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Home My WebLink About212-093DATA SUBMITTAL COMPLIANCE REPORT 3/2/2017 Permit to Drill 2120930 Well Name/No. KUPARUK RIV UNIT 1J -09A MD 12697 TVD 6139 REQUIRED INFORMATION Completion Date 10/3/2012 Mud Log No Z DATA INFORMATION Types Electric or Other Logs Run: GR / RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Rpt Directional Survey Log 21982 See Notes Log 21982 See Notes Log 21982 See Notes ED C Tf 21982 See Notes Well Cores/Samples Information: Name Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23006-01-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No Samples No V Directional Survey Yes V (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 9521 12697 Open 10/3/2012 Directional Survey Report + disc 5 Col 9608 12697 Open 10/26/2012 MD Multiple Propagation Resistivity Gamma Ray Realtime Log 5 Col 9608 12697 Open 10/26/2012 TVD SS Multiple Propagation Resistivity Gamma Ray Realtime Log 2 Col 9608 12697 Open 10/26/2012 MD Multiple Propagation Resistivity Gamma Ray Realtime Log 9608 12697 Open 10/26/2012 Multiple Propagation Resistivity Gamma Ray Realtime Log + Graphics tiff, pdf, cgm, tap, txt Sample Interval Set Start Stop Sent Received Number Comments INFORMATION RECEIVED p� pct Completion Report / Y) Directional / Inclination Data / Y ) Mud Logs, Image Files, Digital Data Y //NH/ Core Chips Y /6) Production Test Informatio ,Y-/��NA Mechanical Integrity Test Information `Y// lAl Composite Logs, Image, Data Files Core Photographs Y NA Geologic Markers/Tops ( Y J Daily Operations Summary Cuttings Samples Y /�A Laboratory Analyses Y NA COMPLIANCE HISTORY Completion Date: 10/3/2012 Release Date: 7/25/2012 AOGCC Page 1 of 2 Thursday, March 02, 2017 DATA SUBMITTAL COMPLIANCE REPORT 3/2/2017 Permit to Drill 2120930 Well Name/No. KUPARUK RIV UNIT 1J -09A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23006-01-00 MD 12697 TVD 6139 Completion Date 10/3/2012 Completion Status 1-0I1- Current Status 1-0I1- UIC No Description Date Comments Comments: Compliance Date: AOGCC Page 2 of 2 Thursday, March 02, 2017 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 ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ StratigraphicTest❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: October 3, 2012 212-093/ 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 September 18, 2012 50-029-23006-01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2152' FSL, 2574' FEL, Sec. 35, T11 N, R1 OE, UM September 27, 2012 1 J -09A Top of Productive Horizon: 8. KB (ft above MSL): 115' RKB 15. Field/Pool(s): 1162' FSL, 940' FWL, Sec. 26, T11 N, R1 OE, UM GL (ft above MSL): 35' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 837' FSL, 1069' FWL, Sec. 26, T11 N, R1 OE, UM 12697' MD / 6139' TVD 56 Kupuruk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x-558635 y- 5945963 Zone -4 12697' MD / 6139' TVD55 ADL 25661 11. SSSV Depth (MD + TVD): 17. Land Use Permit: TPI: x-556830 y- 5950239 Zone -4 Total Depth: x-556963 - 5949915 Zone -4 nipple @ 524' MD / 523' TVD 471 18. Directional Survey: Yes ❑✓ No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MDITVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1602' MD / 1547' 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 9608' MD / 6111' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE AMOUNT PULLED 16" 62.58# H-40 35' 115' 35' 115' 24" 460 sx AS 1 9.625" 36# J-55 35' 5639' 35' 3949' 12.25" 653 sx AS Lite, 340 sx LiteCRETE 7" 26# L-80 32' 9198' 32' 6011' 8.5" 184 sx Class G 2.375" 4.6# L-80 10711' 12697' 6113' 6139' 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" 9028' 8988' MD / 5897' TVD slotted liner 10722'-12696' MD 6113'-6139' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED d ® 2 /L 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) ®pG October 14, 2012 gas lift oil oi? Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO 10/28/2012 11 hours Test Period --> 629 1383 473 100% 1939 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 242 psi 1159 24 -Hour Rate -> 1254 3110 1015 1.5 deg. 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No ❑✓ 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 10/2012 CONTINUED ON REVERSE�� ub 'it original only 29. GEOLOGIC MARKERS (List all formations and m. ..s encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑� 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 1602' 1547' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C4 9608' 6111' Top B3/ Base C4 12170' 6134' Top B3/ Base C4 12337' 6141' N/A Formation at total depth: Kuparuk C4 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 32. 1 hereby certify that the foregoing is true and torr to the best of my knowledge. Contact: K. Starck @ 263-4093 Email: Kai.Starck@conocophillips.com Printed Name Lamar Gantt Title: CTD Supervisor r a j Signature C�. \ f i.�L 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 JJ -09A Proposed CTD Sidetrack Updated: 2 -Oct -12 16" 62# H-40 shoe @ 115' MD 9-5/8" 36#1-55 shoe 5639' MD CA -2 plug set in DS nipple @ 8945' 7" 26# L-80 shoe @ 9198' RKB Liner Deployment sleeve (@ 9579' KOP @ 9609' MD C -sand perfs (squeezed) 9590' - 9599' MD 9604' - 9676' M D 3-1/2" 9.3# L-80 shoe @ 9807' RKB 3-1/2" Camco D nipple @ 523' RKB (ID = 2.875") 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels @ 2922', 5088', 6858', 8067' RKB 3-1/2" Camco MMG gas lift mandrels @ 8893' RKB Stuck orifice valve in GLM#3 (6858'), typically covered by retrievable patch. Patch will be re -installed post -CTD. 3-1/2" Camco DS nipple @ 8945' RKB (ID = 2.813") Baker 3-1/2" GBH -22 seal assembly @ 8990' RKB (3" ID?) Liner top Baker 5" x 7" ZXP liner top packer @ 8988' RKB Baker 5" x 7" Flexlock liner hanger @ 8995' RKB Baker 80-40 PBR (4" ID seal bore) @ 9008' RKB 3-1/2" HES'XN' landing nipple @ 9066' RKB (2.75" min ID, milled out to 2.80") 3-1/2" monobore whipstock @ 9609' MD 2-3/8" solid liner from 9579' to 10204' Slotted liner to 11,212' 1 J-09AL1 C -sand KOP @ 10,700' MD TD@11,217'MD 3" openhole w/ 2-3/8" 1 J -09A C -sand slotted liner TD @ 12,697' MD 2-3/8" Slotted liner %-.I _ Am KUP 1J -09A Conoco'hiliips Well Attributes Max Angle & MD TD i>Iark8.lt1C Wellbore APIJUWI Field Name Well Status ncl (o) MD (ftKB) Act Bt. (ftKB) 500292300601 KUPARUK RIVER UNIT PROD 94.79 12,375.13 Comment HTS (ppm) Date Annotation End Date KB-Grd (k) Rig Release Date . SSSV:NIPPLE 80 9/25/2011 Last WO: 38.05 3/27/2001 weuconn::.1J-09Aaonn9126:2ss3AM- Schemat__Actual Annotation Depth (ftKB) Last Tag: SeLM End Date Annotation Rev Reason: GLV C/O, PULL PLUG Last Mod ... End Date ninam 10/7/2012 HANGER, 30 Casin.. Stria ' Casing Description String 0... String ID... Top (WeI Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd CONDUCTOR 16 15.250 35.4 115.0 115.0 65.00 H-40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth if Set Depth (TVD) ... String Wt... String ... String Top Thrd - - - - - - - - -- - SURFACE 9 5/8 8.921 35.3 5,639.0 3,948.7 36.00 J-55 BTC -MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd tWINDOWAL1 PRODUCTION 7 6.276 32.2 9,197.7 6,011.2 26.00 L-80 BTC -MOD CONDUCTOR, 35-115 Casing Description String 0... String 10 ... 7 6.000 Top (ftKB) Set Depth (f... Set Depth (TVD) ... 9,608.0 9,614.0 6,229.1 String Wt... String ... String Top Third Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 8,981.0 9,807.1 6,249.2 9.30 L-80 SLHT NIPPLE. 524 Liner Details Top Depth (TVD) Topincl Nonni... Top (ftKB) (ftKB) (o) Item Description Comment ID (in) 8,981.0 5,892.6 55.16 TIEBACK TIE BACK SLEEVE 5.250 GAS LIFT, 2'922 8,988.3 5,896.8 55.30 PACKER BAKER ZXP TOP PACKER 4.438 8,995.0 5,900.7 55.42 HANGER BAKER FLEX -LOCK LINER HANGER 425.... 9,007.8 5,908.0 55.66 SBE BAKER 80-40 SBE 4.000 GAS LIFT, 5,088 9,066,6 5,940.4 56.74 NIPPLE XN NIPPLE w/2.75 NO GO 2.750 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 23/8 1.995 10,710.6 12,697.0 6,253.9 4.60 L-80 STL Motor Details Top Depth (TVD) Top incl Nonni... SURFACE, 35-5,639 Top (ftKB) (ftKB) (o) Item Description Comment ID (in) 10,710.6 6,229.1 91.44 BILLET ANCHORED BILLET 1.000 GAS LIFT, 11,461.9 6,230.7 93.46 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 6.858 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Third TUBING 31/2 2.992 29.6 9,026.5 5,918.5 9.30 L-80 EUE8RDMOD Comp] tion Details GAS LIFT, Top Depth 8,067 (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (o) Item Description Comment ID (in) 29.6 29.6 -1.10 HANGER FMC GEN V TUBING HANGER 3.500 GAS LIFT. 523.5 523.0 6.23 NIPPLE CAMCO DS NIPPLE w/ NO GO PROFILE 2.875 8,893 8,945.1 5,871.4 54.50 NIPPLE CAMCO DS NIPPLE w/ NO GO PROFILE 2.812 8,988.5 5,897.0 55.30 LOCATOR BAKER NO GO LOCATOR 3.000 8,989.8 5,897.7 55.32 SEAL ASSY BAKER GBH -22 SEAL ASSEMBLY w/MULE SHOE 3.000 NIPPLE, 8,945 F. ftier In Hole irelina retrievable plugs, valves pumps, fish etc. Top Depth (TVD) Top Incl 1 To (ftKB) (ftKB) (°I Description Comment Run Date ID (in) 9,549 6,185.7 46.83 CEMENT ILAY IN CEMENT FROM 9596 TO 9550' CTMD, TAG TOC 9/6/2012 0.000 @ 9607 RKB, 9549 SLM LOCATOR. 9,609 6,226.61 59.38 WHIPSTOCK MONOBORE WHIPSTOCK (OAL=105) 8/23/2012 0.000 8,989 Perforations & Slots SEAL ASSY, Shot 8,550 Top (TVD) Btm (TVD) Dens I Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Zone Data (sh... Type Comment 10,722 12,696 6,228.6 6,253.9 9/2872012 1 32.0 SLOTS Notes: General & Safetv 1 End Data I Annotation 1011112011 NOTE: STRIPPED FISH NECK ON OV @ 6858'. 10/5/2012 NOTE: WELL SIDETRACKED, ADDED LATERAL AL1 PRODUCTION, 32-9,198 10/5/2012 NOTE: 1J -09A COMES OFF 1J-09AL1 (See Multi-lat Drawing) CEMENT, 9,549 CEMENT, 9,550 ■ WHIPSTOCK, 9,609 WINDOW AL1, ■ 9,608-9,614 CEMENT. 9.604 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (") Make Model (in) S., Type Type (in) (psi) Run Date Com... LINER, 8,981-9,807 1 2,922.3 2,405.8 53.42 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,340.0 10/6/2012 2 5,087.7 3,627.3 54.32 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 10/5/2012 3 6,858.2 4,657.4 54.56 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 6/18/2001 See SLOTS, 10,205-11,212 note 4 8,067.3 5,362.5 54.16 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/12/2011 LINER AL1, 5 8,893.2 5,842.2 54.36 CAMCO MMG 1 V2 GAS LIFT DMY RK 0.000 0.016/1/2001 9,579-11,212 SLOTS, 10,722-12,696 LINER A, 10,711-12.697 KUP ( 1J -09A CmocoPhillips 8.1riC. • KB-Grtl (ft) Rig Release Dab Well Confi `. - iJ-09A10l7/20128'.28'S3 AM 38.05 3/27/2001 Sehematk--Acetal Annotation Depth (ftKB) End Date Last Tag: SLM 9,686.0 7/8/2012 HANGER, 30 CONDUCTOR. 35-115 NIPPLE,524 GAS LIFT, GAS LIFT, 5,088 SURFACE, 35-5,639 GAS LIFT, &858 GAS LIFT, 8,067 GAS LIFT, LOCATOR, 8,989 SEAL ASSY, 8,990 PRODUCTION, 32.9,198 CEMENT, 9,549 CEMENT, 9,550 Eml LINER, 8,981.9,807 SLOTS. 10.205-11.212 LINER AL1, 9,579-11,212 SLOTS, 10.722-12.696 LINER A. 10,711-12,697 ' 09 Pre Rig Well Work Summary DATE SUMMARY 7/7/12 PULLED UPPER 3 1/2" ER PACKER AND PATCH ASSY FROM 6843' RKB. PULLED LOWER 3 1/2" ER PACKER FROM 6873' RKB. IN PROGRESS. 7/8/12 TAGGED @ 9686' SLM, EST. 41' OF RATHOLE. CLEAN DRIFT TO 9717' RKB W/ 17' x 2.62" DUMMY WHIPSTOCK. SET 2.81" XXN PLUG @ 9066' RKB. SET 2.75" AVA CATCHER @ 9033' SLM. PULLED OV FROM 5088' RKB. IN PROGRESS. 7/9/12 FINISH LOADING TBG & IA W/ DIESEL. CMIT TBG x IA TO 2600 PSI ( PASS). SET 3/16" OV @ 5088' RKB. PULLED CATCHER AND XXN PLUG ( LOST PIECES OF PACKING) @ 9066' RKB. RAN BRUSH AND 2.62" GAUGE RING TO 9679' SLM. READY FOR E -LINE. 7/11/12 RECORD SBHP SURVEY. INITIAL 10 MIN WHP SURVEY: PRESSURE=175 PSI, TEMP=79 DEG F 30 MIN STATION @ 9620': PRESSURE=2240 PSI, TEMP=154 DEG F 15 MIN STATION @ 9425': PRESSURE=2199 PSI, TEMP=152 DEG F FINAL 10 MIN WHP SURVEY: PRESSURE=186 PSI, TEMP=64 DEG F ATTEMPTED TO RUN CALIPER LOG, COULD NOT GET ARMS TO OPEN ALL THE WAY DUE TO SAND BUILDUP IN ARM TRACKS. TAGGED PBTD @ 9724' 7/13/12 SUCCESSFULLY LOGGED 24 -ARM CALIPER FROM 9660 FT TO 8850 FT. 8/13/12 MEASURED BHP @ 9620' RKB: 2398 PSI. UNABLE TO PASS HANGER w/ 2.82 CATCHER ASSY. IN PROGRESS. 8/14/12 SET CATCHER @ 8945' RKB, PULLED OV @ 5087' RKB, PULLED GLV @ 2922' RKB, SET DVs @ 5087'& 2922' RKB, PULLED CATCHER ASSY @ 8945' RKB, COMPLETE. 8/19/12 (PRE CTD) SV, MV, SSV PASSED DDT, SV, MV, SSV PASSED PT. 8/22/12 PERFORATED 3.5" LINER AT A DEPTH OF 9590'-9599' USING A 21IX9' GUN LOADED 6 SPF, 60 DEG PHASING, BIG HOLE CIRCULATION CHARGES. WILL RETURN TOMORROW TO SET WHIPSTOCK. 8/23/12 RIH WITH A BAKER 3 1/2" Monobore Whipstock (2.63" O.D.) AND DPU SETTING TOOL. SET THE WHIPSTOCK AT A 349.8 DEG @A DEPTH OF 9609' 8/29/12 PERFORMED BOTTOM HOLE PRESSURE AND TEMPERATURE SURVEY AT DEPTHS OF 9595', 9450', AND AT SURFACE. LOGGED 24 ARM MIT CALIPER ACROSS THE WHIPSTOCK FACE TO VERIFY ORIENTATION. LOG WILL BE POST PROCESSED FOR RESULTS. 9595,:2430 PSI AND 153 DEG F. 9450': 2400 AND 151.5 DEG F 9/5/12 RIH WITH MILLING BHA, DRY TAGGED NPL AT 9050 CTMD, MILLED TO 9053' CTMD, BACK REAMED ACROSS NPL, MADE TWO VERY CLEAN DRY RUNS FROM 9000' TO 9100' CTMD, F/P TBG WITH 25 BBLS WHILE POOH, JOB IN PROGRESS 9/6/12 RIH, CIRC S/D OOH, BULLHEAD 69 BBLS 100 DEG SSW FOLLOWED BY 35 BBLS S/D, PERFORM INJECTIVITY TEST .5 BPM/1 BPM (275 BASELINE WHP), TAG WS AT 9604' CTMD, PUMP 5 BBLS FW, 5 BBLS 15.8# CMT, 10 BBLS 15.8# CMT WITH AGGREGATE, 5 BBLS 15.8# CMT, 5 BBLS FW, LAY IN CMT F/9596' CTMD T/9550' CTMD, CLOSE CHOKE, PERFS SEEM TO BE DRINKING THE CEMENT, UNABLE TO GET WHP ABOVE 330 PSI, PUH TO 9200' CTMD, WAIT 20 MINUTES, TRY TO APPLY WHP, UNABLE TO GET ABOVE 480 PSI, PUMP 2ND CEMENT JOB, 2 BBLS OF CMT OUT OF THE NZL AND PERFS LOCKED UP, PUH TO SAFETY (7000' CTMD), PERFORM HESITATION SQUEEZE TO FINAL WHP OF 1200 PSI AND HOLD FOR 1 HR, CONTAM CMT TO WS TRAY @ 9604' CTMD, CHASE OOH W/ SSW, F/P TBG TO 2500' RKB, READY FOR S/L TAG IN 72 HRS, JOB IN PROGRESS 9/12/12 UNABLE TO DRIFT PAST 6068' RKB WITH BRUSH ASS'Y. TAGGED @ EST. 9607' RKB WITH 2.5" BAILER. ATTEMPTED TEST TBG 1000 PSI. TBG CONSISTENTLY LOST 300 PSI / 10 MIN; IA NOT TRACKING. DRAWDOWN TBG TO ZERO; HELD SOLID 5 MIN. COMPLETE. 9/13/12 MIT IA 1000 PSI, PASSED. ATTEMPTED MIT TBG, FAILED. GAUGED TBG TO 2.83" TO DS NIPPLE @8945- RKB. SET 2.81" CA -2 PLUG @ 8945' RKB. TESTED TBG 1000 PSI /25 PSI, PASSED. READY FOR BPV. ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 1J-09 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 9/17/2012 3:00:00 AM Rig Release: 10/3/2012 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 9/15/2012 24 hr Summary Move rig 21:00 00:00 3.00 MIRU MOVE MOB P Wait on Peak trucks for rig move. Doyon 25 had issues with their move so trucks were delayed until 7am 9/16/2012 Moved rig from 3N-07 to 1J-09. 00:00 09:00 9.00 0 0 MIRU MOVE MOB P Wait on Peak trucks for rig move. Doyon 25 had issues with their move so trucks were delayed until 7am 09:00 18:00 9.00 0 0 MIRU MOVE MOB P Move rig to new location. Minor trenching but clear of CPF3 bad section of road. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P PJSM with Peak,Doyon, Nabors and COP for spotting up rig to 1 J-09. MIRU, NU on 1J-09. 9/17/2012 Completed NU, Performed BOP test, pumped slack management and pulled CA2 plug prong with Slickline. 00:00 03:00 3.00 0 0 MIRU MOVE NUND P Continue to rig up, Nipple up stack 03:00 04:00 1.00 0 0 MIRU WHDBO BOPE P Accepted rig @ 03:00. Start getting readv for BOP test. 04:00 07:00 3.00 0 0 MIRU WHDBO BOPE P Start BOP test @ 04:00. TEST Waived by Chuck Sheave. 07:00 15:30 8.50 0 0 MIRU WHDBO BOPE P Master Valve leaking call Valve crew to come and reservice tree. 15:30 16:30 1.00 0 0 MIRU WHDBO BOPE P PJSM - Pull BPV 16:30 17:30 1.00 0 0 MIRU WHDBO BOPE P RU to pump slack management. 17:30 19:30 2.00 0 0 SLOT WELLPF SLKL P Rig up slick line unit to pull CA2 plug. 19:30 00:00 4.50 0 0 SLOT WELLPF SLKL P Slickline completed pulling prong, working on plug body. 9/18/2012 Milled window from 9606.5'- Exit 9612'. Continue milling formation to 9631'. Three backreaming passes & dry run - clean. POOH. Mills guaged 2.79". Lost 27 bbls after window exit. 00:00 02:00 2.00 0 0 SLOT WELLPF SLKL P Pulled CA2 plug body with slickline-Complete. 02:00 04:30 2.50 0 0 SLOT WELLPF SLPC P Cut coil, MU coil connector and rehead. 04:30 07:30 3.00 0 0 PROD1 WHPST PULD P Rig up Milling BHA #1. 07:30 10:00 2.50 73 9,450 PROD1 WHPST TRIP P RIH 10:00 10:30 0.50 9,450 9,450 PROD1 WHPST DLOG P Tie in depth minus 7.5' correction 10:30 11:00 0.50 9,450 9,607 PROD1 WHPST TRIP P RIH Dry Tag TOWS 9606.5' Page 1 of 12 p i A aof -oqq pTb A 2-og3 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:00 17:00 6.00 9,607 9,611 PROD1 WHPST MILL P Start milling 1 fph, 10 LOHS, 1.75 bpm, 3239 ctp, 0 whp, 10.7 ecd, 16k ctw, 1 k wob. Started losing weight, window exit. 17:00 19:30 2.50 9,611 9,619 PROD1 WHPST MILL P Continue milling - 9611.7'- Increase to 2fph. 19:30 20:00 0.50 9,619 9,628 PROD1 WHPST MILL P Stall - P/U weight 37K. pump min. rate up through window. RIH 10 LOHS 1.5 bpm, clean drift to TD 9620'. Continue milling - 1.55 bpm, 2600, BHP 3380, WOB 1 K, CT weight 16K, ROP 12 - increase to 50 fph, samples are 98% good clean sand, 2% light cement & Glocenite. 20:00 20:30 0.50 9,628 9,631 PROD1 WHPST MILL P Stall 9628'- P/U 10ft weight 36K. Continue milling. 20:30 22:00 1.50 9,631 9,620 PROD1 WHPST REAM P Start backreaming as per procedure, very light motor work. Dry drift clean 9603' - 9620' - 10 fpm. Roughly 10 bbls losses in past 4 hours. 22:00 00:00 2.00 9,620 62 PROD1 WHPST TRIP P POOH following MPD. Bump up at surface. F- 9/19/2012 Drill build section with 2.3+AKO & hughes bit to TD of 9964'; Tie into-RA marker. Total losses = 232 bb_l/24 hours TOW= 9608' RA = 9613' BOW = 9614' 00:00 02:00 2.00 62 0 PROD1 WHPST PULD P PJSM - Undeploy BHA #1. Roughly lost 7 -9 bbls hour holding MPD. 02:00 02:30 0.50 0 0 PROD1 DRILL PULD P Make Up BHA #2 with 2.3+ AKO and bi-center bit. Service injector. 02:30 03:00 0.50 0 0 PROW DRILL SFTY P Pre-spud meeting with Maddy's crew. 03:00 04:45 1.75 0 62 PROD1 DRILL PULD P PJSM - Deploy BHA # 2 04:45 07:15 2.50 62 9,435 PROD1 DRILL TRIP P RIH pumping. 3bpm. 07:15 07:30 0.25 9,435 9,435 PROW DRILL DLOG P Tie in depth to K1 - 9.5' correction 07:30 08:00 0.50 9,600 9,631 PROD1 DRILL TRIP P Close EDC drift window with 2.3 AKO 08:00 08:30 0.50 9,600 9,600 PROD1 DRILL CIRC P Open EDC swap out milling fluid to drilling mud,. 08:30 08:36 0.10 9,600 9,631 PROD1 DRILL TRIP P Close EDC RIH to drill 08:36 08:42 0.10 9,631 9,637 PROD1 DRILL DRLG P Drill ahead 1.48 bpm, 1.35 out, 2480 ctp, 0 whp, 15k ctw, 10.7 ecd 08:42 08:57 0.25 9,637 9,600 PROD1 DRILL RGRP P PU into casing. 2 x 2 vavle SR 10 has small drip at connection. Bleed pressure and tighten. Online RBIH 08:57 11:27 2.50 9,600 9,749 PROD1 DRILL DRLG P Drill Ahead 1.4 bpm in, 1.3 out, 2545 ctp, 15k ctw, 10.7 ecd 11:27 12:42 1.25 9,749 9,756 PROD1 DRILL DRLG P Start losing .5 bpm. Drill ahead, slow ROP aciderite 12:42 13:27 0.75 9,756 9,780 PROD1 DRILL DRLG P Break thru hard formation. Returns increase. Losing .25 bpm Drill Ahead Page 2 of 12 p i A aof -oqq pTb A 2-og3 Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T Comment 13:27 13:57 0.50 9,780 9,435 PROM DRILL WPRT P Wiper trip # 1. 34k puw, PU to K1 13:57 14:12 0.25 9,435 9,435 PROM DRILL DLOG P Log K1, + 1.5' correction, RIH log RA marker TOW- 9608 RA marker - 9613.5 BOW- 9614' 14:12 14:24 0.20 9,435 9,780 PROM DRILL WPRT P RIH to drill 14:24 19:24 5.00 9,780 9,930 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm in, 1.35 out, 2630 ctp, 13k ctw, 10.7 ecd, 2.3wob, 3408 bhp 19:24 20:24 1.00 9,930 9,635 PROM DRILL WPRT P Wiper to window - P/U weight 35K. Hole looks ratty while wiping, WOB had drag & RIH CT weight was bouncing. Good cutting coming over the shakers. 9685' was the worst section. 20:24 20:54 0.50 9,930 9,965 PROM DRILL DRLG P Drilling ahead - 1.45 bpm, 2580psi, BHP 3460, ECD 10.8, ROp 120, WOB 1.8K, Ct weight 13k. rate out 1.35 bpm. IA 290 psi. Complete build section, last two serveys higher doglegs due to ratty drilling. 61 degrees. Average 50. 20:54 23:24 2.50 9,965 61 PROM DRILL TRIP P POOH pumping 1.70 bpm to see if it clean up the hole. P/U weight 35K. 23:24 00:00 0.60 61 PROD1 DRILL PULD P Space out PJSM for undeploying BHA. Undeploy. 9/20/2012 Drill A lateral. Puller through build section every 3rd wipertrip. Total Losses for _24_hours _= 188bbls ^ 00:00 02:00 2.00 62 0 PROD1 DRILL PULD P Undeploy Build BHA. Service injector found 3 sheared bolts in gripper blocks. 02:00 03:00 1.00 0 0 PROM DRILL RGRP P Replace shear screws. Replace 2 X 2 isolation valve on SR10, old cement in line as well. Re -test iron. 03:00 05:00 2.00 0 0 PROM DRILL PULD P PJSM - load BHA & deploy RSM. 05:00 08:00 3.00 68 9,435 PROM DRILL TRIP P RIH with EDC open pumping .3 bpm. 08:00 08:15 0.25 9,435 9,435 PROM DRILL DLOG P Tie in depth to K1. -11.5' correction 08:15 08:45 0.50 9,435 9,964 PROD1 DRILL TRIP P RIH to drill, ratty, slip sticking getting BHA thru build section 08:45 09:45 1.00 9,964 10,025 PROD1 DRILL DRLG P Drill ahead, 1.55 in, 1.36 out, 2668 ctp, 3470 bhp, 14k ctw. Slip sticking drilling. 09:45 14:00 4.25 10,025 10,121 PROM DRILL DRLG P Drilling smoothed out. BHA past high DLS. Cont drilling 14:00 14:15 0.25 10,121 9,980 PROD1 DRILL WPRT P Wiper trip 34K PUW 14:15 15:15 1.00 9,980 9,620 PROM DRILL DLOG P Log build section. (MADD pass) 15:15 15:45 0.50 9,620 10,121 PROD1 DRILL WPRT P RBIH to drill 15:45 19:00 3.25 10,121 10,264 PROM DRILL DRLG P Drill ahead, 1.47 in, 1.33 out, 2800 ctp, 3500 bhp, 12k ctw. 19:00 20:00 1.00 10,264 10,020 PROM DRILL WPRT P P/U weight 35K. Increase speed to 38fpm, wiped twice. Page 3 of 12 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:00 22:30 2.50 10,264 10,420 PROD1 DRILL DRLG P Drilling ahead - 1.45 bpm, 3000, BHP 3560, ECD 11.1, ROP 85, WOB 1.4K, rate out 1.41 bpm. 22:30 23:30 1.00 10,420 10,015 PROD1 DRILL WPRT P Wiper trip - P/U weight 33K. Speed 37 fpm. two short trips for B/U. 23:30 00:00 0.50 10,420 10,461 PROD1 DRILL DRLG P Drilling ahead - 1.50 bpm, 3150, BHP 3530, ROP 100, WOB 1.5K, Ct weight 13K, Rate out 1.43 bpm. D9/21/2012 Continue drilling A lateral. Pre -spud with Gary crew. 24 hour losses = 00:00 03:00 3.00 10,461 10,570 PROD1 DRILL DRLG P Drilling ahead. 10501'- tough drilling, got deflected down. Multiple P/U, then drilling. P/U 35K. 03:00 04:30 1.50 10,570 9,625 PROD1 DRILL WPRT P Wiper trip - P/U weight 33K with tie in +3ft correction. 04:30 06:30 2.00 10,570 10,610 PROD1 DRILL DRLG P Drilling_ ahead - 1.45 bpm, 2700, BHP 3580, ECD 11.2, ROP 25, WOB 1.5, Rate out 1.40 bpm. Drill slowly to get through hard spot. 06:30 08:30 2.00 10,610 10,666 PROD1 DRILL DRLG P Cont. Drilling. 1.45 bpm, 2700, BHP 3580, ECD 11.2, ROP 25, WOB 1.5, Rate out 1.40 bpm. Unable to build. attept to drill thru siderite at slower ROP's. TF continues to get kicked down. 08:30 11:30 3.00 10,666 10,692 PROD1 DRILL DRLG P Unable to build. Set Auto driller 10FPH attempt to drill up thru siderite. Surface weight Stackout. PU increase ROP to 20 FPH time drilling. Unsuccessful. 11:30 12:00 0.50 10,692 10,720 PROD1 DRILL DRLG P Increase ROP drilling ahead in attempt to drill passed siderite. Unable to build. 1.46 bpm, 2950, BHP 3605, ECD 11.4, ROP 100, WOB 2, Rate out 1.36 bpm 12:00 13:00 1.00 10,720 10,720 PROD1 DRILL WPRT P Wiper trip to 10030' keeping BHA below high DLS. 13:00 13:45 0.75 10,720 10,770 PROD1 DRILL DRLG P Drill Ahead 1.45 bpm in, 1.34 out, 3178 ctp, 10k ctw, 11.3 ecd, 3591 bhp. 13:45 14:15 0.50 10,770 10,480 PROD1 DRILL WPRT P PU 30K for geo wiper. Unable to achieve build rate to stay on plan. Discuss options with town 14:15 14:30 0.25 10,480 10,770 PROD1 DRILL WPRT P RBIH 14:30 15:45 1.25 10,770 10,870 PROD1 DRILL DRLG P Drill Ahead 1.45 bpm in, 1.34 out, 3178 ctp, 10k ctw, 11.3 ecd, 3591 bhp. Holding 90deg TF 15:45 17:15 1.50 10,870 10,870 PROD1 DRILL WPRT P Wiper trip to 10040', 34k puw 17:15 19:30 2.25 10,870 11,020 PROD1 DRILL DRLG P Drilling - 1.50 bpm, 2920, BHP 3640, ROP 70, WOB 1.6K, Ct weight 9K, Rate out 1.42 bpm 19:30 20:15 0.75 11,020 9,600 PROD1 DRILL WPRT P Wiper trip with tie in. P/U weight 35K. Bleed down IA & OA. IA = 778, OA = 588. - Took 3 minutes of bleed time for IA. IA = 390, OA = 290 - Took 1 minute bleed time for OA. Page 4 of 12 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:15 21:15 1.00 9,600 9,500 PROD1 DRILL SFTY P Pull into cased hole, Open EDC & do a safety meeting (latest alerts) & pre -spud meeting with Gary Crew. 21:15 22:30 1.25 9,500 11,020 PROD1 DRILL TRIP P Close EDC, RIH tie in +3ft. RIH to TD 22:30 00:00 1.50 11,020 11,092 PROD1 DRILL DRLG P Drilling ahead - 1.50 bpm, 3200, BHP 3670, WOB 1.1 K, ROP 99, ECD 11.5, Ct weight 12K, Rate out 1.42 bpm. 9/22/2012 Continue drilling- Mud swap with 1580ft on mud system. Increased to 4% lubes on new mud system. Pull BHA for bit inspection due to low ROP. 00:00 03:00 3.00 11,092 11,153 PROD1 DRILL DRLG P Ratty drilling, plenty of P/U to keep drilling due to weight transfer or lack of BHA movement. 03:00 04:00 1.00 11,153 11,153 PROD1 DRILL WPRT P Pulled wiper trip 15 ft early due to hard drilling. P/U weight 38K. 04:00 06:00 2.00 11,153 11,200 PROD1 DRILL DRLG P Drilling ahead - 1.45 bpm, 3200, BHP 3690, ECD 11.6, ROP 45, WOB 1 K, Ct weight 12K, rate out 1.38 bpm. Poor drilling - Bit or mud? Increase to 4% lubes for sweep. 06:00 06:30 0.50 11,200 11,225 PROD1 DRILL DRLG P Pump 15 brls low/high 4% pill. ROP increased to 100 fph. Swap out mud system increase lube properies to 4% in new active muds stem 06:30 07:30 1.00 11,225 11,254 PROD1 DRILL DRLG P Cont. drilling, 1.45 bpm, 3200, BHP 3740, ECD 11.6, ROP 70-100, WOB 1 K, Ct weight 10K, rate out 1.38 bpm. 07:30 08:00 0.50 11,254 11,254 PROD1 DRILL WPRT P Stalled PU for BHA wiper. 41 K breaks back to 34k. RBIH, Stall again, PU. RBI attempt to drill. 08:00 08:45 0.75 11,254 11,260 PROD1 DRILL DRLG P Cont. drilling, 1.43 bpm, 3200, BHP 3742, ECD 11.6, WOB 1-2K, Ct weight 9K, rate out 1.32 bpm. Start pumping new mud down 08:45 11:45 3.00 11,260 11,305 PROD1 DRILL DRLG P Drilling Ahead, 1.46 bpm, 2900, BHP 3493, ECD 11, WOB 1-2K, Ct weight 9K, rate out 1.39 bpm. Ratty drilling, stalling. New mud around, lower pressures, inhancing weight transfer. Start increasing lubes to 4% 11:45 13:00 1.25 11,305 11,305 PROD1 DRILL SFTY T LEL & H2S alarm 100ppm. Evacuate the rig, Shut down, Shut in well. Call DSO out for sniff. All good, false alarm. Found bad eletrical connection in Inner -connect (PUTZ) 13:00 15:00 2.00 11,305 9,650 PROD1 DRILL WPRT P Wiper trip to window, tie in depth to RA marker + 3.5' correction. 9757' set down weight running thru build. Did not PU. 10k set down. 15:00 17:00 2.00 11,305 11,317 PROD1 DRILL DRLG P Drill Ahead- 1.46 bpm, 2900, BHP 3742, ECD 11, WOB 1-2K, Ct weight 7-8K, rate out 1.40 bpm Page 5 of 12 Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T Comment 17:00 19:00 2.00 11,317 11,365 PROD1 DRILL DRLG P ROP dropped off to 3 FPH, nothing changed in samples. ROP's slowly decreased thru out afternoon. 19:00 19:30 0.50 11,365 11,368 PROM DRILL DRLG P ROP irratic, call CTD engineer to discuss bit trip & BHA. 100% good sand in B/U samples. Good weight transer to WOB. CT weight dropping off, Ct weight 3-5K. 19:30 00:00 4.50 11,368 68 PROM DRILL TRIP P Trip for BHA swap & inspection. Pump through Bit while POOH following MPD. 9/23/2012 Swap out worn bit, Function test BOP, POOH a second time to replace malfunctioning orienter, Drill ahead slowly, reciprocate BHA to make progress. 00:00 02:00 2.00 0 0 PROD1 DRILL PULD P Lay down RSM BHA - Bit had heavy erosion & wear. Cutters dulled on the nose & reamer. Serviced injector & replaced joystick in console. *Function test BOP's* P/U New BHA. Injected 13 bbls in past 2.5 hours 02:00 03:30 1.50 0 72 PROM DRILL PULD P PJSM - Deploy BHA # 4 with .6+ AKO and razor bi-center bit. 03:30 05:30 2.00 72 9,474 PROM DRILL TRIP P Rlh with EDC open pumping. 3bpm. 05:30 08:30 3.00 9,474 0 PROM DRILL TRIP T Orienter Failure. POOH 08:30 08:45 0.25 0 0 PROW DRILL SFTY T At Surface PJSM 08:45 11:45 3.00 0 0 PROM DRILL PULD T Undeploy BHA 4, Deploy BHA 5 11:45 13:45 2.00 0 9,480 PROM DRILL TRIP T RIH 13:45 14:00 0.25 9,480 9,480 PROM DRILL DLOG T Tie in depth -3.5' correction 14:00 15:00 1.00 9,480 11,368 PROD1 DRILL TRIP P RIH to drill 15:00 18:48 3.80 11,368 11,520 PROM DRILL DRLG P Drill Ahead 1.4 bpm, 1.3 out, 3164 ctp, 3647 bhp, 11k ctw, 1.3k wob, rop 140 fph 18:48 20:00 1.20 11,520 9,638 PROM DRILL WPRT P PUH for wiper rin to window. 20:00 20:48 0.80 9,638 11,520 PROM DRILL WPRT P RBIH 20:48 00:00 3.20 11,520 11,580 PROD1 DRILL DRLG P Drill ahead, 1.45 bpm, 1.42 bpm out, Having to work at making progress, stacking surface wt to 5k, no wt on bit, having to recip several times to drill ahead to 11580ft. 9/24/2012 _ .per trip. Total losses for 24 hours = 74 bbls Drill A lateral. Pulling through build section every 3rd wi 00:00 03:30 3.50 11,580 11,700 PROM DRILL DRLG P Drill ahead, 1.45 bpm, 1.42 bpm out, Having to work at making progress, stacking surface wt to 5k, no wt on bit, having to recip several times to drill ahead to 11700ft. 03:30 04:30 1.00 11,700 9,650 PROM DRILL WPRT P Wiper run to 9650ft 04:30 05:30 1.00 9,650 11,700 PROD1 DRILL WPRT P RBIH Page 6 of 12 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:30 11:15 5.75 11,700 11,820 PROW DRILL DRLG P Drill Ahead 1.4 bpm in, 1.33 out, 3123 ctp, 7k ctw, 1.6 wob, 3680 bhp, 0 whp 11:15 14:00 2.75 11,820 11,820 PROD1 DRILL WPRT P Wiper trip to window, tie in depth to RA marker. +6.5' correction. RBIH 14:00 18:00 4.00 11,820 11,970 PROD1 DRILL DRLG P Drill Ahead 1.6 bpm in, 1.52 out, 3848 ctp, 1-2k ctw, 1-2k wob, 3810 bhp, 0 whp 18:00 19:12 1.20 11,970 9,643 PROD1 DRILL WPRT P PUH for wiper run to 9643ft. PU wt is 35k. 19:12 20:18 1.10 9,643 11,970 PROW DRILL WPRT P RBIH from wiper run. 20:18 00:00 3.70 11,970 12,060 PROD1 DRILL WPRT P Drill ahead, 1.56 bpm, 1.46 bpm out, CT WT is 5k, 3810psi, 9/25/2012 Continued to drill A lateral to 12,326'. Swap mud, trip out of hole to pick up agitator/ new bit. Replace pulsation dampener on pump #1. Total losses to formation last 24 Hrs = 61 bbls. 00:00 02:00 2.00 12,060 12,120 PROD1 DRILL DRLG P Drill ahead, 1.56 bpm, 1.46 bpm out, CT WT is 5k, 3810psi, 02:00 03:00 1.00 12,120 9,637 PROD1 DRILL WPRT P Start Wiper trip, PU WT is 32k. 03:00 04:00 1.00 9,637 12,120 PROD1 DRILL WPRT P RBIH from wiper trip to 9637ft. 04:00 11:30 7.50 12,120 12,270 PROD1 DRILL DRLG P Drill ahead, 1.45 bpm, 1.66 bpm out, CT WT is 5k, 3650psi Note: Mud swap, started pumping new mud @ 11:00. 11:30 14:30 3.00 12,270 12,270 PROD1 DRILL WPRT P Pull wiper 36.5k off btm. Pull up a 1000' to 11270'. RBIH, spend about 30 minutes trouble shooting pump issues. 14:30 17:00 2.50 12,270 12,326 PROD1 DRILL DRLG P 3150 psi free spin 12270' drill ahead. 1.48 BPM @ 3393 psi, WOB 1.46, 3.41 coil wt, 17:00 21:18 4.30 12,326 0 PROD1 DRILL TRIP P Tooh to pick up agitator 21:18 23:00 1.70 0 0 PROD1 DRILL PULD I P At surface. Pressure undeploy BHA. 23:00 00:00 1.00 0 0 PROD1 DRILL P Rig maintenance; replace pulsation �RGRP dampener on pump #1. 9/26/2012 Ran in hole with BHA#6 w/ agitator, new bit. Continued drilling A lateral to 12,610'. Began wiper trip. 24hr fluid losses - 68 bbls. 8 00:00 0 1.50 0 0 PROD1 DRILL RGRP P Repair upper blind ram (slight hyd leak). 01:30 03:30 2.00 0 78 PROD1 DRILL PULD P Make up BHA#6; add .B+AKO motor, agitator, new 2.7" x 3" Duraforce Bit. Pressure deploy. 03:30 07:30 4.00 78 12,326 PROD1 DRILL TRIP P RIH, test agitator, good. tie in for a -3' correction. Open EDC trip in the hole. Close ECD prior to going to open hole. 07:30 13:15 5.75 12,326 12,467 PROD1 DRILL DRLG P Drill ahead @ 1.38 BPM 3511 psi. Slow stating, pull BHA wiper encounter a couple tight spots. Continue drilling. 13:15 14:45 1.50 12,467 12,467 PROD1 DRILL WPRT P Pull wiper, 45k off btm 1000' wiper. 14:45 19:45 5.00 12,467 12,540 PROD1 DRILL DRLG P Drill ahead, 1.40 BPM @ 3670 PSI, 1.51 WOB, 25 ROP, BHP 3675 PSI Page 7 of 12 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:45 00:00 4.25 12,540 12,610 PROD1 DRILL DRLG P Drill ahead, 1.40 BPM @ 3750 psi, 2.0 WOB, 19' ROP, 3714 BHP. 9/27/2012 Drilled to TD @ 12,690'. Pumped 10/10 High/Low sweep and performed wiper to surface. Ran back to bottom and la ed in liner pill in open -hole. Laying in completion fluid to surface. Lost 18 bbls brine, 54 bbls Powervis. 00:00 01:30 1.50 12,610 11,350 PROD1 DRILL WPRT P Pull up hole to 11,350' for 1260' wiper 23'/min. CT Wgt=36k, 1.43 BPM, 01:30 02:30 1.00 11,350 12,535 PROW DRILL TRIP P RBIH @ 35'. RIW swinging from -1.5K to 8K. Rate in 1.08, out 1.11 BPM, CTP=2600 psi. 02:30 03:30 1.00 12,535 9,647 PROD1 DRILL WPRT P Wgt transfer seems poor. Pump high/low sweep, turn around and chase back out of hole to window. 03:30 04:45 1.25 9,647 12,610 PROM DRILL TRIP P At window; RBI and resume drilling ahead. 04:45 10:00 5.25 12,610 12,690 PROM DRILL DRLG P Drilling ahead. 1.4 bpm @ 3892 psi. CT Wgt=6K, WOB=1.97, ROP=16'. Get call from town to call TD. 12,690' 10:00 10:45 0.75 12,690 12,690 PROD1 DRILL WPRT P Get sweep ready, pick off btm, move pipe. Time out for sweep. 10:45 15:15 4.50 12,690 78 PROD1 DRILL WPRT P AT 12690', sweep @ bit, start chasing out to surface. 15:15 17:45 2.50 78 9,550 PROW DRILL WPRT P Open EDC to avoid working a aitator. RIH to kill the well. 17:45 19:45 2.00 9,550 12,572 PROD1 DRILL WPRT P Tie in for -4.5 correction. Close EDC. Cont. RIH to TD. Set down @ 12,572'. PUH 40' and RIH. 19:45 20:30 0.75 12,572 12,697 PROW DRILL DISP P Tag TD @ 12,697' CTM, pick up off bottom and begin pumping 43 bbl liner pill @ 1.33 bpm, 3586 psi CTP. PUW=33k. 20:30 00:00 3.50 12,697 0 PROW DRILL DISP P Pill around, begin POOH laying in @ 45', cont. pumping 0.4 bpm. Flag pipe at 11378'. Open EDC once above window. Pumping 1.08 bpm, pulling 807min, Wgt 26K. Flag pipe @ 8278'. Cont OOH. 9/28/2012 Complete conditioning well, Run "A" Liner in two sections, BOL= 12,697, TOL=10710.5 Trip out, Lost 46 BBIs Completion fluid on round trip 00:00 02:00 2.00 0 0 PROD1 DRILL PULD P Close EDC. At surface. Lay down BHA 02:00 0500 3.00 0 1,279 COMPZ CASING PUTB P PJSM. Deploy 37jts 2-3/8 slotted liner (bullnose on bottom). 05:00 09:45 4.75 1,279 12,691 COMPZ CASING RUNL P RIH W/ Liner run # 1 , tie into flags.Tag BTM @ 12691'. Pick up @ 45k. Re -set liner down @ 12691'. Pump off, 35k liner] one. 09:45 11:00 1.25 12,691 9,420 COMPZ CASING TRIP P TOOK deduct liner from counter. 11:00 12:00 1.00 9,420 9,420 COMPZ CASING DLOG P tie in @ 9420' for a +11' corr. Talk with MWD & DD. decided to change out counter. 12:00 15:00 3.00 9,420 0 COMPZ CASING TRIP P TOOH 15:00 16:15 1.25 0 0 COMPZ CASING PULD P Bump up ... watch for flow. Conduct PJSM on lay down of BHA. Page 8 of 12 Time Logs Date From To Dur S. De th E, De th Phase Code Subcode T Comment 16:15 18:30 2.25 0 812 COMPZ CASING PUTS P Start picking up liner run#2. 22 jts & anchored billet., M/U to coil track and surface test tool 18:30 22:18 3.80 812 9,520 COMPZ CASINGTRIP P Trip in well, EDC closed filling accross the top 22:18 22:30 0.20 9,520 10,185 COMPZ CASING TRIP P Tie into 8700' EOP flag for -8' correction, trip into K1 tie in point 22:30 22:42 0.20 10,185 10,226 COMPZ CASING DLOG P Log tie into K1 for -.5' correction 22:42 22:48 0.10 10,226 11,462 COMPZ CASING TRIP P Tag up at 11462, PUW=38K, Orient to 20 LOHS, See tool shift @ 2700 PSI, TOL=10710, BOL=12697, PUW after release 26K 22:48 00:00 1.20 11,462 9,800 COMPZ CASING TRIP P Trip out of well, remove liner length from counters. 9800' midnight depth 9/29/2012 gmplet� trip out, R!U and test BOPE Test witnessed by Jeff Jones, AOGCC, M/U drill by BHA and RIH_ 00:00 02:36P. 50 9,800 95 COMPZ CASING TRIP P Continue trip OOH 02:30 03:30 1.00 95 0 COMPZ CASING PULD P At surface, PJSM, Flow check well, Pull BHA #8, "A" lateral upper section running tools 03:30 07:30 4.00 0 0 PROD2 DRILL BOPE P Prep for BOPE Test. 07:30 09:00 1.50 0 0 PROD2 DRILL BOPE P Bope shell test complete, state rep on the way to witness start of test. 09:00 16:00 7.00 0 0 PROD2 DRILL BOPE P State rep on location, Jeff Jones. Begin BOPE test. 16:00 18:00 2.00 0 0 PROD2 DRILL BOPE T Leak on lower blind shear ram. Conduct TGSM. Replace. 2 Hrs Billable rig repair hrs 18:00 20:00 2.00 0 0 PROD2 DRILL BOPE P Continue BOPE Test, No further failures, End of test @ 20:00, Call start of test at 11:00 for 9 hrs 20:00 20:36 0.60 0 0 PROD2 DRILL PULD P Rig down BOPE test equipment, Install UQC flapper valves, run valve check list 20:36 21:48 1.20 0 72 PROD2 STK PULD P PJSM, P/U BHA #9,.8o motor with RB Hughes Bi Center, Make up to coil track, Swap out pack offs, surface test tool 21:48 00:00 2.20 72 6,130 PROD2 STK TRIP P RIH EDC open Midnight depth 6130 9/30/2012 Kick off liner top billet @ 10711, Drill ahead to 11,159 00:00 01:06 1.10 6,130 1 9,450 PROD2 STK TRIP P Continue in hole 01:06 01:21 0.25 9,450 9,493 PROD2 STK DLOG P Log tie in, for -9.5 foot correction 01:21 01:57 0.60 9,493 9,590 PROD2 STK TRIP P Trip in to just above window 01:57 02:51 0.90 9,590 9,590 PROD2 STK CIRC P Circulate well to 8.5 PPG flow Prow 02:51 03:27 0.60 9,590 10,711 PROD2 STK TRIP P Shut down pump, Shut EDC, RIH to liner top billet, clean pass through window Page 9 of 12 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:27 08:15 4.80 10,711 10,760 PROD2 STK KOST P Dry tag Liner top billet @ 10711, PUW=36K Pumps off, Bring pumps online 1.4 BPM @ 3000 PSI FS, 1.1 BBM Out rate, TF=75° LOHS, RIW=15.6, BHP=3682, WO Choke, time mill window per recommended practice. Drill to 10760', pu 33k, pull up past billet & drift while @ min rate, qood. 08:15 11:30 3.25 10,760 10,860 PROD2 DRILL DRLG P Drill ahead 1.41 BPM 3091 PSI, 73 ROP, WOB .58, BHP 3682 PSI, 11:30 13:00 1.50 10,860 10,860 PROD2 DRILL WPRT P @ 10860', wiper to window 35k off BTM. 13:00 16:00 3.00 10,860 11,010 PROD2 DRILL DRLG P Drill ahead 1.40 @ 3239 PSI, 30 ROP, 3748 BHP, 16:00 17:42 1.70 11,010 11,010 PROD2 DRILL WPRT P wiper to 9645', 38k off BTM. 17:42 18:42 1.00 11,010 11,042 PROD2 DRILL DRLG P 1101_0', Drill ahead, 1.4 BPM @3300 PSI FS, BHP=3797, Losses - 5 BPH, WO Choke 18:42 18:48 0.10 11,042 11,042 PROD2 DRILL WPRT P BHA Wiper, PUW=39K, Stacking, Low RIW, Low Diff pressure 18:48 22:06 3.30 11,042 11,159 PROD2 DRILL DRLG P 11042', Drill Ahead, 1.37 BPM @ 3250 PSI FS, BHP=3747, try 30 BBI sweep new mud to improve drilling performance, little change 22:06 23:12 1.10 11,159 9,630 PROD2 DRILL WPRT P Wiper to window with tie in, PUW 39K, Saw overpull at 10,800, Slight overpull @ billet 10710', -4 DHWOB. 23:12 23:24 0.20 9,630 9,661 PROD2 DRILL DLOG P Log RA Marker for -3.5' 23:24 00:00 0.60 9,661 10,890 PROD2 DRILL WPRT P Continue wiper trip to bottom Midnight Depth 10890 10/01/2012 TD Al Lateral @ 11217, Condition _Hole, Kill Well, P/U Liner 00:00 00:18 0.30 10,890 11,153 PROD2 DRILL WPRT P Continue wiper trip to bottom 00:18 02:12 1.90 11,153 11,180 PROD2 DRILL DRLG P Tagged up early, 1.37 BPM @ 3160 PSI FS, BHP=3760, RIW=11K, Ratty drilling and stalls. 02:12 03:00 0.80 11,180 11,199 PROD2 DRILL DRLG P Tough drilling with poor weight transfer, surface weight --2 to -5K, pump 30 BBI pill of new mud. Gained 8K surface weight able to transfer to bit after 3 BBIs out of bit. ROP up to 60-80 FPH brief) 03:00 03:12 0.20 11,199 11,199 PROD2 DRILL WPRT P Perform BHA Wiper, PUW=35K, prepping for full mud system swap 0312 06:45 3.55 11,199 11,224 PROD2 DRILL DRLG P Back on bottom drilling, New mud going down 06:45 07:15 0.50 11,224 10,200 PROD2 DRILL WPRT P 11,224. Pull wiper, discuss drilling options. 07:15 10:30 3.25 10,200 72 PROD2 DRILL WPRT P Decided to call TD, wiper to the swab. re -set counters. 10:30 14:45 4.25 72 11,217 PROD2 DRILL TRIP P TIH, tie in to K-1. -12.5 correction. Tag BTM @ 11217' Page 10 of 12 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:45 18:45 4.00 11,217 72 PROD2 DRILL TRIP P @ 11217' start laying in 10.7 KWF bead pill, 30 bbls. Continue laying in 10.7 KWF to surface. 18:45 20:30 1.75 72 0 COMPZ CASING PULD P Bump up. watch for flow while conducting prejob. LD drilling BHA. Bit has some broken teeth and balled up with debris. Service injector. Prep to pu liner. 20:30 23:30 3.00 0 1,677 COMPZ CASING PUTB P Conduct pre -job, pick-up liner, Non Ported bullnose, 30 Jts slotted, 20 As blank CSH 511, Shorty deployment sleeve 23:30 00:00 0.50 1,677 2,434 COMPZ CASINGTRIP P RIH W/ AL1 Liner Midnight Depth 2434 10/02/2012 Run Completion in AL1 lateral down to 11217'. RU SL run gauge ring down to 8063'. 00:00 02:24 2.40 2,434 9,477 COMPZ CASING RUNL P Continue in well with Al Liner, EDC -- Closed 02:24 02:30 0.10 9,477 10,826 COMPZ CASING RUNL P Correct to 7800' EOP flag -9.4', Continue in well 02:30 03:00 0.50 10,826 10,826 COMPZ CASING RUNL P Set down @ 10826, Start working pipe to bottom 03:00 04:06 1.10 10,826 11,212 COMPZ CASING RUNL P Working pipe to bottom, -6K to +60K, Hit hard 3 times @ 11212, unable get liner any further, Pumps on and release form liner, PUW=35K, PUH 20', remove liner length from counters 04:06 05:36 1.50 11,212 9,548 COMPZ CASING CIRC P Swap well to seawater 05:36 08:06 2.50 9,548 54 COMPZ CASINGTRIP P POOH following recovery of 10.7 PPG brine from well 08:06 09:36 1.50 54 0 COMPZ CASING PULD P Tag up, PJSM PUD BHA #10 Liner running tools 09:36 12:36 3.00 0 0 DEMOB WHDBO SLKL P PJSM - Prep rig floor for slick line, Bring WL lubricator to floor R/U slickline to set downhole plug 12:36 15:06 2.50 0 8,063 DEMOB WHDBO SLKL T RIH with 2.85 gauge ring, Set down 8067'. Unable to work past, 15:06 16:36 1.50 8,063 0 DEMOB WHDBO SLKL T POOH to reconfig toolstring. At surface PSJM - Swap out W/L valve. Configure 16' roller stem M/U 2.81" dummy CA Plug 16:36 19:06 2.50 0 8,937 DEMOB WHDBO SLKL T Trip in well - w/Dummy Plug Drift made it to 8945' (8937' SL Depth). 19:06 20:36 1.50 8,937 0 DEMOB WHDBO SLKL T POOH to reconfig toolstring. 20:36 23:06 2.50 0 8,937 DEMOB WHDBO SLKL T RIH with CA2-Plug can't get it to set due to sluggish tool movement. 23:06 00:00 0.90 8,937 0 DEMOB WHDBO SLKL T POOH and check HES tools. Looks like paraffin on tools. Retrieved sample off of tools and put in ambient diesel. Seamed to desperse wtih the diesel. Discuss options with town. RU to brush and flush downto nipple at 8945' (8937' SL Depth). 10/03/2012 Set CA Plug @ 8945 after Brush and flush, RDMO to 2F-11 Page 11 of 12 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 01:30 1.50 0 8,945 DEMOB WHDBO SLKL T RIH with SL to brush and flush. PJSM - RU and PT Little Red. Bull Head 83 bbls of 150 degree diesel. Brush and Flush down to profile at 8945' j 93T SL d_e th . 01:30 02:30 1.00 8,945 0 DEMOB WHDBO SLKL T POOH - to retry the CA2-Plug 02:30 04:00 1.50 0 8,945 DEMOB WHDBO SLKL T RIH with the second attemp to set CA2-Plu on SL. 04:00 05:00 1.00 8,945 0 DEMOB WHDBO SLKL P Set CA2-Plug, POOH 05:00 06:30 1.50 0 0 DEMOB WHDBO SLKL P PT CA2-Plug to 2500psi, No Communication with IA on PT PJSM - RD SL and Little Red. 06:30 09:00 2.50 0 0 DEMOB WHDBO NUND P Set BPV. Unable to get first BPV to set. Get another BPV to location, Unable to get that one to set, confer with town. DH plug set and PT'd. Move forward without BPV 09:00 12:00 3.00 0 0 DEMOB MOVE MOB P Inhibit coil, blow down coil, stack, and rig. RDMO ***Rig Release 12:00*** Page 12 of 12 1 1-09 Post Rig Well Work Summary DATE SUMMARY 10/2/12 *** CDR2 RIG JOB *** DRIFTED TBG TO DS NIPPLE @ 8945' RKB WITH 2.81" DUMMY CA -2 PLUG. ATTEMPTED SET 2.81" CA -2 PLUG @ SAME, UNSUCCESSFUL. BRUSHED & FLUSHED TBG TO DS NIPPLE. SET 2.81" CA -2 PLUG @ 8945' RKB. TESTED TBG 2500 PSI, GOOD. R/D SLICKLINE. _-_ -- - _ 10/3/12 Set CA Plug @ 8945 after Brush and flush, RDMO to 2F-11 10/5/12 SET CATCHER ON PLUG @ 8945' RKB. MITIA 3000 PSI PASSED._ MITT 3.000_PSI PASSFQ. PULLED DV @ 5087' RKB, SET 3/16" OV @ SAME. ATTEMPTED PULL BV @ 2922' RKB, UNABLE TO LATCH. RAN LIBs: OBSTRUCTION ABOVE DV. IN PROGRESS. 10/6/12 PULLED DV @ 2922' RKB. BRUSH POCKET & SET DV @ SAME. TESTED TBG 2000 PSI, GOOD. PULLED CATCHER. PULLED CA -2 PLUG @ 8945' RKB. MEASURED BHP (p 9500' RKB: 2478 PSI. COMPLETE. ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1J Pad fi IDT -1l Baker Hughes INTEQ Definitive Survey Report 02 October, 2012 Few a I BAKER HUGHES ConocoPhillips Baker Hughes INTEQ F/ jS Definitive Survey Report BAIM UN GHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 11-09� e Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Well: Wellbore: 1J-09 11-09 North Reference: True Survey Calculation Method: Minimum Curvature Design: 11-09 Database: EDM Alaska Prod v16 Project Kuparuk River Unit i 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 11-09 Well Position +N/-S 0.00 ft Northing: 5,945,963.35ft Latitude: 70° 15'46.700 N +E/-W 0.00 ft Easting: 558,634.61 ft Longitude: 149° 31'33.517 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1J-09A _ v, Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I V) (nT) BGGM2011 9/1/2012 16.22 79.91 57,377 Design 1J-09A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,521.69 Vertical Section: Depth From (TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 170.00 Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 196.10 9,521.69 11-09 (11-09) MWD+IFR-AK-SCC MWD+IFR AK SCC Sperry 4/9/2001 9,608.00 12,646.49 1 J-09A (1 J-09A) MWD MWD- Standard 9/19/2012 9/28/2012 10/212012 10:54:17AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips Alaska Baker Hughes INTEQ Definitive Survey Report HUI BAKER Company: Conoco Phillips(Alaska) Inc. Local Co-ordinate Reference: 11-09 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) TVDSS Well: 1J-09 North Reference: True Map Wellbore: 11-09 Survey Calculation Method: Minimum Curvature Design: 1J-09 Database: EDM Alaska Prod v16 (ft) Survey MD Inc Azi TVDSS TVD +N/ -S +E[ -W Map Map DLS Vertical ft 1) t°) , 1 )' (ft) Ift) {ft) Ift) Northing Easting t) (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 9,521.69 59.31 343.91 6,066.90 6,066.90 6,413.96 -2,014.51 5,952,36D.82 556,570.42 0.86 -6,666.34 MWD (2) TIP 9,608.00 59.17 344.86 6,111.04 6,111.04 6,485.39 -2,034.47 5,952,432.08 556,549.90 0.96 -6,740.15 MWD (2) KOP 9,630.68 63.91 342.06 6,121.85 6,121.85 6,504.50 -2,040.15 5,952,451.14 556,544.07 23.55 -6,759.95 MWD (2) 9,660.55 77.85 339.12 6,131.61 6,131.61 6,531.03 -2,049.54 5,952,477.60 556,534.48 47.58 -6,787.71 MWD (2) 9,675.46 84.80 337.74 6,133.86 6,133.86 6,544.73 -2,054.95 5,952,491.25 556,528.95 47.50 -6,802.14 MWD (2) 9,700.50 90.92 333.33 6,134.79 6,134.79 6,567.49 -2,065.31 5,952,513.93 556,518.42 30.11 -6,826.35 MWD (2) 9,730.41 89.88 317.50 6,134.58 6,134.58 6,592.04 -2,082.24 5,952,538.34 556,501.31 53.04 -6,853.46 MWD (2) 9,760.43 90.98 303.65 6,134.36 6,134.36 6,611.51 -2,104.98 5,952,557.64 556,478.41 46.28 -6,875.60 MWD (2) 9,785.27 89.72 290.87 6,134.20 6,134.20 6,622.87 -2,127.02 5,952,568.82 556,456.29 51.70 -6,891.60 MWD (2) 9,810.10 90.74 278.62 6,134.10 6,1.34.10 6,629.17 -2,150.98 5,952,574.94 556,432.28 49.51 -6,901.98 MWD (2) 9,840.50 90.12 261.88 6,133.87 6,133.87 6,629.31 -2,181.27 5,952,574.83 556,401.99 55.10 -6,907.37 MWD (2) 9,870.47 92.30 246.41 6,133.24 6,133.24 6,621.15 -2,210.01 5,952,566.45 556,373.33 52.11 -6,904.32 MWD (2) 9,900.68 89.23 227.48 6,132.83 6,132.83 6,604.75 -2,235.21 5,952,549.86 556,348.26 63.47 -6,892.54 MWD (2) 9,930.57 90.25 209.28 6,132.97 6,132.97 6,581.41 -2,253.69 5,952,526.38 556,329.96 60.98 -6,872.78 MWD (2) 9,960.57 91.63 190.80 6,132.47 6,132.47 6,553.36 -2,263.92 5,952,498.25 556,319.95 61.76 -6,846.92 MWD (2) 9,990.46 90.83 186.14 6,131.83 6,131.83 6,523.81 -2,268.32 5,952,468.67 556,315.78 15.81 -6,818.59 MWD (2) 10,025.13 91.75 184.03 6,131.05 6,131.05 6,489.29 -2,271.39 5,952,434.13 556,312.98 6.64 -6,785.12 MWD (2) 10,055.46 90.61 181.23 6,130.42 6,130.42 6,459.00 -2,272.78 5,952,403.83 556,311.82 9.97 -6,755.54 MWD (2) 10,085.13 91.14 179.44 6,129.97 6,129.97 6,429.33 -2,272.96 5,952,374.17 556,311.88 6.29 -6,726.35 MWD (2) 10,115.47 93.96 180.50 6,128.62 6,128.62 6,399.03 -2,272.94 5,952,343.87 556,312.13 9.93 -6,696.50 MWD (2) 10,145.33 92.21 179.15 6,127.01 6,127.01 6,369.21 -2,272.85 5,952,314.06 556,312.45 7.40 -6,667.13 MWD (2) 10,175.14 91.97 176.75 6,125.93 6,125.93 6,339.44 -2,271.78 5,952,284.30 556,313.75 8.09 -6,637.62 MWD (2) 10,205.67 91.99 175.26 6,124.87 6,124.87 6,309.01 -2,269.66 5,952,253.89 556,316.11 4.88 -6,607.28 MWD (2) 10,230.07 91.50 173.47 6,124.13 6,124.13 6,284.74 -2,267.26 5,952,229.64 556,318.70 7.60 -6,582.96 MWD (2) 10,260.49 91.96 172.25 6,123.21 6,123.21 6,254.57 -2,263.48 5,952,199.50 556,322.71 4.28 -6,552.60 MWD (2). 10,290.51 92.27 171.80 6,122.10 6,122.10 6,224.86 -2,259.32 5,952,169.83 556,327.10 1.82 -6,522.62 MWD (2) 10,320.73 90.61 169.77 6,121.34 6,121.34 6,195.04 -2,254.48 5,952,140.05 556,332.17 8.68 -6,492.41 MWD (2) 10,350.68 91.17 167.63 6,120.88 6,120.88 6,165.68 -2,248.62 5,952,110.74 556,338.27 7.38 -6,462.47 MWD (2) 10,380.54 91.47 165.94 6,120.19 6,120.19 6,136.62 -2,241.79 5,952,081.73 556,345.32 5.75 -6,432.67 MWD (2) 10,410.23 92.46 164.29 6,119.17 6,119.17 6,107.94 -2,234.17 5,952,053.12 556,353.16 6.48 -6,403.11 MWD (2) 10/2/2012 10:54:17AM Page 3 COMPASS 2003.16 Build 69 p ConocoPhillips Alaska Baker Hughes INTEQ Definitive Survey Report Azi Merl BAKER RES Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 11-09 Map Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Well: 11-09 North Reference: True Northing Wellbore: 11-09 Survey Calculation Method: Minimum Curvature Survey Tool Name Annotation Design: 11-09 Database: EDM Alaska Prod v16 Survey MD Inc Azi TVDSS TVD +N1 -S +EI -W Map Map DLS Vertical ft (ft) (ft) Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 10,440.72 91.50 163.42 6,118.12 6,118.12 6,078.67 -2,225.70 5,952,023.92 556,361.86 4.25 -6,372.81 MWD (2) 10,470.20 91.66 162.58 6,117.31 6,117.31 6,050.49 -2,217.08 5,951,995.81 556,370.70 2.90 -6,343.56 MWD (2) 10,500.70 91.84 160.47 6,116.37 6,115.37 6,021.58 -2,207.42 5,951,966.98 556,380.58 6.94 6,313.41 MWD (2) 10,530.48 89.66 158.47 6,115.98 6,115.98 5,993.69 -2,196.98 5,951,939.18 556,391.24 9.93 -6,284.14 MWD (2) 10,560.50 91.72 156.90 6,115.62 6,115.62 5,965.73 -2,186.07 5,951,911.30 556,402.36 7.01 -6,254.70 MWD (2) 10,590.34 91.84 158.09 6,114.70 6,114.70 5,937.98 -2,175.14 5,951,883.64 556,413.51 2.74 -6.,225.48 MWD (2) 10,620.15 90.15 156.47 6,114.18 6,114.16 5,910.49 -2,163.63 5,951,856.25 556,425.24 7.85 -6,196.41 MWD (2) 10,650.10 90.71 155.91 6,113.95 6,113.95 5,883.09 -2,151.53 5,951,828.94 556,437.54 2.64 -6,167.32 MWD (2) 10,680.73 91.07 155.95 6,113.48 6,113.48 5,855.13 -2,139.04 5,951,801.08 556,450.25 1.18 -6,137.62 MWD (2) 10,710.49 89.82 155.09 6,113.25 6,113.25 5,828.04 -2,126.71 5,951,774.10 556,462.79 5.10 -6,108.80 MWD (2) 10,740.49 90.15 154.89 6,113.25 6,113.25 5,800.86 -2,114.03 5,951,747.01 556,475.68 1.29 -6,079.83 MWD (2) 10,770.49 88.86 152.96 6,113.51 6,113.51 5,773.91 -2,100.84 5,951,720.18 556,489.07 7.74 -6,051.00 MWD (2) 10,800.79 90.06 155.13 6,113.80 6,113.80 5,746.67 -2,067.58 5,951,693.04 556,502.54 8.18 -6,021.87 MWD (2) 10,830.76 89.32 156.96 6,113.96 6,113.96 5,719.29 -2,075.42 5,951,665.75 556,514.92 6.59 -5,992.79 MWD (2) 10,860.68 89.97 158.71 6,114.15 6,114.15 5,691.56 -2,064.13 5,951,638.14 556,526.42 6.24 -5,963.54 MWD (2) 10,890.74 89.88 160.10 6,114.19 6,114.19 5,663.44 -2,053.56 5,951,610.08 556,537.21 4.63 -5,934.00 MWD (2) 10,920.34 89.97 161.56 6,114.22 6,114.22 5,635.46 -2,043.84 5,951,582.21 556,547.15 4.94 -5,904.76 MWD (2) 10,950.30 90.09 163.02 6,114.21 6,114.21 5,606.94 -2,034.72 5,951,553.74 556,556.49 4.89 -5,875.09 MWD (2) 10,980.00 89.69 163.65 6,114.27 6,114.27 5,578.49 -2,026.21 5,951,525.36 556,565.22 2.51 -5,845.59 MWD (2) 11,010.55 90.25 164.19 6,114.28 6,114.28 5,549.14 -2,017.74 5,951,496.07 556,573.91 2.55 -5,815.21 MWD (2) 11,040.48 90.09 165.08 6,114.19 6,114.19 5,520.28 -2,009.81 5,951,467.28 556,582.07 3.02 -5,785.41 MWD (2) 11,070.36 90.34 166.80 6,114.06 6,114.08 5,491.29 -2,002.56 5,951,438.36 556,589.55 5.62 -5,755.61 MWD (2) 11,100.40 90.95 166.08 6,113.74 6,113.74 5,461.97 -1,996.02 5,951,409.09 556,596.31 4.72 -5,725.60 MWD (2) 11,130.01 91.13 167.71 6,113.21 6,113.21 5,433.03 -1,989.81 5,951,380.20 556,602.74 1.39 -5,696.02 MWD (2) 11,160.29 90.03 167.29 6,112.90 6,112.90 5,403.47 -1,983.26 5,951,350.69 556,609.52 3.89 -5,665.77 MWD (2) 11,190.35 90.15 166.85 6,112.85 6,112.65 5,374.17 -1,976.54 5,951,321.45 556,616.48 1.52 -5,635.75 MWD (2) 11,220.62 90.00 166.79 6,112.81 6,112.81 5,344.70 -1,969.63 5,951,292.04 556,623.61 0.53 -5,605.52 MWD (2) 11,250.05 90.55 164.83 6,112.67 6,112.67 5,316.17 -1,962.42 5,951,263.56 556,631.04 6.92 -5,576.17 MWD (2) 11,280.07 90.43 166.15 6,112.41 6,112.41 5,287.11 -1,954.90 5,951,234.57 556,638.79 4.42 -5,546.25 MWD (2) 11,310.32 88.65 165.34 6,112.66 6,112.66 5,257.79 -1,947.45 5,951,205.31 556,646.47 6.46 -5,516.06 MWD (2) 11,335.04 69.23 165.50 6,113.11 6,113.11 5,233.87 -1,941.23 5,951,181.44 556,652.87 2.43 -5,491.45 MWD (2) 10/2/2012 10:54:17AM Page 4 COMPASS 2003.16 Build 69 10/2/2012 10:54.17AM Page 5 COMPASS 2003.16 Build 69 Baker Hughes INTEQ MA ill ConocoPhillips BAKER Definitive Survey Report HUGHES UGNES Company: ConocoPhill ips(Alaska) Inc. Local Co-ordinate Reference: 11-09 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Well: 11-09 North Reference: True Wellbore: 11-09 Survey Calculation Method: Minimum Curvature Design: 1J-09 Database: EDM Alaska Prod v16 Survey ... MD Inc Azi TVDSS TVD +N/-S +El-W Map Map DLS Vertical ft (ft) (ft) (ft) (ft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 11,367.09 86.96 163.98 6,114.18 6,114.18 5,202.97 -1,932.80 5,951,150.61 556,661.54 8.52 -5,459.55 MWD (2) I 11,395.73 87.82 161.72 6,115.48 6,115.48 5,175.63 -1,924.36 5,951,123.35 556,670.19 8.44 -5,431.17 MWD (2) 11,425.86 91.10 161.32 6,115.77 6,115.77 5,147.06 -1,914.81 5,951,094.85 556,679.96 10.97 -5,401.37 MWD (2) 11,455.11 91.35 158.38 6,115.14 6,115.14 5,119.61 -1,904.74 5,951,067.48 556,690.24 10.09 -5,372.59 MWD (2) 11,466.79 92.21 155.25 6,114.16 6,114.16 5,090.51 -1,892.28 5,951,038.48 556,702.93 10.24 -5,341.76 MWD (2) 11,515.35 90.77 151.76 6,113.41 6,113.41 5,064.96 -1,879.54 5,951,013.04 556,715.87 13.22 -5,314.39 MWD (2) 11,545.30 90.83 148.95 6,113.00 6,113.00 5,038.94 -1,864.73 5,950,987.13 556,730.88 9.38 -5,286.19 MWD (2) 11,575.24 87.79 144.63 6,113.36 6,113.36 5,013.90 -1,848.34 5,950,962.22 556,747.46 17.64 -5,258.69 MWD (2) 11,605.29 88.59 142.05 6,114.31 6,114.31 4,989.81 -1,830.41 5,950,938.27 556,765.58 8.98 -5,231.85 MWD (2) 11,635.34 89.23 144.39 6,114.88 6,114.88 4,965.74 -1,812.42 5,950,914.35 556,783.75 8.07 -5,205.03 MWD (2) 11,665.10 86.77 147.27 6,115.40 6,115.40 4,941.13 -1,795.71 5,950,689.87 556,800.65 9.80 -5,177.88 MWD (2) 11,695.25 88.65 149.96 6,116.08 6,116.08 4,915.40 -1,780.01 5,950,864.27 556,816.55 8.93 -5,149.82 MWD (2) 11,725.25 88.96 154.01 6,116.70 6,116.70 4,888.93 -1,765.93 5,950,837.91 556,830.64 13.54 -5,121.30 MWD (2) 11,755.32 89.23 158.32 6,117.18 6,117.18 4,861.43 -1,753.78 5,950,810.51 556,843.20 14.36 -5,092.11 MWD (2) 11,787.42 88.49 164.19 6,117.82 6,117.82 4,831.05 -1,743.47 5,950,780.22 556,853.74 18.43 -5,060.41 MWD (2) 11,815.82 87.02 165.37 6,118.93 6,118.93 4,803.67 -1,736.02 5,950,752.90 556,861.40 6.64 -5,032.15 MWD (2) g 11,845.12 6 85.80 168.13 6,120.76 6,120.76 4,775.21 -1,729.32 5,950,724.49 556,868.32 10.28 -5,002.96 MWD (2) 11,674.65 86.96 172.10 6,122.63 6,122.63 4,746.18 -1,724.26 5,950,695.51 556,873.61 13.98 -4,973.49 MWD (2) 11,906.84 88.47 176.49 6,123.91 6,123.91 4,714.19 -1,721.07 5,950,663.54 556,877.05 14.41 4,941.43 MWD (2) 11,936.40 88.71 179.21 6,124.64 6,124.64 4,684.66 -1,719.96 5,950,634.02 556,878.39 9.23 4,912.16 MWD (2) _ 11,965.72 88.56 184.58 6,125.34 6,125.34 4,655.37 -1,720.93 5,950,604.74 556,877.65 18.32 4,883.48 MWD (2) 11,995.59 89.85 186.05 6,125.75 6,125.75 4,625.64 -1,723.69 5,950,574.98 556,875.11 6.55 4,854.68 MWD (2) 12,030.52 88.50 194.76 6,126.26 6,126.26 4,591.32 -1,730.00 5,950,540.62 556,869.08 25.23 -4,821.96 MWD (2) 12,061.89 86.01 196.70 6,127.76 6,127.76 4,561.16 -1,736.49 5,950,510.40 556,860.82 10.06 -4,793.75 MWD (2) I 12,090.39 87.82 195.35 6,129.29 6,129.29 4,533.81 -1,746.34 5,950,482.99 556,853.18 7.92 14,768.18 MWD (2) 12,115.03 87.61 193.13 6,130.28 6,130.28 4,509.95 -1,752.40 5,950,459.08 556,847.31 9.04 4,745.73 MWD (2) 6 12,147.17 85.77 189.66 6,132.13 6,132.13 4,478.50 -1,758.74 5,950,427.59 556,841.22 12.20 11,715.86 MWD (2) 12,175.16 84.23 187.31 6,134.57 6,134.57 4,450.92 -1,762.85 5,950,399.99 556,837.32 10.01 4,689.42 MWD (2) 12,200.30 85.15 185.06 6,136.90 6,136.90 4,426.04 -1,765.55 5,950,375.08 556,834.82 9.63 4,665.38 MWD (2) g 12,230.15 8 85.36 184.07 6,139.37 6,139.37 4,396.39 -1,767.92 5,950,345.42 556,832.68 3.36 4,636.59 MWD (2) 12,260.35 87.36 182.67 6,141.29 6,141.29 4,366.30 -1,769.69 5,950,315.32 556,831.15 B.08 4,607.27 MWD (2) 10/2/2012 10:54.17AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips Alaska Baker Hughes INTEQ Definitive Survey Report Azi Company: Conoco Phill ips(Alaska) Inc. Local Co-ordinate Reference: 11-09 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (lJ-09:115.05) Well: 11-09 North Reference: True Wellbore: 11-09 Survey Calculation Method: Minimum Curvature Design: 11-09 Database: EDM Alaska Prod v16 Survey ri.s BAKER HUGHES MD Inc Azi T TVD +(ft) * Map Map Vertical (ft) (ft) (ft) (ft) (ft) t) Northing Easting 100DLS (°1100') Section Survey Tool Name Annotation' y (ft) (ft) (ft) 12,265.16 89.60 182.20 6,141.94 6,141.94 4,341.53 -1,770.74 5,950,290.54 556,830.29 9.23 -4,583.05 MWD (2) 12,315.65 91.01 179.60 6,141.78 6,141.78 4,311.04 -1,771.22 5,950,260.06 556,830.04 9.70 -4,553.12 MWD (2) 12,345.09 94.42 179.21 6,140.39 6,140.39 4,281.64 -1,770.92 5,950,230.66 556,830.58 11.66 -4,524.11 MWD (2) 12,375.12 94.79 176.86 6,137.98 5,137.98 4,251.73 -1,769.89 5,950,200.76 556,831.84 7.90 4,494.47 MWD (2) 12,405.09 91.90 173.57 6,136.23 6,136.23 4,221.92 -1,767.39 5,950,170.98 556,834.57 14.60 4,464.69 MWD (2) 12,430.16 87.94 170.06 6,136.26 6,136.26 4,197.12 -1,763.83 5,950,146.20 556,838.33 21.11 4,439.64 MWD (2) 12,455.13 87.48 165.71 6,137.26 6,137.26 4,172.73 -1,758.59 5,950,121.86 556,843.75 17.50 4,414.71 MWD (2) 12,486.70 89.45 162.47 6,138.11 6,138.11 4,142.38 -1,749.94 5,950,091.58 556,852.63 12.01 -4,383.33 MWD (2) 12,515.32 90.12 158.97 6,138.21 6,138.21 4,115.37 -1,740.49 5,950,064.65 556,862.29 12.45 4,355.08 MWD (2) 12,545.22 91.56 155.07 6,137.78 6,137.78 4,087.85 -1,728.82 5,950,037.23 556,874.17 13.90 4,325.96 MWD (2) 12,575.12 90.28 149.07 6,137.30 6,137.30 4,061.45 -1,714.83 5,950,010.94 556,888.37 20.52 4,297.53 MWD (2) 12,605.27 88.66 144.31 6,137.52 6,137.52 4,036.27 -1,698.28 5,949,985.86 556,905.12 16.47 -4,269.65 MWD (2) 12,635.16 69.05 141.57 6,138.07 6,138.07 4,012.40 -1,680.25 5,949,962.16 556,923.32 9.18 -4,243.22 MWD (2) 12,646.49 89.26 140.79 6,138.23 6,138.23 4,003.59 -1,673.17 5,949,953.41 556,930.48 7.14 -4,233.31 MWD (2) 12,697.00 __.................... 89.26 140.79 6,138.89 6,138.89 3,964.46 -1,641.24 5,949,914.53 556,962.71 0.00 -4,189.23 PROJECTED to TD 10/212012 10:54:17AM Page 6 COMPASS 2003.16 Build 69 we W -- 'A as BAKER Date: HUGHES To: Letter of Transmittal October 2, 2012 OCT 0 3 2012 Christine Mahnken AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Carl Ulrich / Sachin Gandra Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1J -09A •� i `� 93 1J-09AL1 vto (2) 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 ret rn ` Sachin Gandra, Baker Hughes, Project Engineer Sachin. Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Cul.Ulrich@ BakerHughes.com 2-,Z-d=t3 ConocoPhillips RECEIVED Alaska 0 CE a ,AOGCC ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1J Pad IJ -09A Baker Hughes INTEQ FewF& I Definitive Survey Report N �NES 02 October, 2012 ConocoPhillips Baker Hughes INTEQ W>,as Definitive Survey Report HUGHES Adaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 11-09 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Well: 11-09 North Reference: Wellbore: 11-09 Survey Calculation Method: Minimum Curvature Design: 11-09 Database: EDM Alaska Prod v16 Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 11-09 Well Position +N/-S 0.00 ft Northing: 5,945,963.35ft Latitude: 70° 15'46.700 N +E/-W 0.00 ft Easting: 558,634.61 ft Longitude: 149° 31'33.517 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1J-09A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (1) (nT) BGGM2011 9/1/2012 16.22 79.91 57,377 Design 1J-09A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,521.69 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) V) 0.00 0.00 0.00 170.00 Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 196.10 9,521.69 11-09 (11-09) MWD+IFR-AK-SCC MWD+IFR AK SCC Sperry 4/9/2001 9,608.00 12,646.49 1J-09A(1J-09A) MWD MWD- Standard 9/19/2012 9/28/2012 10/212012 10:54:17AM Page 2 COMPASS 2003.16 Build 69 Baker Hughes INTEQ /GFAI ConocoPhillips BAKER Definitive Survey Report HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 11-09 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (lJ-09:115.05) Well: 1J-09 North Reference: Wellbore: 1J-09 Survey Calculation Method: Minimum Curvature Design: 11-09 Database: EDM Alaska Prod v16 Survey MD Inc Azi TVDSS TVD +N/ -S +E/ -W Map Map DLS Vertical () (') (') (ft) (ft) O O Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 9,521.69 59.31 343.91 6,066.90 6,066.90 6,413.96 -2,014.51 5,952,360.82 556,570.42 0.86 -6,666.34 MWD (2) TIP 9,608.00 59.17 344.86 6,111.04 6,111.04 6,485.39 2,034.47 5,952,432.08 556,549.90 0.96 -6,740.15 MWD (2) KOP 9,630.68 63.91 342.06 6,121.85 6,121.85 6,504.50 -2,040.15 5,952,451.14 556,544.07 23.55 -6,759.95 MWD (2) 9,660.55 77.65 339.12 6,131.61 6,131.61 6,531.03 2,049.54 5,952,477.60 556,534.48 47.58 -6,787.71 MWD (2) 9,675.46 84.80 337.74 6,133.86 6,133.86 6,544.73 -2,054.95 5,952,491.25 556,528.95 47.50 -6,802.14 MWD (2) 9,700.50 90.92 333.33 6,134.79 6,134.79 6,567.49 -2,065.31 5,952,513.93 556,518.42 30.11 -6,826.35 MWD (2) 9,730.41 89.88 317.50 6,134.58 6,134.58 6,592.04 -2,082.24 5,952,538.34 556,501.31 53.04 -6,853.46 MWD (2) 9,760.43 90.98 303.65 6,134.36 6,134.36 6,611.51 -2,104.98 5,952,557.64 556,478.41 46.28 -6,876.60 MWD (2) 9,785.27 89.72 290.87 6,134.20 6,134.20 6,622.87 -2,127.02 5,952,568.82 556,456.29 51.70 -6,891.60 MWD (2) 9,810.10 90.74 278.62 6,134.10 6,134.10 6,629.17 -2,150.98 5,952,574.94 556,432.28 49.51 -6,901.98 MWD (2) 9,840.50 90.12 261.88 6,133.87 6,133.87 6,629.31 -2,181.27 5,952,574.83 556,401.99 55.10 -6,907.37 MWD (2) 9,870.47 92.30 246.41 6,133.24 6,133.24 6,621.15 -2,210.01 5,952,566.45 556,373.33 52.11 -6,904.32 MWD (2) 9,900.68 89.23 227.48 6,132.83 6,132.83 6,604.75 -2,235.21 5,952,549.86 556,348.26 63.47 -6,892.54 MWD (2) 9,930.57 90.25 209.28 6,132.97 6,132.97 6,581.41 -2,253.69 5,952,526.38 556,329.96 60.98 -6,872.78 MWD (2) 9,960.57 91.63 190.80 6,132.47 6,132.47 6,553.36 -2,263.92 5,952,498.25 556,319.95 61.76 -6,846.92 MWD (2) 9,990.46 90.83 186.14 6,131.83 6,131.83 6,523.81 -2,268.32 5,952,468.67 556,315.78 15.81 -6,818.59 MWD (2) 10,025.13 91.75 184.03 6,131.05 6,131.05 6,489.29 -2,271.39 5,952,434.13 556,312.98 6.64 -6,785.12 MWD (2) 10,055.46 90.61 181.23 6,130.42 6,130.42 6,459.00 -2,272.78 5,952,403.83 556,311.82 9.97 -6,755.54 MWD (2) 10,085.13 91.14 179.44 6,129.97 6,129.97 6,429.33 -2,272.96 5,952,374.17 556,311.88 6.29 -6,726.35 MWD (2) 10,115.47 93.96 180.50 6,128.62 6,128.62 6,399.03 -2,272.94 5,952,343.87 556,312.13 9.93 -6,696.50 MWD (2) 10,145.33. 92.21 179.15 6,127.01 6,127.01 6,369.21 -2,272.85 5,952,314.06 556,312.45 7.40 -6,667.13 MWD (2) 10,175.14 91.97 176.75 6,125.93 6,125.93 6,339.44 -2,271.78 5,952,284.30 556,313.75 8.09 -6,637.62 MWD (2) 10,205.67 91.99 175.26 6,124.87 6,124.87 6,309.01 -2,269.66 5,952,253.89 556,316.11 4.88 -6,607.28 MWD (2) 10,230.07 91.50 173.47 6,124.13 6,124.13 6,284.74 -2,267.26 5,952,229.64 556,318.70 7.60 -6,582.96 MWD (2) 10,260.49 91.96 172.25 6,123.21 6,123.21 6,254.57 -2,263.48 5,952,199.50 556,322.71 4.28 -6,552.60 MWD (2) 10,290.51 92.27 171.80 6,122.10 6,122.10 6,224.86 -2,259.32 5,952,169.83 556,327.10 1.82 -6,522.62 MWD (2) 10,320.73 90.61 169.77 6,121.34 6,121.34 6,195.04 -2,254.48 5,952,140.05 556,332.17 8.68 -6,492.41 MWD (2) 10,350.68 91.17 167.63 6,120.88 6,120.88 6,165.68 -2,248.62 5,952,110.74 556,338.27 7.38 -6,462.47 MWD (2) 10,380.54 91.47 165.94 6,120.19 6,120.19 6,136.62 -2,241.79 5,952,081.73 556,345.32 5.75 -6,432.67 MWD (2) 10,410.23 92.46 164.29 6,119.17 6,119.17 6,107.94 -2,234.17 5,952,053.12 556,353.16 6.48 -6,403.11 MWD (2) 10/212012 10.54:17AM Page 3 COMPASS 2003.16 Build 69 Baker Hughes INTEQ ConocoPhillips B� AeAI Definitive Survelaskay Report NVER GMS Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 11-09 Project: Kuparuk River Unit ND Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft(1J-09:115.05) Well: 1J-09 North Reference: Wellbore: 1J-09 Survey Calculation Method: Minimum Curvature Design: 1J-09 Database: EDM Alaska Prod v16 Survey MD Inc Azi NDSS TVD +N/-S +E/-W Map Map DLS Vertical' ()Northing i) (°) (ft) (ft) (% (ft) Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) () 10,440.72 91.50 163.42 6,118.12 6,118.12 6,078.67 -2,225.70 5,952,023.92 556,361.86 4.25 -6,372.81 MWD (2) 10,470.20 91.66 162.58 6,117.31 6,117.31 6,050.49 -2,217.08 5,951,995.81 556,370.70 2.90 6,343.56 MWD (2) 10,500.70 91.84 160.47 6,116.37 6,116.37 6,021.58 -2,207.42 5,951,966.98 556,380.58 6.94 -6,313.41 MWD (2) 10,530.48 89.66 158.47 6,115.98 6,115.98 5,993.69 -2,196.98 5,951,939.18 556,391.24 9.93 -6,284.14 MWD (2) 10,560.50 91.72 158.90 6,115.62 6,115.62 5,965.73 -2,186.07 5,951,911.30 556,402.36 7.01 -6,254.70 MWD (2) 10,590.34 91.84 158.09 6,114.70 6,114.70 5,937.98 -2,175.14 5,951,883.64 556,413.51 2.74 -6,225.48 MWD (2) 10,620.15 90.15 156.47 6,114.18 6,114.18 5,910.49 -2,163.63 5,951,856.25 556,425.24 7.85 -6,196.41 MWD (2) 10,650.10 90.71 155.91 6,113.95 6,113.95 5,883.09 -2,151.53 5,951,828.94 556,437.54 2.64 -6,167.32 MWD (2) 10,680.73 91.07 155.95 6,113.48 6,113.48 5,855.13 -2,139.04 5,951,801.08 556,450.25 1.18 -6,137.62 MWD (2) 10,710.49 89.82 155.09 6,113.25 6,113.25 5,828.04 -2,126.71 5,951,774.10 556,462.79 5.10 -6,108.80 MWD (2) 10,740.49 90.15 154.89 6,113.25 6,113.25 5,800.86 -2,114.03 5,951,747.01 556,475.68 1.29 -6,079.83 MWD (2) 10,770.49 88.86 152.96 6,113.51 6,113.51 5,773.91 -2,100.84 5,951,720.18 556,489.07 7.74 -6,051.00 MWD (2) 10,800.79 90.06 155.13 6,113.80 6,113.80 5,746.67 -2,087.58 5,951,693.04 556,502.54 8.18 -6,021.87 MWD (2) 10,830.76 69.32 156.96 6,113.96 6,113.96 5,719.29 -2,075.42 5,951,665.75 556,514.92 6.59 -5,992.79 MWD (2) 10,860.68 89.97 158.71 6,114.15 6,114.15 5,691.58 -2,064.13 5,951,638.14 556,526.42 6.24 -5,963.54 MWD (2) 10,890.74 89.88 160.10 6,114.19 6,114.19 5,663.44 -2,053.56 5,951,610.08 556,537.21 4.63 -5,934.00 MWD (2) 10,920.34 89.97 161.56 6,114.22 6,114.22 5,635.48 -2,043.84 5,951,582.21 556,547.15 4.94 -5,904.78 MWD (2) 4 10,950.30 90.09 163.02 6,114.21 6,114.21 5,606.94 -2,034.72 5,951,553.74 556,556.49 4.89 -5,875.09 MWD (2) 10,980.00 89.69 163.65 6,114.27 6,114.27 5,578.49 -2,026.21 5,951,525.36 556,565.22 2.51 -5,845.59 MWD (2) 11,010.55 90.25 164.19 6,114.28 6,114.28 5,549.14 -2,017.74 5,951,496.07 556,573.91 2.55 -5,815.21 MWD (2) 11,040.48 90.09 165.08 6,114.19 6,114.19 5,520.28 -2,009.81 5,951,467.28 556,582.07 3.02 -5,785.41 MWD (2) 11,070.36 90.34 166.80 6,114.08 6,114.08 5,491.29 -2,002.56 5,951,438.36 556,589.55 5.82 -5,755.61 MWD (2) 11,100.40 90.95 168.08 6,113.74 6,113.74 5,461.97 -1,996.02 5,951,409.09 556,596.31 4.72 -5,725.60 MWD (2) 11,130.01 91.13 167.71 6,113.21 6,113.21 5,433.03 -1,989.81 5,951,380.20 556,602.74 1.39 -5,696.02 MWD (2) 11,160.29 90.03 167.29 6,112.90 6,112.90 5,403.47 -1,983.26 5,951,350.69 556,609.52 3.89 -5,665.77 MWD (2) 11,190.35 90.15 166.85 6,112.85 6,112.85 5,374.17 -1,976.54 5,951,321.45 556,616.48 1.52 -5,635.75 MWD (2) 11,220.62 90.00 166.79 6,112.81 6,112.81 5,344.70 -1,969.63 5,951,292.04 556,623.61 0.53 -5,605.52 MWD (2) 11,250.05 90.55 164.83 6,112.67 6,112.67 5,316.17 -1,962.42 5,951,263.56 556,631.04 6.92 -5,576.17 MWD (2) 11,280.07 90.43 166.15 6,112.41 6,112.41 5,287.11 -1,954.90 5,951,234.57 556,638.79 4.42 -5,546.25 MWD (2) 11,310.32 88.65 165.34 6,112.66 6,112.66 5,257.79 -1,947.45 5,951,205.31 556,646.47 6.46 -5,516.08 MWD (2) 11,335.04 89.23 165.50 6,113.11 6,113.11 5,233.87 -1,941.23 5,951,181.44 556,652.87 2.43 -5,491.45 MWD (2) 10/2/2012 10:54 17AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillip Alaskaa Baker Hughes INTEQ Definitive Survey Repoli Azi Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1J-09 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Well: 11-09 North Reference: (ft) Wellbore: 1J-09 Survey Calculation Method: Minimum Curvature Design: 1J-09 Database: EDM Alaska Prod v16 Survey MD .Inc Azi TVDSS TVD +N/ -S +E/ -W Map Map DLS Vertical (ft) (°) (,) (ft) (ft) (ft) (ft) Northing Easting (°I100') Section Survey Tool Name (ft) (ft) (ft) 11,367.09 86.96 163.98 6,114.18 6,114.18 5,202.97 -1,932.80 5,951,150.61 556,661.54 8.52 -5,459.55 MWD (2) 11,395.73 87.82 161.72 6,115.48 6,115.48 5,175.63 -1,924.36 5,951,123.35 556,670.19 8.44 -5,431.17 MWD (2) 11,425.86 91.10 161.32 6,115.77 6,115.77 5,147.06 -1,914.81 5,951,094.85 556,679.96 10.97 -5,401.37 MWD (2) 11,455.11 91.35 158.38 6,115.14 6,115.14 5,119.61 -1,904.74 5,951,067.48 556,690.24 10.09 5,372.59 MWD (2) 11,486.79 92.21 155.25 6,114.16 6,114.16 5,090.51 -1,892.28 5,951,038.48 556,702.93 10.24 5,341.76 MWD (2) 11,515.35 90.77 151.76 6,113.41 6,113.41 5,064.96 -1,879.54 5,951,013.04 556,715.87 13.22 -5,314.39 MWD (2) 11,545.30 90.83 148.95 6,113.00 6,113.00 5,038.94 -1,864.73 5,950,987.13 556,730.88 9.38 -5,286.19 MWD (2) 11,575.24 87.79 144.63 6,113.36 6,113.36 5,013.90 -1,848.34 5,950,962.22 556,747.46 17.64 5,258.69 MWD (2) 11,605.29 88.59 142.05 6,114.31 6,114.31 4,989.81 -1,830.41 5,950,938.27 556,765.58 8.98 -5,231.85 MWD (2) 11,635.34 89.23 144.39 6,114.88 6,114.88 4,965.74 -1,812.42 5,950,914.35 556,783.75 8.07 -5,205.03 MWD (2) 11,665.10 88.77 147.27 6,115.40 6,115.40 4,941.13 -1,795.71 5,950,889.87 556,800.65 9.80 -5,177.88 MWD (2) 11,695.25 88.65 149.96 6,116.08 6,116.08 4,915.40 -1,780.01 5,950,864.27 556,816.55 8.93 -5,149.82 MWD (2) 11,725.25 88.96 154.01 6,116.70 6,116.70 4,888.93 -1,765.93 5,950,837.91 556,830.84 13.54 -5,121.30 MWD (2) 11,755.32 89.23 158.32 6,117.18 6,117.18 4,861.43 -1,753.78 5,950,810.51 556,843.20 14.36 -5,092.11 MWD (2) 11,787.42 88.49 164.19 6,117.82 6,117.82 4,831.05 -1,743.47 5,950,780.22 556,853.74 18.43 -5,060.41 MWD (2) 11,815.82 87.02 165.37 6,118.93 6,118.93 4,803.67 -1,736.02 5,950,752.90 556,861.40 6.64 -5,032.15 MWD (2) 11,845.12 85.80 168.13 6,120.76 6,120.76 4,775.21 -1,729.32 5,950,724.49 556,868.32 10.28 -5,002.96 MWD (2) 11,874.65 86.96 172.10 6,122.63 6,122.63 4,746.18 -1,724.26 5,950,695.51 556,873.61 13.98 -4,973.49 MWD (2) 11,906.84 88.47 176.49 6,123.91 6,123.91 4,714.19 -1,721.07 5,950,663.54 556,877.05 14.41 -4,941.43 MWD (2) 11,936.40 88.71 179.21 6,124.64 6,124.64 4,664.66 -1,719.96 5,950,634.02 556,878.39 9.23 -4,912.16 MWD (2) 11,965.72 88.56 184.58 6,125.34 6,125.34 4,655.37 -1,720.93 5,950,604.74 556,877.65 18.32 -4,883.48 MWD (2) 11,995.59 89.85 186.05 6,125.75 6,125.75 4,625.64 -1,723.69 5,950,574.98 556,875.11 6.55 -4,854.68 MWD (2) 12,030.52 88.50 194.76 6,126.26 6,126.26 4,591.32 -1,730.00 5,950,540.62 556,869.08 25.23 -4,821.98 MWD (2) 12,061.89 86.01 196.70 6,127.76 6,127.76 4,561.16 -1,738.49 5,950,510.40 556,860.82 10.06 -4,793.75 MWD (2) 12,090.39 87.82 195.35 6,129.29 6,129.29 4,533.81 1,746.34 5,950,482.99 556,853.18 7.92 -4,768.18 MWD (2) 12,115.03 87.61 193.13 6,130.28 6,130.28 4,509.95 -1,752.40 5,950,459.08 556,847.31 9.04 -4,745.73 MWD (2) 12,147.17 85.77 189.66 6,132.13 6,132.13 4,478.50 -1,758.74 5,950,427.59 556,841.22 12.20 x,715.86 MWD (2) 12,175.16 84.23 187.31 6,134.57 6,134.57 4,450.92 -1,762.85 5,950,399.99 556,837.32 10.01 -4,689.42 MWD (2) 12,200.30 85.15 185.06 6,136.90 6,136.90 4,426.04 -1,765.55 5,950,375.08 556,834.82 9.63 -4,665.38 MWD (2) 12,230.15 85.36 184.07 6,139.37 6,139.37 4,396.39 -1,767.92 5,950,345.42 556,832.68 3.38 x,636.59 MWD (2) 12,260.35 87.36 18267 6141.29 6,141.29 4,366.30 -1,769.69 5,950,315.32 556,831.15 8.08 -4,607.27 MWD (2) 101212012 10:54:17AM Page 5 riFAI HUGHES Annotation COMPASS 2003.16 Build 69 ConocoPhillip Alaskaa Baker Hughes INTEQ Definitive Survey Report Azj Company: Conoco Phillips(Alaska) Inc. Local Co-ordinate Reference: 11-09 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Well: 1J-09 North Reference: (ft) Wellbore: 1J-09 Survey Calculation Method: Minimum Curvature Design: 11-09 Database: EDM Alaska Prod v16 Survey MD Inc Azj TVDSS TVD +N/ -S +E/ -W Map Map DLS Vertical (ft) (°) (°) (ft) (ft) (ft) (ft) Northing Northing Easting Survey Tool Name (ft) (ft)) (ft)Section 12,285.16 f 89.60 182.20 6,141.94 6,141.94 4,341.53 1,770.74 5,950,290.54 556,830.29 9.23 -4,583.05 MWD (2) 12,315.65 91.01 179.60 6,141.78 6,141.78 4,311.04 -1,771.22 5,950,260.06 556,830.04 9.70 -4,553.12 MWD (2) 12,345.09 94.42 179.21 6,140.39 6,140.39 4,281.64 -1,770.92 5,950,230.66 556,830.58 11.66 -4,524.11 MWD (2) 12,375.12 94.79 176.86 6,137.98 6,137.98 4,251.73 -1,769.89 5,950,200.76 556,831.84 7.90 -4,494.47 MWD (2) ?' 12,405.09 91.90 173.57 6,136.23 6,136.23 4,221.92 -1,767.39 5,950,170.98 556,834.57 14.60 -4,464.69 MWD (2) 12,430.16 87.94 170.06 6,136.26 6,136.26 4,197.12 -1,763.83 5,950,146.20 556,838.33 21.11 -4,439.64 MWD (2) 12,455.13 87.48 165.71 6,137.26 6,137.26 4,172.73 -1,758.59 5,950,121.86 556,843.75 17.50 -4,414.71 MWD (2) 12,486.70 69.45 162.47 6,138.11 6,138.11 4,142.38 -1,749.94 5,950,091.58 556,852.63 12.01 -4,383.33 MWD (2) 12,515.32 90.12 158.97 6,138.21 6,138.21 4,115.37 -1,740.49 5,950,064.65 556,862.29 12.45 -4,355.08 MWD (2) 12,545.22 91.56 155.07 6,137.78 6,137.78 4,087.85 -1,728.82 5,950,037.23 556,874.17 13.90 -4,325.96 MWD (2) 12,575.12 90.28 149.07 6,137.30 6,137.30 4,061.45 -1,714.83 5,950,010.94 556,888.37 20.52 4,297.53 MWD (2) 12,605.27 88.86 144.31 6,137.52 6,137.52 4,036.27 -1,698.26 5,949,985.88 556,905.12 16.47 -4,269.85 MWD (2) 12,635.18 89.05 141.57 6,138.07 6,138.07 4,012.40 -1,680.25 5,949,962.16 556,923.32 9.18 -4,243.22 MWD (2) 12,646.49 89.26 140.79 6,138.23 6,138.23 4,003.59 -1,673.17 5,949,953.41 556,930.48 7.14 -4,233.31 MWD (2) 12,697.00 i 89.26 140.79 6,138.89 6,138.89 3,964.46 -1,641.24 5,949,914.53 556,962.71 0.00 -4,189.23 PROJECTED to TO Annotation FIRA.11 HUGHES 10/212012 10:54:17AM Page 6 COMPASS 2003.16 Build 69 HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 1 �ConocoPhillips Alaska, Inc. NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 CD rte` - FINAL (digital / BAKER PRINT DISTRIBUTION LIST HUGHES LOGS image) COMPANY ConocoPhillips, Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) # Or HKIN 16 # OF COPIES WELL NAME 1J -09A RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods, Jim - (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: September 28, 2012 TODAYS DATE: 10/24/2012 (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 1 �ConocoPhillips Alaska, Inc. 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 ;A Anchorage, Alaska 99501 J 3 BP 1 1 Petrotechnical Data Center, MB33 David Douglas 900 East Benson Blvd Anchoraee, 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 µ TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 CD FIELD FINAL (digital / LOGS LOGS image) FILM # OF PRINTS # Or HKIN 16 # OF COPIES # OF COPIES 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave, Suite 100 ;A Anchorage, Alaska 99501 J 3 BP 1 1 Petrotechnical Data Center, MB33 David Douglas 900 East Benson Blvd Anchoraee, 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 µ TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 1 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave, Suite 100 ;A Anchorage, Alaska 99501 J 3 BP 1 1 Petrotechnical Data Center, MB33 David Douglas 900 East Benson Blvd Anchoraee, 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 µ TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS � A 3 W. 7th AVENUE, SUITE 100 KA 99501-3539 CONSERVATION COMMISSION PHONE (907) 279-1433 FAX (907) 276-7542 L. Gantt CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1J -09A ConocoPhillips Alaska, Inc. Permit No: 212-093 Surface Location: 2152' FSL, 2574' FEL, SEC. 35, T1 IN, R10E, UM Bottomhole Location: 895' FSL, 1062' FWL, SEC. 26, T11N, R1OE, 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, 6thy . Foerster Chair _Iq DATED this day of July, 2012. cc: Department of Fish 8s Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 12 2012 PERMIT TO DRILL gOGCC 20 AAC 25.005 1 a. Type of Work: Drill ❑ Re -drill El Re-entry ❑ 1 b. Proposed Well Class: Development - Oil ❑ -Service - Winj ❑ Single Zone ❑✓ Stratigraphic Test ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ✓ Blanket Lj Single Well Bond No. " 59-52-180 11. Well Name and Number: 1J -09A - 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12700' ' TVDSS: 6134' • 12. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 2152' FSL, 2574' FEL, Sec. 35, T11 N, R10E, UM Top of Productive Horizon: 1929' FNL, 681' FWL, Sec. 26, T11N, R10E, UM Total Depth: 895' FSL, 1062' FWL, Sec. 26, T11 N, R10E, UM 7. Property Designation (Lease Number): ADL 25661, 0 P 1 `- 8. Land Use Permit: 471,468 13. Approximate Spud Date: 7/28/2012 9. Acres in Property: 2560 14. Distance to Nearest Property: 11450 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 558635- y- 5945963 . Zone- 4 10. KB Elevation above MSL: 115 feet GL Elevation above MSL: 35 feet 15. Distance to Nearest Well Open to Same Pool: 1 E-34, 1950' 16. Deviated wells: Kickoff depth: 9605 ft. Maximum Hole Angle: 93° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2749 psig Surface: 2124 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS(including stage data Y 2.375" 4.7# L-80 ST -L 3105' 9595' 6104' 12700' 6134' slotted liner 19 1 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) 9850' 6350' Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 9739' 6293 Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 460 sx AS 1 115' 115' Surface 5604' 9.625" 653 sx AS Lite, 340 sx LiteC RETE 5639' 3949' Intermediate Production 9166' 7" 184 sx Class G 9198' 6011' Liner 826' 3.5" 196 sx Class G 9807' 6328' Perforation Depth MD (ft): 9604'-9676' Perforation Depth TVD (ft): 6224'-6261' 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: \\\ 22. 1 hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 S `JCZ Printed Name L anti Title CTD Supervisor Signature _ Phon 263-4021 Date Commission Use Only Permit to DrillAPI 1-2- Number: Number: 50- � L _C/ - -;7__ ',�- Permit ApprovaV Date: I See cover letter for other requirements Conditions of approval : If box is checked, well ma not be used to explore for, test, or produce coalbed �mmiiethane, gas hydrates, or gas contained in shales: 3 Sic -7<z�L�%. Samples req'd: Yes ❑ No LJ Mud log req'd: Yes ❑ No Rl Other: 1-12S measures: Yes Fv No ❑ Directional svy req'd: Yes [t No ❑ 246 APPRO ED BY THE COMMISSION �J ( DATE: G �(� t L� - COMMISSIONE Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date•of approval (20 AA 25.005(g)) 7©Tj6ubmit io.P % ca �' ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 10, 2012 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVE® JUL 12 NQ A®CCC ConocoPhillips Alaska, Inc. hereby submits a Permit to Drill (PTD) application to drill and complete 1J -09A from Kuparuk well 1J-09 (PTD# 201-044). Because of scheduling uncertainty, coiled tubing drilling (CTD) operations may begin as early as July 28, 2012 using the Nabors CDR2-AC rig. . The objective of the CTD sidetrack is to improve Kuparuk C sand sweep efficiency and oil recovery within the target pattern. A sundry application is included to plug the existing KRU 1J-09 perforations in preparation for the CTD sidetrack. Once CTD operations are completed then a 10-407 will be submitted to classify the 1J-09 completion as 'Abandoned'. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the perfs in this manner. 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 J -09A — Directional plans for 1 J -09A — Current wellbore schematic — Proposed wellbore schematic — 10-403 to plug the 1J-09 completion with cement — Summary of CTD operations for the 10-403 If you have any questions or require additional information please contact me at my office 907-263-4172. Sin ely, J. Ga Eller Co 0i co�hillips Alas a Coilea" bing Drill g Engineer Kuparuk CTD Sidetrack NABORS ALASKA 1 J -09A CD -49,1 Application for Permit to Drill Document 2AC 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) 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................................................................... 3 (Requirements of 20 AAC 25.005(c)(5))................................................................................................................................................. 3 6. Casing and Cementing Program................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))................................................................................................................................................. 3 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).............................................................. 6 (Requirements of 20 AAC 25.402)......................................................................................................................................................... 6 17. Attachments.................................................................................................................................... 6 Attachment 1: Directional Plans for 1 J-09A.................................................................................................................... 6 Attachment 2: Current Well Schematic for 1J-09........................................................................................................... 6 Attachment 3: Proposed Well Schematic for 1J-09A..................................................................................................... 6 Page 1 of 6 ;lI G t d r July 11, 2012 PTD Application for KRU 1J -09A 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed sidetrack described in this document is KRU 1J -09A. 1J -09A will be a sidetrack from the 1J-09 motherbore that will be classified as a "Development- Oif' well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This sidetrack will target the C sand in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 1J -09A sidetrack. 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 3500 psi. Using a maximum potential formation pressure of 2749 psi, the maximum potential surface pressure is 2124 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 most recent static BHP eas�rement in well 1J-09 was taken in April 2011 recording a pressure of 2129 psi at 9590' MD, 6217' TVD for P 6.6 p g gradient. We plan to obtain an updated static pressure survey prior to squeezing the C sand perfs. T roposed 1 J -09A sidetrack will likely encounter slightly increasing formation pressure as the sidetrack is drilled, although C sand formation pressure in the area is down due to several offset injectors being shut-in for an extended period. Maximum potential formation pressure is based on the February 2010 pressure measurement from 1 D-07 to the north, which had measured formation pressure of 2714 psi at 7988' MD, 6146' TVD for a gradient of 8.5 ppg. In 1J -09A this equates to a maximum potential formation pressure of 2749 psi (9605' MD, 6226' TVD) and a maximum potential surface pressure of 2124 psi assuming a gas gradient to surface. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled, but we will be drilling in an area that has had significant volume of miscible gas injected, so it is likely that an influx will yield significant quantities of gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected downhole risk in the 1J -09A sidetrack is lost circulation due to low formation pressure and thief zones. In anticipation of drilling 1J -09A we have increased injection into offset injection wells in order to build formation pressure, and if necessary we will drill ahead with seawater to keep up with losses. Use of the managed pressure drilling (MPD) technique reduces the risk of a well control event from lost circulation because primary well control is provided by the surface stripper and choke. Other— Tubing x IA Communication via Gas Lift Mandrel at 6858' MD During CTD operations the tubing patch that is isolating the washed-out gas lift mandrel at 6858' MD must be pulled, allowing continuous communication of the tubing to the inner annulus (IA). The well has alread passed a combination MIT which confirms integrity of the 7" casing, packer, and tubing head. Prior to moving the Nabors CDR2 rig on or off of 1J-09, we will perform a drawdown test on a mechanical downhole barrier (i.e. either a cement plug or mechanical plug) in addition to the back pressure valve which we routinely set. During CTD operations we will routinely monitor the annulus pressure, and when CTD operations are complete the patch will be reset to restore the well to production. Page 2 of 6 July 11, 2012 GAS r PTD Application for KRU U -09A 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 J -09A sidetrack 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)) New Completion Details Sidetrack Liner Liner Liner Liner Top MD Name Top MD Btm Top Btm Liner Details 16" 62 MD SSTVD SSTVD 115' 1J -09A 9595' 12,700' 6104' 6135' 2'/", 4.7#, L-80, ST -L slotted liner with 36 J-55 BTC -Mod 0' 5639' deployment sleeve inside 3'/2" liner Existing Casing/Liner Information Category OD Weight f Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62 H-40 Welded 0' 115' 0' 115' Surface 95/8" 36 J-55 BTC -Mod 0' 5639' 0' 3949' 3520 2020 Casing 7" 26 L-80 BTC -Mod 0' 9198' 0' 6011' 7240 5410 Liner 3'/2" 9.3 L-80 SLHT 8995' 9807' 5901' 6328' 10,160 10,530 Tubing 3%" 9.3 L-80 EUE 8rd-Mod 0' 8990' 0' 5898' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system Y is required. 8. Drilling Fluids Program (Requirements of 20 AAC 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 (-9.0 ppg) J — Drilling operations: Chloride -based Flo -Pro Flo Vis mud (9.0 ppg). This mud weight is expected to hydrostatically overbalance formation pressure in the entire 1J -09A sidetrack. Even if elevated formation pressure is encountered, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 1J-09 does not contains a subsurface safety valve, so the liner will be ✓' deployed after loading the well with 12.0 ppg sodium bromide completion fluid to over -balance formation pressure. — Emergency Kill Weight fluid: Two well bore volumes (-220 bbl) of 12.0 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Page 3 of 6 July 11, 2012 PTD Application for KRU U -09A 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 1 J-09 sidetrack 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. Pressure at the 1J -09A Window (9605' MD, 6225' TVD, 6110' SSTVD) 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 1J-09 is an existing Kuparuk C -sand producer. The 1J -09A sidetrack will increase reservoir exposure and improve waterflood sweep. The existing C -sand perfs will be squeezed with cement in preparation for the CTD sidetrack to help minimize losses while drilling. A separate sundry request is being submitted for the abandonment of the original 1J-09 completion in preparation for this CTD sidetrack. The planned plugging of the 1J-09 completion requires a variance from the plugging requirement of 20 AAC 25.112(c)(1). d1 - The 1 J -09A sidetrack will exit the 3'/2" liner at 9605' MD off of a mechanical whipstock and will target the C sand south of the existing well with a 3095' sidetrack. The hole will be completed with a 23/" slotted liner to the TD of 12,700' MD with the final liner top located inside the 3%" liner at 9595' MD. Page 4 of 6 t t.. July 11, 2012 Pumps On 1.5 bpm) Pumps Off Ex ected A -sand Formation Pressure 7.5 2428 psi 2428 psi Mud Hydrostatic 9.0 2913 psi 2913 psi Annular friction i.e. ECD, 0.095psi/ft) 912 psi 0 psi Mud + ECD Combined 3825 psi 2913 psi (no choke pressure) (overbalanced (overbalanced 1400psi) -480psi) Target BHP at Window 11.8 3820 psi 3820 psi Choke Pressure Required to Maintain Target BHP 0 psi 910 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 1J-09 is an existing Kuparuk C -sand producer. The 1J -09A sidetrack will increase reservoir exposure and improve waterflood sweep. The existing C -sand perfs will be squeezed with cement in preparation for the CTD sidetrack to help minimize losses while drilling. A separate sundry request is being submitted for the abandonment of the original 1J-09 completion in preparation for this CTD sidetrack. The planned plugging of the 1J-09 completion requires a variance from the plugging requirement of 20 AAC 25.112(c)(1). d1 - The 1 J -09A sidetrack will exit the 3'/2" liner at 9605' MD off of a mechanical whipstock and will target the C sand south of the existing well with a 3095' sidetrack. The hole will be completed with a 23/" slotted liner to the TD of 12,700' MD with the final liner top located inside the 3%" liner at 9595' MD. Page 4 of 6 t t.. July 11, 2012 PTD Application for KRU U -09A Pre -CTD Work 1. RU slickline. Pull patch isolating the washed-out GLM at 6858'. 2. RU e -line. Caliper 3'/2" liner and tubing. Get updated static BHP survey. 3. Run dummy whipstock to 9650' 4. Set 3%" monobore whipstock at 9605' MD. RDMO a -line. 5. MIRU coiled tubing. Mill out the XN-nipple at 9066' MD to 2.80" ID. 6. Cement squeeze the C -sand perfs at 9604'-9676'. Cleanout excess cement down to the top of the whipstock at 9605' MD. 7. Drift and tag cement. Drawdown test cement plug. If the drawdown test fails, set a mechanical plug in the DS nipple at 8945'.A 8. Prep site for Nabors CDR2-AC, including setting BPV (4/� Rig Work A. 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 J -09A Sidetrack (C sand, south) a. Mill 2.80" window through 3'/" liner at 9605' MD b. Drill 2.70" x 3" bi-center sidetrack to TD of 12,700' MD c. Run 23/" slotted liner from TD up to 9595' MD, inside the 3%2" liner. Will use 12.0 ppg brine to over -balance formation pressure while picking up slotted liner. 3. Set plug in DS nipple at 8945' MD. 4. Freeze protect. Set BPV, ND BOPE. 5. RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV and plug at 8945' MD. Install gas lift design. 2. Perform static BHP survey 3. Re -install patch isolating the washed out GLM at 6858' 4. Put 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. - 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. Page 5 of 6 July 11, 2012 PTD Application for KRU 1J -09A Liner Running , - Since 1J-09 is not equipped with a SSSV, the well will need to be displaced to an over -balancing fluid prior to running liner. We plan to use 12.0 ppg sodium bromide completion fluid for this purpose. See the "Drilling Fluids" section for more details. — While running 23/" slotted liner, a joint of 2%" 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 23/" pipe rams provide secondary well control while running 2%" 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 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 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 sidetrack. — 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. 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for these sidetrack since they are intended to serve as producers. 17. Attachments Attachment 1: Directional Plans for 1J -09A Attachment 2: Current Well Schematic for 1J-09 Attachment 3: Proposed Well Schematic for 1J -09A Page 6 of 6 July 11, 2012 Distance Distance to Sidetrack Directional to Unit Nearest Name Plan Boundary Well Nearest Well 1J -09A WP03 11,450' 1950' 1E-34 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for these sidetrack since they are intended to serve as producers. 17. Attachments Attachment 1: Directional Plans for 1J -09A Attachment 2: Current Well Schematic for 1J-09 Attachment 3: Proposed Well Schematic for 1J -09A Page 6 of 6 July 11, 2012 1 J-O9A 16" 62# H-40 shoe @ 115' MD 9-5/8" 36# J-55 shoe @ 5639' MD 7" 26# L-80 shoe @ 9198' RKB Proposed CTD Sidetrack Updated: 10 -Jul -12 3-1/2" Camco D nipple @ 523' RKB (ID = 2.875") 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels @ 2922', 5088', 6858', 8067' RKB 3-1/2" Camco MMG gas lift mandrels @ 8893' RKB Stuck orifice valve in GLM#3 (6858'), typically covered by retrievable patch. Patch will be re -installed post -CTD. 3-1/2" Camco DS nipple @ 8945' RKB (ID = 2.813") Baker 3-1/2" GBH -22 seal assembly @ 8990' RKB (3" ID?) Baker 5" x 7" ZXP liner top packer @ 8988' RKB Baker 5" x 7" Flexlock liner hanger @ 8995' RKB Baker 80-40 PBR (4" ID seal bore) @ 9008' RKB 3-1/2" HES'XN' landing nipple @ 9066' RKB (2.75" min ID, will be milled out to 2.80") 1J -09A C -sand TD @ 12,700' MD 3-1/2" monobore whipstock @ 9605' MD, cemented in KOP @ 9605' MD place C -sand perfs (squeezed) 9604' - 9676' MD 3" openhole slotted liner 3-1/2" 9.3# L-80 shoe @ 9807' RKB 1J -09A C -sand TD @ 12,700' MD ConocoPhillips Project: Kuparuk River Unit Coordinate (N/E) Reference: AzimWsb True Kbdh Witnetc North. 1627' WELLBORE DETAILS: 1J -09A Site: KuparuklJPad 1J-09 Mag -tic Field Parent Wellbore: 1J-09 Well: 1J-09 Calculation Method: Minimum Curvawre Stregth: MM.NnT Tie on MD: 9521.69 Wellbore: 1J -09A D,pAngie:79.91 0.00 Plan: 1J-09A_wrp03 (1J -09/1J -09A) Mcdei: eccMm1i REFERENCE INFORMATION Coordinate (N/E) Reference: Well 1J-09, Two North vertical (ND) Reference: WELL DETAILS: 1J-09 Slot-(O.00N, 0.90 Measured Depth Reference: 1J-09:115.05 @ 115.0511 (1J-09:115.05 Calculation Method: Minimum Curvawre Ground Level: 0.00 -N/-S +E/ -W Northing Easting Latittude Longitude Slot 0.00 0.00 5,945,963.35 558,634.6 70° 15'46.700 N 149° 31'33.517 W SECTION DETAILS ANNOTATIONS Sec MD Inc Azi TVDSS +NAS +EJ -W DLeg Vace vsec Target Annotation 1 9521.69 59.31 343.91 6066.90 6413.96 -2014.51 0.00 0.00 -6666.34 TIP 2 9605.00 59.17 344.83 6109.51 6482.90 -2033.79 0.96 100.28 -6737.56 KOP 3 9630.00 62.07 343.95 6121.77 6503.88 -2039.66 12.00 345.00 -6759.26 3 4 969227 90.00 341.60 6136.65 6561.00 -2057.44 45.00 355.00 -6818.60 4 5 10022.27 90.00 193.10 6136.65 6549.69 -2302.27 45.00 270.00 -6849.97 End45dis 6 10225.00 93.03 185.58 6131.29 6349.89 -2335.15 4.00 292.00 -6658.92 Start RSM 7 10825.00 92.97 161.55 6099.42 5758.87 -2268.46 4.00 270.50 -6065.29 7 B 11125.00 90.03 149.91 6091.55 5485.99 -2145.38 4.00 256.00 -5775.19 8 9 11325.00 87.56 142.29 6095.77 5320.16 -2033.96 4.00 252.00 -5592.53 9 10 11775.00 87.68 160.31 6114.60 4927.40 -1818.95 4.00 90.00 -5168.40 10 11 12225.00 87.18 176.32 6134.96 4487AB -1735.93 4.00 92.00 14720.74 11 12 12400.00 90.03 171.93 613923 4313.27 -1721.07 4.00 294.00 -4546.60 12 13 12700.00 92.10 160.11 6133.61 4022.74 -1646.73 4.00 280.00 -0247.93 TD at 12700.00 REFERENCE INFORMATION Coordinate (N/E) Reference: Well 1J-09, Two North vertical (ND) Reference: Mean Sea Level Section (VS) Reference: Slot-(O.00N, 0.90 Measured Depth Reference: 1J-09:115.05 @ 115.0511 (1J-09:115.05 Calculation Method: Minimum Curvawre FS ,IB BAKER HUGHES '400 West( -)/East(+) (300 ft/in) 5500 5600 5700 5800- 5900 TIP 6000 KO i r 6100 i - ' 9/11-0 A 6200 - Ind nd 45ds i 6300- 6400 r start M i TD t 1270 .00 6500 1J-09 1J-093 7 8 9 10 1 17 400 -7300 -7200 -7100 -7000 -6900 -6800 -6700 -6600 -6500 -6400 -6300 -6200 -6100 -6000 -5900 -5800 -5700 -5600 -5500 -5400 -5300 -5200 -5100 -5000 4900 -4800 -4700 4600 -4500 -4400 -4300 -4200 -4100 -4000 -3900 -3800 -3700 -3600 Vertical Section at 170.00° (100 Win) ✓ ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1J Pad 1J-09 -7_1 Plan: 1J-09A_wp03 Standard Planning Report 10 July, 2012 'el, f.—) ,- � ,. I f I FeAld FIN BAKER HUGHES ConocoPhillips Alaska Database: EDM Alaska Prod v16 Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1 J-09 Wellbore: 1J -09A Design: 1 J-09A_wp03 ConocoPhillips or its affiliates HIM Planning Report BAKER HUGHES Local Co-ordinate Reference: Well 1J-09 TVD Reference: Mean Sea Level MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) - North Reference: True Survey Calculation Method: 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 [Site Kuparuk 1J Pad Site Position: Northing: 5,945,919.64ft Latitude: 70° 15'46.258 N From: Map Easting: 558,789.95ft Longitude: 149° 31' 29.007 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.45 ° Well 1 J-09 Well Position +N/ -S 0.00 ft Northing: 5,945,963.35 ft Latitude: 70° 15'46.700 N +E/ -W 0.00 ft Easting: 558,634.61 ft Longitude: 149° 31' 33.517 W Position Uncertainty 0.00 It Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 1 J -09A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l (°1 (nT) BGGM2011 8/1/2012 16.27 79.91 57,376 Design 1J-09A_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,521.69 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 170.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°1100ft) (°) Target 9,521.69 59.31 343.91 6,066.90 6,413.96 -2,014.51 0.00 0.00 0.00 0.00 9,605.00 59.17 344.83 6,109.51 6,482.90 -2,033.79 0.96 -0.17 1.10 100.28 9,630.00 62.07 343.95 6,121.77 6,503.88 -2,039.66 12.00 11.60 -3.51 345.00 9,692.27 90.00 341.60 6,136.65 6,561.00 -2,057.44 45.00 44.85 -3.77 355.00 10,022.27 90.00 193.10 6,136.65 6,549.69 -2,302.27 45.00 0.00 -45.00 270.00 10,225.00 93.03 185.58 6,131.29 6,349.89 -2,335.15 4.00 1.49 -3.71 292.00 10,825.00 92.97 161.55 6,099.42 5,758.87 -2,268.46 4.00 -0.01 -4.01 270.50 11,125.00 90.03 149.91 6,091.55 5,485.99 -2,145.38 4.00 -0.98 -3.88 256.00 11,325.00 87.56 142.29 6,095.77 5,320.16 -2,033.96 4.00 -1.23 -3.81 252.00 11,775.00 87.68 160.31 6,114.60 4,927.40 -1,818.95 4.00 0.03 4.00 90.00 12,225.00 87.18 178.32 6,134.96 4,487.48 -1,735.93 4.00 -0.11 4.00 92.00 12,400.00 90.03 171.93 6,139.23 4,313.27 -1,721.07 4.00 1.63 -3.65 294.00 12,700.00 92.10 160.11 6,133.61 4,022.74 -1,648.73 4.00 0.69 -3.94 280.00 7/102012 3.31:17PM Page 2 COMPASS 2003.16 Build 69 �•' ConocoPhillips or its affiliates W1R'G ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 J-09 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Site: Kuparuk 1J Pad North Reference: True Well: 11-09 Survey Calculation Method: Minimum Curvature Wellbore: 1 J -09A Design: 1 J-09A_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) 1°) (ft) (ft) 9,521.69 59.31 343.91 6,066.90 6,413.96 -2,014.51 -6,666.34 0.00 0.00 5,952,360.82 556,570.42 !I TIP 9,600.00 59.18 344.77 6,106.95 6,478.76 -2,032.67 -6,733.30 0.96 100.28 5,952,425.46 556,551.75 9,605.00 59.17 344.83 6,109.51 6,482.90 -2,033.79 -6,737.58 0.96 99.84 5,952,429.60 556,550.59 KOP 9,630.00 62.07 343.95 6,121.77 6,503.88 -2,039.66 -6,759.26 12.00 -15.00 5,952,450.53 556,544.57 3 9,692.27 90.00 341.60 6,136.65 6,561.00 -2,057.44 -6,818.60 45.00 -5.00 5,952,507.50 556,526.34 4 9,700.00 90.00 338.12 6,136.65 6,568.26 -2,060.10 -6,826.21 45.00 -90.00 5,952,514.74 556,523.62 9,800.00 90.00 293.12 6,136.65 6,637.92 -2,128.26 -6,906.64 45.00 -90.00 5,952,583.86 556,454.94 9,900.00 90.00 248.12 6,136.65 6,638.98 -2,225.70 -6,924.61 45.00 -90.00 5,952,584.16 556,357.50 1 10,000.00 90.00 203.12 6,136.65 6,570.83 -2,295.35 -6,869.59 45.00 -90.00 5,952,515.47 556,288.38 10,022.27 90.00 193.10 6,136.65 6,549.69 -2,302.27 -6,849.97 45.00 -90.00 5,952,494.29 556,281.63' End 45dis 10,100.00 91.16 190.22 6,135.86 6,473.58 -2,317.98 -6,777.74 4.00 -68.00 5,952,418.06 556,266.52 10,200.00 92.66 186.51 6,132.53 6,374.72 -2,332.52 -6,682.91 4.00 -68.03 5,952,319.10 556,252.75 110,222.27 92.99 185.68 6,131.43 6,352.60 -2,334.88 -6,661.54 4.00 -68.15 5,952,296.97 556,250.56. Start RSM 10,225.00 93.03 185.58 6,131.29 6,349.89 -2,335.15 -6,658.92 4.00 -68.19 5,952,294.25 556,250.31 10,300.00 93.05 182.57 6,127.31 6,275.19 -2,340.47 -6,586.27 4.00 -89.50 5,952,219.52 556,245.57 10,400.00 93.07 178.57 6,121.97 6,175.36 -2,341.47 -6,488.13 4.00 -89.66 5,952,119.70 556,245.35 10,500.00 93.07 174.56 6,116.61 6,075.70 -2,335.49 -6,388.95 4.00 -89.87 5,952,020.10 556,252.11 10,600.00 93.06 170.56 6,111.27 5,976.70 -2,322.56 -6,289.21 4.00 -90.09 5,951,921.21 556,265.80 10,700.00 93.03 166.55 6,105.96 5,878.85 -2,302.75 -6,189.41 4.00 -90.30 5,951,823.53 556,286.37 10,800.00 92.98 162.55 6,100.72 5,782.62 -2,276.15 -6,090.02 4.00 -90.51 5,951,727.51 556,313.72 10,822.27 92.97 161.66 6,099.56 5,761.46 -2,269.32 -6,067.99 4.00 -90.72 5,951,706.41 556,320.71 7 10,825.00 92.97 161.55 6,099.42 5,758.87 -2,268.46 -6,065.29 4.00 -90.77 5,951,703.83 556,321.59 10,900.00 92.24 158.63 6,096.01 5,688.43 -2,242.95 -5,991.49 4.00 -104.00 5,951,633.60 556,347.65' 11,000.00 91.26 154.75 6,092.95 5,596.65 -2,203.41 -5,894.24 4.00 -104.13 5,951,542.14 556,387.90 11,100.00 90.27 150.88 6,091.62 5,507.73 -2,157.73 -5,798.74 4.00 -104.25 5,951,453.58 556,434.26 11,122.27 90.05 150.01 6,091.55 5,488.36 -2,146.75 -5,777.76 4.00 -104.30 5,951,434.30 556,445.40 8 11,125.00 90.03 149.91 6,091.55 5,485.99 -2,145.38 -5,775.19 4.00 -104.31 5,951,431.95 556,446.78 11,200.00 89.10 147.05 6,092.12 5,422.07 -2,106.18 -5,705.43 4.00 -108.00 5,951,368.33 556,486.48 11,300.00 87.87 143.25 6,094.77 5,340.04 -2,049.07 -5,614.73 4.00 -107.98 5,951,286.76 556,544.22 11,322.27 87.59 142.40 6,095.65 5,322.32 -2,035.62 -5,594.94 4.00 -107.88 5,951,269.14 556,557.80 9 11,325.00 87.56 142.29 6,095.77 5,320.16 -2,033.96 -5,592.53 4.00 -107.84 5,951,267.00 556,559.491 11,400.00 87.56 145.30 6,098.96 5,259.70 -1,989.70 -5,525.30 4.00 90.00 5,951,206.89 556,604.21 11,500.00 87.58 149.30 6,103.20 5,175.64 -1,935.73 -5,433.15 4.00 89.87 5,951,123.26 556,658.82 11,600.00 87.61 153.30 6,107.40 5,088.02 -1,887.77 -5,338.53 4.00 89.70 5,951,036.03 556,707.46 11,700.00 87.64 157.31 6,111.55 4,997.26 -1,846.03 -5,241.90 4.00 89.53 5,950,945.60 556,749.90 11,772.27 87.68 160.20 6,114.49 4,929.97 -1,819.87 -5,171.09 4.00 89.37 5,950,878.53 556,776.581 10 11,775.00 87.68 160.31 6,114.60 4,927.40 -1,818.95 -5,168.40 4.00 89.25 5,950,875.97 556,777.52 11,800.00 87.65 161.31 6,115.62 4,903.81 -1,810.74 -5,143.74 4.00 92.00 5,950,852.44 556,785.92 11,900.00 87.51 165.31 6,119.85 4,808.12 -1,782.05 -5,044.53 4.00 91.96 5,950,756.99 556,815.35 12,000.00 87.40 169.31 6,124.29 4,710.68 -1,760.11 -4,944.76 4.00 91.79 5,950,659.73 556,838.04' 12,100.00 87.29 173.32 6,128.93 4,611.96 -1,745.03 -4,844.91 4.00 91.61 5,950,561.14 556,853.89 12,200.00 87.20 177.32 6,133.74 4,512.43 -1,736.88 -4,745.48 4.00 91.43 5,950,461.68 556,862.81 7/10/2012 3:31:17PM Page 3 COMPASS 2003.16 Build 69 'V-' ConocoPhillips or its affiliates OCRs ConocoPhillips PlAlaskaanning Report HUGHES Planned Survey Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1J-09 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Site: Kuparuk 1J Pad North Reference: True Vertical Well: 11-09 Survey Calculation Method: Minimum Curvature Map Wellbore: Design: 1 J -09A 1 J-09A_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (') (ft) (ft) 12,222.27 87.18 178.21 6,134.83 4,490.20 -1,736.02 -4,723.44 4.00 91.23 5,950,439.47 556,863.85 11 12,225.00 87.18 178.32 6,134.96 4,487.48 -1,735.93 -4,720.74 4.00 91.19 5,950,436.74 556,863.95 12,300.00 88.40 175.58 6,137.86 4,412.64 -1,731.94 -4,646.36 4.00 -66.00 5,950,361.95 556,868.52 12,400.00 90.03 171.93 6,139.23 4,313.27 -1,721.07 -4,546.60 4.00 -65.89 5,950,262.67 556,880.171 12 12,500.00 90.73 167.99 6,138.56 4,214.82 -1,703.64 -4,446.62 4.00 -80.00 5,950,164.37 556,898.37 12,600.00 91.42 164.05 6,136.69 4,117.82 -1,679.49 -4,346.90 4.00 -80.03 5,950,067.57 556,923.27 12,700.00 92.10 160.11 6,133.61 4,022.74 -1,648.73 -4,247.93 4.00 -80.10 5,949,972.74 556,954.76) 7/1012012 3:31:17PM Page 4 COMPASS 2003.16 Build 69 0 Rl, G E S! w "0" ConocoPhillips or its affiliates (f as ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Company: Conoco Phillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 11-09 Wellbore: IJ -09A Design: 1 J-09A_wp03 Targets Target Name Point 1 - hiVmiss target Dip Angle Dip Dir. TVD - Shape V) V) (ft) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: +N/ -S +E/ -W Northing (ft) (ft) (ft) Well 1 J-09 Mean Sea Level 1 J-09:115.05 @ 115.05ft (1 J-09:115.05) True Minimum Curvature Easting (ft) Latitude Longitude 1J -09A T5 0.00 0.00 6,135.00 4,022.77 -1,646.47 5,949,972.79 556,957.03 70° 16'26.262 N 149° 32'21.456 W plan misses target center by 2.66ft at 12700.00ft MD (6133.61 TVD, 4022.74 N, -1648.73 E) Point 1J -09A Polygon 0.00 0.00 115.00 6,386.42 -2,083.09 5,952,332.74 plan misses target center by 5952.36ft at 9521.69ft MD (6066.90 TVD, 6413.96 N, -2014.51 E) Polygon Polygon Point 1 115.00 6,386.42 -2,083.09 5,952,332.74 Point 115.00 6,505.58 -1,843.14 5,952,453.75 Point 3 115.00 6,794.08 -2,031.93 5,952,740.75 Point 4 115.00 6,774.43 -2,337.12 5,952,718.72 Point 5 115.00 6,519.42 -2,469.11 5,952,462.72 Point 6 115.00 6,119.60 -2,498.21 5,952,062.72 Point 7 115.00 5,775.27 -2,461.87 5,951,718.72 Point 8 115.00 5,295.62 -2,256.55 5,951,240.73 Point 9 115.00 4,889.48 -1,985.66 5,950,836.75 Point 10 115.00 4,631.62 -1,879.64 5,950,579.74 Point 11 115.00 4,104.82 -1,783.70 5,950,053.76 Point 12 115.00 3,595.14 -1,704.63 5,949,544.76 Point 13 115.00 3,700.92 -1,286.76 5,949,653.78 Point 14 115.00 4,263.34 -1,460.44 5,950,214.77 Point 15 115.00 4,920.76 -1,633.37 5,950,870.77 Point 16 115.00 5,366.60 -1,864.95 5,951,314.75 Point 17 115.00 5,933.76 -2,134.60 5,951,879.73 Point 18 115.00 6,325.12 -2,174.58 5,952,270.73 Point 19 115.00 6,386.42 -2,083.09 5,952,332.74 1J -09A T3 0.00 0.00 6,116.00 4,927.17 -1,814.44 5,950,875.77 plan misses target center by 4.38ft at 11776.76ft MD (6114.68 TVD, 4925.75 N, -1818.36 E) Point 1J -09A T1 0.00 0.00 6,137.00 6,561.25 -2,059.73 5,952,507.73 plan misses target center by 2.11 ft at 9693.29ft MD (6136.65 TVD, 6561.97 N, -2057.77 E) Point 556,502.05 70° 16'49.507 N 149° 32'34.188 W' 556,502.05 556,741.05 556,550.03 556,245.04 556,115.05 556, 089.06 556,128.08 556,337.11 556,611.13 556,719.14 556,819.17 556,902.20 557,319.19 557,141.16 556,963.13 556,728.11 556,454.08 556,411.05 556,502.05 556.782.04 70° 16'35.156 N 149° 32'26.353 W 556,524.06 70'16'51.226N 149'32'33.509W 1J -09A Fault 1 0.00 0.00 6,116.00 5,015.51 -2,240.79 5,950,960.77 556,355.05 70° 16'36.024 N 149° 32'38.769 W plan misses target center by 344.24ft at 11470.51 ft MD (6101.95 TVD, 5200.82 N, -1951.04 E) Polygon Point 1 6,116.00 5,015.51 -2,240.79 5,950,960.77 556,355.05 Point 6,116.00 4,956.33 -1,831.20 5,950,904.79 556,765.05 Point 3 6,116.00 4,966.87 -1,383.06 5,950,918.82 557,213.05 Point 4 6,116.00 4,956.33 -1,831.20 5,950,904.79 556,765.05 1J -09A T4 0.00 0.00 6,145.00 4,312.39 -1,723.22 5,950,261.78 556,878.03 70° 16' 29.110 N 149'32'23.693W -plan misses target center by 6.20ft at 12400.45ft MD (6139.23 TVD, 4312.83 N, -1721.00 E) - Point 1J -09A T2 0.00 0.00 6,092.00 5,494.27 -2,076.04 5,951,440.76 556,516.05 70° 16'40.733 N 149° 32'33.975 W plan misses target center by 63.88ft at 11154.20ft MD (6091.63 TVD, 5460.87 N, -2130.50 E) Point 7/10/2012 3:31:17PM Page 5 COMPASS 2003.16 Build 69 0 R I G711 idL.- Plan Annotations Measured ConocoPhillips Depth Alaska Database: EDM Alaska Prod v16 Company: Conoco Phil] ips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1 J-09 Wellbore: 1 J -09A Design: 1 J-09A_wp03 Casing Points 6,099.56 11,122.27 Measured Vertical 11,322.27 Depth Depth 11,772.27 (ft) (ft) 12,222.27 5,639.00 3,833.57 9 5/8' 12,400.00 9,198.00 5,896.45 7" 12,700.00 12,700.00 6,133.61 2-3/8 Plan Annotations Measured Vertical Depth Depth (ft) (ft) 9,521.69 6,066.90 9,605.00 6,109.51 9,630.00 6,121.77 9,692.27 6,136.65 10,022.27 6,136.65 10,222.27 6,131.43 10,822.27 6,099.56 11,122.27 6,091.55 11,322.27 6,095.65 11,772.27 6,114.49 12,222.27 6,134.83 12,400.00 6,139.23 12,700.00 6,133.61 ConocoPhillips or its affiliates Planning Report RAW BAKER HUGHES Local Co-ordinate Reference: Well 1J-09 TVD Reference: Mean Sea Level MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) North Reference: True Survey Calculation Method: Minimum Curvature Casing Hole Diameter Diameter Name +E/ -W 9-5/8 12-1/4 7 8-3/4 2-3/8 3 Local Coordinates +N/ -S +E/ -W (ft) (ft) Comment 6,413.96 -2,014.51 TIP 6,482.90 -2,033.79 KOP 6,503.88 -2,039.66 3 6,561.00 -2,057.44 4 6,549.69 -2,302.27 End 45dls 6,352.60 -2,334.88 Start RSM 5,761.46 -2,269.32 7 5,488.36 -2,146.75 8 5,322.32 -2,035.62 9 4,929.97 -1,819.87 10 4,490.20 -1,736.02 11 4,313.27 -1,721.07 12 4,022.74 -1,648.73 TD at 12700.00 7/10/2012 3:31:17PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1J Pad 1J-09 1J -09A 1 J-09A_wp03 Travelling Cylinder Report 10 July, 2012 Few R 6 BAKER HUGHES ConocoPhillips or its affiliates WIPAL ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: 0-00ft Reference Well: 1 J-09 Well Error: 0.00ft Reference Wellbore 1J -09A Reference Design: 1J-09A_wp03 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 J-09 1J-09:115.05 @ 115.05ft (1J-09115.05) 1 J-09:115.05 @ 115.05ft (1 J-09:115.05) True Minimum Curvature 1.00 sigma EDM Alaska Prod v16 Offset Datum Reference 1J-09A_wp03 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refere Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,521.69 to 12,700.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,458.49ft Error Surface: Elliptical Conic Survey Tool Program Date 7/1 012 01 2 From To (ft) (ft) Survey (Wellbore) Tool Name Description 196.10 9,521.69 1J-09 (1J-09) MWD+IFR-AK-SCC MWD+IFR AK SCC Sperry 9,521.69 12,700.00 1J-09A_wp03 (1J -09A) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") O 5,639.00 3,948.62 9 5/8" 9-5/8 12-1/4 9,198.00 6,011.50 7" 7 8-3/4 12,700.00 6,248.66 2-3/8" 2-3/8 3 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7/10/2012 2:30:03PM Page 2 of 6 COMPASS 2003.16 Build 69 nP G 1� iI1, '% — I!�_ "VI ConocoPhillips or its affiliates [1t ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1J-09 Project: Kuparuk River Unit ND Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Reference Site: Kuparuk 1J Pad MD Reference: 1J-09:115.05 @ 115.05ft (1J-09:115.05) Site Error: 0.00ft North Reference: True Reference Well: 11-09 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1J -09A Database: EDM Alaska Prod v16 Reference Design: 1J-09A_wp03 Offset ND Reference: Offset Datum Summary Site Name Offset Well - Wellbore - Design Reference Offset Measured Measured Depth Depth (ft) (ft) Centre to No -Go Allowable Centre Distance Deviation Warning Distance (ft) from Plan (ft) (ft) 'Kuparuk 1J Pad 1J-101 Doyon 141 - Plan 1J-101 - 1J-101 (wp04) 1J-101 Doyon 141 - Plan 1J-101 L1 - 1J-101 L1 (w 1J-101 Doyon 141 - Plan 1J-101 L2 - 1J-101 L2 (w 1J-102 Doyon 15 - 1J-102 - 1J-102 Actual Survey: 1J-102 Doyon 15 - 1J-102 L1 - 1J-102 L1 Actual S 1J-102 Doyon 15 - 1J-102 L2 - 1J-102 L2 Actual S 1J-103 Doyon 141 - 1J-103 - 1J-103 - Actual Sury IJ -103 Doyon 141 - 1 J-103 L1 - 1 J-103 L1 - Actua 1J-103 Doyon 141 - 1J-103 L2 - 1J-103 L2 1J-105 Doyon 141 - 1J-105 - 1J-105 - Actual Sury 1J-105 Doyon 141 - 1J-105 L2 - 1J-105 L2 1J-154 Doyon 141 - 1J-154 - 1J-154 Actual Survel. 1J-154 Doyon 141 - 1J-154 L1 - 1J-154 L1 Actual 1 J-154 Doyon 141 - 1 J-154 L2 - 1 J-154 L2 Actual 1J-156 Doyon 141 - 1J-156 - 1J-156 Actual Surve, 1J-156 Doyon 141 - 1J-156 L1 -Actual- 1J-156 L1 IJ -156 Doyon 141 - 1 J-156 L2 - Actual - 1 J-156 L,' 1J-158 Doyon 15 - 1J-158 - 1J-158 Actual Survey; 1J-159 Doyon 141 - 1J-159 - 1J-159 Actual Surve, 1J-164 Doyon 141 - 1J-164 - 1J-164 (wp07) 1J-164 Doyon 141 - 1J-164 L1 - 1J-164 L1 (wp07) 1J-164 Doyon 141 - 1 J-164 L2 - 1 J-164 L2 (wp07) Kuparuk 1J Pad 1 J-09 - 1 J-09 - 1 J-09 9,624.99 9,625.00 0.43 4.42 -1.97 1J_10 - 1J_10 - ii -10 IJ -10 - ii -10 - ii -10 (wp01) 1J-101 - 1J-101 - 1J-101 1J-101 - 1J-1011_1 - 1J-1011-1 1J-101 - 1J-101 L1 PB1 - 1J-101 L1 PB1 1J-101 -IJ-1011-2-IJ-1011-2 1J -101 -1J -101P131 -1J -101P61 1J-164 - 1J-164 - 1J-164 1J-164 - 1J -164L1 - 1J-1641_1 1J-164 - 1J-1641_2 - 1J-1641_2 Plan 1J-104 (empty) - Prelim: 1J-104 L1 - Prelim: Plan 1J-104 (empty) - Prelim: 1 J-104 L2 - Prelim: Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range FAIL - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7/10/2012 2:30:03PM Page 3 of 6 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates «%s ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.00ft Reference Well: 1 J-09 Well Error: O.00ft Reference Wellbore 1J -09A Reference Design: 1J-09A_wpO3 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 J-09 1J-09:115.05 @ 115.05ft (1J-09:115.05) 1J-09:115.05 @ 115.05ft (1J-09:115.05) True Minimum Curvature 1.00 sigma EDM Alaska Prod v16 Offset Datum teference Depths are relative to 1J-09:115.05 @ 115.05ft (1J-09:115.00oordinates are relative to: 1J-09 Dffset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 ventral Meridian is 150° 0' 0.000 W ° Grid Convergence at Surface is: 0.44° CU L 0, Ladder Plot I I I I I I I I 1600 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 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 1 I I I I I I I I I 1 I I I I I I 1 I I I 1 I I I I I I I 1 I I I I I 1 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 1 I I 1 I I I I I I I I 1 I I I I I I 1 I I I I I 1 I I I I I I I I I I I I 1 - 1200 0 m Q U7 co m 800 CCD U O - C-_ U 400 0 0 2000 4000 6000 8000 10000 12000 M easured Depth LEGEND 1J -09,1J-09,1.109 V8 CU L 0, 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 1 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 1 I I I I I I I I I 1 I I I I I I 1 I I I 1 I I I I I I I 1 I I I I I 1 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 1 I I 1 I I I I I I I I 1 I I I I I I 1 I I I I I 1 I I I I I I I I I I I I 1 - CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7/10/2012 2:30.03PM Page 6 of 6 COMPASS 2003.16 Build 69 TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# f �rDevelopment Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: POOL: f Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTILATERAL 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 1J -09A _ Program DEV _ _ Well bore seg ❑ PTD#:2120930 Company CONOCOPHILLIPS ALASKA INC - Initial Class/Type DEV/PEND - GeoArea 890Unit 11160_ On/Off Shore On Annular Disposal ❑ Administration 17 Non coriven. gas conforms to AS 31.05.0300.1.A),(j.2_.A-D) _ - - - - - I _ - - - NA_ - - _ - - _ - _ _ .. _ 11 -Perm it- fee attached_ NA_ - - - - NA_ 2 Lease number appropriate_ Yes Entire well within ADL 025661 - - - - - - 3 Unique well name and number Yes - - - - - - - - - - - - 4 Well located in a_defined_pool - - - - Yes Kuparuk River Oil_ Pool, governed by Conservation Order No. 432C 5 Well located proper distance from drilling unit_boundary - - - - - Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit - 6 Well located proper distance_ from other wells_ Yes boundaries. _Conservation Order_No_. 432C_ has no inte_rwe_II spacing restrictions._ 7 Sufficient acreage available in -drilling unit - - - - - Yes - - - - - - - Conservation Order No. 432C has no interwell_spacing- restrictions. Wellbore will be more than 8 If deviated, is wellbore platincludedYes 500' from an external property line where.ownership or landownership changes. 9 Operator only affected party - - - Yes - - - - - - - - - - - - - - - - - - - - - - 10 Operator has_appropriate_bond in force Yes - - - - P &A sundry 312-253 approved. - Appr Date 11 Permit. can be issued without conservation order Yes - 12 Permit _can be issued without administrativ_e_approval - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 7/17/2012 _ - - _ Wellhead installed._BOP_will be placed on top of production tree._ Appr Date 28 13 Can permit be approved before 15 -day wait_ Yes GLS 7/17/2012 114 Well located within area arid -strata authorized by Injection Order # (put 10# in -comments)_ (For_ NA_ - - - --- no SSSV ,will use_12ppg brine for KWF to run slotted_ liner -- 15 All wells -within 1/4_mile area 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_ Choke_manifold complies w/API_RP-53 (May 84)_ _ _ - - - - I35 Geologic 18 Conductor string -provided - - - - NA_ Conductor -set-in 113-09 - Engineering 19 Surface casing_ protects all -known_ USDWs NA Surface casing set in 1B-09_ Appr Date 20 CMT vol_ adequate- to circulate on conductor & surF_csg NA Surface casing fully cemented. No aquifers. SFD 7/17/2012 21 CMT.vol adequate to tie -in -long string to surf csg_ NA Production. casing set in 1B-09 39 22 CMT will coverall known -productive horizons_ No Slotted linerpl_anned for horizontal- production section. 23 Casing designs adequate for C, T, B &_permafr_ost Yes 24 Adequate -tankage- or reserve pit Yes Rig has steel pits, 25 If_a_re-drill, has_a 1.0-403 for abandonment been approved Yes - - - - - P &A sundry 312-253 approved. - 26 Adequate wellbore separation proposed - Yes - - - - Proximity analysis performed. Ladder. plot and traveling cylinder data supplied. 27 If diverter required, does it meet regulations_ - - - _ _ - - - - - - _ _ _ _ _ NA_ _ _ - _ - - _ Wellhead installed._BOP_will be placed on top of production tree._ Appr Date 28 Drilling fluid_ program schematic_& equip _list adequate_ Yes - - _ Max formation_ press= 2749 -psi-( 8.5..ppg EMW)_ Will drill with_9_ppg mud and utilize- MPD for BHP control GLS 7/17/2012 29 BOPEs,_do they meet regulation - - - - - - - - Yes _ - - - - - --- no SSSV ,will use_12ppg brine for KWF to run slotted_ liner -- 30 BOPE_press rating appropriate; test to_(put psig in comments)_ - Yes - - - - - - MASP = 2124 -psi -will test BOP_to 3500-psi- 500_Psi_31 31 Choke_manifold complies w/API_RP-53 (May 84)_ _ _ - - - - - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occur without operation -shutdown __-_-. _- Yes_____________ -__-______ _ - - -- - 33 Is Presence of H2S gas probable - - - - - - Yes - - - H2S in area. Rig -has sensors and_alarms.- 34 Mechanical_condition of wells within AOR verified (For service well only) - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - I35 Geologic Permit -can be issued w/o hydrogen sulfide measures No_ - - - - - Wells_on 1J -Pad are H2S-bearino._H2_S_measures required. - Geology 36 Data_presented on potential overpressure zones - - - - - - - - - - - p Yes Expected reservoir pressures_ range from -6 ,6 to 8.5_ppg EMW. -Wellbore will be drilled using 9.0 Ex Appr Date 37 Seismic analysis of shallow gas..zones.. NA_ ppg mud and managed pressure_dril_ling technique._ Two_wellbore volumes of 12.0 ppg kill -weight SFD 7/17/2012 38 Seabed condition survey (if off -shore) - - - - - - NA_ fluid will be nearby during drilling operations. 39 Contact-name/phone for weekly -progress reports_ [exploratory only] - - - - - - - - - - - NA_ - - - - . - - - - - - - - - - - - - - - - - - -- Geologic Engineering DPublic Date CTD sidetrack targeting Kuparuk C sand reserves. Exiting liner in the C sand zone. GLS Date: ate Commissioner: / Commissioner: Commissioner