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HomeMy WebLinkAbout209-132 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file, Q 0 7 - 13 a, Well History File Identifier Organizing (done) ❑ Two -sided III IIIIll llll1 1111 ❑ Rescan Needed I1! 1111111111 Iil lfl RES AN DIGITAL DATA OVERSIZED (Scannable) Col r Items: (( ❑ Diskettes, No. ❑ Maps: Greyscale Items: 1 1 2 9 1---- ❑ Other, No/Type: ❑ Other Items Scannable b �1 by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: WE* Date: • az /s/ f Project Proofing 1111111111111111 BY: ACM Date: a 1 i /s/ M P Scanning Preparation i x 30 = 30 + 1 = TOTAL PAGES '"T C ount does n i nclude cover sheet) BY: Maria . Date: •� a3 /s/ Production Scanning III 1111111 IIIII Stage 1 Page Count from Scanned File: L-1-�J (Count does include cov heet) I Page Count Matches Number in Scanning Pre aration: YES NO BY: Date: o liaZ 1 1 /s/ al ( Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I11 IIIIIIIIIIIII ReScanned 11111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 1 10/6/2005 well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2117/2011 Permit to Drill 2091320 Well Name /No. KUPARUK RIV UNIT 1B -17L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 22461 -61 -00 MD 9320 TVD 6338 Completion Date 12/14/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint IP Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type. Med /Frmt Number )fame Scale Media No Start Stop CH Received Comments - -D C Lis 19323 nd uction /Resistivity 6724 9320 Open 2/6/2010 EWR logs in PDF, EMF ���� and CGm graphics LCog Induction /Resistivity 2 Col 6903 9320 Open 2/6/2010 MD MPR, GR o Induction /Resistivity 5 Col 6903 9320 Open 2/6/2010 MD MPR, GR Log Induction /Resistivity 5 Col 6903 9320 Open 2/6/2010 TVD MPR, GR Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION � . Well Cored? Y /Tf Daily History Received? 6/ N Chips Received ? - Y Formation Tops 6 N Analysis Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/17/2011 Permit to Drill 2091320 Well Name /No. KUPARUK RIV UNIT 1B -17L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50 -029- 22461 -61 -00 MD 9320 TVD 6338 Completion Date 12/14/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N Compliance Reviewed By: Date: - .� I r S • • Conoco Phillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and /or Digital Data contact: Lisa Wright, 907 263 -4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk * / David Douglas in lieu of sepia ** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519 -6612 CHEVRON /KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk * / P.O.Box 196247 in lieu of sepia ** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS • Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk * / 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501 -3510 LIS 9 —13 lg W O 009 -130 /93P3 069-13 /e3 30s • 1B -17 L1 14 and L2 -01 CTD Sidetracks Last update= 12/30 /09(JWL1 . 4" Camco TRDP -4A @ 1896' MD 16" 62# H-40 shoe 4" 11# J -55 BTC Mod tubing (surface - 3554' MD) 2a� -- ( 3 L @ 121' MD 3 -1/2" 9.3# J -55 EUE 8rd AB -Mod Tubing (3554' - 6276' MD) 3 -1/2" 9.2# J -55 SPCLN BTC -Mod Tubing (6276' - 6743' MD) 5 " , 18 #, L -80, LTC, R -3 Class A (6305' - 7477' MD) C amco MMG gas lift mandrels @ 2403', 3590', 4496', 5308', 5904', & 6197' M D 9 -5/8" 40# J -55 shoe @ 4241' MD l f B aker 80 -40 PBR (10' length with 3" ID seal bore) I�� I Baker 7" x 3 -1/2" HB retrievable packer @ 6259' MD Z • 7" 26# L -80 shoe @ — 1 3 -1/2" Camco D landing nipple @ 6274' MD (2.75" min ID) 6629' MD .T---T L2 (in C3 /C4 sands- north fault block), TD @ 9320' MD 3" borehole, Slotted liner (2 -3/8 ", 4.6 #. L -80 ST -L) Deployment sleeve at 8097' MD; Bottom of shoe at 9204' MD Tubing Tail @ 6743' MD / \ / _ / L2 -01 (in C1 sand -north fault block), TD @ 9520' MD C -sand perfs _ / Deployment Sleeve 6693' MD 6907' - 6967' MD Anchor billet at / 2 -3/8" Slotted liner 6994' -6789' MD 8060' MD / 2 -3/8" Blank liner 6789' -7113' MD 3 -1/2 x 5" Baker Gen 2 flow/ 2 -3/8" Slotted liner 7113' -9244' MD R &R Indexing Guide 9224' -9245' MD by whipstock @ 6904' MD \ 2 -3/8" Blank liner 9245' -9247' MD Guide Shoe top at 9247' MD, bottom at 9248' MD \ 3 -1/2 x 5" Baker Gen 2 flow- — _ by whipstock @ 6990' MD Anchor billet at �— 8200' • MD ------ '_ /) )\ A \ L2 -01 PB1 (in C1 sand- north perfs 7013' - 7053' MD E \ fault block), TD @ 8918' MD, 7013' unlined 5" 18.0# L -80 shoe — ) @ 7477' MD _ L1 (in C1 sand -south fault block), TD @ 8975' MD Deployment Sleeve 6969' MD 2 -3/8" Slotted liner 6979' -7065' MD 2 -3/8" Blank liner 7065' -7338' MD 2 -3/8" Slotted liner 7338' -7871' MD 2 -3/8" Blank liner 7871' -8120' MD 2 -3/8" Slotted liner 8120' -8244' MD 2 -3/8" Blank liner 8244' -8431' MD 2 -3/8" Slotted liner 8431' -8620' MD 0 -Ring Sub 8620' -8621' MD 2 -3/8" Solid liner 8621' -8653' MD Guide Shoe top at 8653' MD, bottom at 8654' MD RECEIVhv STATE OF ALASKA JAN 2 6 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOF ? i' Comnisaron la. Well Status: Oil II Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development is Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: December 22, 2009 209 - 132 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 December 8, 2009 50 029 - 22461 - 61 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 502' FNL, 154' FEL, Sec. 9, T11 N, R10E, UM December 12, 2009 1B r Top of Productive Horizon: 8. KB (ft above MSL): 102' RKB 15. Field /Pool(s): 2060' FNL, 749' FWL, Sec. 10, T11 N, R10E, UM GL (ft above MSL): 61' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1574' FNL, 2606' FEL, Sec. 10, T11 N, R10E, UM 9204' MD / 6334' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 550285 y - 5969647 Zone 4 9320' MD / 6338' TVD ADL 25648 TPI: x - 551203 y - 5968095 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit Total Depth: x 553123 y - 5968594 Zone 4 1896' MD / 1896' TVD 466 18. Directional Survey: Yes El No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1700' MD / 1700' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drilULateral Top Window MD/TVD GR/Res 6903' MD / 6421' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 120' Surf. 120' 24" 205sxAS1 9.625" 40# J -55 Surf. 4241' Surf. 4178' 12.25" 950 sx AS III, 400 sx CI G 7" 26# L -80 Surf. 6629' Surf. 6188' 8.5" 225 sx Class G 5" 18# L -80 6298' 7477' 5915' 6936' 6.125" 160 sx Class G 2.375" 4.6# L -80 8099' 9204' 6391' 6335' 3" Slotted liner 24. Open to production or injection? Yes 0 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) none 6260' MD / 5883' TVD alternating solid /slotted liner slots from 8099' -9202' MD 6391' -6334' TVD 32 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na I 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 27, 2009 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 1/1/2010 24 hours Test Period - -> 927 1641 2621 176 Bean 2747 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 213 psi 962 24 -Hour Rate -> 927 1641 2621 23 deg. 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No is Sidewall Cores Acquired? Yes ❑ No 0 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 r-...» ,, fr Submit separate sheets with this form, if needed Submit detailed descriptions, core chips, and laboratory analytical results per 20 AAC 25.07E $ CONthLI `ljt3t ( P )� P P .rY t Y� P D 1O a NONE Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only RBDMS JAN 2 7 ZO'� r • Y•/o -2-4,) rt • 1 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? 0 Yes II No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Top C3 6921' 6437' Top C2 6948' 6457' Top C2 7540' 6421' Top C3 7740' 6397' Top C2 8408' 6365' Top C3 9119' 6338' Top C4 9308' 6337' N/A Formation at total depth: Kuparuk C4 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263 - 4093 QA ©iI2sho Printed N e V. C e Title: Alaska Wells Manager ✓�/ Signature Phone 265 - 6306 Date ifr577-Al o Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 v KUP 1 B-1 7L2 CO11K? ClPI11 \ 500292246,6, _ - — ii JS ; Well A tnbut Ma Angle & MD : TD - lfeska. WellboreAPUUWI Field Name Well Status .Inc' (°) MD (9613) Act Btm (fIKB) :ateco141i�IXIifKUPARUK RIVER UNIT PROD . 10309 7,19541 __ Comment' H2S (ppm) 'Date Annotation End Date KB -Grd (It) Rig Release Date - -- wen conf g; le � 1/4/201U L 412 Pn4 SSSV TRDP I /5 8/18/2008 Last WO: 1 ... 41 01 4/5/1994 Schematic AM OMB) Annotation Depth K6) End Date Annotation Last Mod .. End Dab Last Tag I Rev Reason- GLV C/O, QC SIDETRACKS Imosbor 1/4/2010 1 Casing Strings Casing Description String 0... IStr g ID... Top (HKB) Set Depth (f... Set Depth (ND) ...'String Wt... String ... String Top Thrd *�. -. L2 LINER off L2 -01 I 2 3/8 '.. 7.995 I 8,098 .6 I 9,204.0 I 6334.5 4.60 L-80 STL rwruGC�, a1 � ; Liner etails _. 'Top Depth (TVD) Top Incl Noml - -- Top (ftK8) OMB) ( °) Item Description Comment ID(In) 8,098.6 6,391.8 89 98 DEPLOY 12.625" Baker deployment sleeve 1.995 coNDUCTO21 R,_ P & Slots 42 - _ -- Shot - Top (TVD) Btm (TVD) Dens SAFETY VLV, Top (ftK6) Btm (ftK6) (MB) (ftKB) Zone Date (sh... Type Comment 1,896 8,099 9,202 6,391.8 6,334.5. C -3, C -4, 12/12/2009 32.0 SLOTS Alternating solid /slotted pipe - 1B-17L2 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends GAS LIFT, _ Notes General & Safety 24120 End Date Annotation SI 12/22/2009 NOTE: MULTI - LATERAL WELL CTD 1B -17L1, 1B -17L2, 1B- 17L2 -01 • 1 't 1/4/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 3,590 it AMP SURFACE, 5 i A, 414,241 GAS LIFT, 4,496 GAS LIFT. 5,308 ir GAS LIFT 5,904 _. –. ,- Ilk GAS LIFT, 6,197 It 1; PBR, 6,246 _- -_.... •..:- PACKER, 6,259— '� ®"'�° NIPPLE, 6,274. '. PRODUCTION, J i 31 -6,629 SOS, 6,742 WHIPSTOCK, W IN 2.41, 00W 6,9001,9 IPERF, 0 PERF, 6,907 -6,967 WHIPSTOCK, 80 ti 6, WINDOW L1, 6,990 -7,000 RPERF, 7,013.7,033 IPERF, .__, .' 7 ,_.._._ _ - -e-.. Y .. -- . __ , .__ 7,013 -7,053 RPERF, Top Depth Top -_. Port 7,0334,053 (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (f1513) MSS) ( "1 Make Model (in) Saw TVA Type On) (Psi) Run Date Com... 1 2,403.5 2,402.0 3.16 CAMCO KBUG 1 GAS LIFT GLV BK 0.000 1,342.0 12/25/2009 2 3,589.5 3,581.0 13.54 CAMCO. KBUG 1 GAS LIFT GLV BK 0.188 1,366.012/25/2009 LINER, 3 4,496.3 4 31.68 CAMCO KBUG 1 GAS LIFT OV BK '07250 0.0 12/25/2009 6,293 - 7,477 . -� TD (93 • 4 5,307.5 5,088 5 32.87 CAMCO KBUG 1 GAS LIFT DMY BK 0 000 0 0 12/4/2008 7,500 5 5,904.2 5,586.3 33.29 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/15/2000 1 . 6 6,196.7 5,830.8 33.84 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/13/2009 SLOTS, __. 8,099 -9,202 L2 LINER - off L2 -01, — 8,099 -9,204 • 1B-17 Well Events Summary DATE SUMMARY 11/8/09 (PRE CTD) T & IC POT's - PASSED. MITOA - PASSED. PT /DD MV WF SV SSV - PASSED. DD SSSV - PASSED. 11/11/09 LOGGED CALIPER SURVEY f/ 7110' TO 6226' RKB. RECOVERED GOOD DATA. IN PROGRESS. 11/12/09 SET CAT SV IN D NIPPLE @ 6274' RKB. PULLED GLVs @ 2403' & 4496' RKB; SET DVs @ SAME. PULLED OV © 6197' RKB. READY FOR CIRC OUT. IN PROGRESS. 11/13/09 CIRCULATED 200 BBL DSL TO PROD. SET DV @ 6197' RKB. MITIA 2500 PSI, PASSED. PULLED CAT SV © 6274' RKB. IN PROGRESS. 11/14/09 MEASURED BHP @ 6950' RKB: 2036 PSI. READY FOR E /L. 11/17/09 DRIFT FOR SETTING TOOL & WHIPSTOCK TO 7050' SLM W/ SETTING TOOL DRIFT ASSY (2.74" CENT, 3' OF 1.875" WB & 2.74" X 3' CENT, OAL =7.5') & DMY WHIPSTOP DRIFT ASSY (2.65" X 9', 1.85" X 1', 2.62" X 9', OAL =18'), NO PROBLEMS. JOB COMPLETE 11/23/09 SET BAKER THRU- TUBING GEN II 2.625" WHIPSTOCK USING DPU -i. TOP OF WHIPSTOCK AT 6980' WITH WHIPSTOCK TRAY 15 DEG RIGHT OF HIGHSIDE LOOKING DOWNHOLE. TWO Co60 RA BEADS PLACED IN WHIPSTOCK AT 6987.5'. WHIPSTOCK SCHEMATIC IN WELLVIEW ATTACHMENTS. 11/25/09 ATTEMPTED TO BLEED T ABOVE SSSV UNABLE TO BLEED TO 0 PSI APPEARS SSSV NOT HOLDING POTENTIALLY DUE TO LOW T PRESSURE 12/24/09 GAUGE TBG 2.78" TO 6274' RKB. MEASURED BHP @ 6650' RKB (2565 PSI) & GRADIENT @ 6525' RKB (2507 PSI) SET CATCHER @ 6274' RKB. PULLED DMY VLV's @ 4496 & 3590' RKB. IN PROGRESS. 12/25/09 PULLED DV @ 2403' RKB. SET 1/4" OV @ 4496. SET GLV'S © 3590' & 2403' RKB. PULLED CATCHER © 6274' RKB. TEST TBG BELOW GLM © 4496' RKB W/ D &D HF, GOOD. COMPLETE. r Time Logs. Date From To ! Dur S. Depth E. Depth Phase Code Subcode T Comment 20:48 23:42 2.90 8,747 8,875 PROD1 DRILL DRLG P Reemed down from 8730'. Drilling ahead, 1.4 BPM, 0.4 BPM returns, 2400 CTP, 12K RIW, 1 -2K WOB, 100 -250 psi motor work. 3280 BHP. 10 FPH ROP increased to 80 FPH at at 8758', pumped 15 Bbls sweep. 23:42 00:00 0.30 8,875 8,500 PROD1 DRILL WPRT P Wiper to window 12/07/2009 TD well at 8975', conditioned hole and ran liner. 00:00 02:42 2.70 8,500 8,875 PROD1 DRILL WPRT P Continue wiper trip to window. Same issues while running back to bottom. Hole is good until 8620'. Dropped pump rate to .6 BPM to pass and resume 1.5 BPM at 8670' to bottom. 02:42 03:42 1.00 8,875 8,940 PROD1 DRILL DRLG P Continue drilling, 1.45 BPM, 0.4 BPM returns, 3400 CTP, 3350 BHP, 12K RIW, 32K PUW, 70 - 100 ROP at 1 -2K WOB and 200 psi motor work 03:42 04:24 0.70 8,940 8,975 PROD1 DRILL DRLG P PUH to 8800', clean PU. Continue drilling, 1.45 BPM, 0.4 BPM returns, 3400 CTP, 3350 BHP, 12K RIW, 32K PUW, 60 - 100 ROP at 1 -2K WOB and 200 psi motor work 04:24 08:54 4.50 8,975 6,238 PROD1 DRILL WPRT P Planned TD. Wiper trip with tie -in Pull up through 5" Liner Got good cuttingd from 5 " RBIH Tie in +4' Correction 08:54 10:24 1.50 8,620 6,872 PROD1 DRILL TRIP P 8620, POOH laying in Alpine Beaded Pill 10:24 11:00 0.60 6,872 5,322 PROD1 DRILL TRIP P 6872, Paint 6800" End of Pipe Flag Continue out of well 11:00 12:00 1.00 5,322 0 PROD1 DRILL TRIP P 5322' Paint 5250 End of pipe flag Continue out of well 12:00 12:48 0.80 0 0 PROD1 DRILL PULD P PJSM, Monitor well, pull BHA #5 out of well 12:48 13:18 0.50 0 0 COMPZ CASING SFTY P PJSM, Rig up floor to run tubing, Set crown and floor saver. Move PDL 13:18 15:48 2.50 0 1,730 COMPZ CASING PUTB P P/U L1 Liner 15:48 17:18 1.50 1,730 1,730:. COMPZ CASING PULD P P/U coil Track and make up to liner, surface test 17:18 18:18 1.00 1,730 6,980 COMPZ CASING TRIP P RIH 18:18 19:18 1.00 6,980 8,652 COMPZ CASINGTRIP P Correct to flag, +14, 26K PUW, 14K RIW. Continue RIH. Second falg came in +2 19:18 19:36 0.30 8,652 6,969 COMPZ CASING TRIP P 12K RIW 40K PUW with .3 BPM, Increase pump rate to 1.6 BPM, 3600 CTP. 23K PUW, shut down pump, 25K PUW. PUH to tie in to gamma 19:36 19:54 0.30 6,969 6,969 COMPZ CASING DLOG P Tie in, , +4', deployment sleeve is at 6969' 19:54 21:00 1.10 6,969 0 COMPZ CASING TRIP P POOH, 0.6 in, 0.1 out. 21:00 21:24 0.40 0 0 COMPZ CASING SFTY P Flow check well and PJSM for LD and PU BHA Page 7 of 27 • • Time Logs Date ` From To Dur S. Depth E. Depth Phase Code Subcode_ T Comment 21:24 21:54 0.50 0 0 COMPZ CASING PULD P Lay down liner running BHA 21:54 23:24 1.50 0 0 PROD2 RPEQPI PULD P Service injector, Install 2 PIP tags in wipstock. PU whipstock BHA 23:24 00:00 0.60 0 4,000 PROD2 RPEQP1TRIP P RIH 12/08/2009 RIH setting whipstock on depth 6912', 6900' TOWS, POOH, PU milling BHA, mill window with 8' of rat hole. TOW= 6904', BOW= 6910'. POOH, PU Drilling BHA with 2.6 deg AKO, Drill ahead drilling build section 6918' - 7003'. Losses last 24hr up to midnight = 476 bbrls 00:00 00:54 0.90 4,000 6,700 PROD2 RPEQP1TRIP P Continue RIH 00:54 01:24 0.50 6,700 6,960 PROD2 RPEQP1DLOG P Tie -in log, +18', CCL to 6960' 01:24 01:42 0.30 6,960 6,913 PROD2 RPEQP1WPST P PUH to set depth at 6912.9', Top of whipstock will be 6900'. Set TF at 0 deg (high side) Close EDC and roll pump at .6 BPM. Tool set at 2800 CTP, setting 4K down. Shut down pump and POOH. 01:42 03:00 1.30 6,913 0 PROD2 RPEQP1TRIP P POOH, 0.65 BPM in, 0.1 BPM out. 03:00 03:30 0.50 0 0 PROD2 RPEQP1 PULD P Lay down WS setting BHA 03:30 04:00 0.50 0 0 PROD2 WHPST BOPE P Bi Weekly Function test of BOPE 04:00 04:30 0.50 0 0 PROD2 WHPST PULD P M/U Window milling BHA #8, surface test All good 04:30 05:30 1.00 0 6,720 PROD2 WHPST TRIP P Trip in hole 05:30 05:45 0.25 6,720 6,755 PROD2 WHPST DLOG P 6720, Perform Gamma tie In for a +15' Correction, continue in well 05:45 06:00 0.25 6,755 6,905 PROD2 WHPST TRIP P 6905, Dry tag whipstock, Pick up and RIH to mill 06:00 12:30 6.50 6,905 6,909 PROD2 WHPST MILL P 6904.3, Call pinch point, TOW Start time Milling 1.4 In 1.1 Out, Reduced rate due to vibration BHP =3200 12:30 14:42 2.20 6,909 6,918 PROD2 WHPST MILL P Drilling formation, holding ROP to 2 FPH for first four feet, increasing ROP and WOB 14:42 15:42 1.00 6,918 6,918 PROD2 WHPST MILL P Back ream window, dry pass clean 15:42 16:54 1.20 6,918 0 PROD2 WHPST TRIP P POOH 16:54 17:06 0.20 0 0 PROD2 WHPST SFTY P PJSM for laying down BHA #8 17:06 19:21 2.25 0 0 PROD2 DRILL PULD P Lay down BHA #8, PU /MU BHA #9 19:21 20:36 1.25 0 6,730 PROD2 DRILL TRIP P RIH BHA #9 20:36 20:51 0.25 6,730 6,748 PROD2 DRILL DLOG P Tie in depth to Gamma, +18' correction, RIH 20:51 22:12 1.35 6,748 6,917 PROD2 DRILL TRIP P Tag up at window 6910', with 0 deg TF. PUH Orient 10 deg right of HS, RIH tag 6911'. PUH Orient 10 deg left of HS TF RIH tag 6910.5'. PUH orient 0 Deg TF, RIH 8 FPM, POP through. tag 6916.5', PUH online with pumps. 22:12 00:00 1.80 6,918 7,003 PROD2 DRILL DRLG P Drill ahead 1.4 BPM, 2180 CTP off bottom, 2435 CTP on bottom. 2 -3K DHWOB. 10 -20 FPH Page 8 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/09/2009 24 hr Summary Drill /Land build section 6918' -7165' MD. POOH for AKO change 1.2 deg, PU /MU Resistivity section of BHA. Drill 1B-17L2 lateral 7165'- 7633'. Total loses for last 24hrs= 653bbrls 00:00 00:33 0.55 7,003 7,015 PROD2 DRILL DRLG P Drilling Ahead 00:33 00:54 0.35 7,015 7,015 PROD2 DRILL WPRT P Wiper trip back to 6915.0', 30K CTW 00:54 04:09 3.25 7,015 7,133 PROD2 DRILL DRLG P Drill Ahead 04:09 04:24 0.25 7,133 7,113 PROD2 DRILL WPRT P Bha wiper 75' 30K CTW 04:24 05:54 1.50 7,133 7,165 PROD2 DRILL DRLG P Drill Ahead 05:54 07:12 1.30 7,165 0 PROD2 DRILL TRIP P POOH for lateral BHA. Losses while POOH at .3 BPM 07:12 09:12 2.00 0 0 PROD2 DRILL PULD P Lay down Build BHA, PU lateral BHA 09:12 10:24 1.20 0 6,700 PROD2 DRILL TRIP P RIH, losing .5 BPM while RIH pumping .5 BPM 10:24 10:36 0.20 6,730 6,780 PROD2 DRILL DLOG P Tie in, +17'. Close EDC 10:36 10:48 0.20 6,780 7,165 PROD2 DRILL TRIP P Continue RIH. No issues at window 10:48 13:48 3.00 7,165 7,265 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .8 BPM returns, 2370 CTP, 3215 BHP, 14K RIW, 1 - 2K WOB, 200 -300 psi motor work, 20 - 50 ROP 13:48 14:36 0.80 7,265 6,918 PROD2 DRILL DLOG P MAD pass to window 14:36 15:06 0.50 6,918 7,265 PROD2 DRILL WPRT P wiper in hole 15:06 18:36 3.50 7,265 7,415 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .8 BPM returns, 2400 CTP, 3230 BHP, 14K RIW, 1 - 2K WOB, 200 -300 psi motor work, 30 - 60 ROP. Pump 10 bbls. geo -vis sweep 18:36 19:27 0.85 7,415 7,415 PROD2 DRILL WPRT P Wiper trip back to window (6920'), 29K CTW 19:27 21:57 2.50 7,415 7,565 PROD2 DRILL DRLG P Drill Ahead, 1.6K DHWOB, 8.8K surface CTW, 1.4 BPM in, .8 BPM out, 2500 off bottom CTP, 2800 on bottom CTP. 21:57 23:03 1.10 7,565 7,565 PROD2 DRILL WPRT P Wiper trip back to window (6920'), 29K CTW, Tie in with RA marker -1' correction. RIH, Slight tag at 7466'. Wipe back through area. RIH without any weight change, Cont. RIH 23:03 23:42 0.65 7,565 7,620 PROD2 DRILL DRLG P Drill Ahead, 1.6K DHWOB, 8.8K surface CTW, 1.4 BPM in, .85 BPM out, 2526 off bottom CTP, 2735 on bottom CTP. 23:42 23:51 0.15 7,620 7,620 PROD2 DRILL WPRT P BHA wiper trip, 25.5K CTW 23:51 00:00 0.15 7,620 7,636 PROD2 DRILL DRLG P Drill Ahead 60-70 FPH, 1.6K DHWOB, 10K surface CTW, 1.4 BPM in, .8 BPM out, 2526 off bottom CTP, 2735 on bottom CTP. 12/10/2009 Drill 1B-17L2 lateral 7633' -8280' with .75 -1 BPM losses. Total losses for last 24hrs= 1380bbrls Page 9 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase ` Code Subcode T Comment 00:00 00:15 0.25 7,636 7,645 PROD2 DRILL DRLG P Drill Ahead 60 -70 FPH, 1.6K DHWOB, 10K surface CTW, 1.4 BPM in, .8 BPM out, 2526 off bottom CTP, 2735 on bottom CTP. 00:15 00:42 0.45 7,645 7,654 PROD2 DRILL WPRT P PUH, pumping 5bbrl new mud sweep, Giving DD time to project plan for Geo. 00:42 01:42 1.00 7,654 7,715 PROD2 DRILL DRLG P Drill Ahead 60 -70 FPH, 1.6K DHWOB, 12K surface CTW, 1.46 BPM in, .73 BPM out, 2526 off bottom CTP, 2835 on bottom CTP. 01:42 02:42 1.00 7,715 7,715 PROD2 DRILL WPRT P Wiper trip back to window (6920') 29K CTW 02:42 04:06 1.40 7,715 7,764 PROD2 DRILL DRLG P Drill Ahead 60 -80 FPH, 1.7K DHWOB, 10K surface CTW, 1.46 BPM in, .73 BPM out, 2526 off bottom CTP, 2835 on bottom CTP. 7764' Stalling X 5, Transition area from C3 to C4. 04:06 04:12 0.10 7,765 7,765 PROD2 DRILL DRLG P Drilling Ahead with caution. Lower pump rate 1.3 BPM, drill through tough area, start stacking surface weight, PUH. 42K break free. Wiper trip back to 7400'. 04:12 05:30 1.30 7,765 7,828 PROD2 DRILL DRLG P Drill Ahead 70 -80 FPH, 1K DHWOB, 12K surface CTW, 1.43 BPM in, .56 BPM out, 2526 off bottom CTP, 2735 on bottom CTP. 05:30 07:30 2.00 7,828 7,828 PROD2 DRILL WPRT P Lost all returns, PUH pumping sweep. Wiper to window 07:30 08:30 1.00 7,828 7,840 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .2 BPM returns, 2470 CTP, 3175 BHP, 14K RIW, 2 -3K WOB, 200 -300 psi motor work, 10 - 20ROP with lots of stalls 08:30 08:54 0.40 7,840 7,875 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .2 BPM returns, 2500 CTP, 3160 BHP, 14K RIW, 1 - 2K WOB, 200 psi motor work, 70 -100 ROP, limiting ROP to 100. At 7875' and 7925' pump 5 Bbls Geo -vis sweep and PUH to 7775', 30K PUW, 27K while PUH. Continue Drilling 08:54 09:06 0.20 7,875 7,875 PROD2 DRILL WPRT P At 7875' pump 5 Bbls Geo -vis sweep and PUH to 7775', 30K PUW, 27K while PUH. 09:06 10:30 1.40 7,875 7,925 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .3 BPM returns, 2500 CTP, 3180 BHP, 14K RIW, 1 - 2K WOB, 200 psi motor work, 50 -70 ROP. 10:30 10:42 0.20 7,925 7,925 PROD2 DRILL WPRT P 7925 pump 5 Bbls Geo -vis sweep and PUH to 7775', 30K PUW, 27K while PUH. 10:42 11:42 1.00 7,925 7,975 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .3 BPM returns, 2500 CTP, 3200 BHP, 14K RIW, 1 - 2K WOB, 200 psi motor work, 40 -70 ROP. Page 10 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:42 13:18 1.60 7,975 7,978 PROD2 DRILL WPRT P Wiper to window with tie -in, +3' 13:18 16:00 2.70 7,978 8,080 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .4 BPM returns, 2500 CTP, 3200 BHP, 14K RIW, 1 - 2K WOB, 200 psi motor work, 25 -70 ROP. Pumping 5 Bbls. sweep every 30 minutes. Some differential sticking. 16:00 17:30 1.50 8,080 8,080 PROD2 DRILL WPRT P Geo -wiper to 7131'. 28K CTW. 17:30 19:00 1.50 8,080 8,130 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .3 BPM returns, 2500 CTP, 3200 BHP, 14K RIW, 1 - 2K WOB, 200 psi motor work, 40 -70 ROP. 19:00 20:30 1.50 8,130 8,130 PROD2 DRILL WPRT P Wiper Trip back to window 6920'. 30K CTW 20:30 21:00 0.50 8,130 8,165 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM out, 2526 CTP, 3179 BHP, 14K RIW, 1 - 2K WOB, 200 psi motor work, 40-70 ROP. 21:00 21:15 0.25 8,165 8,165 PROD2 DRILL WPRT P Surface weight stacking -4K, PU for BHA, 30K CTW. 21:15 22:30 1.25 8,165 8,220 PROD2 DRILL DRLG P Drilling ahead, 1.3 BPM, .34 BPM out, 2226 CTP, 3161 BHP, 2-4K surface weight, 2.5K WOB, 20-40 FPH, 22:30 23:30 1.00 8,220 8,280 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .48 BPM out, 2426 CTP, 3196 BHP, 9K surface weight, 1.2K WOB, 50 -60 FPH, 23:30 00:00 0.50 8,280 8,280 PROD2 DRILL WPRT P Wiper Trip back to window 6920'. 29K CTW. 12/11/2009 Drill 1B-17L2 lateral 8280' to 8910' with 1 BPM losses. Total losses for last 24hrs= 1362bbrls 00:00 01:09 1.15 8,280 8,280 PROD2 DRILL WPRT P Continue wiper trip to window 6920'. 01:09 02:09 1.00 8,280 8,330 PROD2 DRILL DRLG P Drill ahead 1.45 BPM in, .45 BPM out, 2565 CTP, 3184 BHP, 1.5K WOB, 8K surface wt. 70-80 FPH 8330', slow ROP's possible transition from C2 -C3 02:09 04:09 2.00 8,330 8,430 PROD2 DRILL DRLG P Weight check, 30K CTW, Drill ahead 1.46 BPM in, .4 BPM out, 2K WOB, 6 -7K surface CTW, 40- 50FPH, 3179 BHP. Stall 8320', offline pumps PUH, Drill ahead 04:09 06:09 2.00 8,430 8,430 PROD2 DRILL WPRT P Wiper Trip back to window, 32K CTW. Tie in depth to RA marker 06:09 07:27 1.30 8,430 8,503 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .4 BPM returns, 2400 CTP, 3170 BHP, 13K RIW, 1 - 2K WOB, 200 psi motor work, 50 -100 ROP. Pumping 5 Bbls. sweeps every hour. 07:27 08:15 0.80 8,503 8,503 PROD2 DRILL WPRT P Wiper trip to above loss zone at 7825' Page 11 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code ` Subcode T Comment 08:15 09:33 1.30 8,503 8,580 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .4 BPM returns, 2400 CTP, 3170 BHP, 11K RIW, 1 - 2K WOB, 200 psi motor work, 50 -100 ROP. Pumping 5 Bbls. sweeps every hour. 09:33 11:33 2.00 8,580 8,580 PROD2 DRILL WPRT P Wiper trip to window, 29K PUW 11:33 13 :03 1.50 8,580 8,675 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .4 BPM returns, 2400 CTP, 3170 BHP, 11K RIW, 1 - 2K WOB, 200 psi motor work, 50 -100 ROP. Pumping 5 Bbls. sweeps every hour. 13:03 14:03 1.00 8,675 8,675 PROD2 DRILL WPRT P Stacking weight, wiper to 7825', 28K PUW 14:03 14:45 0.70 8,675 8,686 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .4 BPM returns, 2300 CTP, 3140 BHP, 11K RIW, Stacking weight at surface, 0 to -3K for 2 - 3K WOB, 150 psi motor work, 10- 15ROP. Pumping 5 Bbls. sweeps every hour. 14:45 15:15 0.50 8,686 8,730 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .4 BPM returns, 2300 CTP, 3170 BHP, Stacking weight at surface, 2 - OK , 1 - 2K WOB, 200 - 300 psi motor work, Limiting ROP to 100 FPH. 15:15 17:21 2.10 8,730 8,730 PROD2 DRILL WPRT P Wiper to window, 5 Bbls. sweep. 30K PUW 17:21 19:12 1.85 8,730 8,880 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .4 BPM returns, 2400 CTP, 3170 BHP, Stacking weight at surface, 5 - OK , 1 - 2K WOB, 200 - 300 psi motor work, Limiting ROP to 100 FPH. 19:12 21 :57 2.75 8,880 8,880 PROD2 DRILL WPRT P Wiper to window, 6920', 30K PUW, Tie in depth to RA marker. +6' correction. 8410', 8680, 8760, Set down weight, While RIH to bottom, PU working/backreaming areas. 21:57 22:18 0.35 8,880 8,910 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM returns, 2320 CTP, 3118 BHP, Stacking weight at surface, 3 - OK , 1 - 2K WOB, 200 - 300 psi motor work, Limiting ROP to 70 -80 FPH. 22:18 22:30 0.20 8,910 8,910 PROD2 DRILL WPRT P Surface weight stacking -3 to -5K PUH for BHA wiper 22:30 23:00 0.50 8,910 8,910 PROD2 DRILL OTHR T On bottom to drill, surface weight stacking -5 to -2K. PU, 45K STUCK. Work pipe up and down trying to pull free. Pull 45 -50K, 8 Times, Indications CT stuck above. No readings on WOB sensor. Page 12 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 8,910 8,910 PROD2 DRILL WPRT P Offline with pumps 5 minutes leaving CT in compression -3K Surface weight. Start to get readings on weight on bit sensor indicating bit movement, CT sliding. PUH, pull free 41K. Continue PUH working bad areas 8410', 8680', 8760'. 12/12/2009 Drill 1B-17L2 lateral 8910' to 9320' with 1 BPM losses. Total losses for last 24hrs= 1210bbrls 00:00 00:45 0.75 8,910 8,934 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM returns, 2320 CTP off bottom, 3171 BHP, Stacking weight at surface, -10 -OK, 1.5 - 2K WOB, 200 - 300 psi motor work, Limiting ROP to10 -30 FPH. 8925' Surface weight +5K, Drilling Ahead 00:45 01:00 0.25 8,934 8,934 PROD2 DRILL WPRT P Surface weight stacking -10K, WOB 0, PUH, pull heavy 38K, continue PUH, BHA wiper. 01:00 01:06 0.10 8,934 8,938 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM returns, 2436 CTP off bottom, 3154 BHP, Stacking weight at surface, -10 - OK , 1K WOB, 100 psi motor work, ROP to10 FPH. WOB drop off to .2 to .4K PU weight check, 34K PUW, RIH to drill 1.5K WOB, 2550 CTP, Drill Ahead through hard stringers possible fault. 01:06 01:30 0.40 8,938 8,945 PROD2 DRILL DRLG P Break through Drill ahead, 1.4BPM in, .5 BPM out, 2520 on bottom, 2320 off bottom CTP, 3167 BHP, 200 psi motor work. 60 -70 FPH 01:30 01:36 0.10 8,945 8,945 PROD2 DRILL WPRT P WOB & Differential dropping off, PUH 34K PUW. Inclination not dropping, Continue PUH diagnose BHA,. BHA ok. RIH to drill 01:36 01:57 0.35 8,945 8,958 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM returns, 2290 CTP off bottom, 2500 on bottom, 3189 BHP, Stacking weight at surface, -10 - OK , 1.5 - 2K WOB, 200 - 300 psi motor work, ROP to 10 -50 FPH. 01:57 02:12 0.25 8,958 8,958 PROD2 DRILL OTHR T PUH weight check, 42K PUW, pull free, RIH, unable to get weight to bit, PUH 50K X 4...Stuck..No readings on WOB. offline with pumps. 02:12 03:39 1.45 8,958 8,680 PROD2 DRILL WPRT P Pull Free 40K, online with pumps 1.4 BPM in .5 BPM out, 2320 CTP, Wiper trip back to loss zone. 7825'. 03:39 04:00 0.35 8,680 8,958 PROD2 DRILL WPRT P Set down weight 8680', 8760, 8930 PUH back reaming. Page 13 of 27 • • Time Logs Date ` From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:06 1.10 8,958 8,972 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM returns, 2290 CTP off bottom, 2500 on bottom, 3159 BHP, Stacking weight at surface, -10 - OK , 1.8 - 2K WOB, 200 - 300 psi motor work, ROP to 10 -20 FPH. 05:06 06:00 0.90 8,972 8,980 PROD2 DRILL DRLG P Weight check 34K, Drill ahead 1.4BPM in, .5BPM out, 2350 off, 2550 on bottom CTP, -10K CTW, 1.5K WOB, 10 -20 FPH, 3184 BHP. WOB drops off right away Continue to pick up trying maintain WOB drilling ahead. 06:00 06:24 0.40 8,980 9,019 PROD2 DRILL DRLG P ROP has picked up to 70 -90 with surface weight in the positive range 06:24 07:54 1.50 9,019 6,930 PROD2 DRILL WPRT P Stacking weight at surface, wiper to window, 10 Bbls. Hi -Vis pill 07:54 08:06 0.20 6,930 6,960 PROD2 DRILL DLOG P Tie in to RA, +3' 08:06 09:18 1.20 6,960 9,019 PROD2 DRILL WPRT P Wiper back down 09:18 10:06 0.80 9,019 9,074 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM returns, 2290 CTP, 3150 BHP, 7K RIW, Stacking weight at surface -1 K 1K WOB, 200 - 300 psi motor work, Limiting ROP to 80 FPH. 10:06 10:24 0.30 9,074 9,077 PROD2 DRILL DRLG P Stacking weight, ROP decrease to <10 FPH. 10K overpulls when pick up off bottom, 30K up and 9K RIW. Decrease pump rate to 1.3 BPM, returns still 0.5 BPM. 10:24 11:12 0.80 9,077 9,113 PROD2 DRILL DRLG P ROP increase to 80. 11:12 12:48 1.60 9,113 9,113 PROD2 DRILL WPRT P Wiper to above loss zone at 7825' 12:48 15:12 2.40 9,113 9,170 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM returns, 2320 CTP, 3155 BHP, Stacking weight at surface, -10 - OK , 1.8 - 2K WOB, 200 - 300 psi motor work, ROP varies between 2 and 100 FPH. 15:12 18:12 3.00 9,170 9,170 PROD2 DRILL WPRT P Wiper to window, 29K PUW 18:12 21:12 3.00 9,170 9,200 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM returns, 2350 CTP off bottom, 2550 on bottom, 3155 BHP, Stacking weight at surface, -10 - OK , 1.8 - 2K WOB, 200 - 300 psi motor work, ROP varies between 2 and 100 FPH. 9184' Hard drilling, stacking wt. -16K, hard to maintain WOB, Repeat PU /RIH to drill ahead maintaining WOB 21:12 22:42 1.50 9,200 9,297 PROD2 DRILL DRLG P Break through, Drilling 40 -50 FPH, -17K Surface wt., 1.4 BPM in, .53 out, 2350 off bottom, 2650 on bottom, 3184 BHP, 1.5K WOB Page 14 of 27 ! A Time Logs Date From To Dur S. Depth E. Depth Phase ` Code Subcode T Comment 22:42 22:54 0.20 9,297 9,297 PROD2 DRILL WPRT P BHA wiper, 32K PUW 22:54 00:00 1.10 9,297 9,320 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, .5 BPM returns, 2320 CTP, 3155 BHP, Stacking weight at surface, -16 - OK , 1.8 - 2K WOB, 50 - 300 psi motor work, ROP varies between 2 and 100 FPH drilling through hard stringers 12/13/2009 TD 1B-17L2 at 9190'. Perform cleanout run. PU /run liner setting at 9185'. 00:00 01:45 1.75 9,320 9,320 PROD2 DRILL DRLG P Conference call to town. Concerns of drilling through "D" Zone. Decision: At scheduled wiper trip wipe back to loss zone 7825'. Drill to a TD of 9370'. Perform Wiper trip to loss zone 7825'. 30K PUW. no over pulls. Wiper looked good 01:45 04:15 2.50 8,957 8,957 PROD2 DRILL RGRP T While RIH injector brake set. Call out electircian, electrician call Peter with Academy. Diagnose problem. Orient TF to TF hole was drilled. Continue circulating 1.2 BPM in, .27 out, pumping 10bbrl sweep. NPT= 2.5hrs Injector down. (Bad Relay in storage reel) 2.5 Hours of Billable Rig Repair time 04:15 04:45 0.50 8,957 9,190 PROD2 DRILL WPRT P Injector working, bypassed relay on storage reel. PUH 20'. PUW =27K. RIH to drill. 04:45 06:15 1.50 9,190 7,000 PROD2 DRILL WPRT P Tag 9190', (Dzone). PU, PUW =39KX 3, chains slipping due to dirty gripper blocks. Concerns of getting stuck and not being able to pull full capacity of injector. Motor stalls when tagging at 9190' with correct TF as drilled. Wiper trip to window, talk to town. 06:15 07:15 1.00 7,000 0 PROD2 DRILL WPRT P Continue wiper trip to the Swab. Open EDC in 5 ", 1.5 BPM in , .5 out. 24 Hour notification for BOP test, witnessing waived by Chuck Sheve 07:15 08:15 1.00 0 0 PROD2 DRILL SVRG P Injector Maint. Clean and inspect gripper blocks, replace relay for reel motor and test 08:15 11:15 3.00 0 9,190 PROD2 DRILL WPRT P Wiper trip in hole, tie in to gamma, + 17' 11:15 13:15 2.00 9,190 6,900 PROD2 DRILL DISP P Lay in liner pill with alpine beads in OH 13:15 14:27 1.20 6,900 0 PROD2 DRILL TRIP P POOH 14:27 15:09 0.70 0 0 PROD2 DRILL PULD P Lay down drilling BHA 15:09 16:27 1.30 0 0 COMPZ CASING PUTB P RU for liner operations 16:27 16:57 0.50 0 0 COMPZ CASING SFTY P PJSM for liner operations Page 15 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:57 17:27 0.50 0 0 COMPZ CASING PUTB P PU liner string 17:27 17:42 0.25 0 0 COMPZ CASING SFTY P Hold Safety Drill, taking a kick while running liner 17:42 18:12 0.50 0 0 COMPZ CASING SFTY P Crew Change, Hold PJSM running liner 18:12 19:21 1.15 0 0 COMPZ CASING PULD P Continue running liner 19:21 19:36 0.25 0 0 COMPZ CASING SFTY P PJSM, PU deployment sleeve, coiltrack. MU to CT 19:36 20:36 1.00 0 0 COMPZ CASING PULD P MU deployment sleeve, coiltrack to CT 20:36 22:18 1.70 0 6,800 COMPZ CASING RUNL P RIH, pumping minimum rate 22:18 22:54 0.60 6,800 7,820 COMPZ CASING RUNL P Offline with pumps, closed EDC. Record up and down weights. RIH =14K, PUW =26K RIH through window 20FPM, Increasing to 50 FPM running liner to bottom 22:54 23:24 0.50 7,820 9,185 COMPZ CASING RUNL P Slow down to 2.5 FPM to tie in depth with Gamma. Stacking weight. PUH 29K PUW. RIH to bottom. 12K =RIW, 3K WOB, pumping .2 BPM in, 883 CTP. 23:24 23:33 0.15 9,185 7,994 COMPZ CASING RUNL P Tag 9185' MD, -16K CTW. 7K WOB. Online with pumps max rate. 1.56 BPM 3300psi CTP, PUH releasing from liner. 23K PUW. Liner released. Stop at 9100' subtracting liner from bit depth. Corrected depth= 7994.47' 23:33 00:00 0.45 7,994 6,895 COMPZ CASING RUNL P POOH 40 FPM .7 BPMin, .07 BPM out, to window. Tie in to RA marker 12/14/2009 Set billet with OH anchor on depth. POOH Perform full BOP test, waived by the state. 10hr BOP test. RIH to sidetrack off billet L2 -01 with 1.2 AKO. 00:00 02:30 2.50 6,895 0 COMPZ CASING RUNL P Tie in RA marker. +19' correction. Places bottom of liner 9204'. TOL= 8098.5'. POOH. 02:30 02:45 0.25 0 0 COMPZ CASING SFTY P At surface, Hold PJSM LD BOT tools, PU /MU BHA 02:45 04:30 1.75 0 0 PROD3 DRILL PULD P LD /PU /MU tools. 04:30 06:36 2.10 0 6,760 PROD3 DRILL TRIP P Open EDC, pumping minimum rate RIH 06:36 06:48 0.20 6,760 6,780 PROD3 DRILL DLOG P Tie in, +17', close EDC and continue RIH 06:48 07:18 0.50 6,780 8,093 PROD3 DRILL TRIP P Continue RIH 07:18 07:30 0.20 8,093 8,090 PROD3 DRILL WPST P Tag liner top at 8092' with 2.5K WOB, 27K PUW, 15K RIW. Set down 200 WOB at 8090', pump .25 BPM, anchor set at 3900 CTP. 26K PUW 07:30 09:00 1.50 8,090 0 PROD3 DRILL TRIP P POOH, .3 BPM at 50 FPM in open hole, .6 BPM at 100 FPM in cased hole. Page 16 of 27 c�nochiiiip Alaska ConocoPhillips(Alaska) Inc. • Kuparuk River Unit Kuparuk 1B Pad 1B-17L2 500292246161 Baker Hughes INTEQ Definitive Survey Report HU BAKER GHES 28 December, 2009 ra t Conoco Phillips Willi 1" OCOPh[lFIpS Definitive Survey Report 4t Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1B-17 Project: Kuparuk River Unit TVD Reference: 1B @ 102.00ft (1B-17) Site: Kuparuk 1B Pad MD Reference: 1B @ 102.00ft (1B-17) Well: 1B-17 North Reference: TRUE Welibore: 1 B - 17 Survey Calculation Method: Minimum Curvature Design: 1B Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S _ +E!-W Northing Easting °[1LS, Section Survey Teal Name Annotation (ft) ( °) ' ( °) (ft) (ft) (ft) (ft) (ft) ( f t ) (1100) (ft) 6,898.80 28.78 148.76 6,417.78 6,315.78 - 1,557.16 905.76 5,968,096.24 551,201.46 1.24 1,398.58 GCT -MS (1) TIP 1B - 6,903.00 28.76 148.76 6,421.46 6,319.46 - 1,558.89 906.81 5,968,094.51 551,202.52 0.48 1,400.18 MWD (2) KOP 6,930.16 37.35 145.72 6,444.21 6,342.21 - 1,571.31 914.85 5,968,082.15 551,210.64 32.20 1,412.10 MWD (2) Interpolated AZI 6,945.05 44.37 144.90 6,455.46 6,353.46 - 1,579.31 920.40 5,968,074.19 551,216.24 47.28 1,420.12 MWD (2) 6,990.03 61.44 128.09 6,482.61 6,380.61 - 1,604.66 945.28 5,968,049.00 551,241.29 48.05 1,452.37 MWD (2) 7,019.98 71.04 130.78 6,494.67 6,392.67 - 1,622.07 966.41 5,968,031.74 551,262.54 33.09 1,478.29 MWD (2) 7,050.03 82.39 139.39 6,501.57 6,399.57 - 1,642.76 986.97 5,968,011.19 551,283.23 46.92 1,504.85 MWD (2) 7,080.11 93.10 148.91 6,502.76 6,400.76 - 1,667,07 1,004.52 5,967,987.00 551,300.94 47.59 1,529.87 MWD (2) 7,109.99 99.10 136.58 6,499;57 6,397.57 - 1,690:67 1,022.45 5,967,963.53 551,319.02 45.66 1,554.99 MWD (2) 7,135,08 103.04 124.10 6,494.74 6,392.74 - 1,706.58 1,041.16 5,967,947.74 551;337.84: 51.27 1,578.13 MWD (2) 7,165.26 102.92 111.52 6,487.93 6,385.93 - 1,720.27 1,067.11 5,967,934.22 551,363.89 40.62 1,607.25 MWD (2) 7,195.42 103.09 106.85 6,481.14 6,379.14 - 1,729.93 1,094.86 5,967,924.76 551,391.69 15.10 1,636.62 MWD (2) 7,225.35 102.43 102.23 6,474.53 6,372.53 - 1,737.25 1,123.11 5,967,917.62 551,419.99 15.22 1,665.63 MWD (2) 7,255.17 102.11 97.34 6,468.19 6,366.19 - 1,742.20 1,151,81 5,967,912.86 551,448.72 16.06 1,694.23 MWD (2) 7,285.54 102.09 93.00 6,461.82 6,359.82 - 1,744.88 1,181.38 5,967,910.39 551,478.30 13.97 1,722.82 MWD (2) 7,320.23 101.49 87.08 6,454.72 6,352.72 - 1,744.90 1,215.32 5,967,910.59 551,512.24 16.79 1,754.57 MWD (2) 7,350.34 101.21 82.55 6,448.80 6,346.80 - 1,742.23 1,244.71 5,967,913.46 551,541.61 14.78 1,781.11 MWD (2) 7,380.29 99.28 78.63 6,443.47 6,341.47 - 1,737.41 1,273.78 5,967,918.47 551,570.64 14.40 1,806.59 MWD (2) . 7,410.44 99.09 74.33 6,438.65 6,336.65 - 1,730.46 1,302.71 5,967,925.62 551,599.52 14.09 1,831.18 MWD (2) 7,440.27 97.85 70.70 6,434.26 6,332.26 - 1,721.59 1,330.85 5,967,934.67 551,627.60 12.73 1,854.35 MWD (2) 7,470.32 97.76 65.81 6,430.17 6,328.17 - 1,710.56 1,358.49 5,967,945.88 551,655.16 16.12 1,876.30 MWD (2) 7,500.38 97.76 61.39 6,426.11 6,324.11 - 1,697.32 1,385.17 5,967,959.30 551,681.74 14.57 1,896.55 MWD (2) 7,530.43 97.14 56.44 6,422.21 6,320.21 - 1,681.94 1,410.67 5,967,974.85 551,707.15 16.46 1,914.96 MWD (2) 7,560.47 96.68 51.88 6,418.60 6,316.60 - 1,664.49 1,434.84 5,967,992.47 551,731.20 15.15 1,931.38 MWD (2) 7,590.45 95.35 48.38 6,415.46 6,313.46 - 1,645,38 1,457.72 5,968,011,73 551,753.94 12.43 1,946.01 MWD (2) 7,620.24 94.27 44.34 6,412.96 6,310.96 - 1,624.89 1,479.20 5,968,032.35 551,775.28 13.99 1,958.84 MWD (2) 7,650.32 97.01 40.31 6,410.00 6,308.00 - 1,602.77 1,499.35 5,968,054.61 551,795.28 16.15 1,969.85 MWD (2) 7,680.40 97.89 35.47 6,406.10 6,304.10 -1,579.24 1,517.66 5,968,078.26 551,813.43 16.22 1,978.64 MWD 2 1 7,710.36 98.87 30.93 6,401.73 6,299.73 - 1,554.45 1,533.89 5,968,103.16 551,829.49 15.34 1,985.03 MWD (2) 7,740.62 99.88 26.00 6,396.80 6,294.80 - 1,528.21 1,548.12 5,968,129.49 551,843.54 16.42 1,989.04 MWD (2) 12/28/2009 11:27:25AM Page 3 COMPASS 2003.16 Build 69 r-` ConocoPhillips r ocoPilIIhtps Definitive Survey Report NUCf14115 Alaska Company; ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1 B -17 Project Kuparuk River Unit TVD Reference: 1B-17 @ 102.006 (1B-17) Site: Kuparuk 1B Pad MD Reference: 1B-17 @ 102.00ft (1B-17) Well; 1B-17 North Reference: TRUE Welibore: 1 B -17 Survey Calculation Method: Minimum Curvature Design: 1B-17 Database: EDM Alaska Prod v16 Survey Map Map' Vertical MD Inc Azi TVD TVDSS +NI -S +E / -W Northing Easting 0LS Section :Survey Tool Name Annotation (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ., ( /100') (ft) 7,770.35 97.51 23.34 6,392.30 6,290.30 - 1,501.51 1,560.38 5,968,156.27 551,855.62 11.91 1,991.05 MWD (2) 7,800.10 94.27 21.02 6,389.25 6,287.25 - 1,474.11 1,571.55 5,968,183.74 551,866.61 13.37 1,991.79 MWD (2) 7,830.44 90.89 24.79 6,387.88 6,285.88 - 1,446.20 1,583.34 5,968,211.72 551,878.21 16.68 1,992.93 MWD (2) 7,865.52 89.66 30.40 6,387.71 6,285.72 - 1,415.12 1,599.58 5,968,242.90 551,894.24 16.37 1,997,12 MWD (2) 7,896.47 90.22 34.83 6,387.75 6,285.75 - 1,389.06 1,616.26 5,968,269.08 551,910.75 14.43 2,003.48 MWD (2) 7,925.44 87.91 37.96 6,388.22 6,286.22 - 1,365.75 1,633.44 5,968,292.50 551,927.77 13.43 2,011.29 MWD (2) 7,955.24 88.74 41.43 6,389.09 6,287.09 - 1,342.83 1,652.47 5,968,315.54 551,946.64 11.97 2,020.97 MWD (2) 7,985.39 89,57 43.91 6,389.54 6,287.54 - 1,320.67 1,672.90 5,968,337.84 551,966.92 8.67 2,032.22 MWD (2) 8,015.24 87.94 38.28 6,390.1 6,288 19 - 1,298.19 1,692.50 5,968,360.45 551,986,37 19.63 2,042.60. MWD (2) 8,042.50 88;37 34.59 6,391.06 6,289.06 1,276.27 1,708.68 5,968,382.47 552,002.40 13.62 2,049.96 MWD (2) 8,070.23 89.23 30.58 6,391.64 6,289.64 -1,252.92 1,723.61 5,968,405.92 552,017.17 14:79 2,055.65 MWD (2) 8,100.42 90.03 25.51 6,391.84 6,289.84 - 1,226.28 1,737.80 5,968,432.65 552,031.18 17.00 2,059.49 MWD (2) 8,130.26 91.87 29.68 6,391.34 6,289.34 - 1,199.85 1,751.62 5,968,459.17 552,044.82 15.27 2,063.04 MWD (2) 8,160.33 93.53 34.14 6,389.93 6,287.93 - 1,174.36 1,767.49 5,968,484.77 552,060.52 15.81 2,068.86 MWD (2) 8,190.07 95.72 38.56 6,387.53 6,285.53 - 1,150.49 1,785.05 5,968,508.75 552,077.92 16.54 2,076.83 MWD (2) 8,220.35 96.33 39.53 6,384.35 6,282.35 - 1,127.10 1,804.02 5,968,532.26 552,096.73 3.77 2,086.28 MWD (2) 8,250.43 95.78 45.39 6,381.17 6,279.17 - 1,105.04 1,824.20 5,968,554.45 552,116.76 19.46 2,097.35 MWD (2) 8,285.29 95.53 51.13 6,377.74 6,275.74 - 1,081.96 1,850.08 5,968,577.71 552,142.48 16.40 2,113.37 MWD (2) • 8,320.32 95.63 57.08 6,374.33 6,272.33 - 1,061.53 1,878.31 5,968,598.33 552,170.57 16.91 2,132.53 MWD (2) 8,350.30 95.63 62.13 6,371.38 6,269.38 - 1,046.44 1,904.03 5,968,613.59 552,196.19 16.76 2,151.24 MWD (2) 8,380.43 96.40 67.25 6,368.22 6,266.22 - 1,033.63 1,931.11 5,968,626.57 552,223.18 17.09 2,172.03 MWD (2) 8,410.31 96.09 71.79 6,364,97 6,262.97 - 1,023.24 1,958.93 5,968,637.15 552,250.92 15.14 2,194.36 MWD (2) 8,440.41 95.47 76.18 6,361.94 6,259.94 - 1,014,98 1,987.71 5,968,645.60 552,279.64 14.66 2,218.35 MWD (2) 8,470.35 94.58 81.06 6,359.32 6,257.32 - 1,009.10 2,016.94 5,968,651.68 552,308.83 16.51 2,243.60 MWD (2) 8,500.31 94.06 85.93 6,357.06 6,255.06 - 1,005.72 2,046.61 5,968,655.26 552,338.48 16.30 2,270.15 MWD (2) 8,530.42 93.69 90.71 6,355.02 6,253.02 - 1,004.84 2,076.63 5,968,656.34 552,368.49 15.89 2,297.91 MWD (2) 8,560.32 93.69 95.94 6,353.10 6,251.10 - 1,006.57 2,106.41 5,968,654.81 552,398.27 17.46 2,326.37 MWD (2) 8,590.32 94.52 99.87 6,350.95 6,248.95 - 1,010.68 2,136.04 5,968,650.90 552,427,93 13.36 2,355.54 MWD (2) 8,620.58 96.80 96,26 6,347.96 6,245.96 - 1,014.91 2,165.85 5,968,646.87 552,457.76 14.06 2,384.91 MWD (2) 8,650.58 96.92 91.83 6,344.38 6,242.38 - 1,017.01 2,195.55 5,968,644.97 552,487.47 14.67 2,413.44 MWD (2) 8,680.58 95.65 87.91 6,341.09 6,239.09 -1,016.94 2,225.36 5,968,645.24 552,517.28 13.66 2,441.29 MWD (2) 12/28/2009 11:27:25AM Page 4 COMPASS 2003.16 Build 69 ■ .10.-' ConocoPhillips tiocoP itlips Definitive Survey Report HUGHES; Alaska Company: ConocoPhillips(Alaska) Inc. Local Coordinate Reference: 1B-17 Project: Kuparuk River Unit TVD Reference: 1B-17 @ 102.00ft (1B-17) Site: Kuparuk 1B Pad MD Reference: 1B-17 @ 102.00ft (1B-17) Well: 1B-17 North Reference: TRUE Wellbore: 1B-17 Survey Calculation Method: Minimum Curvature Design: 1B-17 Database:! EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Aai TV('-) TVDSS +N/-S +E / *W D Northing Fasting Section ! Surve y T N ame Annotation (ft) ( °) (0) (ft) (ft) (g) (ft) {ft) (ft) ( °!'100') (ft) 8,720.51 93.13 83.22 6,338.03 6,236.03 - 1,013.86 2,265.04 5,968,648.58 552,556.94 13.30 2,477.31 MWD (2) 8,750.43 91.72 80.30 6,336.77 6,234.77 - 1,009.57 2,294.62 5,968,653.07 552,586.49 10.83 2,503.45 MWD (2) 8,780.59 89.85 77.29 6,336.35 6,234.35 - 1,003.71 2,324.20 5,968,659.12 552,616.02 11.75 2,529.04 MWD (2) 8,810.45 88.01 74.27 6,336.91 6,234.91 - 996.38 2,353.14 5,968,666.65 552,644.90 11.84 2,553.50 MWD (2) 8,840.64 87.36 70.24 6,338.13 6,236.13 - 987.19 2,381.86 5,968,676.03 552,673.56 13.51 2,577.11 MWD (2) 8,870.39 87.64 71.86 6,339.43 6,237.43 - 977.54 2,409.97 5,968,685.87 552,701.60 5.52 2,599.98 MWD (2) 8,900.49 88.19 76.88 6,340.53 6,238.53 - 969.44 2,438.93 5,968,694.16 552,730.50 16.77 2,624.19 MWD (2) 8,930.03 89.91 83.07 6,341.02 6,239.02 - 964.30 2,468.00 5,968,699.50 552,759.54 21.75 2,649.55 MWD (2) 8,960.39 89.23 88.51. 6,341,24 6,239.24 - 962.07 2,498.26 5,968,701.93 552,789.78 18.06 2,677.07 MWD (2) 8,990.60 87.33 89.70 6,342.15 6,240.15 - 961.60 2,528.46 5,968,702.60 552,819.97 7.42 2,705.13 MWD (2) 9,020.50 88.31 94.43 6,343.29 6,241.29 962.68 2,558.31 5,968,701.72 552,849.82 16.14 2,733.43 MWD (2) 9,050.47 92.61 95.67 6,343.05 6,241.05 - 965.31 2,588.15 5,968,699.29 552,879.68 14.93 2,762.27 MWD (2) 9,080.39 95.81 98.55 6,340.85 6,238,85 - 969.00 2,617.75 5,968,695.80 552,909.30 14.37 2,791.27 MWD (2) 9,120.71 92.76 103.90 6,337.84 6,235.84 - 976.83 2,657.17 5,968,688.23 552,948.77 15.24 2,830.90 MWD (2) 9,150.32 93.62 111.21 6,336.19 6,234.19 - 985.74 2,685.34 5,968,679.51 552,976.99 24.82 2,860.40 MWD (2) 9,180.42 91.96 115.20 6,334.72 6,232.72 - 997.58 2,712.97 5,968,667.86 553,004.70 14.34 2,890.43 MWD (2) 9,210.20 88.46 118.51 6,334.61 6,232.61 - 1,011.03 2,739.53 5,968,654.59 553,031.34 16.17 2,920.03 MWD (2) 9,240.53 90.68 122.89 6,334.84 6,232.84 - 1,026.51 2,765.60 5,968,639.28 553,057.51 16.19 2,949.89 MWD (2) 9,270.40 86.93 125.54 6,335.46 6,233.46 - 1,043.30 2,790.28 5,968,622.66 553,082.31 15.37 2,978.93 MWD (2) 9,320.00 86.93 125.54 6,338.12 6,236.12 - 1,072.09 2,830.59 5,968,594.15 553,122.80 0.00 3,026.81 PROJECTED to TD 12/28/2009 11 :27 :25AM Page 5 COMPASS 2003.16 Build 69 • 1 i e ;t a. t * 3a j g P %' 1 k i g i , "4 i 13 \ s & 1 L \ I - ' p ) LLL F , 1 1 11 , i SEAN PARNELL, GOVERNOR U r ,. r AND P ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMhIISSION / ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. V. Cawvey Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1B -17L2 ConocoPhillips Alaska, Inc. Permit No: 209 -132 Surface Location: 502' FNL, 154' FEL, Sec. 9, T11N, R1OE, UM Bottomhole Location: 1798' FNL, 2413' FEL, Sec. 10, T11N, R10E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1B -17, Permit No. 1940450, API No. 50 -029- 22461 -00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). incerely, 4 . / r D. :el T. Seamount, Jr. Chair DATED this day of November, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 8 2009 N, PERMIT TO DRILL 20 AAC 25.005 Alaska Oil & Gas ► � Cons. Commission 1 a. Type of Work: , 1 b. Current Well Class: Exploratory ❑ Development Oil 0 ' lc. Specify if well is propo §�dTb'r! Drill ❑ Re -drill 0 Stratigraphic Test ❑ Service ❑ Development Gas ❑ . ' A Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone❑ Single Zone V l; Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket u Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 • 1B 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9600' • TVD: 6298' • Kuparuk River Field , 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 502' FNL, 154' FEL, Sec. 9, T11N, R10E, UM • ADL 25648 • Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2062' FNL, 750' FWL, Sec. 10, T11N, R10E, UM 466 12/1/2009 • Total Depth: 9. Acres in Property: 14. Distance to 1798' FNL, 2413' FEL Sec. 10, T11N, R10E, UM 2560 Nearest Property: 19300' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 102 fee 15. Distance to Nearest Well Open Surface: x - 550285 • y - 5969647 • Zone 4 KB Elevation above GL: .�e'f feet o Same Pool: 16 -08AL1 , 1605' . 16. Deviated wells: Kickoff depth: 6906 • ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 99° d Downhole: 2113 psig • Surface: 1457 psig • 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2 - 3/8" 4.7# L - 80 ST - L 1300' 8300' 6293' 9600' 6298' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 7500' 6957' 7392' 6857' Casing Length Size Cement Volume MD TVD Conductor /Structural 80' 16" 205 sx AS 1 120' 120' Surface 4200' 9 -5/8" 950 sx AS III, 400 sx CI G 4241' 4178' Intermediate Production 6588' 7" 225 sx Class G 6629' 6188' Liner 1184' 5" 160 sx Class G 7477' 6936' Perforation Depth MD (ft): Perforation Depth TVD (ft): 6907'- 6967', 7013' -7053' 6425'- 6478', 6518' -6553' 20. Attachments: Filing Fee ❑ BOP Sketch Q Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: /�,,�`(Q 22. I hereby certify that the foregoing is true and correct. Contact J. Long @ 263 - 4093(9' I0 of Printed Nam V. Cawve Title Wells Manager 111 Signature Phone 74,6 Date 0/2_776• Commission Use Only Permit to Drill . , / A PI Number: Permit Approv See cover letter Number: Z - C 50 2 , 50 9._ 2 z � ' ( 1 I Date: �� /_�0' for other requirements Conditions of approval : If box is checked, wel may not be used to explore for, test, or produce coalbed me hane, gas hydrates, or gas contained in shales: g t s.- 3,500 t o Si: Z3c f (e Samples req'd: Yes ❑ . No Mud log req'd: Yes ❑ No p• Other.. 2 s-C v p s;. A hk Tig C H2S measures: Yes gr No ❑ Directional svy req'd: Yes [] No ❑ - /6. 963 r C3(.t. c e-,,, r0 Ce i► v.. e L r, e a 7'd r. APPROVED BY THE COMMISSION // DATE: A � , COMMISSIONER For 10 -401 e vised 1/2009) l I t, 1 . Submit in Duplicate ( ) ... i . t ; .. '1 .. — / -�� � 0 / 0 , fb it - Oci • • COflOcOPhiI Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1B Pad 1B-17 1B-17 L2 Plan: Plan 2, 1B-17 L2 Standard Planning Report 19 October, 2009 BAKER HUGHES n r !N At L L.) t ConocoPhillips Wahl ConocoPhillips Planning Report BAKER KNE Alaska Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1B - 17 Company: ConocoPhillips(Alaska) Inc. TVD Reference. _` Mean Sea Level Project , Kuparuk River Unit MD Reference: i 1B © 102.00ft (1E3-17) Site: Kuparuk 1B Pad North Reference: True Well: 1 B -17 Survey Calculation Method: - Minimum Curvature Wellbore: ' 1 B -17 L2 Design; Plan 2, 1B-17 L2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1B Pad Site Position: Northing: 5,969,646.72ft Latitude: 70° 19' 40.290 N From: Map Easting: 549,457.39ft . Longitude: 149° 35' 56.057 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38 ° Well 1B Well Position +NI - 0.00 ft Northing: 5,969,647.14 ft • Latitude: 70° 19' 40.240 N +E / - 0.00 ft Easting: 550,285.37 ft . Longitude: 149° 35' 31.884 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 61.00ft Wellbore 1B-17 L2 Magnetics Model Name < Sample Date Declination Dip Angle Field Strength (a) ( (nT) BGGM2009 12/2/2009 17.45 79.81 57,361 Design Plan 2, 1B-17 L2 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,898.80 Vertical Section: Depth From (TVD) +W-S +EI W Direction (ft) (ft) (ft) r) -61.00 0.00 0.00 83.00 I 10/19/2009 2.45 :42PM Page 2 COMPASS 2003.16 Build 69 0 -'''' 1 r‘ I i \ibt � L. • ConocoPhillips • raam Conoc Phillips Planning Report BSA "ER Alaska HUGHES Database: - EDM Alaska Prod v16 Local Co- ordinate Reference: Well 16 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1B-17 @ 102.00ft (1B-17) Site: Kuparuk 1B Pad North Reference: True Well: 1B Survey Calculation Method: Minimum Curvature Wellbore: 1 B - 17 L2 Design: Plan 2, 1B L2 Plan Sections Measured TVD Below Dogleg Build ` Turn Depth. Inclination Azimuth System +NI-S +E/ -W Rate Rate Rate TFO (ft) ' ( °) ( °) (ft) (ft) (ft) ( ° /100ft) ( ° /100ft) (1100ft) ( °) Target 6,898.80 28.78 148.76 6,315.78 - 1,557.16 905.76 0.00 0.00 0.00 0.00 6,906.00 28.74 148.76 6,322.09 - 1,560.12 907.56 0.56 -0.56 0.00 180.00 6,921.00 30.07 148.29 6,335.16 - 1,566.40 911.40 9.00 8.87 -3.12 350.00 7,066.17 95.00 139.18 6,398.69 - 1,662.73 986.06 45.00 44.73 -6.28 350.00 7,141.17 95.27 105.29 6,391.78 - 1,701.99 1,048.31 45.00 0.35 -45.19 272.00 7,341.17 98.87 81.37 6,366.81 - 1,713.60 1,244.93 12.00 1.80 -11.96 280.00 7,441.17 98.67 93.51 6,351.51 - 1,709.20 1,343.47 12.00 -0.20 12.14 90.00 7,816.17 93.32 48.56 6,310.24 - 1,590.50 1,686.62 12.00 -1.43 -11.99 266.00 7,916.17 91.38 36.70 6,306.12 - 1,517.12 1,754.16 12.00 -1.93 -11.85 261.00 8,116.17 91.26 12.70 6,301.43 - 1,336.80 1,837.10 12.00 -0.06 -12.00 270.00 8,191.17 91.25 21.70 6,299.78 - 1,265.24 1,859.25 12.00 -0.02 12.00 90.00 8,391.17 99.15 44.48 6,281.44 - 1,099.47 1,966.96 12.00 3.95 11.39 70.00 8,466.17 96.72 53.23 6,271.07 - 1,050.66 2,022.85 12.00 -3.23 11.67 105.00 8,516.17 91.98 56.92 6,267.27 - 1,022.13 2,063.71 12.00 -9.48 7.38 142.00 8,766.17 91.72 86.93 6,259.01 - 945.50 2,298.54 12.00 -0.11 12.01 90.00 8,866.17 92.93 98.88 6,254.95 - 950.56 2,398.14 12.00 1.21 11.95 84.00 8,991.17 90.00 113.60 6,251.74 - 985.42 2,517.77 12.00 -2.34 11.77 101.00 9,166.17 84.68 133.95 6,259.95 - 1,082.00 2,662.30 12.00 -3.04 11.63 105.00 9,221.17 87.49 139.93 6,263.71 - 1,122.07 2,699.74 12.00 5.11 10.88 65.00 9,391.17 88.34 119.53 6,269.96 - 1,230.08 2,829.71 12.00 0.50 -12.00 272.00 9,600.00 76.24 97.35 6,298.26 - 1,295.54 3,024.21 12.00 -5.80 -10.63 240.00 i 10/19/2009 2:45:42PM Page 3 COMPASS 2003.16 Build 69 OR kGINAL ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1 B -17 Company: ConocoPhillips(Alaska) Inc. TVD Reference: -- Mean Sea Level Project~ - Kuparuk River Unit MD Reference: ` 1B-17 © 102.00ft (1B-17) Site' Kuparuk 1B Pad North Reference: True Welt: 1 B -17 Survey Calculation Method: Minimum Curvature Wellbore• 1 B -17 L2 Design: Plan 2, 1B L2 Planned Survey Measured TVD Below Vertical - Dogleg Toolface " Map Map nth I nclination Azimuth System -` +Ni. +E! W: Section Rate Azimuth Northing Basting- (ft) r) (`) (ft) (ft) (ft) (ft) ( °MOOft) r) O (ft) 6,898.80 28.78 148.76 6,315.78 - 1,557.16 905.76 709.24 0.00 0.00 5,968,096.24 551,201.46 TIP 1B - 17 6,900.00 28.77 148.76 6,316.83 - 1,557.65 906.06 709.48 0.56 - 180.00 5,968,095.74 551,201.76 6,906.00 • 28.74 148.76 6,322.09 - 1,560.12 907.56 710.66 0.56 180.00 5,968,093.29 551,203.27 KOP 6,921.00 30.07 148.29 6,335.16 - 1,566.40 911.40 713.71 9.00 - 10.00 5,968,087.03 551,207.16 End of DLS 9 7,000.00 65.34 141.91 6,387.51 - 1,613.00 945.03 741.42 45.00 -10.00 5,968,040.67 551,241.10 7,066.17 95.00 139.18 6,398.69 - 1,662.73 986.06 776.07 45.00 -5.49 5,967,991.21 551,282.45 4 7,100.00 95.35 123.90 6,395.62 - 1,685.01 1,011.20 798.31 45.00 -88.00 5,967,969.11 551,307.74 7,141.17 95.27 105.29 6,391.78 - 1,701.99 1,048.31 833.07 45.00 -89.39 5,967,952.38 551,344.96 End of DLS 45 7,200.00 96.45 98.29 6,385.76 - 1,713.95 1,105.56 888.44 12.00 -80.00 5,967,940.81 551,402.28 7,300.00 98.23 86.33 6,372.94 - 1,717.96 1,204.46 986.12 12.00 -80.71 5,967,937.46 551,501.20 7,341.17 98.87 81.37 6,366.81 - 1,713.60 1,244.93 1,026.82 12.00 -82.25 5,967,942.09 551,541.64 6 7,400.00 98.80 88.52 6,357.77 - 1,708.48 1,302.80 1,084.87 12.00 90.00 5,967,947.59 551,599.46 I 7,441.17 98.67 93.51 6,351.51 - 1,709.20 1,343.47 1,125.16 12.00 91.10 5,967,947.15 551,640.13 7 7,500.00 98.12 86.40 6,342.91 - 1,709.16 1,401.63 1,182.89 12.00 -94.00 5,967,947.58 551,698.28 7,600.00 96.89 74.36 6,329.80 - 1,692.60 1,499.19 1,281.74 12.00 -95.04 5,967,964.79 551,795.72 7,700.00 95.37 62.39 6,319.08 - 1,656.01 1,591.43 1,377.76 12.00 -96.62 5,968,001.99 551,887.71 7,800.00 93.62 50.48 6,311.21 - 1,600.98 1,674.34 1,466.75 12.00 -97.90 5,968,057.57 551,970.24 7,816.17 93.32 48.56 6,310.24 - 1,590.50 1,686.62 1,480.21 12.00 -98.84 5,968,068.13 551,982.45 8 7,900.00 91.70 38.62 6,306.56 - 1,529.92 1,744.28 1,544.83 12.00 -99.00 5,968,129.09 552,039.70 7,916.17 91.38 36.70 6,306.12 - 1,517.12 1,754.16 1,556.19 12.00 -99.44 5,968,141.95 552,049.49 9 8,000.00 91.36 26.64 6,304.11 - 1,445.89 1,798.10 1,608.49 12.00 -90.00 5,968,213.47 552,092.95 8,100.00 91.28 14.64 6,301.79 - 1,352.51 1,833.28 1,654.79 12.00 -90.24 5,968,307.08 552,127.49 8,116.17 91.26 12.70 6,301.43 - 1,336.80 1,837.10 1,660.49 12.00 -90.52 5,968,322.81 552,131.21 10 8,191.17 91.25 21.70 6,299.78 - 1,265.24 1,859.25 1,691.20 12.00 90.00 5,968,394.51 552,152.87 11 8,200.00 91.61 22.70 6,299.56 - 1,257.07 1,862.58 1,695.50 12.00 70.00 5,968,402.70 552,156.15 i 8,300.00 95.65 34.02 6,293.21 - 1,169.40 1,909.88 1,753.13 12.00 70.02 5,968,490.68 552,202.86 1 8,391.17 99.15 44.48 6,281.44 - 1,099.47 1,966.96 1,818.31 12.00 70.74 5,968,560.98 552,259.47 12 8,400.00 98.87 45.51 6,280.06 - 1,093.31 1,973.13 1,825.18 12.00 105.00 5,968,567.19 552,265.59 8,466.17 96.72 53.23 6,271.07 - 1,050.66 2,022.85 1,879.73 12.00 105.16 5,968,610.16 552,315.02 13 8,500.00 93.52 55.73 6,268.05 - 1,031.09 2,050.27 1,909.32 12.00 142.00 5,968,629.91 552,342.30 8,516.17 91.98 56.92 6,267.27 - 1,022.13 2,063.71 1,923.76 12.00 142.22 5,968,638.96 552,355.68 14 8,600.00 91.95 66.98 6,264.39 - 982.79 2,137.55 2,001.85 12.00 90.00 5,968,678.79 552,429.25 8,700.00 91.84 78.99 6,261.07 - 953.60 2,232.95 2,100.09 12.00 90.35 5,968,708.62 552,524.44 8,766.17 91.72 86.93 6,259.01 - 945.50 2,298.54 2,166.18 12.00 90.75 5,968,717.15 552,589.97 15 8,800.00 92.14 90.97 6,257.87 - 944.89 2,332.33 2,199.80 12.00 84.00 5,968,718.00 552,623.76 8,866.17 92.93 98.88 6,254.95 - 950.56 2,398.14 2,264.42 12.00 84.14 5,968,712.76 552,689.60 16 10/19/2009 2:45:42PM Page 4 COMPASS 2003.16 Build 69 r)7-?iGlis\I F L • ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1 B -17 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference 1 B 17 C«2 102.00ft (1B Site: Kuparuk 1B Pad North Reference: True Well: 1 B - 17 Survey C method:- Method Minimum Curvature Welibore: 113 B -17 L2 Design: P an 2, 1 B - 17 L2 Planned Survey - Measured TVD Below Vertical Dogleg - Toolt Map Map De tndnnatton Azimuth System +N/8 .11:4111 won Rate Az Northing Fasting, . (ft) C} (°} lff) ( ft) ( (ft) ( °t1 0 0 it} ( °} O." (ft} 8,900.00 92.14 102.87 6,253.45 956.94 2,431.32 2,296.58 12.00 101.00 5,968,706.61 552,722.82 8,991.17 90.00 113.60 6,251.74 - 985.42 2,517.77 2,378.91 12.00 101.18 5,968,678.71 552,809.44 17 9,000.00 89.72 114.62 6,251.76 - 989.03 2,525.83 2,386.47 12.00 105.00 5,968,675.16 552,817.52 9,100.00 86.65 126.23 6,254.94 - 1,039.55 2,611.86 2,465.70 12.00 105.00 5,968,625.22 552,903.88 9,166.17 84.68 133.95 6,259.95 - 1,082.00 2,662.30 2,510.59 12.00 104.63 5,968,583.11 552,954.60 18 9,200.00 86.40 137.63 6,262.58 - 1,106.17 2,685.81 2,530.98 12.00 65.00 5,968,559.10 552,978.27 9,221.17 87.49 139.93 6,263.71 - 1,122.07 2,699.74 2,542.87 12.00 64.71 5,968,543.30 552,992.31 19 9,300.00 87.85 130.47 6,266.92 - 1,177.89 2,755.18 2,591.09 12.00 -88.00 5,968,487.85 553,048.11 9,391.17 88.34 119.53 6,269.96 -1,230.08 2,829.71 2,658.70 12.00 -87.61 5,968,436.17 553,122.98 20 9,400.00 87.81 118.62 6,270.25 - 1,234.37 2,837.42 2,665.84 12.00 -120.00 5,968,431.93 553,130.72 9,500.00 81.89 108.13 6,279.24 - 1,273.85 2,928.65 2,751.58 12.00 - 119.97 5,968,393.07 553,222.21 • 9,600.00 76.24 97.35 6,298.26 . - 1,295.54 3,024.21 2,843.78 12.00 - 119.02 5,968,372.02 553,317.90 TD I I 10/19/2009 2 :45.42PM Page 5 COMPASS 2003.16 Build 69 f-Nit\IA1 ConocoPhillips • ran ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1 B -17 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 B -17 @ 102.00ft (1 B -17) Site: Kuparuk 1B Pad North Reference: True Well: 1 B - 17 Survey Calculation Method: Minimum Curvature Wellbore: 1 B - 17 L2 Design: Plan 2, 1B - 17 L2 Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +14/-S +Ef -W Northing , Easting - Shape (°) ( °) (ft) (ft) (ft) ( ( Latitude Longitude; 11B L2 t1.2 0.00 0.00 6,271.00 - 1,050.40 2,024.08 5,968,610.43 552,316.25 70° 19' 29.906 N 149° 34' 32.804 W - plan hits target center - Point 1B -17 L2 Fault 3 0.00 0.00 0.00 - 1,148.77 1,036.32 5,968,505.45 551,329.27 70° 19' 28.941 N 149° 35' 1.636 W - plan misses target center by 6330.32ft at 6898.80ft MD (6315.78 TVD, - 1557.16 N, 905.76 E) - Polygon j Point 1 0.00 - 1,148.77 1,036.32 5,968,505.45 551,329.27 Point 2 0.00 - 1,388.40 1,577.79 5,968,269.47 551,872.28 Point 3 0.00 - 1,376.05 1,825.90 5,968,283.49 552,120.27 Point 4 0.00 - 1,370.07 1,978.96 5,968,290.49 552,273.28 Point 5 0.00 - 1,706.72 3,123.86 5,967,961.55 553,420.30 Point 6 0.00 - 1,370.07 1,978.96 5,968,290.49 552,273.28 Point 7 0.00 - 1,376.05 1,825.90 5,968,283.49 552,120.27 Point 8 0.00 - 1,388.40 1,577.79 5,968,269.47 551,872.28 1B -17 L2 t4.2 0.00 0.00 6,260.00 - 1,094.61 2,648.85 5,968,570.42 552,941.24 70° 19' 29.470 N 149° 34' 14.568 W - plan misses target center by 18.45ft at 9164.01ft MD (6259.75 TVD, - 1080.51 N, 2660.75 E) - Point 1B -17 1.2 Polygon 0.00 0.00 0.00 - 1,579.63 860.41 5,968,073.46 551,156.27 70° 19' 24.704 N 149° 35' 6.771 W - plan misses target center by 6315.98ft at 6898.80ft MD (6315.78 TVD, - 1557.16 N, 905.76 E) - Polygon Point 1 0.00 - 1,579.63 860.41 5,968,073.46 551,156.27 Point 2 0.00 - 1,912.63 1,005.21 5,967,741.47 551,303.28 Point 3 0.00 - 1,802.14 1,534.01 5,967,855.49 551,831.28 Point4 0.00 - 1,732.50 1,740.50 5,967,926.51 552,037.27 Point 5 0.00 - 1,450.78 1,938.40 5,968,209.52 552,233.26 Point 6 0.00 - 1,217.34 2,026.96 5,968,443.53 552,320.25 Point 7 0.00 - 1,098.91 2,114.76 5,968,562.53 552,407.24 Point 8 0.00 - 1,077.53 2,207.91 5,968,584.53 552,500.24 Point 9 0.00 - 1,116.55 2,359.67 5,968,546.53 552,652.24 Point 10 0.00 - 1,254.44 2,641.79 5,968,410.55 552,935.25 Point 11 0.00 - 1,381.91 3,010.98 5,968,285.57 553,305.25 Point 12 0.00 - 1,382.60 3,114.99 5,968,285.58 553,409.26 Point 13 0.00 - 1,170.94 3,170.40 5,968,497.58 553,463.24 Point 14 0.00 - 1,148.29 3,072.54 5,968,519.57 553,365.24 Point 15 0.00 - 945.25 2,768.86 5,968,720.55 553,060.24 Point 16 0.00 - 796.03 2,437.81 5,968,867.54 552,728.23 Point 17 0.00 - 782.39 2,040.85 5,968,878.52 552,331.22 Point 18 0.00 - 1,031.36 1,882.18 5,968,628.51 552,174.24 Point 19 0.00 - 1,150.72 1,783.37 5,968,508.51 552,076.24 Point 20 0.00 - 1,373.16 1,694.88 5,968,285.50 551,989.25 Point 21 0.00 - 1,551.82 1,491.67 5,968,105.50 551,787.26 Point 22 0.00 - 1,625.70 1,170.14 5,968,029.47 551,466.27 Point 23 0.00 -1,515.13 936.85 5,968,138.47 551,232.26 Point 24 0.00 - 1,579.63 860.41 5,968,073.46 551,156.27 1B-17 L2 Fault 4 0.00 0.00 0.00 - 881.55 2,643.28 5,968,783.41 552,934.24 70° 19' 31.565 N 149° 34' 14.729 W - plan misses target center by 6253.79ft at 9000.00ft MD (6251.76 TVD, - 989.03 N, 2525.83 E) - Polygon Point 1 0.00 - 881.55 2,643.28 5,968,783.41 552,934.24 Point 2 0.00 - 1,067.59 2,646.04 5,968,597.41 552,938.25 Point 3 0.00 - 1,277.64 2,649.65 5,968,387.41 552,943.26 Point 4 0.00 - 1,067.59 2,646.04 5,968,597.41 552,938.25 1B -17 L2 t5.2 0.00 0.00 6,270.00 - 1,242.83 2,828.87 5,968,423.42 553,122.24 70° 19' 28.011 N 149° 34' 9.315 W - plan misses target center by 11.53ft at 9396.64ft MD (6270.13 TVD, - 1232.75 N, 2834.47 E) - Point 10/19/2009 2:45:42PM Page 6 COMPASS 2003.16 Build 69 • ConocoPhilli s • ' ConocOPhilii 5 N Planning Report TAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1B Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1B-17 © 102.00ft (1B-17) Site: Kuparuk 1B Pad North Reference: True Well: 1 B -17 Survey, Calculation Method: Minimum Curvature Wellbore: 1B L2 Design: - Plan 2, 1B-17 L2 1 B -17 L2 t6.2 0.00 0.00 6,298.00 - 1,292.22 3,035.56 5,968,375.41 553,329.23 70° 19' 27.525 N 149° 34' 3.283 W - plan misses target center by 11.83ft at 9600.00ft MD (6298.26 TVD, - 1295.54 N, 3024.21 E) - Point 1B-17 L2 t3.2 0.00 0.00 6,252.00 - 995.61 2,501.50 5,968,668.42 552,793.24 70° 19' 30.444 N 149° 34' 18.868 W - plan misses target center by 15.76ft at 8978.89ft MD (6251.77 TVD, - 980.65 N, 2506.45 E) - Point 1B-17 L2 t2.2 0.00 0.00 6,259.00 - 957.26 2,301.74 5,968,705.42 552,593.25 70° 19' 30.822 N 149° 34' 24.699 W - plan misses target center by 11.91ft at 8769.16ft MD (6258.92 TVD, - 945.35 N, 2301.52 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter . Diameter ( (ft) Name r) ("1 9,600.00 6,298.26 2 - 3/8" 2 - 3/8 3 ! Plan Annotations Measured Vertical Local Coordinates Depth Depth +W-S +E/ 4N (ft) (ft) (ft) (ft) Comment 6,898.80 6,315.78 -1,557.16 905.76 TIP 1B -17 6,906.00 6,322.09 - 1,560.12 907.56 KOP 6,921.00 6,335.16 - 1,566.40 911.40 End of DLS 9 7,066.17 6,398.69 - 1,662.73 986.06 4 7,141.17 6,391.78 - 1,701.99 1,048.31 End of DLS 45 7,341.17 6,366.81 - 1,713.60 1,244.93 6 7,441.17 6,351.51 - 1,709.20 1,343.47 7 7,816.17 6,310.24 - 1,590.50 1,686.62 8 7,916.17 6,306.12 - 1,517.12 1,754.16 9 8,116.17 6,301.43 - 1,336.80 1,837.10 10 8,191.17 6,299.78 - 1,265.24 1,859.25 11 8,391.17 6,281.44 - 1,099.47 1,966.96 12 8,466.17 6,271.07 - 1,050.66 2,022.85 13 8,516.17 6,267.27 - 1,022.13 2,063.71 14 8,766.17 6,259.01 - 945.50 2,298.54 15 8,866.17 6,254.95 - 950.56 2,398.14 16 8,991.17 6,251.74 - 985.42 2,517.77 17 9,166.17 6,259.95 - 1,082.00 2,662.30 18 9,221.17 6,263.71 - 1,122.07 2,699.74 19 9,391.17 6,269.96 - 1,230.08 2,829.71 20 9,600.00 6,298.26 - 1,295.54 3,024.21 TD 10/19/2009 2:45:42PM Page 7 COMPASS 2003.16 Build 69 ^_' t, toT Norm WELLBORE DETAILS: 18 -17 L2 REFERENCE INFORMATION ' 1p"' Project: Kuparuk River Unit !Magnetic North 21.99° Site: Kuparuk 1 B Pad Meg ec Field P Wellbore: 1 B -17 Coordinate (NIE) Reference. Well 1B-17, True North - • W 1 B - Strength 57649.9 Vertical (1VD) Reference: Mean Sea Level BA ,,.. T ie on MD: 6898.80 l���,I+r Wellbore: 16 L2 Dip 12 6206° Section (VS) Reference: Slot. (0.009, 0.00E) Qf FV+V.V � � - Plan: Plan 2, 1B L2 1B 1796 - 17 LZ -- - - - - -- Date. 12nno2e Measured De Reference: 1B -17 m 102.Curvature 00ft (1B -17) Calculation Method Minimum H ! _ GHES L2) MDoe1. 8001322 (Y■ : m -450 .......... I__. WELL DETAILS: 1B -17 -600 - .. Ground Level: 61.00 -750 +N1 -S +E / -W Northing Easting Latittude Longitude Slot 0.00 0.00 5969647.14 550285.37 70° 19' 40.240 N 149° 35' 31.884 W -- -_- -- - - - - - -- - --- - -- -._._____ .- -- -900 -.__. ... ..15_...16 _. _... SECTION DETAILS ANNOTATIONS r , 18 17 - 1050 Sec MD Inc Azi TVDSS +N/-S +E/_W DLeg TFace VSec T.rget Annotation 19 1 6898.80 28.78 148.76 6315.78 - 1557.16 905.76 0.00 0.00 709.24 TIP 18 -17 PO 2 6906.00 28.74 148.76 6322.09 - 1560:12 907.56 0.56 180.00 710.66 KOP - 1200 TIP IB - 17 11 3 6921.00 30.07 148.29 6335.16 - 1566.40 911.40 9.00 350.00 713.71 End of DLS 9 b 4 7066.17 95.00 139.18 6398.69 - 1662.73 986.06 45.00 350.00 776.07 4 a35o KOP lo '' °TD 5 7141.17 95.27 105.29 6391.78 - 1701.99 1048.31 45.00 272.00 833.07 End of DLS 45 End of DLS 9 6 7341.17 98:87 81.37 6366.81 - 1713.60 1244.93 12.00 280.00 1026.82 6 4.1_1500 End of DLS 45 7 7441.17 98.67 93.51 6351.51 - 1709.20 1343.47 12.00 90.00 1125.16 7 ° B - 17/1 B•17 L2 8 7816.17 93.32 48.56 6310.24 - 1590.50 1686.62 12.00 266.00 1460.21 8 9 7916.17 91.38 36.70 6306.12 - 1517.12 1754.16 12.00 261.00 1556.19 9 + - 1650 10 8116.17 91.26 12.70 6301.43 - 1336.60 1837.10 12.00 270.00 1660.49 10 11 8191.17 91.25 21.70 6299.78 - 1265.24 1859.25 12.00 90.00 1691.20 11 0-1 12 8391.17 99.15 44.48 6281.44 - 1099.47 1966.96 12.00 70.00 1818.31 12 1 i \ � -\ 13 8466.17 96.72 53.23 6271.07 - 1050.66 2022.85 12.00 105.00 1879.73 13 `.1950 r 14 8516.17 91.98 56.92 6267.27 - 1022.13 2063.71 12.00 142.00 1923.76 14 ,.= 15 8766.17 91.72 86.93 8259.01 - 945.50 2298.54 12.00 90.00 2166.18 15 5 IB 17 /1B- 17 L1 16 8866.17 92.93 98.88 6254.95 - 950.56 2398.14 12.00 84.00 2264.42 16 0- 2100 17 8991.17 90.00 113.60 6251.74 - 985.42 2517.77 12.00 101.00 2378.91 17 ..--- 18 9166.17 84.68 133.95 6259.95 - 1082.00 2662.30 12.00 105.00 2510.59 18 - 2250 G 19 9.- 19 20 9391 17 8 88 7 14 9 119.53 139.93 6263.71 6269.96 - 1230.08 1122.07 2829.71 2699.14 12.00 12.00 272.00 65.00 2658.7 0 20 - 2400 21 9600.00 76.24 97.35 6298.26 - 1295.54 3024.21 12.00 240.00 2843.78 TD - 2550 ,,., -2700 r , -.. 600 750 900 1050 1200 1350 1500 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 3300 West( -) /East( +) (150 ft /in) 6000 6106 'a 6200 .. TIP 1B -17 12 13 14 15 16 17 ] , 8 19 20 • 8 9 10 11 O 6300 7 .. - TD O KOP...._ 6 4'. s...i 6400 _ _. ."5-• .. End of DLS 9 1B- 17/1B -17 L2 T N tD J 6500. 71 N 6600 ! ... End of DLS 45 1B- 17/1B -17 L] U c m .. 6700 N 68001 - !. f~ ._ 1B- 17.1B -17 ',. 6900 -... _._.. .... ___. _. _... i 7000 _. _... 7100 '.. -100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 Vertical Section at 83.00° (100 ft/in) 111°V • ConocoPh Alaska P.O. BOX 100360 OGT 2Qp9 ANCHORAGE, ALASKA 99510 -0360 October 27, 2009 Alaska as Cons® Cor _ °ssion Anchorage Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three lateral sidetracks out of Kuparuk Well 1B-17 (PTD# 194 -045) using the coiled tubing drilling rig, Nabors CDR2 -AC. Work is scheduled to begin on 1B-17 as early as December 2009. The CTD objective is to drill three lateral sidetracks (1B-17 L1, 1B-17 L2, and 1B-17 L2 -01) targeting the C1 & C3 /C4 sands across faults into unsupported areas. The well will be pre - produced for approximately 6 months and then converted to injection service. Because the conversion will not occur immediately, these permit to drill applications are for production service. In preparation for the conversion, however, the following work has already been done to identify any issues that need to be addressed before proceeding with the sidetracks. — The Quarter Mile Injection Review is included in this packet. — The cement bond log was sent to Guy Schwartz (AOGCC) on Friday, October 23, for review. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 1B-17L1, 1B-17 L2, and 1B-17L2-01 — Proposed Schematic — BOP Schematic — Detailed Summary of Operations — Directional Plans If you have any questions or require additional information please contact me at 907 - 263 -4093. Sincerely, Jill L. - Coiled Tubing Drilling Engineer Perm!to Drill Summary of Opeetions KRU 1B-17 L1, 1B-17 L2, and 1B-17 L2 -01 Lateral Coiled Tubing Drilling Overview: Well 1B-17 is a C -sand producing, single completion well equipped with 4" tubing (from surface to 3554' MD), 3.5" tubing (from 3554' to 6743' MD), and a 5" production liner (from 6305' to 7477' MD). The upper completion consists of a 3.5" TRDP -4A surface controlled subsurface safety valve, six gas lift mandrels, and a 3.5" D nipple in the tubing tail. The existing perforations in the 1B-17 completion will remain open after the three proposed CTD laterals are drilled and completed. CTD will mill the first 5" window by kicking off of the 3.5" x 5" flow - through whipstock set pre -rig at —6980'. The first lateral, 1B -17 L1, will land in the B5 shale and then invert upward to intersect the C1. Drilling will continue, crosscutting up through the C1 until reaching the target top of C1 pay. After reaching the target, drilling will turn downwards, crosscuting towards the base of the C1 sands until TD (-8975' MD). The 1995' lateral will be drilled with a 2.70" x 3" bi- center bit on 2" e coil, as will all the subsequent laterals. The completion will consist of a 2%" slotted liner (8 slots per foot) across the C1 pay; the B5 shale section will be covered with 2 solid liner. The liner top will be placed inside the tubing, just above the whipstock. After the 1B-17 L1 lateral is complete, the second 3.5" x 5" flow- through whipstock will be set inside the 5" liner at —6906' MD. • The second window will then be milled by kicking off the whipstock. Drilling of the 1B-17 L2 lateral then begin, landing in the upper C1 and inverting up to crosscut the C3 /C4 prior to crossing Fault #3. • After crossing Fault #3, the well path is planned to invert up through the C2 and intersect the C3 /C4 pay to crest 5' below the top of the C4. Drilling with then turn downwards, crosscutting to the base of the C3 and reaching TD at 9600'. • The completion will consist of a 2%" slotted liner (8 slots per foot) from TD to —8300' where an openhole anchored billet will be set for kicking off the next lateral. The 1B-17 L2 -01 lateral will exit (low -side) off the anchored billet set in the L2 lateral at —8300' MD. The kickoff will take place in the C2 and the well will then be directed down into the C1 sands, inverting up to the top of the C1 pay. After the target is reached, the well will be drilled down, crosscutting to the base of the C1 to TD at —9650' MD. The completion will consist of 2%" slotted liner from TD to up across the junction with the 1 B -17 L2 lateral. The completion will then continue with blank liner being placed across the C2 sands and finishing with slotted liner to just outside the window. A liner deployment sleeve will be on top of the liner to facilitate re -entry. The upper whipstock will be left in the well for access to the 1 B -17 L2 -01 lateral post rig. The drill -in fluid will be Flo -Pro xanthan -based polymer with potassium chloride. The managed pressure drilling technique will be applied to manage bottom hole pressure, thereby minimizing hole stability problem. Page 1 of 5 Q R! G I L 10/27/2009 Permit to Drill Summary of Options Cont. KRU•17 L1, 1B -17 L2, & 1B -17 L2 -01 Operational Outline Pre -Rig Work 1. Tag fill and obtain a SBHP survey 2. Set lower whipstock (NOTE: kickoff point target depth is 6980') 3. Prepare wellsite for rig arrival Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. 2. Window Milling- Mill 2.74" window at 6980' 3. 1B-17 L1 Lateral a. Drill 2.70" x 3" bi- center lateral to the south at a TD of 8975' MD b. Run the 2005' of 2 %" slotted liner from TD to —6970' (just above the whipstock). Blank liner will be placed across the B5 sands. 4. Window Milling a. Set the second 3.5" x 5" Flow- through Whipstock at —6906' MD b. Mill 2.74" window off this whipstock 5. 1B-17 L2 Lateral a. Drill 2.70" x 3" bi- center lateral to the north at a TD of 9600' MD • b. Run the 1300' of 2'/8" slotted liner from TD to 8300'. An aluminum billet will be placed at 8300'. 6. 1B-17 L2 -01 Lateral a. Kick off of the open -hole anchored aluminum billet at 8300' MD. b. Drill 2.70" x 3" bi- center lateral to the north at a TD of 9650' MD c. Run the —2740' of 2%" slotted liner from TD to just outside of the window (-6910' MD). Blank liner will be placed across the C2 sands. 7. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Post - Rig Work 1. Obtain SBHP 2. Flowback to tanks for well cleanup 3. Begin production Page 2 of 5 ORIGINAL 10/27/2009 Permit to Drill Summary of Opillions Cont. KRU 017 L1, 1B -17 L2, & 1B -17 L2 -01 Mud Program • Chloride -based Biozan brine (8.6 ppg) for milling operations, and chloride -based Flo-Pro mud (8.6 ppg) for • drilling operations. • There is a SCSSV installed in 1B-17 which should be able to be used during running the 2%" slotted liner of the completion. This will eliminate the need for kill weight fluid during running of the completion. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well . • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class 1 wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 1B-17 L1 6970 8975 6380 6408 2%", 4.7 #, L -80, ST -L slotted liner across pay sand, blank liner across B5. 1B -17 L2 8300 9600 6293 6298 2%", 4.7 #, L -80, ST -L slotted. Anchored • billet set on top. 18-17 L2 -01 6910 9650 6326 6376 2 ", 4.7 #, L -80, ST -L slotted across pay sand, blank across C2 sands. Existing Completion Details: Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 0 120 0 120 1640 630 Surface 9 5 /8" 40 J -55 BTC 0 4241 0 4178 3950 2570 Casing 7" 26 L -80 BTC Mod 0 6629 0 6188 7240 5410 Liner 5 " 18.0 L -80 LTC R -3 6293 7477 5911 6936 10140 10490 Tubing 4 " 11 J -55 BTC Mod 0 3554 0 3547 6300 6590 Tubing 3 " 9.3 J -55 ABM -EUE 3554 6743 3547 6283 6990 7400 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum potential surface pressure is 1457 psi assuming a gas gradient to surface based on the most recent bottom hole pressure measurement which was 2113 psi at 6417' TVDss on April 7, 2009. An updated SBHP reading is planned prior to rig arrival. • The annular preventer will be tested to 250 psi and 2500 psi. Page 3 of 5 op ! G I N , IT 10/27/2009 Permit to Drill Summary of Opiions Cont. KRU 117 L1, 1B -17 L2, & 1B -17 L2 -01 Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1B-17 L1 19800' 1B • -17 L2 19300' 1B-17 L2 -01 19350' • Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset Well 1B-17 L1 1905' 1B-07 1B-17 L2 1605' 1 B -08AL 1 . 1B-17 L2 -01 1645' 1 B -08AL 1 Logging MWD directional, resistivity, and gamma ray will be run over the entire open -hole sections. Hazards • The most recent H reading on 1B-17 was taken on 08/06/09 and read 30 ppm. All H monitoring equipment will be operational while drilling the 1B-17 laterals. • Siderite is possible in upper C1 sand. • Higher than expected water saturations may be encountered. If this is the case in any lateral, TD may be called earlier than the planned TD. Quarter Mile Injection Review There are no existing wellbores within a quarter mile of the planned 1B-17 laterals. The closest existing wellbores for each of the planned lateral well paths are as follows: 1B-17 L1 The well with the closest proximity to any point in the 1B-17 L1 planned wellbore trajectory is 1B-18. The closest distance between 1B-18 and 1B-17 L1 is 1455 ft. 1B-18 is a single Kuparuk producer with perforations in the A4, C1, C2, C3 and C4 sands. 1B-17 L2 The well with the closest proximity to any point in the 1B-17 L2 planned wellbore trajectory is 1B-18. The closest distance between 1B-18 and 1B-17 L2 is 1455 ft. 1B-18 is a single Kuparuk producer with • perforations in the A4, C1, C2, C3 and C4 sands. 1B-17 L2 -01 The well with the closest proximity to any point in the 1B-17 L2 -01 planned wellbore trajectory is 1B-08. The closest distance between 1B-08 and 1 B -17 L2 -01 is 1645 ft. 1B-08 is a multi - lateral injector with two laterals in the C3 /C4 and C1 sands. Motherbore perforations exist in the C3 and C4 sands and are open to injection. Page 4 of 5 a''Nf-Nre•sI J/ 1 P 10/27/2009 Permit to Drill Summary of ()pitons Cont. KRUI17 L1, 1B -17 L2, & 1B -17 L2 -01 Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows for the use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 2 BHA will be accomplished utilizing the 2%" pipe rams and slip rams. Well 1 B -17 has a SCSSV, so the well should not have to be loaded with overbalanced fluid prior to running the completions. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following charts show the different pressure parameters in both "pumps on" and "pumps off' conditions. Reservoir pressure at the KOP is currently estimated to be 2,096 psi (6980' MD/ 6387' TVD). Milling and Drilling Conditions Pumps On Pumps off Mud weight 8.6 ppg 8.6 ppg Hydrostatic 2856 psi 2856 psi Annular Friction 628 psi 0 psi Surface Choke 0 psi 0 psi TOTAL 3484 psi 2856 psi EMW 10.5 ppg 8.6 ppg *Assume annular friction is 90 psi /1000 ft at 1.5 bpm Reservoir Pressure Wells 1B-03, 1B-18, and 1B-06 are the closest offset wells in the C -sand intervals. They are also the target producing wells for the CTD injection patterns. The most recent static bottom hole pressure readings in each well are as follows: Well name Pressure (psi) SSTVD of Est. Measured Date EMW (ppg) 1B-03 2310 6280 3/10/2007 7.1 1B-18 2450 6350 8/23/2007 7.4 1B • -06 2265 6365 3/12/2007 6.8 Page 5 of 5 ORIGINAL 10/27/2009 Last update= 10/07/09 OWL) 1 B -17 Proposed CTD Sidetrack . , 3 -1/2" Camco TRDP -4A @ 1896' MD ■ =NM 16" 62# H -40 shoe 4" 11# J -55 BTC Mod tubing (surface - 3554' MD) @ 121' MD 3 -1/2" 9.3# J -55 EUE 8rd AB -Mod Tubing (3554' - 6276' MD) 3 -1/2" 9.2# J -55 SPCLN BTC -Mod Tubing (6276' - 6743' MD) 5 ", 18 #, L -80, LTC, R -3 Class A (6305' -7477' MD) Camco MMG gas lift mandrels @ 2403', 3590', 4496', 5308', 5904',& 6197' MD 9 -5/8" 40# J -55 MO shoe @ 4241' MD ■•■.—_ Baker 80 -40 PBR (10' length with 3" ID seal bore) • r ...--- , Baker 7" x 3 -1/2" HB retrievable packer @ 6259' MD CD or 7" 26# L -80 shoe — 3 1!2" Camco D landing nipple @ 6274' MD (2.75" min ID) @ 6629' MD Tubing Tail @ 6743' MD C saperfs ' 3 -1/2 x 5" Baker Gen 2 flow -by whipstock C - 6967' MD @ 6906' MD, leave for access post -rig ...._.._..- _,......::,, \ 8300' MD _ 1...:____• Anchor Anchor billet at L2 lateral in C3 /C4 sands (north fault block), TD @ 9,600' MD \ 3" borehole, Slotted liner (2 -3/8 ", 4.6 #, L -80 ST -L) \ — ‘ _____ — _ — _ — — — ) • \ / 3-1/2 x 5" Baker Gen 2 flow- � '.-,- \ by whipstock @ 6980' MD -- — — — — — — — ) /) C - sand perfs \ L2 -01 lateral in 01 sand (north fault block), TD @ 9,650' MD 7013' - 7053' MD 3" borehole, Slotted liner from TD to across junction (2 -3/8 ", 4.6 #, L -80 ST -L), Blank liner across C2, Slotted liner up to outside the window _ ) 5" 18.0# L - 80 shoe — — — — — — @ 7477 MD L1 lateral in 01 sand (south fault block), TD @ 8,975' MD 3" borehole, Slotted liner across pay (2 -3/8 ", 4.6 #, L -80 ST -L) Blank liner will be placed across B5 • • Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing I Lubricator --L-1 Riser 1 Annular/ ■ Blind / Shear j 2" Pipe / Slip (CT) Pump into Lubricator 4. L ��T� above BHA rams 1 1/ �i� � � / W i Choke 1 2 -3/8" Pipe / Slip (BHA) Vj Choke Equalize Manifold 2 -3/8" Pipe / Slip (BHA) L- ----1 - n � --1 \\ J I Kill W'5 (. I✓ (}:><! <; � 7 ► 7 1 1 1 � �I Blind / Shear i _ 2" Pipe / Slip (CT) Q . Ch 2 1 $ SwabValves 1 � Wing Valves 1 � J I; Tree Flow Cross ' Surface Safety Valve BOPE: 7- 1/16 ", 5M psi, TOT A Choke Line: 2- 1/16 ", 5M psi Master Valve Kill Line: 2- 1/16 ", 5M psi Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union OR IGINAL 1,--._ -4000 1 /2000 , , X- B 3 -200 - tiO J , -WS I - „NI° I , ) I c -300 ", , 13 ,,,,--.- / -F.--1. _ : __, , -3000 - f10 t I I '.-----, -- i I I lib - . 1 Will - 1 &_4!• ) tleo,#.1,,s4:: ;*, 4* ,, • .4 ) ::§ ii i -0- irli i lre iititcaYriC.546 :'- ' ,.I ' . ,' ,,'. ,, I 1 -2TJ dia I ULI 1 -- ) 3L ------ )(10 P !ILL 1 4 / ,,, 4 111° W 4. 1 \ 1 " rk' in. Li 113-08AL1 , - - _200 1 0 _.'6;3E11 ill _,.,2 .... Ass -51'1 2000 glOk - -2001tfr , VVS , (0 / , ip . Id - " -5000 000 . I/ • -----"\r"-'3000 -_-10,41, NIA ic lit 111 SW-5 V000 4 q 51 - 1t _I: 5010 -6000 51 44000 \ , ■ , 1B 1 6, „ ...: A / - -::"' 00 iro a I 3 r 1 1.----- ` ° M c ) (V5 iih iii,„,.. i i i i / lei B 7_-loo J r Nt-- i / - -4000 • .„,........_ On y 1 : I : 8 lies within the AOR ' t 1 B-1frL1 withi the uparuk Riv Oil Pool 1 B-1 7 4000 i i , I —.010 -40 iCs 1141 / , 1 , 7 -5000 1B- ; , , / -4000 0 i 1 B-17 , w; course lies at i I I ---Innn .5nnn 6,200' ssu ea - <Z..... ti /// CPF-01 A l 6141.1c 7 -11CrN 1 B-1 5AL.. 47 7 / 1-5000 4 - 1 B-04 4 / i i 1 1 0 4 I \ KRU 1B-1 7L2 Area of Re 0 61-./0 6 view 1 B 7 Well course tick marks are in intervals of 100' TVDsubsea l' ' i 1 E-1 68 - 4 SFD 11/3/2009 1 i — — , - __. TRANSMITTAL LETTER CHECKLIST WELL NAME 0 �- � / — f 7 L 2_" PTD# 2-c- ✓ /3 ✓- c -c" tat c2/ -` 6 ✓ Development Service Exploratory Stratigraphic Test Non- Conventional Well FIELD: eG ( i-t V POOL: <e„)(Zw C 1 0; J Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well 0 /13 / ( ����� (If last two digits in Permit No. /ND API No. 50-61 2 It — 6• 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 perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 IIIIIIIIIIIIIIIIIIIIIIIField & Pool KUPARUK RIVER - 490000 Well Name: KUPARUK RIV UNIT 1B -17L2 Program DEV Well bore seg Q PTD #:2091320 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 _ On /Off Shore On Annular Disposal Li Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Entire horizontal lateral wellbore will lie within ADL 25648 3 Unique well name and number Yes 4 Well located in a defined pool Yes Kuparuk River Oil Pool, govemed by Conservation Order NQ. 432C 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 6 Well located proper distance from other wells Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 3 -1/2 miles 7 Sufficient acreage available in drilling unit Yes from an external property line where ownership or landownership changes. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes SFD 11/3/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes Area injection Order No. 2B IIII 15 All wells within 1/4 mile area of review identified (For service well only) Yes KRU 1B-08 16 Pre- produced injector: duration of pre production less than 3 months (For service well only) Yes Lateral wellbore - well will be produced for -6 months, then converted to injection. 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in 1B-17 Engineering 19 Surface casing protects all known USDWs . NA Surface casing set in 1B -17 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set in 1B-17 and cemented 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 1 B -17 22 CMT will cover all known productive horizons No OH slotted liner completion 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage Of reserye pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA Using flowthrough whipstocks to allow 1 B -17 to flow after laterals are drilled. 26 Adequate wellbore separation proposed Yes Proximity analysis performed . No issues. 27 If diverter required, does it meet regulations NA Wellhead already in place. BOP stack installed. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 2113 psi (6.3 ppg). Drilling with 8.6ppg mud ( using MPD technique) GLS 11/4/2009 29 BOPEs,_do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 1457 psi ... Will Test BOP to 3500 psi 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 reported at 1B pad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) Yes Well plan is to convert to injector after 6 months production. AOR complete. 35 Permit can be issued w/o hydrogen sulfide measures No 1B -17 measured 30 ppm H2S on 8/6/09; measures required. Geology 36 Data presented on potential overpressure zones _ _ Yes Expected reservoir pressure is 6.3 ppg EMW; will be drilled with 8.6 ppg mud using Managed Appr Date 37 Seismic analysis of shallow gas zones NA Pressure Drilling techniques. SFD 11/3/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Date: Engineering Date bli Date Lateral wellbore. Will be pre - produced for about 6 months prior to conversion to injector. Commissioner: Commission r: ‘- om _ i er / 4e"" d?