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210-138
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. aI 0 - 1 3 "Well History File Identifier Organizing(done) ❑ Two-sided 111111111 IllHlII ❑ Rescan Needed I 111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) C Ior Items: i ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner Poor Quality Originals: j 012_. OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: AM, Date: /s/ u P Project Proofing I 411111111M 9 BY: Maria) Date: J J/LLJ/L/ /s/ 01P Scanning Preparation I x 30 = Z3O + _-12_ = TOTAL PAGES !'� (Count does not include cover sheet) BY: Date: dl `tie I1# /s/ Production Scanning 1 1111111 11 III Stage 1 Page Count from Scanned File: L .17 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: 1/YES NO BY: Date: a c ii.. /ti. /s/ wi p 1 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. I I IIII ReScanned 1 BY: Maria Date: /s/ Comments about this file: Quality Checked III Dill 111 III III 19/99/9r111 \A/cli I-liernn,Film cn„nr P.n.Ann 9 .E 1 N T 0 0 U � 0 o L ort Z 0 a c`a6 N — 0) co U .�3. 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Cl) el- ET C 0 ■ i *iii ril =a Omb ='Q 1 m VI STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: November 1,2010 ' 210-138/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 October 29,2010 ' 50-029-21497-62 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1140'FSL,565'FWL,Sec.3,T12N, R9E, UM • October 30,2010 • 3J-15L1-02 • Top of Productive Horizon: 8. KB(ft above MSL): 74'RKB 15.Field/Pool(s): 993'FNL, 1134'FEL,Sec.3,T12N, R9E, UM GL(ft above MSL): 40'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 963'FNL,360'FEL,Sec.3,T12N,R9E,UM 8089'MD/6321'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-519545 y- 6002823 • Zone-4 •9433'MD/6464'TVD ADL 25630 TPI: x-523111 y- 6005979 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-523885 y- 6006013 Zone-4 1806'MD/1805'TVD 2563 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) 2160'MD/2146'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 8409'MD/6443'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 104' Surf. 104' 24" 200 sx AS II 9.625" 36# J-55 Surf. 4039' Surf. 3486' 12.25" 1300 sx AS III,325 sx Class G 7" 26# J-55 Surf. 8500' Surf. 6630' 8.5" 360 sx Class G 2.375" 4.6# L-80 8089' •'' 9433' V 6321' 6464' 3" slotted/solid liner 24.Open to production or injection? Yes Q No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5/2.875 8152'/8166' 7972'MD/6241'TVD,8144'MD/6355'TVD slotted liner from 8089'-9433'MD 6321'-6464'TVD 8111'MD/6336'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) November 11,2010 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/14/2010 32 hours Test Period--> 1106 446 774 75 Bean 480 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 126 psi 1306 24-Hour Rate-> 760 330 570 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 . Sidewall Cores Acquired? Yes ❑ . No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results er 20 C 25.071. '`O' tt?a;9, .. CEIVED NONE ! .,,. DEC 0 1 2010 RBDMS DEC 01 •" ,-J Alaska Oil&Gas Cons. Commission (.its-P..7 Anc!torapo Form 10-407 Revised 12/2009 CONTINUED ON RE SE Submit original only � r/..- r2 �� 27'Z ' G 28. GEOLOGIC MARKERS(List all formations and marker,.,countered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El 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 2160' 2146' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A-2 8610' 6517' Top Kuparuk A-3 8520' 6492' Bottom Kuparuk A-3 9150' 6485' . N/A Formation at total depth: Kuparuk A2&A3 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohli�lger @ 265-1102 11/;6/2.014 �///o Printed N e V.Ca a Title: Alaska Wells Manager Signature Phone 265-6306 Date ///4 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 ill W NI Z `W; m d a ca 0 0. VI 1 Q I— >, •a 2 u) z w .— •— 0 S w1) o O a = ` N U O _ 1.. 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( ( ƒ« » / 0122 $_ § 04 ) CO \ CI V « q _ g co CF _ & 3 ` ° w co k > « \ 3 N. / \ ƒ CTS C U) 2C/ \ ( = « « �� \ j B a ) 10 } 0 / / j j j Lo _c / j 0 } } / U c N w N- o ta O £ �_ S00UR /ri E � m .. .0K « 00000 en 0 k / 0 iii k k o t 2 KUP 3J-15L1-02 W 11 butes Max Angie&MID TD AIaSI the €" Wellborn AUWI Field Name Well Status Inel r) MD(ftKB) Act Btm(ftKB) 4 PY500292149762 IKUPARUK RIVER UNIT (PROD 10316 9,050.03 94330 -Comment H2S(pprrr) Date Annotation ,End Date KB Grd(ft) Rig Release Date w copryg1 q;,-11yr�p,{g-409WPM,,,_ SSSV:TRDP I 170 12/17/2009 Last WO I --33.91 2/5/1986 Se�nalic A91uai_. T Annotation Depth(ftKB)lEnd Date An Rotation Last Mod End Dale Last Tag:SLM 8,118M 10/10/2010 R_ev Reason:ADD 3 LATERALS Imosbor ! 11/4/2010 Casing Strings Casing Description (String 0... ;String ID [Top(ftKB) [Set Depth(t...l Set Depth(ND) [String Wt.[String...!Siring Top Thrd t I LINER L1-02 2 3/8 1 995 8,089.9 9,433.0 6,463 8 L 4 60 L-80 STL y'91' l - Liner Details -_ HANGER,30 --. b ,:. Top Depth (ND) Top Inc> NorL.. `?' / ,+- Top(ftKB) (ftKB) (') Item Description Comment ID(in) 8,089.9 6,322.2 46.35 DEPLOY GS PROFILE DEPLOYMENT SLEEVE 1.995 Notes:General&Safes End Date Annotation 1/25/1989 NOTE:WAIVERED WELL:IA x OA COMMUNICATION II 10/31/2010 NOTE MULTI-LATERALS DRILLED 3J-15L1,11-01,L1-02 CONDUCTOR, _ - ___. -.__ ... 34-104 I SAFETY VLV,__ 1,806 GAS L,309 IFT._—_.. II 2 - r ti' SURFACE9, 33-4,03 GAS LIFT, _ 4,545 tr GAS LIFT, - 5.975 1. II GAS LIFT, 6,838 `._ t GAS LIFT,- .... 7,276 V GAS LIFT,___ 1,592 GAS LIFT, 7,912 I it: PBR,7,958 PRODUCTION,_.. 8,010 IPERF, 8,047-8,064 i I Mandrel Details a . 7s4l4.;. .. °: `Arl WI Z Top Depth Top Port (TVD) Ind OD Veto. Latch SW TRO%tn _ Ste Top(ftKB) MKS) (*) Make Model (m) Sery 1YM TYW (in) (pat Run Dab Corn... WHIPSTOCK,6 oe k,' 1 2,309.3 2,278.7 29.81 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,33'.0 8/17/2009 2 4,544.7 3,823.8 45.26 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 8/17/2009 PRODUCTION, _ 3 5,975.1 4,841.2 45.06 CAMCO KBUG -- 1 GAS LIFT GLV BK 0.188 1,344.0 8/18/2009 31-8,500 - - -- 4 6,837.7 5,452.5 44.05 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,329.0 8/18/2009 5 7,275.7 5,759.9 45.76 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/18/2009 6 7,592.1 5,978.6 47.37 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 8/18/2009 7 7,911.7 6,199.2 46.51 MERLA TPDX 1 12 GAS LIFT DMY RM 0.000 0.0 8/172009 LINER L1-02, 8 8,010.2 6,267.2 46.43 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 4/16/1986 Closed 8,0909.433� -.._.. . TD (3J-1511-02), 9,433 I I 1 1 1 1 II co V II co 11 a It 1 1 I I I I 1 (O N ' I 1 I I` r I I O∎■ I I I 1 _ I I 1 1 OO O Q II I I 1 1 1 M 0 2 N V II co oo O O C c0 I I I (V Z II co - f0 O J N II IIt 1 � Lo a J O 0 it 1 0) N. ,— 11 LU N C II O 1 1 1 1 CO _E O 0 O C 1 I 11 11 O V Y J I- CO J 1 I I (U6 V LO E. Y N J 11 I 11 II — CO N W / I I 0 Q O o Y / / I— O b co O_ m 'o / / 11 co M V M Y CO N M O V O_ 7 . i °' © co m 00 © v c' CL Y a N CO 1,0 CO Q m M m w cr a (A` O I- -O N 112 d V CO`O_ M N / / co 12 N o) Z N v M N //� -O _C Cfl f6 CD / N U O o U� w �16 E -c m Q�� o WN V a E'V J it N 1 (d CO CL' 'Cr) O - Q C J I- J I Q Ii'//� 11 (6 Q N N J E Q Y E C I I a' M m a) = N > a co 1 I I M i— O) U M LL. U Q m U .O. 1 I ' (B J N N N N N N N N CO W N it r f6 ca T I` I I O Q M M M I- CO CO M M N N N I I I J F- • II II CO 1 I Y i C J W I 1 ZN 1 I CV E O pOp , i CO O I lil i g P o -002° ._ o i- 0 I III III t y o I • O p r Q '&5 �1 c y _ CL ago % � 0W 0 @� - r° "' L 'C �CD -1 t0 w a 117 L U N� W cnm o 't '- CO0 14) E0 0 d M Cs.] O = M co N > N C 00 M * Q oo m w c n t n N °° M Q a d O - Q co °d 2 io0 5 o ConocoPhiIIips Time Log & Summary We/View Web Reporting Report Well Name: 3J-15 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 10/13/2010 3:00:00 AM Rig Release: 11/1/2010 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/11/2010 24 hr Summary Released from 3A-17 @ 2100 21:00 00:00 3.00 MIRU MOVE MOB P Relaesed from 3A-17,move to 3J-15 10/12/2010 Move rig from 3A to 3J. MIRU, Swap out skates on Injector Head 00:00 00:00 24.00 0 0 MIRU MOVE RGRP P MIRU,Skate repairs 10/13/2010 Perform Slack Management, cutting 110'CT, Perform BOP test, Remove BPV 00:00 03:00 3.00 0 MIRU MOVE RGRP P Repair Skates 03:00 04:00 1.00 MIRU WHDBO SLPC P Prepare to reverse circulate for Slack Management, Install MP line, OA, IA sensors Rig Accept 3 AM 04:00 05:30 1.50 MIRU WHDBO SLPC P MU injector to well and change stripper 05:30 07:00 1.50 MIRU WHDBO SLPC P Fill CT and all lines,pump slack 07:00 08:30 1.50 MIRU WHDBO SLPC P Cut 110'CT 08:30 09:00 0.50 MIRU WHDBO SFTY P PJSM for BOP test/rehead CT 09:00 21:00 12.00 MIRU WHDBO BOPE P Start testing BOPE,state witness waived by John Crisp. MU CTC, Pull to 30K. MU Inteq UQC 21:00 22:00 1.00 MIRU WHDBO BOPE P BOP testing complete, RD floor, PJSM pull BPV 22:00 22:45 0.75 MIRU WHDBO BOPE P Pull BPV,and RD 22:45 23:15 0.50 MIRU WHDBO BOPE P Install check valves 23:15 23:30 0.25 SURPRI WELLPF SFTY P PJSM,open well up confirm well is dead 23:30 00:00 0.50 SURPRI WELLPF UREM P PU BHA#1 10/14/2010 Under-ream 8100-8120', POOH, Mill CBP out,drifting down to 8165'. Pinhole CT while POOH,7700'. 00:00 00:30 0.50 0 0 SURPRI WELLPF UREM P MU BHA#1 00:30 02:30 2.00 0 7,710 SURPRI WELLPF UREM P RIH, displacing well to tiger tank 02:30 03:00 0.50 7,710 7,710 SURPRI WELLPF DLOG P Tie in depth, correction-7'. RIH 03:00 03:18 0.30 8,100 8,120 SURPRI WELLPF UREM P Start under reaming, 1.5 BPM, 2-2.5 FPM 8100-8120'1 for 1' returns Stall x 2 8109', PUH RIH.5 FPM,Continue RIH Page 1 of 16 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:18 03:42 0.40 8,120 8,100 SURPRI WELLPF UREM P PUH 1 FPM, 1.5 BPM, 1 for 1 returns, 03:42 03:54 0.20 8,100 8,120 SURPRI WELLPF UREM P RIH,3 FPM, 1.5 BPM 03:54 04:00 0.10 8,120 8,100 SURPRI WELLPF UREM P PUH 3.5 FPM 04:00 04:12 0.20 8,100 8,120 SURPRI WELLPF UREM P RIH, 3.5 FPM, PUH to 8100,Offline with pumps, open EDC 04:12 06:00 1.80 8,120 0 SURPRI WELLPF UREM P Looks good, POOH 06:00 06:30 0.50 0 0 SURPRI WELLPF SFTY P PJSM,monitor well, no flow 06:30 08:30 2.00 0 0 SURPRI WELLPF MILL P Lay down underreaming BHA, PU milling BHA 08:30 10:30 2.00 0 8,120 SURPRI WELLPF MILL P RIH,Tie in to formation at 7719', -7.5', continue RIH 10:30 10:48 0.30 8,120 8,150 SURPRI WELLPF MILL P Bring pump on at 1.0 BPM, 1500 CTP,34K PUW, 17K RIW,360 differential pressure at the BHA. 10:48 11:18 0.50 8,150 8,150 SURPRI WELLPF MILL P First WOB and motor work,mill with 300-500 WOB and 40 to 80 PSI motor work. at 8150'started losing returns, PU clean to 8120, losing 0.6 BPM. RBIH and get some motor work and WOB at 8150'. Continue milling down 11:18 17:18 6.00 8,150 8,151 SURPRI WELLPF MILL P Multiple stalls at 8150.8',clean PU. Return rate back to normal. Very slow milling 17:18 18:18 1.00 8,151 8,152 SURPRI WELLPF MILL P Stall, lose returns. PUH,Try to drift. No luck Continue milling down. 18:18 18:30 0.20 8,152 8,152 SURPRI WELLPF MILL P Pump 5bbrl 100K LSRV for losses. Stall PU. RIH Mill Ahead 18:30 19:06 0.60 8,152 8,165 SURPRI WELLPF MILL P Break through fast drill,Continue rih to 8165 19:06 19:36 0.50 8,165 8,165 SURPRI WELLPF MILL P PUH 31K,to 8130', Dry run down to 8165'. Looks good 19:36 20:03 0.45 8,130 8,130 SURPRI WELLPFCIRC P PUH to 8130', Displace 45bbrl, 100K LSRV, Hi Vis pill. Pumping through EDC 1.5 BPM in .32 BPM out. 20:03 20:33 0.50 8,130 7,780 SURPRI WELLPF MILL P Unable to establish 1 for 1 returns, 1.18 bbrl loss/min at 1.5 BPM with 9.9 ECD„ POOH 20:33 22:03 1.50 7,700 0 SURPRI WELLPF MILL P 7700', Pinhole in CT, Slowly spool onto reel.Continue POOH. 22:03 22:18 0.25 0 0 SURPRI WELLPF SFTY P At surface, PJSM 22:18 23:00 0.70 0 0 SURPRI WELLPF MILL P Close SSSV, LD tools 23:00 00:00 1.00 0 0 PROD1 RPEQP1CTOP T RU N2 unit 10/15/2010 Swap CT reels 00:00 00:30 0.50 0 0 PROD1 RPEQP1CTOP T PJSM, Pressure test N2 line. 00:30 00:45 0.25 0 0 PROD1 RPEQP1CTOP T Blow down CT 00:45 01:00 0.25 0 0 PROD1 RPEQP1CTOP T PJSM, Prepare to unstab 01:00 06:00 5.00 0 0 PROD1 RPEQP1CTOP T Unstab CT, Prepare for reel swap Page 2 of 16 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:00 15:30 9.50 0 0 PROD1 RPEQPI CTOP T Crew change PJSM 15:30 21:30 6.00 0 0 PROD1 RPEQP1CTOP T Continue swapping reels 21:30 22:30 1.00 0 0 PROD1 RPEQP1CTOP T Changeout brass in stripper assembly 22:30 00:00 1.50 0 0 PROD1 RPEQP1CTOP T Stab CT 10/16/2010 Complete reel swap, RIH w/packer assembly, set at 8120'. RIH w/WS assembly, latch into packer at 8111'. Perform leak off test.(Good). Release off WS, POOH. 1 for 1 returns. 00:00 02:00 2.00 0 0 PROD1 RPEQP1CTOP T Continue stabbing CT 02:00 04:00 2.00 0 0 PROD1 RPEQP1 CTOP T Pressure test Inner reel iron, inner reel valve, pressure bulk head, and stripper 04:00 06:00 2.00 0 0 PROD1 RPEQP1SLPC T Cut Coil,(10')MU CTC,and head up BHI drilling head 06:00 06:30 0.50 0 0 PROD1 RPEQP1SLPC T PT CTC 06:30 07:30 1.00 0 0 PROD1 RPEQP1PULD P Fill hole,MU dummy whipstock BHA 07:30 09:30 2.00 0 7,320 PROD1 RPEQP1TRIP P RIH, pumping 1.3 BPM 09:30 10:00 0.50 7,320 8,120 PROD1 RPEQP1TRIP P Tie-in, -8',continue RIH to 8120'. 10:00 12:00 2.00 8,120 0 PROD1 RPEQP1TRIP P Clean drift, POOH,29K PUW 12:00 13:00 1.00 0 0 PROD1 RPEQP1PULD P Swap BHA, PU Weatherford SS-WSR-BB Packer and running tools. 13:00 15:30 2.50 0 8,100 PROD1 RPEQPI TRIP P RIH,Tie in at 7740',-11.5',continue RIH 15:30 15:48 0.30 8,100 8,120 PROD1 RPEQP1TRIP P Weight check, 32K PUW, 17K RIW. Close EDC,orient to high side. RIH to 8120'and saw 1K WOB. Pick up and run in to 8119.5'with no WOB. Come on line at.5 BPM, increase to .7 BPM,4200 DP down hole holding steady. Stop p[umping and set down 2K. Pick up and pull 15K over, packer is set but have not sheared off. 15:48 16:30 0.70 8,120 8,120 PROD1 RPEQP1TRIP P Set down 2K WOB(15K RIW), PU -20K WOB(59K string weight), no movement. Set down 8K WOB, pump at.7 BPM,4200 DP at BHA. Pick up to-20K WOB. Repeat these steps 8 times. 16:30 18:30 2.00 8,120 8,120 PROD1 RPEQP1TRIP P Pump at.7 BPM and PUH sheared at just under 4000 PSI and-10K WOB(50K PUW). Close EDC and POOH 18:30 20:00 1.50 0 0 PROD1 RPEQP1PULD P At surface, PJSM, LD BHA 4, PU BHA 5. 20:00 22:00 2.00 0 7,740 PROD1 RPEQP1TRIP P RIH 22:00 22:06 0.10 7,740 8,050 PROD1 RPEQP1DLOG P Tie in depth-9'correction, RIH 22:06 22:12 0.10 8,050 8,120 PROD1 RPEQP1TRIP P Weight check 32K PUW, RIW 18K. Page 3 of 16 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:12 22:42 0.50 8,111 8,111 PROD1 RPEQP1TRIP P Start to see weight stabbing into packer 8111'. 5K WOB down at 8114.5'.Jars hit. 1BPM in.73 BPM out.Cock jars 35K up RIH 8.8K WOB down.Jars hit. 1 BPM in.73 out. Increase rate 1.5BPM in, 1.4out. Pressure up well to 610psi,hold 1 minute,608psi. after 1 minute. PUH 43K shear off. 22:42 00:00 1.30 8,111 2,800 PROD1 RPEQP1TRIP P POOH 10/17/2010 Mill 5.5'thorugh 3.5"tubing with.6 AKO motor 8106-8113.5'. POOH, PU 2 deg AKO motor. Mill 2.5'through 7"casing 8113'-8115.5'.Continue milling 10'rat hole. 00:00 00:30 0.50 2,800 0 PROD1 RPEQP1TRIP P Cont. POOH 00:30 01:15 0.75 0 0 PROD1 RPEQP1PULD P PJSM, LD BHA 5 01:15 01:45 0.50 0 0 PROD1 WHPST PULD P PU BHA 6 01:45 03:15 1.50 0 0 PROD1 WHPST TRIP P RIH 03:15 03:30 0.25 7,740 7,740 PROD1 WHPST DLOG P Tie in depth,-9 correction, RIH, Displacing well to 9L4 Flo-Pro 03:30 03:45 0.25 8,050 8,108 PROD1 WHPST TRIP P Record up and doWn weights.33K PUW, 17 RIW, RIH, 03:45 04:00 0.25 8,108 8,108 PROD1 WHPST TRIP P Dry tag 8108'. PU 35K.Close EDC 04:00 09:30 5.50 8,108 8,114 PROD1 WHPST MILL P RIH,Online with pumps, 1.45 BPM, 3100 CTP, 16K CTW,8108.18'start millling. 1 -2K WOB, 150 PSI motor work. 09:30 10:30 1.00 8,114 8,114 PROD1 WHPST MILL P Ream up and down at 1 FPM,three times each,clean 10:30 12:30 2.00 8,114 0 PROD1 WHPST TRIP P POOH 12:30 13:42 1.20 0 0 PROD1 WHPST PULD P Lay down first milling BHA. Mill 2.80",String Reamer 2.79"no-go. PU Weatherford 2.0 Deg.motor and 2.80"fat radius mill 13:42 15:48 2.10 0 7,730 PROD1 WHPST TRIP P RIH 15:48 16:06 0.30 7,730 8,113 PROD1 WHPST DLOG P Tie in,-10.5' 16:06 20:06 4.00 8,113 8,116 PROD1 WHPST MILL P Continue in hole and dry tag at 8113. 33K PUW, 14K RIW. Online with pump at 1.4,3560 CTP,590 differential pressure free spin. Start time milling at 8113' 20:06 23:21 3.25 8,116 8,119 PROD1 WHPST MILL P 8115.5'Pop through 7"casing. Continue milling 1 FPH 23:21 00:00 0.65 8,119 8,121 PROD1 WHPST MILL P 8119' Increase ROP 3 FPH, 1-1.5 WOB,739 diff. 1.4 BPM, 3600 CTP, milling rat hole 10/18/2010 Complete window milling,8108'TOW,8115'BOW. Drill L1 Lateral to 8170'. POOH for AKO change. RIH, EDC failure. POOH Page 4 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 8,121 8,128 PROD1 WHPST MILL P Continue milling rat hole Unofficial window depths: TOW-8108' BOW-8115' 01:30 02:00 0.50 8,128 8,128 PROD1 WHPST MILL P PUH 15 deg rt back reaming, RIH HS X 3,2'above and below window.32K PUW, 12K RIW, 1 FPM, Pump high vis 10 bbrl sweep 02:00 03:06 1.10 8,128 8,128 PROD1 WHPST MILL P RIH HS, backream 45 deg left and rt of 15 deg.2 above and below window X 2 each 03:06 03:21 0.25 8,128 8,128 PROD1 WHPST MILL P Perform dry run through window 5 FPM, Looks good 03:21 06:00 2.65 8,128 8,128 PROD1 WHPST TRIP P POOH 06:00 06:30 0.50 0 0 PROD1 WHPST SFTY P Valve Checklist, PJSM 06:30 08:00 1.50 0 0 PROD1 WHPST PULD P Undeploy milling BHA, 08:00 10:12 2.20 0 0 PROD1 DRILL PULD P Deploy drilling BHA 10:12 12:12 2.00 0 7,730 PROD1 DRILL TRIP P RIH 12:12 12:24 0.20 7,730 7,750 PROD1 DRILL DLOG P Tie-in,-10.5' 12:24 12:42 0.30 7,750 8,128 PROD1 DRILL TRIP P Close EDC and continue RIH 12:42 14:00 1.30 8,128 8,170 PROD1 DRILL DRLG P Window drifted clean,Start new mud down hole. 1.4 BPM,3400 CTP, 13K RIW. 14:00 16:00 2.00 8,170 0 PROD1 DRILL TRIP P POOH, pull up past window and close open EDC 16:00 16:12 0.20 0 0 PROD1 DRILL SFTY P PJSM 16:12 18:12 2.00 0 0 PROD1 DRILL PULD P Undeploy 18:12 18:27 0.25 0 0 PROD1 DRILL SFTY P Crew change/PJSM 18:27 19:57 1.50 0 0 PROD1 DRILL PULD P Deploy 19:57 21:57 2.00 0 7,735 PROD1 DRILL TRIP P RIH 21:57 22:09 0.20 7,735 7,735 PROD1 DRILL DLOG P Tie in depth,-11'correction, RIH, hit RA marker to confirm window depths. 22:09 22:24 0.25 7,735 8,170 PROD1 DRILL TRIP T EDC did not close.POOH 22:24 00:00 1.60 8,170 0 PROD1 DRILL TRIP T POOH 10/19/2010 P/U BHA#10 with 1.2 AKO continue drilling ahead. Lower pump rates through section 8530'-8560'. 00:00 00:15 0.25 1,000 0 PROD1 DRILL TRIP T Contuinue POOH 00:15 01:30 1.25 0 0 PROD1 DRILL PULD T At surface, PJSM. Undepoy BHA 9 01:30 03:00 1.50 0 0 PROD1 DRILL PULD T Deploy BHA 10 03:00 04:48 1.80 0 7,730 PROD1 DRILL TRIP T RIH,test tools at 1000' 04:48 05:00 0.20 7,730 7,755 PROD1 DRILL DLOG T Tie in,-10.5',Close EDC 05:00 05:18 0.30 7,755 8,170 PROD1 DRILL TRIP P Continue RIH. Page 5 of 16 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:18 07:48 2.50 8,170 8,320 PROD1 DRILL DRLG P Drilling ahead, 1.4 BPM, 3600 CTP, 3888 BHP, 13K RIW 07:48 08:06 0.30 8,320 8,320 PROD1 DRILL WPRT P Wiper to the window,32K PUW, 12K RIW 08:06 12:06 4.00 8,320 8,470 PROD1 DRILL DRLG P Drilling ahead, 1.3 BPM,3600 CTP, 3888 BHP, 13K RIW 12:06 12:45 0.65 8,470 8,470 PROD1 DRILL WPRT P Wiper tirp to window,33K PUW 12:45 16:45 4.00 8,470 8,620 PROD1 DRILL DRLG P Drill Ahead, 1.37 BPM,3350 CTP, 4000BHP, 1-2K WOB, 12 ECD 16:45 18:00 1.25 8,620 8,620 PROD1 DRILL WPRT P Wiper Trip to window,33K PUW 18:00 20:00 2.00 8,620 8,770 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3580, BHP 4020,2K WOB. BHA wiper @ 8690' for GEO's-drill ahead.2 bbl/hour losses. 20:00 21:00 1.00 8,770 8,770 PROD1 DRILL WPRT P Wiper trip-Set down while RIH @ 8540'-Lower pump rate though section.Clean. 21:00 22:30 1.50 8,770 8,920 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3600, BHP 4040, ECD 12.2, ROP 80,WOB 2K. Good A-3 pay. 22:30 23:30 1.00 8,920 8,920 PROD1 DRILL WPRT P Wiper trip-P/U weight 34K. Lower pump rate from 8560-8530'-clean no set down.2 bbls/hour losses. 23:30 00:00 0.50 8,920 8,942 PROD1 DRILL DRLG P Drilling ahead hard/slow driling from 8940' 10/20/2010 P/U 1.o AKO BHA-shaker motor while RIH. Held Field wide Safety Discussion&re-conditioned lateral prior to drilling ahead. 00:00 02:00 2.00 8,942 9,070 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3700, BHP 4080, ECD 12.2, ROP 70,WOB 2K. 02:00 05:00 3.00 9,070 0 PROD1 DRILL TRIP P Wiper trip&POOH to surface for BHA(AKO change) 05:00 06:00 1.00 0 0 PROD1 DRILL PULD P PJSM Undeploy BHA 10 06:00 06:15 0.25 0 0 PROD1 DRILL SFTY P Crew Change, PJSM 06:15 07:00 0.75 0 0 PROD1 DRILL PULD P Continue Undeploy 07:00 07:07 0.12 0 0 PROD1 DRILL BOPE P Function test BOP's 07:07 08:22 1.25 0 0 PROD1 DRILL PULD P Deploy BHA 11 08:22 10:07 1.75 0 7,735 PROD1 DRILL TRIP P RIH 10:07 10:29 0.38 7,735 7,735 PROD1 DRILL DLOG P Tie in depth,-13 correction, RIH Perform mud swap 10:29 15:44 5.25 7,773 8,400 PROD1 DRILL RGRP T Shaker motor burnt up, PUH above window and circulate. Wait on shaker motor from Deadhorse. ***Nabors Billable Repair Hours***9 hours total 15:44 16:29 0.75 8,400 8,400 PROD1 DRILL RGRP T Shaker motor on location. Install 16:29 17:59 1.50 8,400 8,400 PROD1 DRILL RGRP T Shaker does not have correct components to operate,wait on parts. Page 6 of 16 • , Time Logs . Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:59 19:29 1.50 8,400 8,400 PROD1 DRILL SFTY P Field wide CDR-2 safety Discusion with Von&Brian.Continue circulating holding MPD. 19:29 20:59 1.50 8,400 8,400 PROD1 DRILL RGRP T New Shaker motor arrived and installed. Function tested&back to work. 20:59 21:59 1.00 9,060 9,088 PROD1 DRILL DRLG P Drilling ahead-Tagged early @ 9060' motor work. Drilled to 9088'and annular starting climbing to 4500 psi.. Pull a wiper to clean up OH. P/U weight 35K. 21:59 23:59 2.00 9,088 8,000 PROD1 DRILL WPRT P Wiper trip&blow out choke due to lighter shale build up. Had two overpulls while wiping @ 8670'& 8650'.Work through areas. Pump 5/5 bbl low/high sweep&wipe from TD to window twice,. Retunrs and hole conditions cleaned up. 10/21/2010 Drilling ahead all day.Two fault crossings and 1 long wiper to 1700',slight increase in returns. 16 bbl losses in 24 hours. 00:00 00:30 0.50 9,088 9,088 PROD1 DRILL WPRT P Continue with hole conditioning wiper. 00:30 02:00 1.50 9,088 9,220 PROD1 DRILL DRLG P Drilling ahead-1.38 bpm,3600, BHP 4050, ECD 12, ROP 105,WOB 1.5K, Ct weight 12K. 02:00 03:00 1.00 9,220 9,220 PROD1 DRILL WPRT P Wiper trip-35K P/U.Clean through troubled spots. 03:00 04:45 1.75 9,220 9,220 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3670, BHP 4050, ECD 12, ROP 98,WOB 1.3K, Ct weight 12K 04:45 06:15 1.50 9,370 9,370 PROD1 DRILL WPRT P Wiper trip-P/U weight 36K 06:15 08:15 2.00 9,370 9,520 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4100, BHP 4050, ECD 12, ROP 100-120,WOB 1.3K, Ct weight 12K 08:15 10:00 1.75 9,520 9,520 PROD1 DRILL WPRT P Chase 5bbrl hi/low sweep with wiper trip to window, 36K PUW 10:00 12:00 2.00 9,520 9,670 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4160, BHP 3850, ECD 12.4, ROP 50-120,WOB 1.3K, Ct weight 12K 12:00 14:00 2.00 9,670 9,670 PROD1 DRILL WPRT P Chase 5bbrl hi/low sweep with wiper trip to window, 36K PUW 14:00 16:00 2.00 9,670 9,820 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4160, BHP 3850, ECD 12.4, ROP 50-120,WOB 1.3K,Ct weight 12K 16:00 21:00 5.00 9,820 9,820 PROD1 DRILL WPRT P Pump 5bbrl low/high sweep chasing with wiper trip, 35K PUW, Wiper trip back to 1700'. Light increase in cutting near top of the wiper,shale returns. 21:00 22:00 1.00 9,820 9,820 PROD1 DRILL DLOG P Survey from 9600 to 9700'prior to Getting on bottom. 22:00 00:00 2.00 9,820 9,921 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3700, BHP 4160, ECD 12.5, ROP 50,WOB 2K, ct weight 10K. Page 7 of 16 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10/22/2010 24 hr Summary Drilling ahead-hit a higher pressured zone after fault#3 in the A-2 pay zone. New Static test @ window is 4260 psi.Mud swap with 1050'on system with 15 bbl losses for 24 hours. 00:00 01:00 1.00 9,921 9,980 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4000, BHP 4200, ECD 12.5, ROP 55,WOB 2K, CT weight 10K-slow shale drilling. Possible break through @ 9960' ROP 100'. 01:00 03:00 2.00 9,980 9,980 PROD1 DRILL WPRT P Wiper trip-P/U weight 37K. Smooth through ratty sections. 03:00 05:00 2.00 9,980 10,120 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4000, BHP 4220, ECD 12.5, ROP 95,WOB 2K, Ct weight 10K.. Micro motion out stopped working.getting good 1:1 returns. Getting oily formation returns in mud @ 10,080'. Increase choke to 50 psi. BHP 4270 psi. 05:00 07:30 2.50 10,120 10,120 PROD1 DRILL WPRT P Wiper trip 37K pick up. 07:30 09:30 2.00 10,120 10,270 PROD1 DRILL DRLG P Drill Ahead 60-100 FPH, 1.3 BPM in. 9K CTW, 1-2K WOB,Crude in returns,apply 200psi on MP choke, new mud at bit. Mud gas cut.. Increase to 13ppg ECD, 351 WHP 09:30 11:00 1.50 10,270 10,270 PROD1 DRILL WPRT P Wiper Trip to window,35K PUW, holding 13ppg ECD on well during wiper trip. 11:00 11:15 0.25 8,110 8,110 PROD1 DRILL LOT P At window,get static BHP.4260. 12.98 ECD 11:15 11:30 0.25 8,110 8,110 PROD1 DRILL DLOG P Tie in depth to RA marker.-3' correction 11:30 12:45 1.25 8,110 8,110 PROD1 DRILL WPRT P RIH,Start weighting up active system.9.4ppg to 9.8ppg 12:45 14:30 1.75 10,270 10,420 PROD1 DRILL DRLG P Drill Ahead, 1.4BPM,4000CTP,4435 BHP, 13 ECD, 9K CTW, 1-2K WOB 14:30 18:00 3.50 10,420 10,420 PROD1 DRILL WPRT P Wiper trip to window,35K PUW, 9.8ppg mud at surface. Light oily returns after wiper trip-increase WHP 75 psi during wiper trips. 18:00 20:00 2.00 10,420 10,570 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4100, BHP 4511, ECD 13.2,WHP 185, ROP 60, WOB 1.8K, Ct weight 7K. Quick 50'wiper @ 10530'CT weight dropped off from 7K to-2K.Clean P/U 37K. 20:00 23:00 3.00 10,570 10,570 PROD1 DRILL WPRT P Wiper trip-hold additional 75 psi on WHP-now 275 psi. P/U weight 39K. Little to no oil in returns during wiper trip. 23:00 00:00 1.00 10,570 10,629 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4300, BHP 4580, ECD 13.4, ROP 80,WOB 2K, Ct weight 5K. Start increasing tubes from 4%to 5%. 10/23/2010 Drill ahead slowly all day in Ankerite. Mud swap with 800'on system. 19 bbls losses to formation in 24 hours. Page 8 of 16 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 01:30 1.50 10,629 10,720 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4300, BHP 4590, ECD 13.4, ROP 70,WOB 1.8K, CT weight 4K. 01:30 05:00 3.50 10,720 10,720 PROD1 DRILL WPRT P Wiper trip P/U 38K. Increae WHP to 275 psi. Clean through shale. 05:00 11:00 6.00 10,720 10,860 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4300, BHP 4600, ECD 13.5,WHP 175, ROP 80, WOB 1.8K,Ct weight 7K. 11:00 16:00 5.00 10,860 10,890 PROD1 DRILL DRLG P Drilling Ahead slow drilling,3-10FPH, 2-3K WOB,-12K CTW 16:00 19:00 3.00 10,890 10,890 PROD1 DRILL WPRT P Wiper trip P/U weight 37K 19:00 21:00 2.00 10,890 10,898 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4200, BHP 4600, ROP 2,WO$2.8K, Ct weight 2K,WHP 170 psi. 21:00 21:30 0.50 10,898 10,899 PROD1 DRILL DRLG P Mud properties are good but looks very diluted with oil,residual. Pump 10 bbls of fresh mud to see diffrence DH. ROP increased,to 40 fph,CT weight came back to 9K& WOB is 1K. 21:30 23:00 1.50 10,899 10,910 PROD1 DRILL DRLG P Continue drilling ahead on old mud to see if changes back, poor ROP 3fph &CT weight-8K. Ordered trucks for Mud swap. P/U 40 ft due to weight transfer @ 10908'35 K. 23:00 00:00 1.00 10,910 10,912 PROD1 DRILL DRLG P Start pumping new mud-better weight transfer once mud came up backside.-15K to-6K. ROP still slow. 10/24/2010 TD lateral @ 10920'Slow ROP in Ankerite.Wiper to 1700'SSSV failed function test. RIH spot liner pill& KWF.Start P/U liner assembly. 00:00 02:30 2.50 10,912 10,919 PROD1 DRILL DRLG P 40 ft wiper-P/U weight 36K, Ct RIH weight 12K. Drilling ahead with new mud-1.40 bpm,3950, BHP 4550, ECD 13.3, ROP 7,WOB 2.8K,Ct weight 1K, WHP 350 psi. 02:30 03:30 1.00 10,919 10,921 PROD1 DRILL DRLG P ROP down to 2 fph. Discuss with town-high vibrations on BHA,good weight transfer no ROP-Steer straight up for an hour then call TD if no change due to ankerite or bit dull. 03:30 04:00 0.50 10,921 10,923 PROD1 DRILL DRLG P Slight ROP incease to 10 fph. Continue drilling 30 minutes. Pump Low/high sweep. 1.40 bpm,4000, BHP 4545, ROP 10,WOB 2.8K,Ct weight-2K.WHP 350 04:00 07:45 3.75 10,923 1,860 PROD1 DRILL WPRT P Pull long wiper to 1700'. P/U weight 37K 07:45 08:00 0.25 1,860 1,860 PROD1 DRILL CIRC P Jet SSSV thru EDC X 5 08:00 08:30 0.50 1,860 1,860 PROD1 DRILL OWFF P PUH above SSSV,Test. • 08:30 08:45 0.25 1,750 1,750 PROD1 DRILL OWFF P Test failed, 08:45 10:30 1.75 1,750 7,735 PROD1 DRILL TRIP P RIH, Page 9 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 10:45 0.25 7,735 7,735 PROD1 DRILL DLOG P Tie in depth.-4'Correction, RIH 10:45 12:30 1.75 7,735 10,920 PROD1 DRILL WPRT P Condition hole,Crude/gas in returns, take returns to tiger tank.47bbrls sent to tiger tank,shut down pumps for static BHP @ 10200'=4430 BHP in minutes 12:30 13:45 1.25 10,920 10,920 PROD1 DRILL WPRT P Take returns back inside, RIH to lay in liner running pill 13:45 15:00 1.25 10,920 8,000 PROD1 DRILL WPRT P Lay in liner pill, 15:00 16:30 1.50 8,000 6,500 PROD1 DRILL CIRC P Circulate KWF to surface,slowly POOH 16:30 17:00 0.50 6,500 6,500 PROD1 DRILL OWFF P Stop CT, check well for flow.Good 17:00 18:45 1.75 6,500 68 PROD1 DRILL TRIP P POOH Pumping KWF, 18:45 19:15 0.50 68 68 PROD1 DRILL OWFF P Flow-check @ surface for 30 minutes.safety meeting for Laying Down BHA&Liner prep. 19:15 20:15 1.00 68 0 PROD1 DRILL PULD P Lay down BHA-secure well. 20:15 21:45 1.50 0 0 COMPZ CASING RGRP P Service injector,valves&Top drive prior to P/U liner run. 21:45 23:15 1.50 0 600 COMPZ CASING PUTB P PJSM for P/U liner T Start P/U liner. safety joint drill with 1.1 minute response. 23:15 00:00 0.75 600 600 COMPZ CASING OTHR T Power Black out on Pad-21 joints in. Monitor well-no flow. Power came back up within 1 minute to pad. Start back up generator on rig& pick up safety joint(4 minutes).Wait for all clear from Pad operator before continuing ahead with liner running. 10/25/2010 RIH with liner assembly and set from TD 10,923 to TOB @ 9790'. POOH laying in KWF. BOP test waived by Chuck Cheeve. 00:00 00:30 0.50 600 600 COMPZ CASING OTHR T Rig on Generator power,waiting for the all clear from Pad operator prior to complete running liner.All clear on pad.lay down Safety joint. 00:30 02:00 1.50 600 1,173 COMPZ CASING PUTB P Continue with liner running.P/U Coiltrack BHA. 02:00 05:00 3.00 1,173 10,680 COMPZ CASING RUNL P Rlh with Liner pumping.3 bpm.-6.2 flag tie in. Clean through window. tagged up @ 10680' P/U weight 43K. Made it down to 10780'tag, 10828, worked down to TD-10923'. 05:00 05:15 0.25 10,680 10,923 COMPZ CASING RUNL P Bring pumps online @ 1bpm,4000 psi and P/U string weight 30K. Liner left on bottom. re-set depth POOH. TOB 9790' 05:15 07:15 2.00 10,923 3,000 COMPZ CASING RUNL P POOH laying in KWF 07:15 07:30 0.25 3,000 2,500 COMPZ CASING RUNL P Gas/Crude in returns.Take returns to tiger tank. 07:30 08:45 1.25 2,500 0 COMPZ CASING RUNL P Returns back inside. Mud cleaned up. Conitnue POOH 08:45 09:15 0.50 0 0 COMPZ CASING OWFF P At surface, PJSM,Monitor well Page 10 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 10:30 1.25 0 0 COMPZ CASING PUTB P LD BHA 10:30 13:00 2.50 0 0 PROD2 WHDBO SVRG P Swap out R2 on Kill line. Displace CT to water, Flush and grease stack and choke. 13:00 20:00 7.00 0 0 PROD2 WHDBO BOPE P Start BOP testing Low 250 psi high 4000psi-BOP test complete& waived by Chuck Cheeve. 20:00 22:30 2.50 0 0 PROD2 WHDBO BOPE P Test inner reel valve&Off drillers side PDL to 2500 psi.Start pumping KWM into CT string. 22:30 00:00 1.50 0 71 PROD2 STK PULD P PJSM-P/U new BHA with a 1.1 AKO.Well still dead-no flow. 10/26/2010 Tagged TOB @ 9789'-KOBT from 9788'continue drilling ahead. Mud swap after shale section vitas drilled. 00:00 02:00 2.00 71 8,700 PROD2 STK TRIP P RIH pumping.3bpm. EDC open.Tie in with-12 ft correction.Close EDC. Continue to TD to try and recover KWF. 02:00 02:30 0.50 8,700 9,200 PROD2 STK TRIP P Start getting oilly KWM across shakers after 30 bbls. Foam sweep at nozzle @ 9200'.1POOh chasing KWF.Send the lighter KWF to cuttings pit(12#or less). 02:30 03:30 1.00 9,200 8,600 PROD2 STK TRIP P POOh slowly to clean out KWF. Pump rate.7 bpm, ECD 13.7,4800 psi Annular.Started getting gas cut returns. Sent to TT.WHP choke @ 350, ECD 13.6, 1.3 bpm pump rate @ 8700'.Start RIH and getting set up to KOB. Keeping ECD 13.4 03:30 04:00 0.50 8,600 9,789 PROD2 STK TRIP P Good clean mud coming back. Continue RIH to TD.tag TOB dry @ 9789'Loss roughly 35 bbls of formate. 04:00 06:15 2.25 9,789 9,791 PROD2 STK KOST P Start time milling off Billet 80 left from 9788'. 1.36 bpm,3800, BHP 4500, ECD 13.5,WHP 250,WOB 1K,Ct weight 16.5K. 06:15 07:00 0.75 9,791 9,820 PROD2 STK KOST P Drill Ahead, 15 FPH 07:00 07:15 0.25 9,820 9,820 PROD2 STK KOST P PUH drift through sidetrack pumps off.Good, RIH 07:15 10:00 2.75 9,820 9,967 PROD2 DRILL DRLG P Drill Ahead 10:00 11:45 1.75 9,967 8,143 PROD2 DRILL WPRT P PUH,wiper to window. Maintain ECD @ 13.5 11:45 12:45 1.00 8,143 9,967 PROD2 DRILL TRIP P RIH ,still maintaining ECD @ 13.5 12:45 15:00 2.25 9,967 10,015 PROD2 DRILL DRLG P Drill Ahead 15:00 16:00 1.00 10,015 10,041 PROD2 DRILL DRLG P Continue drilling while swapping out to new 9.8 mud system. Recover old mud in tiger tank. 16:00 17:30 1.50 10,041 10,120 PROD2 DRILL DRLG P New mud system around.Continue to drill ahead. Page 11 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 20:00 2.50 10,120 10,120 PROD2 DRILL WPRT P Wiper trip-clean-RIH had Diff. pressure spike to 1700 psi on DH guage but no stacking of weight and no change in fluid rates in/out or circ pressures. Depth-9600'P/U weight -36K 20:00 21:00 1.00 10,120 10,177 PROD2 DRILL DRLG P Drilling ahead-free spin 3850 psi, 1.35 bpm,4050 psi, BHP 4570, ECD 13.3,WHP 175, ROP 110,WOB 1.1K,CT weight 12K. Bore pressure still not working correctly but all other paremeters are good. Drill ahead. 21:00 22:00 1.00 10,177 10,270 PROD2 DRILL DRLG P ROP dropping &WOB 2.8K-might be fault or ankerite stringers. Changing HP screens to.80 to lesson pump pressure.Currently 4150 psi @ 1.34 bpm.Slight pressure drop with new screen to 3990 @ 1.35 bpm. 22:00 00:00 2.00 10,270 10,270 PROD2 DRILL WPRT P Wiper trip-P/U weight 37K.tie in-5 ft correction. 10/27/2010 Drilling ahead in good formation all day.One long wiper trip to 1700'with good cuttings in returns. Possible ledge @ 8530'during wipers-lower pump rates through area @ 45 right.43 bbls loss in 24 hours to formation. 00:00 01:00 1.00 10,270 10,270 PROD2 DRILL WPRT P RIH from wiper trip-Bore& differential no working.still going to drill ahead. 01:00 02:30 1.50 10,270 10,420 PROD2 DRILL DRLG P Drilling ahead 1.35 bpm,3980 psi, BHP 4520, ECD 13.3,WHP 170, ROP 118,WOB 1.7K,CT weight 13K. 02:30 04:15 1.75 10,420 8,149 PROD2 DRILL WPRT P Wiper trip-P/U weight 38K 04:15 05:15 1.00 8,149 10,420 PROD2 DRILL TRIP P RBIH 05:15 07:00 1.75 10,420 10,570 PROD2 DRILL DRLG P Drill ahead 1.3 BPM,4025 psi. 07:00 08:45 1.75 10,570 8,100 PROD2 DRILL WPRT P Wiper Trip up to window,40k off btm. 08:45 10:00 1.25 8,100 10,570 PROD2 DRILL TRIP P RBIH 10:00 12:00 2.00 10,570 10,720 PROD2 DRILL DRLG P Drilling Ahead 12:00 18:00 6.00 10,720 10,720 PROD2 DRILL WPRT P Wiper,over pull to 45k leveled out to 40k.decided to pull wiper up to 1700' . near bottom of wiper had oil returns to surface. 18:00 20:00 2.00 10,720 10,870 PROD2 DRILL DRLG P Drilling ahead-1.32 bpm,4000, BHP 4600, ECD 13.5,WHP 200,WOB 1.2K, Ct weight 10K, ROP 115 Page 12 of 16 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:00 23:30 3.50 10,870 10,870 PROD2 DRILL WPRT P Wiper trip-P/U weight 38K.tagged up @ 8530'while RIH @ 1 bpm. trying to work through at lower pump rates. First time TF was 5 left then other times 15 right. Made it through 45 Right @.7 bpm.Wipe back up through it,to ensure area is clean. No issues, looks like a ledge. RIH. Clean to bottom. 23:30 00:00 0.50 10,870 10,890 PROD2 DRILL DRLG P Drilling ahead-1.35 bpm,4100psi, BHP 4560, ECD 13.3, ROP 90, WOB 1.1K,Ct weight 6K. 10/28/2010 Drill ahead&TD lateral @ 11052'-Wiper up to 1700', RIH lay in liner pill&KWF. P/U first liner section 69 joints. 00:00 01:00 1.00 1 10,890 10,985 IPROD2 DRILL DRLG P Drilling ahead-1.35 bpm,4100, BHP 4600, ECD 13.5, ROP 80,WOB 2.5K,Ct weight 8k.-10,960' Formation returns are slowing down to surface. Pump 5/5 sweeps continue to monitor shakers. 01:00 02:30 1.50 10,985 11,054 PROD2 DRILL DRLG P P/U 100'for weight check.38K. Sweep leaving bit. Little better cuttings at surface with sweep. Continue drilling ahead to TD. ROP dropped off last 8 ft. 02:30 07:00 4.50 11,054 1,700 PROD2 DRILL WPRT P TD Wiper trip Pumped 10/10 bbls sweep-P/U weight 45K Wipe to window and guage cuttings-heavier cuttings up near window,wipe to 1700'prior to liner run. 07:00 10:30 3.50 1,700 11,052 PROD2 DRILL TRIP P RBIH.Tie into formation for-9 correction. Paint window flag @ 5771.73 Continue RIH to TD 11052' 35k off btm. Paint TD Flag @ 8771.73 10:30 15:30 5.00 11,052 0 PROD2 DRILL TRIP P Begin pumping 13.1 liner pill up to the window. Lay in 13.1 KWF to surface. Note had trouble getting 1:1 returns at first, had to slow down pump rates&POOH speed. 15:30 17:30 2.00 0 0 PROD2 DRILL PULD P On surface,watch for flow for 15 minutes, looks good.Conduct pre-job prior to laying down BHA. Lay down BHA in 2 pieces. 17:30 19:30 2.00 0 0 COMPZ CASING SVRG P Crew change,Service the top drive& set up the rig floor. 19:30 22:30 3.00 0 2,234 COMPZ CASING PUTB P PJSM-Start picking up liner-safety joint drill.total of 69 joints. 22:30 23:30 1.00 2,234 2,278 COMPZ CASING PUTB P P/U BHA-Strip down injector. 11.2K string weight. 23:30 00:00 0.50 2,278 3,000 COMPZ CASING RUNL P RIH pumping .3 bpm through closed EDC 10/29/2010 Ran liner as far as it could @ 10720'-330'prior to TD due to push&P/U weights.Set top of Anchored billet @ 8409'. Kick off from 8408'.Clean kick off. Page 13 of 16 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 3,000 7,987 COMPZ CASING RUNL P RIH-stop @ 7987'-10ft correction at flag. P/U weight 40K. RIH through window 01:00 02:30 1.50 7,987 10,170 COMPZ CASING RUNL P Window was clean, Start seeing weight loss around 9650'Shale section-Stacking out @ 9970'51K P/U,continue working down. Not moving from 10150'P/U weight 60K, RIH-20K Ct life in good shape. 02:30 04:00 1.50 10,170 10,721 COMPZ CASING RUNL P Pump down Backside to try&push liner pills down @.3 bpm.Cycled pipe another 6 trimes and started working in hole much smoother. Next bad spot 10670', P/U weight 60K. Hard time breaking the pipe friction DH max.of 10708'. Call town and release liner. 04:00 06:45 2.75 10,721 10,721 COMPZ CASING RUNL P Bring pumps up to 1.2 bpm, P/U weight 32K. Released. POOH laying in KWF. Bottom of liner @ 10721 -top 8487'. Solid liner from 9707'to 9342'. 06:45 09:15 2.50 0 0 COMPZ CASING PUTB P OOH.Watch for no flow,good. Lay down BHA#14. Pick-up BHA#15, _liner run#2. 09:15 12:00 2.75 0 8,483 COMPZ CASING RUNL P Open EDC, RIH W/BHA#15. pumping.25 BPM.Tie into formation -15'correction 12:00 12:15 0.25 8,483 8,483 COMPZ CASING RUNL P Tag @ 8483'. Pick-up&retry several times, same depth. Pump down down,pressure up to 4500 psi, set billet. 12:15 14:30 2.25 8,483 0 COMPZ CASING RUNL P POOH to surface, pumping 13.1 KWF to keep hole full 14:30 15:15 0.75 0 0 COMPZ CASING SFTY P OOH,30 minute no flow test while conducting un-deploy safety meeting. 15:15 17:15 2.00 0 0 COMPZ CASING PUTB P Lay down BHA. Pick-up Drilling BHA. 17:15 20:45 3.50 0 8,100 PROD3 STK TRIP P RIH W/BHA#16. Start pumping Sweep&Drilling fluid to be at window.Tie in-14'. Swap pumps due to pump problems. Good B/U with KWF, no oil in recovery. Pumped .9 bpm from window to 7600'slowly. RIH holding MPD with _drill mud. 20:45 21:00 0.25 8,100 8,409 PROD3 STK TRIP P Stop pumping, Close EDC. RIH to TOB,dry tag @ 8409.5'P/U weight 21:00 00:00 3.00 8,409 8,422 PROD3 STK KOST P ,Start time milling from 8409'. Continue with milling procedure P/U to 20 fph @ 8417'. Billet looks clean. Drill ahead @ 8422' 10/30/2010 Continue drilling ahead to TD of 9433'. Long wiper trip to 1700' 00:00 00:30 0.50 8,422 8,430 PROD3 DRILL DRLG P Drilling ahead-Wipe up through Billet,clean. Start mud swap. Page 14 of 16 Time Logs . . Date From To, bur S. Depth E. Depth Phase Code Subcode T Comment 00:30 02:30 2.00 8,430 8,490 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4100 psi, BHP 4400, ECD 13.1,WHP 250, WOB 2K,Ct weight 15K, ROP 40. New mud coming around. 02:30 03:00 0.50 8,490 8,490 PROD3 DRILL WPRT P Wipe up to window,cutting lightened up over shakers with new mud, ROP slowed to 20. P/U weight clean 33K. 03:00 06:30 3.50 8,490 8,640 PROD3 DRILL DRLG P Drilling ahead-1.35 bpm,4000psi, BHP 4400, ECD 13.2,WHP 250, ROP 70,WOB 1.3K, Ct weight 14K, better cuttings to surface. 06:30 07:30 1.00 8,640 8,640 PROD3 DRILL WPRT P Drilled to 8640' 34k off btm.Wiper up to window @ 8138'hold 13.4 ECD while tripping RBIH 07:30 09:00 1.50 8,640 8,790 PROD3 DRILL DRLG P @ 8640'drill a head. 1.38 BPM, 4300 PSI, BHP 4442 PSI,WHP 191 PSI, ECD 13.2 RO�98 09:00 09:45 0.75 8,790 8,790 PROD3 DRILL WPRT P Pu WT @ 34k.wip r up to window Good cutting returns &tie in to RA for-0 correction. RBIH 09:45 11:15 1.50 8,790 8,940 PROD3 DRILL DRLG P Drill Ahead 1.36 BIM,4200 PSI, BHP 4429 PSI,WHP 190, ECD 13.2 11:15 12:30 1.25 8,940 8,940 PROD3 DRILL WPRT P Wiper up to window.Good cutting returns RBIH 12:30 14:30 2.00 8,940 9,090 PROD3 DRILL DRLG P Drill Ahead ROP 104, 1.33 BPM 4250 PSI, BHP 4444 PSI,WHP 183, ECD 13.2 14:30 16:00 1.50 9,090 9,090 PROD3 DRILL WPRT P Wiper up to window. RBIH 16:00 17:30 1.50 9,090 9,240 PROD3 DRILL DRLG P Drill Ahead 1.3 BPM,4300 psi, BHP 4438 PSI,WHP 175 PSI, ECD 13.2 17:30 19:00 1.50 9,240 9,240 PROD3 DRILL DRLG P Wiper trip to window tie in-1. P/U 35K. 19:00 20:45 1.75 9,240 9,390 PROD3 DRILL DRLG P Drilling ahead-1.30 bpm,4100, BHP 4441, ECD 13.4,WHP 200, ROP 100,WOB 2K,Ct weight 13K. 20:45 22:15 1.50 9,390 9,390 PROD3 DRILL WPRT P Wiper trip-P/U weight 36K-started to get oil cut mud on wiper. Increased MPD pressure by 75 psi. 22:15 23:30 1.25 9,390 9,433 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,4100, BHP 4520, ECD 13.4,WHP 275, ROP 70, WOB 1.3, Ct weight 11K. Pump low -high sweep. 23:30 00:00 0.50 9,433 9,433 PROD3 DRILL WPRT P P/U weight 35K-wiper up to 1700' holding MPD 10/31/2010 Run&set final liner run from 9433-8089'.Circulate out KWF,freeze protect well from 2500'to surface. Undeploy BHA.WHP 1700 psi.fluid packed. 00:00 05:00 5.00 9,433 9,433 PROD3 DRILL WPRT P Wiper trip to 1700'to clean out wellbore.Tie in-7ft.Close EDC- continue RIH to TD. 05:00 09:00 4.00 9,433 0 PROD3 DRILL TRIP P POOH laying in liner pill KWF 09:00 09:30 0.50 0 0 PROD3 DRILL SFTY P OOH. No flow test for 30 minutes, conduct pre-job meeting prior to laying down BHA. 09:30 10:45 1.25 0 0 PROD3 DRILL PULD P Lay down BHA. Page 15 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 11:00 0.25 0 0 COMPZ CASING SFTY P Conduct pre-job on running liner. 11:00 14:30 3.50 0 1,387 COMPZ CASING PUTB P Pick-up LI-02 liner.&BHA 14:30 16:45 2.25 1,387 9,435 COMPZ CASING RUNL P RIH, pu wt @ window 39k. Liner @ 9435'Pump off liner with no problems.Top of Liner @ 8089'. 16:45 18:45 2.00 8,078 8,078 COMPZ CASING CIRC P Re-set bit depth from 9421'to 8078'.Start displ coil&well to seawater recovering 13.1 KWF.Oily crude returns with bottom section of KWF. 18:45 20:45 2.00 8,078 2,500 COMPZ CASING RUNL P POOH holding 1000 psi on WHP to keep BHP 4200psi with SW.Clean SW returns to surface. 20:45 21:45 1.00 2,500 71 DEMOB WELLPF TRIP P Set up to pump diesel down CT string for freeze protect.WHP 1600psi, BHP 2600. Pump 30 bbls of diesel down CT siting. POOH displacing well to diesel,taking returns to TT. 21:45 23:30 1.75 71 0 DEMOB WELLPF PULD P PJSM-pessure un leploying. Ciro pressure 1600psi,WHP 1580, Bore 1630 psi. 23:30 00:00 0.50 0 0 DEMOB WELLPF SEQP P Prep floor and equipment for BPV installation. 11/01/2010 Set BPV with 1700 psi below. Flushing stack&blowing down equipment. Unstab Plpe, Injector maintenance. ***Rig release @ 12:00. noon) 00:00 02:30 2.50 0 0 DEMOB WHDBO MPSP P Set BPV. Recorded SITP 1700 psi below plug. Remove all excess fluid from pits&flush. 02:30 05:30 3.00 0 0 DEMOB MOVE CIRC P Start flushing stack and purge lines to pits.Breaking down hard line. Blow down all lines and CT string. 05:30 12:00 6.50 0 0 DEMOB MOVE RGRP P Continue with rig move items. Unstab injector and prep for skate change 0 DEMOB *****RIG Release off 3J-15 at noon ****. 1 Page 16 of 16 3J-15 Well Work Summary DATE SUMMARY 11/6/10 TAGGED LINER TOP @ 8089' RKB. MEASURED BHP @ SAME: 4218 PSI. SET CATCHER @ 8085' SLM. PULLED DV @ 7912' RKB & REPLACED WITH OV. IN PROGRESS. 11/7/10 PULLED DVs @ 7592', 6838', 5975', 4545' &2309' RKB, REPLACED WITH GLVs. PULLED CATCHER @ 8085' SLM. COMLETE. Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, October 25, 2010 2:18 PM To: 'Ohlinger, James J' Subject: RE: 3J-15 L1-02 (PTD 210-138) (PTD 210-139) James, The changes to the wellplan for 3J-15L1-02 (PTD 210-138) are acceptable as they stay within 500' of the original BHL per 20 AAC 25.015 (a)(2). The PTD for 3J-15L1-03 (PTD 210-139) will be withdrawn at your request. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ohlinger, James J [mailto:James.J.Ohlinger @conocophillips.com] Sent: Monday, October 25, 2010 9:59 AM To: Schwartz, Guy L(DOA) Subject: 33-15 We're looking at modifying the L1-02 lateral and dropping the L1-03. Schematic attached. James Oh linger CTD Engineer ConocoPhillips AK, Inc. 907-265-1102 office 907-748-1051 cell 10/25/2010 (}� �v� ' 03 y�N J M s a MEI c 1 m 0 z NI a.t t E:� Co E a :8 t .r, cc. �. a —i Z .o om I -,t m °�c o`O 2 + -4 i+ iF ,+ -+- -+- H+-aj I q1 I I I I I I' I I 4 + I in Q ov t :. i ro _ i !{ i o it Jil �!1 ,� E. V Q IT .. .a _ lel M ++ 1-- - CI - N Ii 0 Q . v F . N _ _ a wr r � .....LL� J - o (V1 A. C O LA r I r r S J ——y M _ LLY , ) OMI CD ■ .1:73 2 di CD NI ..t- o0 Lr) O M - _ i \ Cli ° u.,- � a o m ( , L O if QM .V.` J a g CI: 1 0 o I 51 N WO O 0 0 O O O CO 0 a M 1 V Q kr ■ N a L _ umm a-t-_, d m .• z v o1,"3 . m mom: ;H,ii.-.-14--,+-a—I—a+ -Hal.- :-4--:—* N`s i i i 1 1 I I i i 1 an o� .. N •.o2 3 = o e I ; s c r - a -- C�J O CO .• I W CI 2 2 Q o w w � - O O w co co r O O _ - a o _ o Q. � _ 0 ■ 0 0 _ . m a CO al. 0., Q - O - • w • o CU Cr) m i CO •moo N M o - - i 0) O O i °° L J fJ $cs a C,O N + +-s a 1 f 0 _c 0 O N _ 1 I N m } •o 0 O o Cf o O G E"o c°h c�'i " "' ..°-, 4C, CC, 1"-- scipllIE Dif a B L / SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3J-15L1-02 ConocoPhillips Alaska, Inc. Permit No: 210-138 Surface Location: 1140' FSL, 565'FWL, SEC. 3, T12N, R9E, UM Bottomhole Location: 1040' FNL, 384' FEL, SEC. 3, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 3J-15, Permit No 185- 289, API 50-029-21497-00. 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. Sincerely, Daniel T. Seamount, Jr. 71‹ Chair DATED this/ day of September, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) , , RE 'ExV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ti Ft 1 4 2010 PERMIT TO DRILL .y, r,� ,, rt_ r } r�. 20 AAC 25.005 "40.7115"x109 la.Type of Work: lb.Proposed Well Class: Development-Oil le Service-Winj ❑ Single Zone 0 lc.Specify if well Is Proposed for: Drill ❑ Re-drill 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates Cl Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 . 3J-15L1-02 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:9475' TVD: 6405' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1140'FSL,565'FWL,Sec.3,T12N,R9E,UM " ADL 25630 , Kuparuk River Oil Pool ' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 944'FNL, 1052'FEL,Sec.3,T12N, R9E, UM 2563 10/3/2010 Total Depth: 9.Acres in Property: 14.Distance to 1040'FNL,384'FEL,Sec.3,T12N, R9E, UM 2560 Nearest Property: 15600 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 74 feet 15.Distance to Nearest Well Open Surface:x- 519545 ' y- 6002823 ' Zone- 4 GL Elevation above MSL: 40 feet to Same Pool: 3K-08,1200 ' 16.Deviated wells: Kickoff depth: 8700 -ft. 17.Maximum Anticipated Pressures in psig(see 20 AAc 25.035) Maximum Hole Angle: 97° deg Downhole:4233 psig Surface:3623 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling , Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 975' 8500' 6403' 9475' 6405' 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) 8659' 6746' none 8409' 6562' none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 200 sx AS II 104' 104' Surface 4009' 9.625" 1300 sx AS III,325 sx Class G 4039' 3486' Intermediate Production 8470' 7" 360 sx Class G, 175 sx AS I 8500' 6630' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 8047'-8064',8235-8254',8274'-8311' 6305-6316',6439'-6450',6465'-6491' 20.Attachments: Property Plat Li BOP Sketch❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program El 20 MC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-1102 O Printed Name V. Cawvey Title Alaska Wells Manager Signature 7- Phon2s5-63o6 Date ,(,t)��� /�f(� Commission Use Only ,�//jjjjjj// (( '�`� Permit to Drill API Num r: Permit Approval See cover letter ��() / 621,2i�` 7 : oL(tsf Number: y / ..n .', 50- �z, Date: for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed mejhane,gas hydrates,or gas contained in shales: D dF I-f QeZ) p Scl SOP 7S f-- Samples req'd: Yes ❑ No Q' Mud log req'd: Yes ❑ No [r Other: / -� H2S measures: Yes 0 No II Directional svy req'd: Yes [ No ❑ ZS®° — ArtnwJ�t✓ ( �S�/ '\ - DATE: O R `1 L APPROVED BY THE COMMISSION 9� ,/Ci COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in 9•/11• /6 f✓4, /6 q.l �� Permit to Drill Summary of Operations KRU 3J-15L1, 3J-15L1-01, 3J-15L1-02, 3J-15L1-03 Laterals Coiled Tubing Drilling Overview: The 3J-15 well is in an area that contains many sealing and highly baffling faults. The result of this is lower than expected oil recovery as oil resource is not being adequately produced from nearby fault blocks that have injection support with little or no production off-take. The scope of this project is to drill four CTD laterals out of the 3J-15 motherbore in order to target these areas of under-produced oil resource in the Kuparuk A-sand. Pre-rig work will be performed to allow CTD while maintaining the parent well's original A-sand completion. This will involve cement squeezing and abandoning the C-sand interval in the parent well which currently produces approximately 75 BWPD and zero oil. The sidetrack will utilize a monobore whipstock to conduct a dual string exit through the 3-1/2"tubing and 7" liner. The top of the whipstock is planned for 8,110' MD within the straddle,with Packers set at 7972'and 8144' MD. The 3J-15 motherbore completion will be retained by use of a flow through whipstock to maintain the original area. The first CTD lateral will target the A2 sand and will be drilled across the large south to north fault into the block containing the 3K-08 injection well. The second lateral will target the A3 sand and will kick out of the first lateral. It will run parallel to the first lateral so that both A-sands will have sufficient reservoir exposure on that side of the fault. The third and forth laterals will kick out of the first lateral on the west side of the south to north fault to increase exposure in both the A2 and A3 sands. Approximately 5,550 ft of total hole will be drilled and the productive intervals will be completed with slotted liners. The 3J-15L1 is planned for a 2-3/8" slotted liner with a liner-top aluminum billet for the KOP for the L1-01 lateral at—9,950' MD. The 3J-15L1-01 is planned for a 2-3/8"slotted liner with a liner-top aluminum billet for the KOP . for the L1-02 lateral at—8,700' MD. The 3J-15L1-02 is planned fora 2-3/8" slotted liner with a liner-top aluminum billet for the KOP for the L1-03 lateral at—8,500'MD. 3K-12L1-03 will be completed with 2-3/8" slotted liner from TD to—8150' MD in the original well bore. Operational Outline Pre-Rig Work • Slickline: A-sand SBHP,pull TPI from AVA, dummy GLV's, MIT-IA Drift w/dummy whipstock, • E-line: Run GRJCCL jewelry log/tie-in log(7900' to 8200' RKB). Set 2-7/8"HES "FasDril"Composite Bridge Plug(CBP) in the tubing tail @ 8,161' RKB. Con firm injection into the C-sand interval. • Slickline: Bail in sand with a barite cap. • E-line: Shoot holes in the 3'/2"tubing 8020' —8030' RKB, and 8110' —8120'. • Coil: Lay in cement plug from sand plug up to the 3-1/2"Cameo Production Mandrel @ 8010' RKB. • Slickline: Tag TOC and PT to 1500 psi. • Coil: Mill out cement, sand/barite plug, and CBP • Slickline: Run dummy whipstock • 0: Set BPV,prepare Wellsite for rig arrival Page 2 of 5 9/7/2010 Permit to Drill Summary of Operations Cont. KRU 3J-15L1,3J-15L1-01,3J-15L1-02,3J-15L1-03 Rig Work t. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU BOPE and test 2. Set top of whipstock at 8,110' ELM 3. Mill 2.80"window at 8,110'; dual string exit 3-1/2"x 7" 4. 3J-15L1 Lateral a. Drill a 2.70"x 3"bi-center lateral to a TD of 11,050' MD b. Run the 2%" slotted liner to TD with an aluminum liner top billet at 9,950' MD. 5. 3J-15L1-01 Sidetrack a. Kick off of the aluminum liner top billet at 9,950' MD b. Drill a 2.70"x 3" bi-center lateral to a TD of 11,100' MD c. Run the 2%" slotted liner from TD with an aluminum liner top billet at 8,700' MD. 6. 3J-I5L1-02 Sidetrack a. Kick off of the aluminum liner top billet at 8,700' MD TD'S b. Drill a 2.70"x 3"bi-center lateral to a TD of 9,475' MD ?ID c. Run the 2%" slotted liner from TD with an aluminum liner top billet at 8,500' MD. T 7. 3J-15L1-03 Sidetrack a. Kick off of the aluminum liner top billet at 8,500' MD b. Drill a 2.70"x 3"bi-center lateral to a TD of 9,175' MD Post-Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system Mud Program • Chloride-based Biozan brine (8.9 ppg) for milling operations, and chloride-based Flo-Pro mud (-9.20 ppg) for drilling operations. • There is an SSSV installed in 3J-15 so we may not have to load the well with completion fluid to deploy the 2-%"slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Top Btm Liner Details Other Details MD MD 3J-15L1 9,950 11,050 2%", 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3J-15L1-01 8,700 11,100 2%', 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3J-15L1-02 8,500 9,475 2%', 4.7#, L-80, ST-L slotted Unanchored aluminum billet 3J-15L1-03 8,105 9,175 2%",4.7#, L-80, ST-L slotted Page 3 of 5 9/7/2010 , IGIIL Permit to Drill Summary of Operations Cont. KRU 3J-15L1,3J-15L1-01,3J-15L1-02,3J-15L1-03 Existing Completion Details: Category OD Weight Grade Top Btm Burst Collapse (ppf) MD MD psi psi Conductor 16" 65 H-40 0 104 1640 670 Surface 9'/8" 36 J-55 0 4,039 3520 2020 Casing 7" 26 J-55 0 8,500 4980 4320 Tubing 3 '/2" 9.3 J-55 0 8,152 6,980 7,400 Tubing 2 '/8" 6.5 J-55 8,152 8,166 7,260 7,680 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Maximum potential surface pressure is 3623 psi assuming a gas gradient to surface based on the potential pressure of an equivalent 13.0 ppg mud weight. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3J-15L1 14,650' 3J-15L1-01 14,650 3J-15L1-02 15,600 • 3J-15L1-03 15,900' • Distance to Nearest Well within Pool (toe measured to offset well 3K-08) Lateral Name Distance 3J-15L1 1200' 3J-15L1-01 1200' 3J-15L1-02 1200' 3J-15L1-03 1235' Logging MWD directional, resistivity, and gamma ray will be run over the entire open-hole sections. Reservoir Pressure 3J-15 is currently completed in both the C and A sands as a single-selective type completion, and had a static bottom hole pressure for the C-sand of 2302 psi (7.1 ppg EMW), and the A-sand was 2049 psi (6.4 ppg EMW). 3K-13 has been shut in, and recently measured 4247 psi (12.5 ppg EMW) on August 31St. 3K-08 has also been shut in from injecting water and it measured 4194 psi (12.3 ppg EMW, June '10). Similar pressures are expected as the laterals are drilled. Page 4 of 5 9/7/2010 ORIGINAL Permit to Drill Summary of Operations Cont. KRU 3J-15L1,3J-15L1-01,3J-15L1-02,3J-15L1-03 Hazards • Pressure is expected to increase along wellbore. Maintain sufficient ECD to overbalance. A 9.2 ppg mud system and annular friction will supply enough pressure to overbalance the expected reservoir pressure. Choke pressure can be applied to if higher pressures are encountered as we near the surrounding injectors. • Well 3J-15 has 170 ppm H2S as measured on Dec. '09, and is the maximum H2S level on the 3J pad. All H2S monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling (MPD)techniques will be employed to provide constant bottom hole pressure by using 9.20 ppg drilling fluid in combination with annular friction losses and if needed 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 3J-15 does have a SSSV, so the well may not have to be loaded with completion fluid prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following charts show the different pressure parameters in both "pumps on" and "pumps off'conditions. Drilling Conditions: Pressure at the Window Using MPD (FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 2050 psi 2050 psi Mud Hydrostatic(9.20 ppg) 3000 psi 3000 psi Annular Friction 770 psi 0 psi Mud?+Annular Friction 3770 psi 3000 psi (no choke pressure) (overbalanced (overbalanced -1720 psi) -950 psi) Target Pressure(11.5 ppg) 3745 psi 3745 psi Choke Pressure Required 0 psi 745 psi to Maintain 11.5 ppg Example: Using the 3J-15 SBHP from July'08 with a reservoir pressure of 2050 psi at 6290 TVDss (6.3 ppg EMW). While drilling and circulating at 1.5 bpm with 2" e-coil, head from the 9.20 mud (3000 psi), plus an estimated 770 psi of annular friction (assuming friction of 95 psi/1000 ft)will provide 3770 psi BHP (11.57 ppg EMW) and overbalance the reservoir by-1720 psi. When circulation is shut down, the mud will still be overbalanced to the reservoir pressure. However maintaining -745 psi at surface when the pumps are shut down will maintain a constant 11.5 ppg EMW to promote wellbore stability. Page 5 of 5 9/7/2010 ORIGINAL -o c -a b U) c CI L0 co al 0) .' 2 en co < C) CO 0.) p ,▪ -..., -J •s- 2 C s- A_I I- 21 II "- as U) . , : 5, N to __I H _Ti : I - < r..D cp --- .,_ , zo To 2 co _ , , , , " N - - -0 a) Lo in c N- N- " as o_ ea , , Co o -.1 '-- o u) - a) - o , , ,, ,, co CD c 0 ., $_. Co c=, " co L5 0 • 0 < c0 „ A . CO ---- ' o c —0 co .9_ z _J 1- . , N- io 0 " " . ■ • cn N- ra N. a) . • , , . ; s 5 ' . , " _- E N , LO 00 0 I I -.) , , ■ Y .. io 2 ' a 0 . , o La CD , , 0,1 _J 7-1 I-- Zi co .1- --- 0 Y " `t - ___p - on oi LU " , , • ZS) 0 - CC c." Y - . ' „ cr, cp - n') o co _ . , , co Y - N Z•0 4 .--- ••-• CO 0 :'t 3 --3. Y cn c g co Op CO '2 -- ,- 1,-- , , (TS A , , C la- Y Y g a) co a, ca „ „ : u_ ',,, FY -a ,z,‘,-- Y , , . , ' , o▪ )- -o 725_ - , , • W co -2 c , . 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(P ir Or 0 U) -c 0_co N o - LI, •i-i 1- c0 0 0 ts) co Y CD 'C'ts u) -0 c°. i,- c0 co c '7 I C.'"> 4* a oa a) t- EL 1) CO ir) ---- co co ? 0 0- 0 < 00 ;:1- Z.o o r'''‘ ni. 1 G 1 1\4 iNk L KUP 3J-15 Conoco Phillips �49 1�- Well Attributes Max Angle&MD TD -4 � Wellbore APW WI Field Name Well Status Ind(7 MD(RKB) Act Bhn(RKB) AI951(5.t1C. 500292149700 IKUPARUK RIVER UNIT (PROD 50.03 3,400.00 8659.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date web cQ rg,.;s�t�g„7, ,o.,.,@gs<)_c-2N ""'-SSSV:TRDP 140 12/10/2008 Last WO: 33.91 2/5/1986 Sg1�aJiG.AtBUaL,^ -. ,.,_Annotation Depth RK ( B) End Dote (Annotation (Last Mod By End Date Last Tag:SLM 8,329.0 8/52009 Rev Reason:PULL PLUG,SET TPC Imoshor 1126/2009 Casing Strings _ String OD String ID Set Depth Set Depth(TVD) String Wt String Casing Description (in) (in) Top(BKB) (RKB) (RKB) (Ibsltt) Grade String Top Thud .�,- _., V:1i.:. CONDUCTOR 16 15.062 OA 104.0 104.0 62.50 H-40 SURFACE 95/8 8.765 0.0 4,039.0 3,485.6 36.00 J-55 SURFACE(OC) 95/8 8.835 33.1 4,038.9 36.00 J-55 BTC PRODUCTION 7 6.151 0.0 8,500.0 6,630.3 26.00 J-55 CONDUCro PRODUCTION(DC) 7 6.276 30.8 8,499.6 26.00 J-55 BTC Tubing Strings S = AFETYVLV, 1,806 String OD String ID Set Depth Set Depth(ND) String Wt String Tubing Description (in) (in) Top MD) (8KB) MKS) (Ibs/R) Grads String TopThrd TUBING 3 12 2.992 0.0 8,152.0 6,377.6 9.30 J-55 EUE8rdABMOD OAS LIFT .309' jr- TUBING 27/8 2.441 8,152-0 8,166.0 6,387.4 6.50 J-55 8RD EUE 2 '; Othe'rtn.Hole 1All Jewelry.Tilb i Run&Retrievable,Fish,etc.) Top Depth d, (TVD) Top Inel Top(MKB) (RKB) (') Description Comment Run Date ID(in) 1,806 1,805.4 9.41 SAFETY VLV Camco"'ADP-IA-SSA' 4/16/1986 2.812 2,309 2,279.6 29.63 GAS UFT CAMCO/KBUG/1/GLV/BK/.156/1331/Comment STA 1 8/17/2009 2.875 SURFACE, 4,039 4,545 3,8292 44.79 GAS UFT CAMCO/KBUG/1/GLV/BK/.156/1319/Comment STA 2 8/17/2009 2.875 ,. 5,975 4,849.0 44.59 GAS UFT CAMCO/KBUG/1/GLV/BK/.188/1344/Comment STA 3 8/18/2009 2.875 GAS LIFT, 4,545 -, :. 6,838 5,462.8 44.67 GAS UFT CAMCO/KBUG/1/GLV/BK/.188/1329/Comment STA 4 8/18/2009 2.875 J 7,276 5,771.1 45.95 GAS UFT CAMCO/KBUG/1/DMYBK///Comment STA5 8/18/2009 2.875 GAS LIFT• _y 7,592 5,989.6 46.24 GAS UFT CAMCO/KBUG/1/OVBK/.25//Comment STA6 8/182009 2.875 5,975 - ____ __ _ 17 7,912 6,210.7 46.21 GAS LIFT MERLA/TPDX/1.5/DMY/RM///Comment:STA 7 8/17/2009 2.875 7,958 6,242.5 46.19 PBR _.._Baker 4/16/1986 3.000 GAS LIFT, - 6,638 ., 7,971-6,2522 46.18 PACKER Baker'FHL' 4/16/1986 3.000 8,010 6,2793 47.07 PRODUCTION CAMCO/KBUG/1/DMYBK///Comment CLOSED STA 8 I 4/16/1986 2.875 GAS LIFT, '..,.a' 8,130 6,362.0 45.51 NIPPLE AVA BPL Ported Nipple 4/16/1986 2.750 7,276 _ 8,130 6,362.0 45.51 SLEEVE-0 2.75"TPC NEW STYLE w2.31"ID 11/8/2009 2.310 8,144 6,372.0 45.33 PACKER Baker'FB-1' 4/16/1986 4.000 GAS LIFT,- ' 7,592 8,157 6,381.1 45.16 NIPPLE Camco'D'Nipple NO GO 4/16/1986 2.250 8,165 6,386.7 45.06 SOS Camco 4/16/1986 2.441 GAS LIFT, 'r 7,912 8,166 6,387.4 45.04 TTL 4/16/1986 2.441 Perforations&Slots PER,7,956- ---,1 Top(ND) Btm(N Shot D)F Dann _ Top(RKB) Bim(RKit (RKB) (MIKE) Zone Date (sh-. Type Comment 8,047 8,064 6,304.6 6,316.2 C-1,UNIT B, 4/15/1986 12.0 IPERF 5"HJ II Csg Gun,120 deg ph PACKER,7,972 3J-15 8,238 8,245 6,438.7 6,443.7 A-3,3J-15 4/11/1988 4.0 REPE...2 1/8"EnerJet,90 deg ph PRODUCTION,_ 8,245 8,246 6.443.7 6,444.4 A-3,3J-15 4/11/1988 5.0 REPE...2 1/8"EnerJet,90 deg ph 0,019 _. 8,246 8.252 6,444.4 6,448.7 A-3,3J-15 4/11/1988 4.0 REPE...2 1/8"EnerJet,90 deg ph 8,252 8,253 6,448.7 6,449.4 A-3,3J-15 4/11/1988 5.0 REPE..21/8"EnerJet,90 deg ph IPERF, ,...7 8,253 8,254 6,449.4 6,450.1 AA-3,3J-15 4/11/1988 4.0 REPE..21/8'EnerJet,90 deg ph 6,0474,064 R 8,274 -8,311 6,464.6 6,491.4 A-2,3J-15 4/15/1986 4.0 IPERF 4"NJ II Csg Gun,90 deg ph NIPPLE EEEi30.\ _ Notes General&Safety w - 0.130 End D to Annotation IF1/25/1989 I NOTE:WAIVERED WELL:IA OA COMMUNICATION PACKER,8,144 ,__ LIJ NIPPLE,8.157 Er SOS,8,185-- ' 4.. TTL,8,166- - REPERF, 8,238-8,245 REPERF, 8,245.8,240 PERF, 8,246RE4,252 M. REPERF. -- 8,2524,253 REPERF, 8,253-8.254 IPERF, 8,274-8,311 - PRODUCTION, 8,500 TO,8,659 flIGIh-A ConocoPhil l ii�- s Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3J Pad 3J-15 3J-15L1-02 Plan: 3J-15L1-02_wp01 Standard Planning Report 30 August, 2010 r BAKER HUGHES Iv ConocoPhillips rPI' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3J-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3J-15 @ 74.00ft(Rowan 34) Site: Kuparuk 3J Pad North Reference: True Well: 3J-15 Survey Calculation Method: Minimum Curvature Wellbore: 3J-15L1-02 Design: 3J-15L1-02_wp01 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3J Pad ■ Site Position: Northing: 6,002,422.64ft Latitude: 70°25'4.020 N From: Map Easting: 519,544.60ft Longitude: 149°50'26.870 W 11 Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.15° Well 3J-15 Well Position +N/-S 0.00 ft Northing: 6,002,822.60 ft Latitude: 70°25'7.954 N +E/-W 0.00 ft Easting: 519,544.80 ft Longitude: 149°50'26.833 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 40.10ft Wellbore 3J-15L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 8/26/2010 17.00 79.89 57,351 Design 3J-15L1-02_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,700.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -40.10 0.00 0.00 54.82 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (0) (0) (ft) (ft) (ft) (°/100ft) (°/100ft) 0100ft) (°) Target 8,700.00 87.96 64.44 6,418.18 3,196.47 3,656.32 0.00 0.00 0.00 0.00 8,735.00 94.03 67.94 6,417.57 3,210.59 3,688.32 20.00 17.32 10.01 30.00 8,765.00 97.01 73.18 6,414.68 3,220.52 3,716.46 20.00 9.93 17.44 60.00 8,795.00 96.97 79.22 6,411.03 3,227.62 3,745.36 20.00 -0.13 20.15 90.00 8,865.00 88.85 90.65 6,407.47 3,233.75 3,814.83 20.00 -11.59 16.33 125.00 8,925.00 86.81 102.49 6,409.75 3,226.91 3,874.28 20.00 -3.41 19.72 100.00 8,995.00 90.02 116.12 6,411.70 3,203.83 3,940.16 20.00 4.59 19.48 77.00 9,045.00 96.42 123.81 6,408.89 3,178.93 3,983.35 20.00 12.82 15.39 50.00 9,115.00 94.55 109.88 6,402.16 3,147.56 4,045.37 20.00 -2.68 -19.91 263.00 9,215.00 91.21 90.13 6,397.09 3,130.32 4,143.23 20.00 -3.33 -19.75 261.00 9,315.00 89.77 110.08 6,396.22 3,112.87 4,241.17 20.00 -1.44 19.95 94.00 9,475.00 84.00 78.54 6,405.13 3,100.90 4,398.40 20.00 -3.61 -19.71 259.00 8130/2010 3:29:13PM Page 2 COMPASS 2003.16 Build 69 r ) R ! GINAL • r ConocoPhillips /S" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3J-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3J-15 @ 74.00ft(Rowan 34) Site: Kuparuk 3J Pad North Reference: True $ Well: 3J-15 Survey Calculation Method: Minimum Curvature Wellbore: 3J-15L1-02 Design: 3J-15L1-02_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (o) (o) (ft) (ft) (ft) (ft) 0100ft) (°) (ft) (ft) 8,700.00 87.96 64.44 6,418.18 3,196.47 3,656.32 4,830.15 0.00 0.00 6,006,028.31 523,192.37 TIP/KOP 8,735.00 94.03 67.94 6,417.57 3,210.59 3,688.32 4,864.44 20.00 30.00 6,006,042.51 523,224.33 2 8,765.00 97.01 73.18 6,414.68 3,220.52 3,716.46 4,893.17 20.00 60.00 6,006,052.52 523,252.45 3 8,795.00 96.97 79.22 6,411.03 3,227.62 3,745.36 4,920.88 20.00 90.00 6,006,059.70 523,281.33 4 8,800.00 96.39 80.05 6,410.45 3,228.52 3,750.25 4,925.39 20.00 125.00 6,006,060.60 523,286.21 8,865.00 88.85 90.65 6,407.47 3,233.75 3,814.83 4,981.18 20.00 125.10 6,006,066.00 523,350.77 5 8,900.00 87.65 97.55 6,408.54 3,231.25 3,849.70 5,008.24 20.00 100.00 6,006,063.60 523,385.65 8,925.00 86.81 102.49 6,409.75 3,226.91 3,874.28 5,025.83 20.00 99.79 6,006,059.32 523,410.24 6 8,995.00 90.02 116.12 6,411.70 3,203.83 3,940.16 5,066.37 20.00 77.00 6,006,036.41 523,476.16 1 7 j 9,000.00 90.66 116.89 6,411.67 3,201.59 3,944.63 5,068.74 20.00 50.00 6,006,034.19 523,480.64 9,045.00 96.42 123.81 6,408.89 3,178.93 3,983.35 5,087.33 20.00 50.00 6,006,011.63 523,519.42 8 9,100.00 94.98 112.86 6,403.41 3,153.00 4,031.45 5,111.70 20.00 -97.00 6,005,985.83 523,567.58 9,115.00 94.55 109.88 6,402.16 3,147.56 4,045.37 5,119.94 20.00 -98.09 6,005,980.42 523,581.51 9 9,200.00 91.73 93.08 6,397.48 3,130.74 4,128.24 5,177.98 20.00 -99.00 6,005,963.83 523,664.42 9,215.00 91.21 90.13 6,397.09 3,130.32 4,143.23 5,189.99 20.00 -99.93 6,005,963.45 523,679.41 10 9,300.00 89.99 107.09 6,396.19 3,117.65 4,226.96 5,251.12 20.00 94.00 6,005,950.99 523,763.16 9,315.00 89.77 110.08 6,396.22 3,112.87 4,241.17 5,259.98 20.00 94.18 6,005,946.25 523,777.39 11 9,400.00 86.58 93.37 6,398.94 3,095.66 4,324.05 5,317.80 20.00 -101.00 6,005,929.26 523,860.30 9,475.00 84.00 78.54 6,405.13 3,100.90 4,398.40 5,381.58 20.00 -100.46 6,005,934.69 523,934.62 TD 8130,-2010 3:29:13PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillipsr' ConocoPhi lips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3J-15 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3J-15 @ 74.00ft(Rowan 34) Site Kuparuk 3J Pad North Reference: True Well 3J-15 Survey Calculation Method: Minimum Curvature Wellbore: 3J-15L1-02' Design: 3J-15L1-02_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3J-15L1-02 fault 2 0.00 0.00 0.00 3,346.22 4,109.78 6,006,179.24 523,645.40 70°25'40.853 N 149°48'26.269 W -plan misses target center by 6400.78ft at 9217.58ft MD(6397.04 TVD,3130.30 N,4145.81 E) -Polygon Point 1 0.00 3,346.22 4,109.78 6,006,179.24 523,645.40 Point 2 0.00 3,142.33 4,060.25 6,005,975.24 523,596.41 Point 3 0.00 2,957.43 4,013.77 6,005,790.24 523,550.42 Point 4 0.00 3,142.33 4,060.25 6,005,975.24 523,596.41 I 3J-15L1-02 t1 0.00 0.00 6,405.00 3,100.44 4,399.18 6,005,934.24 523,935.41 70°25'38.434 N 149°48'17.783 W i -plan hits target center -Point 3J-15L1,L1-01,L1-02 0.00 0.00 0.00 3,319.66 3,566.64 6,006,151.25 523,102.38 70°25'40.594 NI 149°48'42.203 W -plan misses target center by 6412.85ft at 8865.00ft MD(6407.47 TVD,3233.75 N,3814.83 E) -Polygon Point 1 0.00 3,319.66 3,566.64 6,006,151.25 523,102.38 ■ 1 Point 2 0.00 3,390.00 3,827.85 6,006,222.27 523,363.38 f Point 3 0.00 3,342.19 4,141.76 6,006,175.29 523,677.38 Point 4 0.00 3,364.10 4,566.86 6,006,198.31 524,102.38 l Point 5 0.00 3,634.87 5,057.60 6,006,470.33 524,592.36 Point 6 0.00 4,248.40 5,26420 6,007,084.34 524,797.33 Point 7 0.00 4,120.44 5,630.91 6,006,957.35 525,164.34 Point 8 0.00 3,473.82 5,459.23 6,006,310.35 524,994.37 Point 9 0.00 3,155.39 5,223.39 6,005,991.34 524,759.39 y Point 10 0.00 2,962.73 4,693.84 6,005,797.31 524,230.40 1 Point 11 0.00 2,940.35 4,060.72 6,005,773.27 523,597.40 ! Point 12 0.00 2,922.27 3,701.63 6,005,754.26 523,238.40 Point 13 0.00 2,607.00 3,404.79 6,005,43824 522,942.41 Point 14 0.00 2,891.73 3,134.50 6,005,72223 522,671.41 Point 15 0.00 3,168.08 3,398.23 6,005,99925 522,934.39 Point 16 0.00 3,319.66 3,566.64 6,006,151.25 523,102.38 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 9,475.00 6,405.13 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,700.00 6,418.18 3,196.47 3,656.32 TIP/KOP 8,735.00 6,417.57 3,210.59 3,688.32 2 8,765.00 6,414.68 3,220.52 3,716.46 3 8,795.00 6,411.03 3,227.62 3,745.36 4 8,865.00 6,407.47 3,233.75 3,814.83 5 8,925.00 6,409.75 3,226.91 3,874.28 6 8,995.00 6,411.70 3,203.83 3,940.16 7 9,045.00 6,408.89 3,178.93 3,983.35 8 9,115.00 6,402.16 3,147.56 4,045.37 9 9,215.00 6,397.09 3,130.32 4,143.23 10 9,315.00 6,396.22 3,112.87 4,241.17 11 9,475.00 6,405.13 3,100.90 4,398.40 TD 8/30/2010 3:29:13PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL 7 Y A ^ `b W o WWI I 1:4 1 1--------4 tg Ii MI 1 ° o ° i e Y 1 ) . i 1^1 I so G — • qz� ° o• b __ y os w• ��Q s O .. � _ I I 3 o> I • ° O�• 4N -8 p r N• 18 cl • Mm o LLI b.. 8 b 3 6 6 b g . _ d: -j I ° �O CD N 00 .igy a" z P-- ° Q HNMQtAlOf CO.--1 I. 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W s (uyiJ 0gZ) (+)giiom/(—)Ipnos c Gi. - 0 U oi O C to ORIGINAL Conoco Phillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 3J Pad 3J-15 3J-15L1-02 3J-15L1-02_wp01 Travelling Cylinder Report 08 September, 2010 FAR BAKER HUGHES iff R (J l G I 'ea\� L 5 ConocoPhillips v/- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3J-15 Project: Kuparuk River Unit TVD Reference: 3J-15 @ 74.00ft(Rowan 34) Reference Site: Kuparuk 3J Pad MD Reference: 3J-15 @ 74.00ft(Rowan 34) Site Error: 0.00ft North Reference: True Reference Well: 3J-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3J-15L1-02 Database: EDM Alaska Prod v16 Reference Design: 3J-15L1-02_wp01 Offset TVD Reference: Offset Datum Reference 3J-15L1-02_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,700.00 to 9,475.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,144.11ft Error Surface: Elliptical Conic Survey Tool Program Date 8/30/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 75.00 8,100.00 3J-15 GyroData(3J-15) GYD-CT-CMS Gyrodata cont.casing m/s 8,100.00 8,700.00 3J-15L1_wp09(3J-15L1) MWD MWD-Standard 8,700.00 9,475.00 3J-15L1-02_wp01(3J-15L1-02) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (') 9,475.00 6,479.13 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3J Pad 3J-06-3J-06-3J-06 Out of range 3J-101 -3J-101 -3J-101 • Out of range 3J-101 -3J-101 -3J-101 (wp07) Out of range 3J-15-3J-15L1 -3J-15L1_wp09 8,724.95 8,725.00 0.95 0.97 0.19 Pass-Major Risk 3J-15-3J-15L1-01-3J-15L1-01_wp07 8,724.95 8,725.00 0.95 0.97 0.19 Pass-Major Risk 3J-15-3J-15L1-03-3J-15L1-03_wp01 8,723.77 8,725.00 34.94 0.37 34.71 Pass-No Errors CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/8/2010 9:41:31 AM Page 2 of 6 COMPASS 2003.16 Build 69 R1G1NAL TRANSMITTAL LETTER CHECKLIST WELL NAME K' l & 7-i6--/ PTD# 2-/C- -, c Development Service Exploratory Stratigraphic Test Non-Conventional Well p�, FIELD: Ki . /--i �- lK i I/1- ►� POOL: ier ?1/"-e-') C.- 1-'1 r/ ,'" I Circle Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for aannew wellbore segment of existing well k.„( (If last two digits in Permit No. % 'c 2,W. ,API No. 50-‘,2/-- 21 V77 - 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 To o O) 0 a) °- N _N 0 ❑ s ° ns w _ 7 0 c Q a O 3 CI o c � 2 3 0 o 0 a) m U) o O c a), 7 U U o E 0 O > L -° M a) -C a. C a.) ..-• 0 E O O ca- 0 0) o) E O v, c n o 0 @ 0 O () n O" 0 7 °) U L E N 0 LO N N Q Q) L C a o c 3 N o 2 •3 a 2 y o o Z O a) c n C = o m .Q a) ` 0 0 t g $ n = n 0 >_ E 0 N ) N 2 D > N 0 0 C 0) L 2 2 ( 0 c N C O C 0 n j N O O ❑ CO 0 C n .O ° >� O ai y0 N U 0 Z a. o t n _ u v a 0 co a) (n C U 'L"' p w U) C U OD• "6 N 0)to CO r- N O C N C 3 (n c d O @ ❑. E �.TO M, J U C O 30 7 ° °O C. 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