -W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) l") (ft) (ft) (ft) (ft) (ft) (ft) 10,142.51 6,588.76 10,150.00 6,617.88 10.57 8.31 -110.49 2,529.71 2,816.05 0.65 45.82 3.82 45.18 Pass - Minor 1/10 10,168.10 6,588.58 10,175.00 6,618.63 10.71 8.50 -113.10 2,553.13 2,824.75 0.65 45.78 3.83 45.13 Pass - Minor 1/10 10,193.69 6,588.40 10,200.00 6,619.38 10.86 8.68 -115.43 2,576.81 2,832.73 0.65 46.00 3.83 45.35 Pass - Minor 1/10 10,219.28 6,588.22 10,225.00 6,620.13 11.02 8.88 -117.48 2,600.72 2,839.99 0.65 46.47 3.83 45.83 Pass - Minor 1/10 10,244.87 6,588.04 10,250.00 6,620.87 11.20 9.08 -119.23 2,624.85 2,846.51 0.65 47.18 3.82 46.54 Pass - Minor 1/10 10,270.46 6,587.86 10,275.00 6,621.60 11.37 9.29 -120.68 2,649.16 2,852.29 0.65 48.12 3.81 47.48 Pass - Minor 1/10 10,296.05 6,587.68 10,300.00 6,622.33 11.54 9.49 -121.86 2,673,63 2,857.32 0.65 49.28 3.80 48.64 Pass - Minor 1/10 10,321.65 6,587.50 10,325.00 6,623.04 11.73 9.71 -122.76 2,698.25 2,861.60 0.65 50.66 3.78 50.02 Pass - Minor 1/10 10,347.25 6,587.33 10,350.00 6,623.75 11.92 9.93 -123.43 2,722.99 2,865.13 0.65 52.26 3.76 51.62 Pass - Minor 1/10 10,372.87 6,587.15 10,375.00 6,624.46 12.11 10.16 -123.87 2,747.82 2,867.91 0.65 54.09 3.73 53.44 Pass - Minor 1/10 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/1212013 8:42:06AM Page 6 of 9 COMPASS 2003.16 Build 69 0 ConocoPhillips or its affiliates .ela. ConocoPhillips Travelling Cylinder Report EIMER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1G-10 Project: Kuparuk River Unit TVD Reference: 1G -10A: @ 94.17ft (1G -10A:) Reference Site: Kuparuk 1G Pad MD Reference: 1G -10A: @ 94.17ft (1G -10A:) Site Error: 0.00ft North Reference: True Reference Well: 1G-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1G -10B Database: EDM Alaska Prod v16 Reference Design: 1G-108_wp11 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1 G Pad - 1 G-10 - 1 G-10BL2 - 1 G-10BL2_wp05 Offset Site Error: 0,00 It Survey Program: 95 -BOSS -GYRO, 6390 -MWD, 7422 -MWD, 7895 -MWD Rule Assigned: Major Risk Offset Well Error: 0.00 It Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toofface+ Offset Wellbore Centre Casing - Centre tc No Go Allowable Warming Depth Depth Depth Depth Azimuth +N/S +E1 -W Hole Size Centre Distance Deviation (n) (n) (n) (n) 7,900.00 6,642.36 7,900.00 6,642.38 0.01 0.27 172.87 449.02 3,086.30 0.65 0.08 1.16 -0.75 FAIL - Major Risk, CC, ES, SF 7,924.59 6,636.61 7,925.00 6,637.05 0.07 0.27 -174.20 450.00 3,061.90 0.65 3.02 1.53 1.78 Pass - Major Risk 7,947.58 6,631.58 7,950.00 6,632.73 0.12 0.27 -162.55 451.36 3,037.32 0.65 9.96 1.93 8.30 Pass - Major Risk 7,968.19 6,627.51 7,975.00 6,629.42 0.16 0.28 -152.64 453.10 3,012.60 0.65 20.35 2.29 18.27 Pass - Major Risk 7,986.25 6,624.67 8,000.00 6,627.13 0.19 0.30 -144.18 455.21 2,987.79 0.65 33.46 2.63 31.01 Pass - Major Risk 8,001.81 6,622.86 8,025.00 6,625.88 0.21 0.32 -137.31 457.69 2,962.95 0.65 48.71 2.92 45.94 Pass - Major Risk 8,014.93 6,621.82 8,050.00 6,625.26 0.22 0.35 -131.57 460.07 2,938.07 0.65 65.91 3.17 62.89 Pass - Major Risk 8,020.00 6,621.54 9,200.00 6,590.65 0.23 4.88 -125.04 -119.04 2,092.65 0.65 1,090.61 10.37 1,082.35 Pass - Major Risk 8,020.00 6,621.54 9,225.00 6,590.11 0.23 5.02 -125.02 -141.11 2,080.94 0.65 1,112.91 10.41 1,104.63 Pass - Major Risk 8,020.00 6,621.54 9,250.00 6,589.58 0.23 5.16 -125.00 -162.66 2,068.27 0.65 1,135.79 10.43 1,127.49 Pass - Major Risk 8,020.00 6,621.54 9,275.00 6,589.05 0.23 5.32 -124.98 -183.63 2,054.67 0.65 1,159.16 10.49 1,150.81 Pass - Major Risk 8,020.00 6,621.54 9,300.00 6,588.54 0.23 5.48 -124.97 -204.15 2,040.41 0.65 1,182.86 10.57 1,174.45 Pass - Major Risk 8,020.00 6,621.54 9,325.00 6,588.02 0.23 5.68 -124.96 -225.15 2,026.85 0.65 1,206.34 10.66 1,197.85 Pass - Major Risk 8,025.35 6,621.31 9,175.00 6,591.19 0.23 4.76 -122.87 -96.47 2,103.40 0.65 1,068.83 9.94 1,060.84 Pass - Major Risk 8,025.50 6,621.30 8,075.00 6,624.47 0.23 0.38 -126.56 461.41 2,913.13 0.65 85.16 3.37 81.95 Pass - Major Risk 8,030.00 6,621.17 9,100.00 6,592.85 0.23 4.42 -121.06 -26.27 2,129.59 0.65 1,008.24 9.67 1,000.34 Pass - Major Risk 8,030.00 6,621.17 9,125.00 6,592.29 0.23 4.53 -121.04 -50.05 2,121.88 0.65 1,027.60 9.62 1,019.78 Pass - Major Risk 8,030.00 6,621.17 9,150.00 6,591.74 0.23 4.63 -121.02 -73.46 2,113.15 0.65 1,047.86 9.56 1,040.11 Pass- Major Risk 8,035.64 6,621.05 8,100.00 6,623.50 0.24 0.42 -123.44 461.68 2,888.15 0.65 105.94 3.58 102.54 Pass - Major Risk 8,038.42 6,621.00 9,075.00 6,593.40 0.24 4.30 -120.25 -2.19 2,136.25 0.65 989.75 9.61 981.81 Pass - Major Risk 8,046.02 6,620.86 8,125.00 6,622.34 0.24 0.45 -121.78 460.87 2,863.19 0.65 127.60 3.79 124.00 Pass - Major Risk 8,050.00 6,620.80 8,150.00 6,621.01 0.25 0.49 -120.84 458.99 2,838.30 0.65 150.07 3.98 146.33 Pass - Major Risk 8,050.00 6,620.80 8,975.00 6,595.80 0.25 3.72 -119.19 93.43 2,165.07 0.65 916.48 9.47 908.46 Pass - Major Risk 8,050.00 6,620.80 9,000.00 6,595.16 0.25 3.87 -119.17 70.00 2,156.38 0.65 935.44 9.52 927.40 Pass - Major Risk 8,050.00 6,620.80 9,025.00 6,594.55 0.25 4.02 -119.15 46.21 2,148.72 0.65 953.98 9.52 945.96 Pass - Major Risk 8,050.00 6,620.80 9,050.00 6,593.96 0.25 4.16 -119.13 22.11 2,142.10 0.65 972.08 9.50 964.10 Pass - Major Risk 8,062.93 6,620.66 8,175.00 6,619.55 0.25 0.53 -119.11 456.32 2,813.48 0.65 172.81 4.18 168.87 Pass - Major Risk 8,070.32 6,620.61 8,950.00 6,596.46 0.25 3.58 -117.22 116.45 2,174.78 0.65 896.51 9.20 888.55 Pass - Major Risk 8,070.92 6,620.61 8,200.00 6,618.32 0.25 0.57 -118.04 454.46 2,788.59 0.65 195.48 4.38 191.37 Pass - Major Risk 8,076.20 6,620.59 8,925.00 6,597.15 0.25 3.43 -116.66 139.04 2,185.48 0.65 876.32 9.06 868.43 Pass - Major Risk 8,079.17 6,620.59 8,225.00 6,617.38 0.25 0.61 -117.07 453.65 2,763.62 0.65 217.86 4.58 213.57 Pass - Major Risk 8,081.89 6,620.59 8,900.00 6,597.86 0.26 3.29 -116.13 161.13 2,197.16 0.65 855.65 8.93 847.83 Pass - Major Risk 8,087.64 6,620.60 8,250.00 6,616.73 0.26 0.65 -116.17 453.89 2,738.63 0.65 239.92 4.78 235.46 Pass - Major Risk 8,100.00 6,620.67 8,275.00 6,616.31 0.26 0.70 -114.96 454.89 2,713.65 0.65 261.84 4.97 257.17 Pass - Major Risk 8,100.00 6,620.67 8,300.00 6,615.90 0.26 0.74 -114.93 455.05 2,688.66 0.65 284.25 5.14 279.50 Pass - Major Risk 8,100.00 6,620.67 8,750.00 6,602.51 0.26 2.44 -114.44 281.13 2,286.32 0.65 722.71 7.99 715.64 Pass - Major Risk 8,100.00 6,620.67 8,775.00 6,601.69 0.26 2.58 -114.43 262.82 2,269.32 0.65 745.75 8.14 738.53 Pass - Major Risk 8,100.00 6,620.67 8,800.00 6,600.89 0.26 2.72 -114.42 243.78 2,253.14 0.65 768.49 8.28 761.12 Pass - Major Risk 8,100.00 6,620.67 8,825.00 6,600.11 0.26 2.86 -114.41 224.05 2,237.81 0.65 790.91 8.41 783.41 Pass - Major Risk 8,100.00 6,620.67 8,850.00 6,599.34 0.26 3.00 -114.41 203.68 2,223.35 0.65 812.99 8.54 805.38 Pass - Major Risk 8,100.00 6,620.67 8,875.00 6,598.59 0.26 3.14 -114.40 182.69 2,209.79 0.65 834.74 8.64 827.02 Pass - Major Risk 8,112.82 6,620.78 8,325.00 6,615.43 0.26 0.79 -114.39 454.12 2,663.68 0.65 307.15 5.34 302.19 Pass - Major Risk 8,120.02 6,620.84 8,350.00 6,614.92 0.26 0.84 -114.08 452.10 2,638.77 0.65 330.55 5.52 325.45 Pass - Major Risk 8,122.02 6,620.85 8,725.00 6,603.34 0.26 2.31 -113.59 298.68 2,304.10 0.65 698.86 7.84 691.80 Pass - Major Risk 8,126.21 6,620.88 8,375.00 6,614.36 0.26 0.90 -113.80 449.00 2,613.97 0.65 354.34 5.69 349.10 Pass - Major Risk 8,127.03 6,620.89 8,700.00 6,604.17 0.26 2.18 -113.40 315.45 2,322.63 0.65 674.99 7.69 668.05 Pass - Major Risk 8,131.40 6,620.92 8,400.00 6,613.76 0.26 0.96 -113.56 444.82 2,589.34 0.65 378.47 5.85 373.09 Pass - Major Risk 8,131.43 6,620.92 8,675.00 6,605.02 0.26 2.05 -113.25 331.38 2,341.87 0.65 650.83 7.54 644.02 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2112/2013 8:42:06AM Page 7 of 9p�[�e' COMPASS 2003.16 Build 69 0 i �k 4"t �- ConocoPhillips or its affiliates HFAI ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1G Pad Site Error: 0.00ft Reference Well: 1G-10 Well Error: 0.00ft Reference Wellbore 1G-106 Reference Design: 1 G-10B_wpl 1 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 1G-10 1G -10A: @ 94.17ft (1G -10A:) 1G -10A: @ 94.17ft (1G -10A:) True Minimum Curvature 1.00 sigma EDM Alaska Prod v16 Offset Datum Offset Design Kuparuk 1 G Pad - 1 G-10 - 1 G-10131-2 - 1 G-10BL2_wp05 Offset Site Error: 0.00 It Survey Program: 95 -BOSS -GYRO, 6390 -MWD, 7422 -MWD, 7895 -MWD Rule Assigned: Major Risk Offset Well Error: 0.00 It Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NIS +E/ -W Hole Size Centre Distance Deviation (ft) (ft)(ft) (ft) (it) rt) (°) (ft) 00 (it) (it) (ft) (it) 8,135.20 6,620.94 8,650.00 6,605.87 0.26 1.93 -113.12 346.46 2,361.79 0.65 626.43 7.38 619.75 Pass - Major Risk 8,135.63 6,620.95 8,425.00 6,613.12 0.26 1.03 -113.37 439.57 2,564.90 0.65 402.89 6.01 397.37 Pass - Major Risk 8,138.30 6,620.96 8,625.00 6,606.73 0.26 1.81 -113.02 360.66 2,382.34 0.65 601.83 7.23 595.27 Pass - Major Risk 8,138.92 6,620.97 8,450.00 6,612.44 0.26 1.10 -113.20 433.26 2,540.72 0.65 427.52 6.17 421.88 Pass - Major Risk 8,140.71 6,620.98 8600.00 6,607.59 0.26 1.69 -112.95 373.95 2,403.50 0.65 577.06 7.07 570.64 Pass - Major Risk 8,141.31 6,620.98 8,475.00 6,611.72 0.26 1.19 -113.08 425.90 2,516.84 0.65 452.32 6.32 446.54 Pass - Major Risk 8,142.40 6,620.99 8,575.00 6,608,46 0.26 1.58 -112.91 386.30 2,425.22 0.65 552.18 6.92 545.88 Pass - Major Risk 8,142.82 6,620.99 8,500.00 6,610,95 0.26 1.28 -112.99 417.51 2,493.31 0.65 477.24 6.47 471.33 Pass - Major Risk 8,143.34 6,620.99 8,550.00 6,609.32 0.26 1.47 -112.90 397.69 2,447.45 0.65 527.22 6.77 521.05 Pass - Major Risk 8,143.49 6,621.00 8,525.00 6,610.16 0.26 1.37 -112.93 408.10 2,470.16 0.65 502.22 6.62 496.18 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/1212013 8:42:06AM Page 8 of 9 COMPASS 2003.16 Build 69 �- ConocoPhillips or its affiliates WE as ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1 G Pad Site Error: 0,00ft Reference Well: 1G-10 Well Error: 0.00ft Reference Wellbore 1G-1013 Reference Design: 1 G-1 013_wp11 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 1G-10 1G -10A: @ 94A7ft (1G -10A') 1G -10A: @ 94.17ft (1G -10A:) True Minimum Curvature 1.00 sigma EDM Alaska Prod v16 Offset Datum Reference Depths are relative to 1G -10A: @ 94.17ft (1G -10A:) Coordinates are relative to: 1G-10 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 Central Meridian is 150° 0'0.000 W' Grid Convergence at Surface is: 0.31° CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/12/2013 8:42:06AM Page 9 of 9 COMPASS 2003.16 Build 69 Ladder Plot I I I I 1 I I I 1200 I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I - I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 900 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I 1 0 ca Q N U) N U 600 0 a� C N U 300 0 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND -° 1G -10,1G -10,1G -10V2 v 1 G-10,1 G-10BL1,1 G-10I3L1 wp04 V0 1 G-10,1 G -10A,1 G -10A V0 $ 1 G-10,1 G-10BL2,1 G-10BL2_vvp05 V0 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/12/2013 8:42:06AM Page 9 of 9 COMPASS 2003.16 Build 69 I I I I 1 I I I 1 I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I - I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I 1 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/12/2013 8:42:06AM Page 9 of 9 COMPASS 2003.16 Build 69 W 1� ConoeoPhillips Mean YI:DIi 260( 240( 220( 4200( 0 C0 180( + 160t 140f C 120( 15 loot R0( r001 40( 20( REFERENCEINFORMATION Co-ordinate(NIP Reference: We11G.10,True North Vertical JVD) Referexe: Mean Sea Level Section (VS) Reference: Slot .(0.06N, 0.60E) Measured Depth Reference: 1G10A: @ 94.1711(1G10A:) Cakulatkn Method: Minimum Curvdue Project: Kuparuk River Uni! AvmMFebine NoM Masne�Nonn; 16. WELLBORE DETAILS: 1G -10B Site: klG Pad 16-10 Well: 1G-10 M.&Feld e Parent Wellbore: 1G -10A Wellbore: 1G-108 svarem. srdasnsn DpAwb1:mw Tie on MD: 7422.00 Plan: 1G-10B_vvp11(1G-10/1G-108) Abdo SM6011 Mean YI:DIi 260( 240( 220( 4200( 0 C0 180( + 160t 140f C 120( 15 loot R0( r001 40( 20( REFERENCEINFORMATION Co-ordinate(NIP Reference: We11G.10,True North Vertical JVD) Referexe: Mean Sea Level Section (VS) Reference: Slot .(0.06N, 0.60E) Measured Depth Reference: 1G10A: @ 94.1711(1G10A:) Cakulatkn Method: Minimum Curvdue WELL DETAILS: 1G-10 Ground Level: D.00 4N/S +E/ -W Northing Easting LatittudeLongitude Slot 0.00 0.00 59B1034.77 540572.19 70° 21' 32.824 N 149-40.13.660 W ■■■■■WHw ►►i\ ■■■■■I SECTION DETAILS ANNOTATIONS Sec MD Inc Azi TVDSS -NI-S 4FJ-W DLeg TFace VSec Target Annotation 1 7422.00 29.39 116.50 6349.63 666.44 3234.90 0.00 0.00 94.58 TIP 2 7482.00 28.86 114.69 6402.05 65392 3261.23 1.71 -121.82 77.58 KOP 3 7502.00 27.06 118.08 6419.71 649.66 3269.63 12.00 140.D0 72.03 Start 42DLS 4 7572.00 18.75 197.06 6485.47 631.00 3280.62 42.00 140.00 51.74 4 5 7768.11 100.00 217.19 6577.77 500.68 3198.32 42.00 20.00 -62.31 5 6 7960.00 101.37 299.50 6534.88 465.78 3030.75 42.00 80.00 -67.58 6 7 8030.00 91.32 32734 6527.00 513.18 2980.90 42.00 108.00 -12.25 Start 10 OLS 8 8100.00 89.50 334.10 6526,50 574.19 2946.69 10.00 105.00 53.78 Start4DLS 9 8300.00 9020 34207 6527.03 75959 2872.11 4.00 85.00 249.32 9 10 8400.00 90.55 338.09 6526.37 85359 2838.04 4.00 275.00 347.80 10 11 8600.00 98.43 336.69 6510.74 1037.50 2761.45 4.00 350.00 542.22 11 12 8795.00 92.43 341.69 6492.30 1218.83 2692.57 4.00 140.00 732.76 12 13 9245.00 87.73 359.08 6491.69 1660.69 2617.72 4.00 105.00 11B0.90 13 14 9645.00 90.42 14.85 649820 2056.40 2666.07 4.00 80.50 156220 14 15 9945.00 90.41 26.85 6496.01 233623 2772.66 4.00 90.00 181927 15 16 10380.00 90.39 9.45 6492.93 2747.99 2907.65 4.00 270.00 2201.33 TO at 10380.00 Mean YI:DIi 260( 240( 220( 4200( 0 C0 180( + 160t 140f C 120( 15 loot R0( r001 40( 20( REFERENCEINFORMATION Co-ordinate(NIP Reference: We11G.10,True North Vertical JVD) Referexe: Mean Sea Level Section (VS) Reference: Slot .(0.06N, 0.60E) Measured Depth Reference: 1G10A: @ 94.1711(1G10A:) Cakulatkn Method: Minimum Curvdue row rcuu -uu -11 rauu 2uuu LLUU L4UU 26UU LSUu 3000 32UU 340U 3600 3800 4000 4200 4400 460( Vertical Section at 350.00° (70 ft/in) I��llaii� il'IR�■��■�;r(�r�■■■��i[t3[li�l ■■■■■WHw ►►i\ ■■■■■I row rcuu -uu -11 rauu 2uuu LLUU L4UU 26UU LSUu 3000 32UU 340U 3600 3800 4000 4200 4400 460( Vertical Section at 350.00° (70 ft/in) TRANSMITTAL LETTER CHECKLIST WELL NAME 1Zl l /6-108 PTD# � / 3 o7 j /Development Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: �(,�,x,�,v. l�i ✓ - POOL: kl,"� f�� J�J. i��.,`x�. 1a, v- U, Check Box for 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 (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(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 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 tar et 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: 9/09/2011 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 1G -10B Program DEV PTD#:2130210 Company CONOCOPH_ ILLIPS ALASKA INC _ _ Initial Class/Type DEV / PEND _ GeoArea 890 Unit 11160 On/Off Shore On Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA Well bore seg Annular Disposal Geologic Engineering is Commissioner: Date: Commissioner: Date Co mi i er Date 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025640; entire wellbore 3 Unique well name and number Yes KRU 1G -10B 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100; governed by Conservation Order No. 432C .5 Well located proper distance from drilling unit boundary Yes CO No. 432C contains _no -spacing restrictions with respect to drilling unit boundaries - 6 Well located proper distance from other wells Yes CO No. 432C has no interwell spacing restrictions 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 2/15/2013 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10#din comments) (For NA 15 All wells within 1/4 milearea of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production Less than 3 months (For service well only) NA 18 Conductor stringprovided- NA Conductor set in KRU 1G-10 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in KRU 1 G-10 20 CMT_ vol -adequate, to circulate -on conductor & surf csg NA - Surface casing fully cemented - 21 CMT vol adequate to tie-in long string to surf csg NA_ 7*'casing set; 3.5" liner set. 22 CMT -will cover all known -productive horizons No Productive_ interval will -be completed with slotted liner 23 Casing designs adequate for C, -T, B &- permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel pits. All waste to -approved disposal. wells. 25 If -a -re -drill, has_a 10-403 for abandonment been approved - Yes Sundry_313-082; cement squeeze perfs, set whipshock and mill window 26 Adequate wellbore separation.proposed Yes - Proximity analysis performed, 1G-10A,1G-10BL1&1G-10B_L2 fail. - 27 If_diverter required, does it meet regulations_ NA_ - - Appr Date 28 _Drilling fluid_ program schematic equip list adequate_ Yes Max expected form_pressure 3907-psi(EMW 12.1)Will drill w/ 9.5_ppg FloPro mud and use MPD for BHP control. VLF 2/21/2013 29 BOPEs, do they meet regulation Yes 30 BOPE.press rating appropriate; test to -(put psig in comments)- - Yes . MPSP is 3383 psi. Will test_B_O_Ps to 4000 psi. - 31 Choke manifold complies w/API_ RP -53 (May84)_ Yes - _ _ - _ _ _ _ _ _ _ _ 32 Work will occur without operation shutdown_ Yes . - _ - - - - _ _ I33 Is presence of 1-12S gas_ probable Yes - H2S measures required 134 Mechanical -condition of wells within AOR verified (For_ service well only) - - NA_ - - - - - - 35 Permit_can be issued _w/o hydrogen sulfide measures - No Wells- on_1G-Pad are H2S bearing. H2S measus_rerequired. - - Geology 36 _D_ata_presented on potential overpressure zones Yes - Max possible reservoir_ pressure is. 12.1_ppg EMW; will be drilled with 9.5 ppg. M.W. and managed pressure- - Appr Date 37 Seismic analysis -of shallow gas zones - - - - - - - NA- _ - - drilling technique.- Two wellbore volumes of 12 ppg-emergency_kill_weight mud will be available. PKB 2(15/2013 38 Seabed condition survey (if off -shore) NA_ - - - - - - _ . - - - 39 -Contact-name/phone for weekly_ progress reports [exploratory only] - - - - - - - - . - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering is Commissioner: Date: Commissioner: Date Co mi i er Date