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210-149
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. al 0 - _1 14- q Well History File Identifier Organizing (done) ❑ Two-sided I1 1 1111 111111111 ❑ Rescan Needed 111111111111111 7RE AN DIGITAL DATA OVERSIZED (Scannable) C for Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: a g I /s/ me Project Proofing 1 1liii Ull I I III BY: �j-� Date: a /s/ MP Scanning Preparation I x 30 = 30 + Q I = TOTAL PAGES S I (Count does not include cover sheet) P BY: Date: /s/ Production Scanning 1111111111111111 Stage 1 Page Count from Scanned File: 'o1, (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES _ NO BY: 42191° Date: a 1 $ ' / /s/ ' f r Stage 1 If NO in stage 1, page(s) discrepancies were found: YES j NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I ( 1111 ReScanned 111111111111 DM BY: Maria Date: /s/ Comments about this file: Quality Checked III IIiIIIII 111111 o c 0 o T 2 N U) co a U- o m I= '' CI q TD- -0 C ol C a [01- ce 3 U a a a o co Z o 2 0 O 1-d cn c O o 2 2 O li 2 o 2_7.1.-- 2 MI a o -°c o I Z N 0 y N N• N N U J N N N N 0 Z C Q o c c c c c c c E y h`1 w E I— J CO n 1 1 0 0 0 o 0 0 0. 0. 0 o ce a @ a 0 0 0 0 0 m ° 00 °O 0 E. 0 0 d m z • U ° O 0 0 0 0 0 o.y .0 a � � 3 wCl) Cl) Z 6 0 N c) e. t O O c) rn CI rn LO In Lo U co o CO o coo r- co N- -a W Z -) > Z a) cu U0 o Z X ° ' ° 1- re ° c Cl)ICC ` _ CO 0 O c . E aN o ZI U U U c i CC r a) y Cl) 7 O el E a E J ) N u) ca Un 0 J < v) < 9 r M O o. H O - M Z O la N CO � j > > a) t V) a 0 N Q a oI Y °- I— a� o 4 Q a Z cn w � � .> Z a I W . 0 • 0 o y w w in 1 'co (.0 � 70 CO 0 0 v) a) Cl) Cl) C d o 0 C C C c d 0 0 0 0 N C i4 U U 7 7 7 C a) a) O (0 H Z 0 0 c c c c •a Z h !1 E m Z v a>i cz a 00 D O c• c O , Q J aa) Z Z c coi cs. c in E = Q ayi J 'J 0 JJJ V 0 U n .c..9 E E a 0 i Joy w w�- �w J J - ¢ 0 < O 0 c9/0 --/ /9 Company ConocoPhillips, Alaska, Inc. RECEVED Well Name 3K-08AL1 FEB 072011 Date 2/3/2011 Oil eav Com-. C,f-mmar son Ando:wags. ►nocoPhillips Alaska Greater Kuparuk Area*** Data Distributi RECIPIENTS No other distribution is allowed without OH FIELD 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 DS Engineer/ Rig Foreman 2 Prints TOTAL Hardcopy Prints 2 4 Graphic Image File 4 Electronic Data 5 *Vault documents must be pre-inventoried (bar coding on documents with digital inventory files), Please see page 2 for definition of Reservoir Analysis Logs and Completion Logs (Cased Hole F Page 1 of 4 t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ 0 • WAG ❑ WDSPL ❑ No.of Completions: Service El Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: December 1,2010 • 210-149/ • 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 November 15,2010 • 50-029-21621-60 • 0 0 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1259'FSL,317'FWL,Sec.35,T13N,R9E, UM • November 19,2010 3K-08AL1 . Top of Productive Horizon: 8.KB(ft above MSL): 69'RKB 15.Field/Pool(s): 1308'FSL, 2417'FWL,Sec.34,T13N,R9E,UM GL(ft above MSL): 36'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2025'FSL,2616'FWL,Sec.34,T13N, R9E, UM 10010'MD/6622'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-529306 • y- 6008254 • Zone-4 . 10010'MD/6622'TVD• ADL 25519,25520 • TPI: x-526126 y- 6008290 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit Total Depth: x-526321 y- 6009008 Zone-4 1995'MD/1988'TVD 2555,2556 18.Directional Survey: Yes 0 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/1699'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 8417'MD/6649'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. 110' Surf. 110' 24" 1540#Poleset 9.625" 36.0# J-55 Surf. 4244' Surf. 3758' 12.25" 1200 sx AS IV&300 sx Class G 7" 26.0# J-55 Surf. 8475' Surf. 6646' 8.5" 335 sx Class G&175 sx ASI 2.375" 4.7# L-80 7961' 10010' 6508' 6622' 3" slotted liner 24.Open to production or injection? Yes Q No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5"x 2.875" 7983' 7818'MD/6399'ND 8184'-10009'MD 6614'-6622'ND t ( . 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ,l '4'+„ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED z 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) December 10,2010 pre-produced injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 12/10/2010 24 hours Test Period-> 7 66 1846 10% not available Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 392 psi not available 24-Hour Rate-> 7 66 1846 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquire ? Yes El 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 per 20 AAC 25.071. RECEIVED NONE DEC 2 1 2010 RBDMS DEC 2 2 2n !)'1 AI Rka Oil&Gas Coos.Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE An geginal only (• ,,, , ,t.._ i_if , 0 28. GEOLOGIC MARKERS(List all formations arru markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 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' 1699' • needed,and submit detailed test information per 20 AAC 25.071. Top A2/Base A3 8535' 6625' Top A2 9320' 6585' Top A2 9604' 6600' Kuparuk A2 10010' 6622' N/A Formation at total depth: A2 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: Gary Eller @ 263-4172 Printed Na V. wve Title: Alaska Wells Manager Signature , 265-6306 Date \22.0 1 jf� �Q // 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 V �,. / KUP 3K-08AL1 Conoc©Phillips f ) 1 Well Attributes Max Angle&MD TD Alt;SkB Inc + 1 Wellbore APUUWI Fold Name Well Status Inc/(°) MD(HKB) Act Btm(HKB) 500292162160 KUPARUK HIVE H UNI 1 PROD 106 08 8.S0S 45 10,010.3 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date — SSSV:TRDP Last WO: 2/16/2008 40.00 9/30/1986 Yva},canfai.,..X&'�.y7?13/2om a a7:02 PM -_ - J' 3titetnWe Actual Annotation Depth(flKB) End Date Annotation Last Mod.. End Date Last Tag: Rev Reason:SIDETRACK w/4 LATERALS Imosbor 12/3/2010 Casing Strings I ---- - -- -—-- 'Casing Description String O... String ID...Top(flKB) Set Depth(L..Set Depth(TVD) 'String WL.'String...'Stri g Top Thrd HANGER,35-- - ... w"' LINERAL1 23/8 t 1.995 I 7,960.5 1 10,010.3. i 4.60 , L80 1 STL Liner Details -_ Top Depth ITVD) Top Intl N I orm_. P Top(HKB) (PKB) (') Item Description Comment ID(in) 7,960.5 6,507.8 40.59 DEPLOY Deployment sleeve 1.992 CONDUCTOR, 11.1','" 8,643.4 6,603.0 95-16 DEPLOY Deployment sleeve 1.992- 39-„0 Perforations8 Slots — Shot Top(TVD) Ben(TVD) Dens Top(HKB) Bbn(m(B) (HKB) (HKB) Zone oat. (eh... Type Q mment SAFETY VLV, 8,184.0 10,009.0 6,613.7 6,621.9 11/20/2010 32M SLOTS Slotted pipe-(.125"x2.5"@ 4 1,995 circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends Notes:General&Safety 1 — End Date Annotation ion ;; 8/13/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 12/2/2010 NOTE:WELL SIDETRACK TO'A',ALl,AL2,AL2-01,AL2-02 SURFACE, 374,244 INJECTION, f.. 7,750 LOCATOR,- 7,802 SEAL ASSY, `C_ 7,803 FOR.7.805 r„ PACKER,7,818 �mtr. --- lir INJECTION,_ 7,871 7,910-7,934— 4-1- 7,945-7,949 _ WHIPSTOCK, 7.84/ WINDOW AL2, 7,944-7,952 WHIPSTOCK, 7,980 WINDOW A, 7,959-7,989 CMr SW, 7,945 rr .;Y, PRODUCTION, ' Mandrel 32-8,475 .. el Details SLOTS, Top Depth Top Port 8,184-10.009 (TVD) Intl OD Valve Latch Si. TRO Run LINER Alt, Stn Top(HKBE (HKB) (') Make Model WA Sere Type Type (in) (pe) Run Da4 Com... 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CO Ni ✓ n n O) )o co to O co 0) n n N 5- N CO n N V n CO )0 CO V et 0 t• 0 co N V N N n C) 0 (O t0 CO n n n n to n N n V CO )o to 0 N T 0 0 0 0 0 O O (V O p 0 0 0 0 O O O N O 0 0 0 O O • C Cl `% U) 4 n 0 co co 6) N 0 co n 0 co co C) N 4) a0 V n Q (6 U — O C T 2 . N M M M 4. 7 V R 0 10 U) CO (O (O n n h n a0 a0 aD O) 0) O) O n O- 0) co co co O) co C) C) 0) 0) 0) 0) 0) 0) 0) 0) co 0) 0) 0) 0) 0) 0) 0) 0) C) 0 0 I o O ..°'. a N v�- '+t✓ U d to 0 (I) N Conoco P hillips Time Log & Summary We/!view Web Reporting Report Well Name: 3K-08 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 11/5/2010 12:00:00 AM Rig Release: 12/2/2010 6:00:00 AM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11/01/2010 24hrSummary Rig Stand-by on 3 J pad since 12:00(Noon) Break down 12:00-16:00 hrs wait on Trucks. 16:00-00:00 wait on CPF 3 repairs. 12:00 16:00 4.00 MIRU MOVE MOB P Peak trucks not available due to another rig move.Tear down injector for skate repairs while waiting on trucks. 16:00 00:00 8.00 MIRU MOVE MOB P Issues with CPF 3 Pipe line.Spine road closed to rig traffic.Complete skate repairs&stab pipe while waiting for road to open. 11/02/2010 Stand-by on 3J pad. 00:00 08:00 8.00 MIRU MOVE MOB P Still waiting on road to re-open. Cut 900'of coil for maintenance while waiting. 08:00 00:00 16.00 MIRU MOVE MOB T Wait on road to re-open after CPF3 repairs. Performing rig maintenance while waiting. 11/03/2010 00:00 00:00 24.00 MIRU MOVE MOB T Continue stand-by for road repairs 11/04/2010 Move rig to 3K, MIRU 00:00 11:00 11.00 MIRU MOVE MOB T Stand-by on 3J pad. 11:00 12:00 1.00 MIRU MOVE MOB P Pull off well and hook up jeeps 12:00 18:00 6.00 MIRU MOVE MOB P Move to 3K 18:00 22:00 4.00 MIRU MOVE MOB P Spot rig 22:00 00:00 2.00 MIRU MOVE MOB P Continue with RU 11/05/2010 RU and test BOP, pump slack and cut Coil, rehead CT and PU whipstock 00:00 02:30 2.50 MIRU WHDBO NUND P Accept rig at 0:00 hrs, 11/5/10. Nipple up BOP 02:30 04:00 1.50 MIRU WHDBO PRTS P RU MPD line,grease tree. 04:00 12:00 8.00 MIRU WHDBO BOPE P Testing BOP,State witnessing waived by John Crisp. Passed all BOP tests. 12:00 14:00 2.00 SURPRI WELLPF SLPC P Pump slack management,test inner reel valve. 14:00 16:30 2.50 SURPRI WELLPF BOPE P Perform pre job meeting W/FMC. Pull BPV. Page 1 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 16:30 19:30 3.00 SURPRI WELLPF SLPC P Cut coil to find the end of the line. Re-head,install CTC.pull test connector. Cut 65'to e-line and cut additional 45'CT,total CT cut 110'. Cut 45' of e-line. 19:30 21:30 2.00 SURPRI WELLPFSLPC P Install CTC, pull test to 35K. Install UQC, PT to 4000 psi. 21:30 21:42 0.20 PROD1 RPEQP1SFTY P PJSM for PU BHA 21:42 22:42 1.00 PROD1 RPEQPI PULD P PU whipstock BHA#1 22:42 00:00 1.30 PROD1 RPEQP1TRIP P RIH 11/06/2010 Set whipstock at 7959.6'TOWS,Tagged cement at 7971'. Milled first window run to 7965.2' 00:00 00:42 0.70 4,500 7,570 PROD1 RPEQP1TRIP P Continue RIH 00:42 01:24 0.70 7,570 7,900 PROD1 RPEQPI DLOG P Tie in log, missed K1 marker on first attempt, re-logged and corrected a +20'. Logged jewelry(CCL) 01:24 02:06 0.70 7,900 7,971 PROD1 RPEQPI WPST P RIH and tag cement at 7970.5', PUH (32K PUW)and retag to confirm. Tagging cement higher than expected-apparently did not drill out cement deep enough pre-rig. PUH and run in to 7969.4'(7959.6' TOWS),zero WOB,oriented to 0 deg.close EDC. Pump at.3 BPM set at 3100PSI. 02:06 04:18 2.20 7,971 0 PROD1 RPEQP1TRIP P Swap well to used flo-pro and POOH 04:18 04:48 0.50 0 0 PROD1 RPEQPI PULD P Lay down WS running tools Y 9 04:48 05:45 0.95 0 0 PROD1 WHPST PULD P PU window milling BHA#2,2.80" DSM and string reamer on 0.6 deg motor with wear band turned backwards 05:45 07:45 2.00 0 7,959 PROD1 WHPST TRIP P RIH W/BHA#2,tie in for+19 correction.dry tag TOW @ 7959'. pick up. 07:45 15:15 7.50 7,959 7,965 PROD1 WHPST MILL P 1.5 BPM @ 4100 psi FS BHP 4708 psi begin time milling window mill 6'. 15:15 16:30 1.25 7,965 7,965 PROD1 WHPST REAM P Ream up to 7955',make a couple reaming passes back down to 7965'. Dry drift window W/no problems. 16:30 18:30 2.00 7,965 0 PROD1 WHPST TRIP P POOH to surface. 18:30 19:42 1.20 0 0 PROD1 WHPST PULD P Lay down 0.6 deg. motor and PU BHA#3 with 2.0 deg WFT motor and fat radius mill 19:42 22:12 2.50 0 7,550 PROD1 WHPST TRIP P RIH,stacking out on tubing collars, slow down to 50 FPM and ratate bit while RIH 22:12 22:24 0.20 7,550 7,600 PROD1 WHPST DLOG P Tie in,+18.5'correction 22:24 22:42 0.30 7,600 7,965 PROD1 WHPST TRIP P Continue RIH, 1.4 BPM,4100 CTP, 627 Dif at BHA, 11K RIW,32K PUW. Tag at 7965' 22:42 00:00 1.30 7,965 7,966 PROD1 WHPST MILL P Start time milling Page 2 of 23 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 11/07/2010 24 hr Summary Completed window milling operation and began drilling"A"lateral P 9 P 9 9 00:00 06:30 6.50 7,966 7,977 PROD1 WHPST MILL P Continue time milling, 1.4 BPM, 4100 CTP,635 Dif at BHA, 11K RIW, 32K PUW. Appear to have exited casing at 7969.2' ***Daylight savings time,6.5 hour total time*** 06:30 09:00 2.50 7,977 7,977 PROD1 WHPST REAM P Ream window 09:00 10:45 1.75 7,977 0 PROD1 WHPST TRIP P Equilize&open EDC,trip out 10:45 11:00 0.25 0 0 PROD1 WHPST SFTY P Pre-job meeting for pressure un-deploy. 11:00 14:18 3.30 0 0 PROD1 WHPST PULD P Pressure un deploy, lay down BHA. Pick-up Build section BHA#4& pressure deploy. 14:18 16:18 2.00 0 7,977 PROD1 DRILL TRIP P RIH W/Build section BHA#4. AKO 1.7 deg.@ 7560'tie in for+18'corr. RIH drift thru window with no problems. 16:18 19:30 3.20 7,977 8,120 PROD1 DRILL DRLG P Pumps up,swap well to new 9.7 flow pro mud. RIH to 7977' starting to drilling, 1.4,3650 CTP,200 WHP to maintain 4250 BHP 19:30 19:48 0.30 8,120 8,120 PROD1 DRILL WPRT P Wiper to window,27K PUW, 13K RIW 19:48 23:24 3.60 8,120 8,270 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,230 WHP,4255 BHP,20-30 ROP 23:24 23:54 0.50 8,270 8,270 PROD1 DRILL WPRT P Wiper to window,27K PUW, 13K RIW 23:54 01:00 1.10 8,270 8,377 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,230 WHP,4270 BHP 11/08/2010 Drilled build section to 8540'.Attempt to drill with RSM BHA but had to trip out oh ole due to EDC failure. 00:00 00:30 0.50 8,377 8,420 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,230 WHP,4270 BHP 00:30 00:54 0.40 8,420 7,990 PROD1 DRILL WPRT P Wiper to window,28K PUW 00:54 01:24 0.50 7,990 7,990 PROD1 DRILL DLOG P PU into cased hole for tie-in, zero correction, log RA at 7965'. 01:24 01:48 0.40 7,990 8,420 PROD1 DRILL WPRT P Wiper in hole, 13K RiW 01:48 03:36 1.80 8,420 8,540 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3600 CTP,230 WHP,4300 BHP 03:36 05:51 2.25 8,540 0 PROD1 DRILL TRIP P Landed build, POOH for BHA swap 05:51 06:30 0.65 0 0 PROD1 DRILL SFTY P OOH.Good stopping point for change out.Conduct pre-job for un-deploy 06:30 09:30 3.00 0 0 PROD1 DRILL PULD P Pressure undeploy,lay down build BHA. P/U RSM BHA. Pressure deploy. 09:30 11:20 1.84 0 7,560 PROD1 DRILL TRIP P RIH w/BHA#5 RSM assembly. 11:20 11:29 0.16 7,560 7,600 PROD1 DRILL DLOG P Tie in @ 7560'for a+17.5 correction 11:29 12:14 0.75 7,600 8,520 PROD1 DRILL TRIP P Continue to RIH Page 3 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:14 12:29 0.25 8,520 8,540 PROD1 DRILL TRIP P Pumps up. 1.4 BPM,3400 psi slowly rih to btm @ 8540'. BHP 4320 psi, ECD 12.65. No motor work noticed.Only have 75 psi DP down hole. DD thinks we might have an EDC failure. Pick-up,try again,same result. 12:29 14:59 2.50 8,540 0 PROD1 DRILL TRIP T PUH above the window. Perform coil intergity check. Bleed coil pressure to 0 psi,WHP @ 800 psi. Leak likely in EDC/BHA below upper check valve. POOH to surface. 14:59 15:29 0.50 0 0 PROD1 DRILL SFTY T Tag up.Conduct pre-job. Discuss hazards with suspected EDC failure leaving lower check valve in BHA as single pressure barrier. 15:29 15:59 0.50 0 0 PROD1 DRILL OWFF T Shut SSSV,watch for flow.No flow confirmed.Shut in choke, no pressure build.2 barriers established now. 15:59 17:59 2.00 0 0 PROD1 DRILL PULD T Pressure un-deploy. 17:59 19:29 1.50 0 0 PROD1 DRILL PULD T Deploy BHA#6-RSM. 19:29 23:59 4.50 0 0 PROD1 DRILL PULD T Drillers side PDL will not pull back from over hole center. Troubleshooting hydraulics on jib arm.Top Hydraulic cylinder seams to be twisted or tweaked causing it to lock up when extended over the well.All hydrulaics work going to and from cylinder. **Nabors downtime** 11/09/2010 Drill 8540'to 9290'. POOH, RSM unable to achieve build rates. 00:00 00:30 0.50 0 0 PROD1 DRILL PULD T Continue to trouble shooting PDL jib. 00:30 01:00 0.50 0 0 PROD1 DRILL PULD T Test MWD,Strip on the well. 01:00 03:15 2.25 0 8,540 PROD1 DRILL TRIP T RIH W/RSM drilling BHA#5,tie in for a+18 correction. RIH to 8540 03:15 04:45 1.50 8,540 8,690 PROD1 DRILL DRLG P Pumps up, 1.4 BPM @ 4200 PSI, BHP 4404 PSI. ROP 100 04:45 06:15 1.50 8,690 7,965 PROD1 DRILL DLOG P Wiper&start MAD pass @ 8530' puh @ 6 FPM. 06:15 06:30 0.25 7,965 8,690 PROD1 DRILL TRIP P RBIH 06:30 08:30 2.00 8,690 8,840 PROD1 DRILL DRLG P Drill Ahead. 1.4 BPM @ 4000 psi BHP 4295 psi. ROP 40. ECD @ 12.6 08:30 09:30 1.00 8,840 8,840 PROD1 DRILL WPRT P Wiper trip-30K 09:30 11:30 2.00 8,840 8,990 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3900 psi, BHP 4380, ECD 12.9,WHP 130, ROP 100,WOB 1.3K,CT weight 12K. 11:30 12:30 1.00 8,990 8,990 PROD1 DRILL WPRT P Wiper trip-P/U weight 28K. IA 440 /OA 220 12:30 14:30 2.00 8,990 9,140 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3980, BHP 4380, ECD 12.9,WHP 130,ROP 98, WOB 1.3,Ct weight 12K. Page 4 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:30 16:30 2.00 9,140 9,140 PROD1 DRILL WPRT P Wiper trip P/U weight 28K-noticed small marks on pipe. POOH slowly inspecting dripper blocks. Pull up into cased hole for to clean blocks. 16:30 19:00 2.50 9,140 9,290 PROD1 DRILL DRLG P Drilling ahead-1.38 bpm,4050 psi, BHP 4380, ECD 12.9,WHP 120, WOB 1.5K, ROP 80,Ct weight 13K. 19:00 21:30 2.50 9,290 0 PROD1 DRILL TRIP T POOH, Unable to get adequate build rate with RSM motor. Wants to continue drilling straight ahead. 21:30 21:45 0.25 0 0 PROD1 DRILL SFTY T At surface, PJSM 21:45 23:15 1.50 0 0 PROD1 DRILL PULD T Undeploy BHA 6 23:15 00:00 0.75 0 0 PROD1 DRILL PULD T Deploy BHA#7 with conventional lateral drilling assembly 11/10/2010 Lay down RSM,PU 1 deg AKO motor RIH to drill ahead. EDC failure, POOH. PU new EDC,RIH,drill ahead 9290'-9674'. 00:00 00:30 0.50 0 0 PROD1 DRILL PULD T Continue deploy BHA 7 00:30 02:00 1.50 0 7,570 PROD1 DRILL TRIP T RIH 02:00 02:15 0.25 7,570 7,570 PROD1 DRILL DLOG T Tie in Depth+17.5'correction,Close EDC 02:15 02:45 0.50 7,570 9,290 PROD1 DRILL TRIP T RIH, Perform mud swap 02:45 03:45 1.00 9,290 7,778 PROD1 DRILL TRIP T EDC Failed, POOH 03:45 04:00 0.25 7,778 7,778 PROD1 DRILL TRIP T Try to function EDC, unsuccessful, POOH 04:00 06:00 2.00 7,778 7,778 PROD1 DRILL TRIP T POOH 06:00 07:00 1.00 71 71 PROD1 DRILL SFTY T HOLD PJSM for undeploying with failed EDC 07:00 09:00 2.00 71 0 PROD1 DRILL PULD T Undeploy BHA#7 09:00 10:00 1.00 0 72 PROD1 DRILL SFTY T Pre-spud meeting&PJSM for deployment. 10:00 12:30 2.50 72 72 PROD1 DRILL PULD T Deploy BHA#8,another lateral drilling BHA.Test EDC 150 ft from surface.Good test 12:30 14:30 2.00 72 7,900 PROD1 DRILL TRIP T RIH pumping.3bpm.Tie in+17.5 14:30 15:30 1.00 7,900 9,291 PROD1 DRILL TRIP P Continue RIH-smooth through window-got a small amount of rock/shale back over shakers while RIH.Very small amount. 15:30 17:00 1.50 9,291 9,441 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4000, BHP 4440,WHP 230, ROP 120,WOB 2.4,CT weight 10K. 17:00 18:45 1.75 9,441 9,441 PROD1 DRILL WPRT P Wiper Trip to window,31K PUW 18:45 20:30 1.75 9,441 9,590 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3850, BHP 4340,WHP 230, ROP 120,WOB 2.4,CT weight 10K. 20:30 22:15 1.75 9,590 9,590 PROD1 DRILL WPRT P Wiper Trip to window,27K PUW 22:15 23:00 0.75 9,590 9,667 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3800, BHP 4310,WHP 230, ROP 120,WOB 2-3.5K,CT weight 10K. Page 5 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 23:00 00:00 1.00 9,667 9,674 PROD1 DRILL DRLG P Drilling Ahead slow,5-6 FPH, 2.5K-3.5K WOB 11/11/2010 Drill"A"Lateral 9674'-10023',TD. Perform wiper trip above SSSV, RIH to TD. POOH, laying in liner running pill. Pinhole CT 1800'. POOH secure CT onto reel.Secure well closing SSSV holding 971 psi on formation. Start cutting ct to remove pinhole from CT string 00:00 01:30 1.50 9,674 9,682 PROD1 DRILL DRLG P Drill Ahead slow 5-6 FPH 2.5-3.5K WOB 01:30 02:00 0.50 9,682 9,740 PROD1 DRILL DRLG P Drill Ahead, 100-150 FPH 1.5K WOB,3800 CTP,250 WHP, 10K CTW,4420 BHP 02:00 03:00 1.00 9,740 9,740 PROD1 DRILL WPRT P Wiper Trip to Window,28K PUW 03:00 04:00 1.00 7,970 7,970 PROD1 DRILL DLOG P Tie into depth to RA marker, 0 Correction, RIH 04:00 05:15 1.25 9,740 9,890 PROD1 DRILL DRLG P Drill Ahead 100-150 FPH, 1.5-2K WOB,4450 BHP, 1.4 BPM,3900 CTP,220 WHP 05:15 07:30 2.25 9,890 9,890 PROD1 DRILL WPRT P Wiper trip back to window 07:30 10:00 2.50 9,890 10,023 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4100, BHP 4480, ECD 13.2,WHP 225, ROP 60, WOB 1.7K,Ct weight 10K.***TD lateral at 10,023'*** Pump 10 low&8 bbl high visc sweep. 10:00 11:30 1.50 10,023 7,900 PROD1 DRILL WPRT P Low sweep out nozzle-slowly Cycle off bottom until out the lateral pumping 1.56 bpm. Wiper trip-P/U weight 28K 11:30 13:00 1.50 7,900 1,800 PROD1 DRILL WPRT P Clean through window-continue POOH to 1800'for wiper&test SSSV 13:00 13:30 0.50 1,800 1,800 PROD1 DRILL OWFF P Dump SSSV with 980 psi below bleed off WH to 400 psi-no gain, bleed down to 0-no increase on shut in-Open wide open for 10 minutes to monitor flow. BHP 930-no flow at surface. Put 600 psi on WH&bump open SSSV 120 psi spike when open SSSV. Good test.720 psi below SSSV. 13:30 16:30 3.00 1,800 10,023 PROD1 DRILL TRIP P RIH to lay in beaded liner pill in 9.7 ppg mud-tie in with-2 ft correction. Tag bottom lightly. 16:30 19:00 2.50 10,023 1,999 PROD1 DRILL TRIP P POOH laying in liner pill to window pumping 0.4 bpm @ 40 fpm. Continue POH pumping 9.7 ppg mud. 19:00 19:30 0.50 1,999 1,989 PROD1 DRILL TRIP T Fail pipe 2000'from free end while jetting on SSSV.Shut well in trapping MP,Close 2"P/S securing pipe in 2",Confirm check valves are holding. ****Nabors Rig Repair Rate******3 hours for the day Page 6 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:00 0.50 1,989 1,989 PROD1 DRILL TRIP T PJSM,Open 2"P/S rams, PUH above SSSV,pressure up well to 1000psi. Close SSSV trapping MP below it. 20:00 20:15 0.25 1,989 1,989 PROD1 DRILL TRIP T SSSV closed and holding. 20:15 21:15 1.00 1,989 1,989 PROD1 DRILL TRIP P PJSM,POOH securing CT on reel. Spool damaged pipe section onto reel. 21:15 21:30 0.25 1,989 0 PROD1 DRILL OWFF P At surface,perform flow check, PJSM 21:30 22:15 0.75 0 0 PROD1 DRILL PULD P LD BHA#8(lateral drilling BHA) 22:15 22:30 0.25 0 0 PROD1 DRILL SFTY T PJSM for cutting CT 22:30 23:00 0.50 0 0 PROD1 DRILL SLPC T RU CT cutter to cut CT 23:00 00:00 1.00 0 0 PROD1 DRILL SLPC T Cut CT 11/12/2010 Cut CT back to pinholed tubing 1910'. Inspect injector head,finding debris in sump. Root cause to pinhole. ;Make repairs to injector head. 00:00 01:00 1.00 0 0 PROD1 DRILL SLPC T Continue cutting CT ***Nabors on down time for 23 hours for the day*** 01:00 01:30 0.50 0 0 PROD1 DRILL SFTY T Shut down, PJSM in conference room for cutting CT at pinhole. Perform and Discuss JSA. 01:30 03:45 2.25 0 0 PROD1 DRILL SLPC T Secure CT at pinhole to prevent parting 03:45 04:00 0.25 0 0 PROD1 DRILL SFTY T PJSM ****Nabors off Billable Repair Rate*******3 Hours ****Nabors Down Time******* 04:00 05:00 1.00 0 0 PROD1 DRILL SLPC T Continue cutting CT 05:00 08:00 3.00 0 0 PROD1 DRILL SLPC T Pipe secured in levelwind with clamp. Secure pipe to cut remaining pipe out of injector head.Crew change& PJSM to complete pipe cutting task. 08:00 09:30 1.50 0 0 PROD1 DRILL SLPC T Complete pipe cutting and remove stripper to unpack stuffing box. Cut total of 1910'of coil to get beyond pipe damage. 09:30 11:00 1.50 0 0 PROD1 DRILL RGRP T Find damaged brass; replaced stripper brass. 11:00 12:00 1.00 0 0 PROD1 DRILL RGRP T Prep to pull chains and inspect. 12:00 13:00 1.00 0 0 PROD1 DRILL RGRP T Removed new brass from stripper assembly and swapped out with set of good but previously run brass in order to better accomodate 300,000 running-feet CT. 13:00 14:00 1.00 0 0 PROD1 DRILL BOPE P Install test joint and function test BOPE. 14:00 14:30 0.50 0 0 PROD1 DRILL RGRP T Remove gooseneck cylinder. Page 7 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:30 16:30 2.00 0 0 PROD1 DRILL RGRP T Begin partially uninstalling injector chains to inspect skates and chains. No damage observable on chains. Need to remove chains in entirety from injector to find the known dovetail block damage. 16:30 18:00 1.50 0 0 PROD1 DRILL RGRP T Chains on floor;find damage on several gripper/dovetail blocks. 18:00 18:15 0.25 0 0 PROD1 DRILL SFTY T Crew Change, PJSM 18:15 00:00 5.75 0 0 PROD1 DRILL RGRP T Continue working on Injector Head 11/13/2010 Complete injector head repairs. Deploy BHA#9, RIH.Unable to pass 7975'. POOH. Undeploy BHA#9,MP chokes not operating correctly. Repair. 00:00 04:00 4.00 0 0 PROD1 DRILL RGRP T Continue injector repairs 04:00 10:00 6.00 0 0 PROD1 DRILL SLPC T Stab CT into injector,make up CT connector-Pull test to 30K and pressure test to 5K. Injector cart drive motor"love joy"connector sheared.Have to move cart by come alongs to get over sump for re-heading. 10:00 12:00 2.00 0 62 COMPZ CASING PULD P PJSM&start deploying cleanout BHA#9 with 2.79"D331 bit. ***Nabors off Down Time*** Ten hours of non-billable repair time for the day 12:00 15:00 3.00 62 7,978 COMPZ CASING TRIP P RIH and test/close EDC 150 ft from surface. Follow MPD.Tie in with+ 20 ft correction.Tagged at bottom of window @ 7978'. P/U through window&roll pumps lightly.Tag up in same spot.Orientate 30R,try again. Hard tags not gaining any hole 15:00 15:30 0.50 7,978 7,500 COMPZ CASING TRIP P Bring pumps up close to bottom to 1 bpm, no luck-hard tag @ 7976'. Motor stalling,come down on pumps.try rotating to the left-no luck-higher tag. POOH&tie in again.-1ft correction. 15:30 18:00 2.50 7,500 0 COMPZ CASING TRIP P POOH for 1.80 AKO&2.74"D331. Stop POOH @ 6500'MP choke is surging. Blow it out,no shale.choke washed out,switch to choke A. POOH both chokes acting up. continue POOH. 18:00 18:30 0.50 0 0 COMPZ CASING SFTY P At surface,Crew Change, PJSM 18:30 20:00 1.50 0 0 COMPZ CASING PULD P Undeploy cleanout BHA#9 20:00 21:00 1.00 0 0 COMPZ CASING PULD P Work on MP chokes. Not operating correctly. 21:00 00:00 3.00 0 COMPZ CASING RGRP T Continue working on MP choke ***Nabors Down Time 3 hours Page 8 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/14/2010 24 hr summary Repair MP choke, Deploy BHA 10, RIH to TD successfull, Lay in liner running pill, POOH, PU/MU liner. 00:00 06:00 6.00 0 0 COMPZ CASING RGRP T Conitnue working on MP choke 06:00 08:30 2.50 0 0 COMPZ CASING RGRP T Crew change-Changed air hose- better supply. Eliminate it being the hydraulic/air panel.Start working on paremter choke setting panel.Get calibration numbers from X-pro- choke working better,much smoother. 08:30 10:00 1.50 0 62 COMPZ CASING PULD P PJSM-P/U&deploy BHA#10 with 1.8 AKO with 2.74"D331. 10:00 12:30 2.50 62 8,580 COMPZ CASING TRIP P Rlh 150 ft-close EDC-test-RIH, choke working smooth.Tie in+17ft. RIH.Small weight bobbles at 7968'& 7985'-continue in hole down to 8580'-clean 12:30 14:00 1.50 8,580 10,020 COMPZ CASING TRIP P Wiper up through window-RIH- clean,continue to TD pumping.8 bpm @ 40 fpm. RIH with no problems. Light cuttings returns over shaker. Increase pump rate to 1.2 bpm.Original liner beads corning back over shaker,with light gas cut/crude in mud. 14:00 16:00 2.00 10,020 7,800 COMPZ CASING WPRT P Wipe up&start pumping beads down CT. Increase pump rate to 1.4 bpm. Lay in liner pill from TD @.40 bpm. 16:00 18:30 2.50 7,800 1,800 COMPZ CASING TRIP P Stop&Open EDC-continue POOH folllowing MPD. Mull cleaned up. 18:30 18:45 0.25 1,800 1,800 COMPZ CASINGCIRC P JetSSSV 18:45 19:00 0.25 1,800 0 COMPZ CASING TRIP P POOH 19:00 19:15 0.25 0 0 COMPZ CASING SFTY P At surface, PJSM 19:15 20:15 1.00 0 0 COMPZ CASING PULD P LD cleanout BHA 10 20:15 21:00 0.75 0 0 COMPZ CASING SVRG P Prep floor to run liner,service injector head 21:00 22:30 1.50 0 0 COMPZ CASING PUTB P PU/MU liner 22:30 23:00 0.50 0 0 COMPZ CASING SFTY P Safety Joint Drill,discuss 23:00 00:00 1.00 0 0 COMPZ CASING PUTB P Continue PU/MU liner I'I 11/15/2010 Run liner to TD leaving billet at 8417',drill off billet and continue drilling ahead 00:00 00:30 0.50 0 0 COMPZ CASING PUTB P MU liner complete 00:30 01:30 1.00 0 0 COMPZ CASING PULD P PU Coil Track BHA#11 01:30 03:15 1.75 0 0 COMPZ CASING RUNL P Open SSSV, RIH 03:15 04:15 1.00 7,854 10,026 COMPZ CASING RUNL P Correct depth to EOP flag+17', RIH to TD.Weight check 36K, RIH-set down 5K-increase pumps&release liner P/U weight 33K. Liner top 8416' 04:15 06:45 2.50 10,026 48 COMPZ CASING TRIP P POOH-tie in with+1 ft correction. Liner 8417'-10026'. POOH Page 9 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:45 08:45 2.00 48 0 COMPZ CASING PULD P PJSM&undeploy BHA.Stop undeploying due to Bravo 4 hydraulic actuator not working. PDL is made up to tool.Close Bravo 3 by hand, complete undeploying and repair Bravo 4 once swabs are closed. 08:45 11:30 2.75 0 0 COMPZ CASING PULD P Swap out BHA,service injector& repiar Bravo 4 hydrailic actuator. 11:30 12:30 1.00 0 0 PROD2 STK PULD P Deploy BHA 12,lateral drilling BHA 12:30 14:30 2.00 0 160 PROD2 STK TRIP P RIH, EDC closed,minimum rate,at 160'test EDC, RIH 14:30 14:45 0.25 160 7,590 PROD2 STK DLOG P Tie in depth+17'correction 14:45 15:00 0.25 7,590 8,416 PROD2 STK TRIP P RIH 15:00 15:15 0.25 8,416 8,416 PROD2 STK KOST P Dry Tag Billet, PUH,Slowly RIH, 1.3 BPM,3430 CTP,441 off bottom diff, 174 WHP, 14K CTW,till slight motor work. 15:15 16:15 1.00 8,414 8,415 PROD2 STK KOST P Start milling 1K WOB,460 diff psi, 1 fph P 16:15 16:45 0.50 8,415 8,417 PROD2 STK KOST P Increase ROP to 2 fph, .3-.5K WOB 16:45 17:30 0.75 8,417 8,430 PROD2 STK KOST P Increase ROP to 5 then 20 fph,due to low WOB 17:30 17:45 0.25 8,430 8,430 PROD2 STK KOST P Perform dry run through ST, Looks good 17:45 20:00 2.25 8,430 8,565 PROD2 DRILL DRLG P Drill Ahead 1.4BPM,3850 CTP,200 WHP, 11K CTW, 1.5-2.5K WOB, 20:00 20:48 0.80 8,565 8,565 PROD2 DRILL WPRT P Wiper to window,30K PUW, 16K RIW 20:48 00:00 3.20 8,565 8,663 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3350 CTP,200 WHP,4330 BHP. At 8655'drilling slowed to 3 FPH 11/16/2010 Drilled AL1 lateral 00:00 07:15 7.25 8,663 1 8,715 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3350 CTP,200 WHP,4330 BHP.still in ankerite. Geo inclination to 95-deg at 04:30, until out of Akerite. Appear to start out of Ankerite vicinity 8700', around 07:10. 07:15 08:15 1.00 8,715 8,715 PROD2 DRILL WPRT P Wiper trip#2 to 7990'. PUW 29k#. 08:15 10:15 2.00 8,715 8,865 PROD2 DRILL DRLG P Drill ahead averaging 75-FPH, 1.38 BPM,4000 CTP,200 WHP,4330 BHP, 11k#CT weight. 10:15 11:30 1.25 8,865 8,865 PROD2 DRILL WPRT P Wiper trip with tie-in. PUH 29k#off bottom. Slow pumps to 0.25 BPM prior to top of BHA entering window. Stop at 7988'and log RA marker. RIH(25-FPM;0.25-BPM until passed billet).(-1'correction) 11:30 13:15 1.75 8,865 9,015 PROD2 DRILL DRLG P Drill ahead averaging 75-FPH, 1.86k# WOB, 1.4 BPM,3900 CTP, 150 WHP,4380 BHP, 11k#CT weight. 13:15 14:30 1.25 9,015 9,015 PROD2 DRILL WPRT P Wiper trip(#1). PUH 28k#off bottom. Page 10 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:30 00:00 9.50 9,015 9,150 PROD2 DRILL DRLG P Drill ahead. Made about 3'and ROP dropped to 3.5 FPH. Pick up 20' after 35-40-min and RBIH. Drill ahead 3.7 FPH,2.9k#WOB, 1.4 BPM,3900 CTP, 145 WHP,4400 BHP, 10k#CT weight. 11/17/2010 Drilled ahead AL1 lateral to 9466'when Kuparuk Field put into Phase 3 for weather conditions. Pulled up into cased hole and circulated 0.7-bpm through open EDC reciprocating CT periodically. Waited on weather. 00:00 00:24 0.40 9,150 9,165 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3550 CTP,4370 BHP, 120 WHP 00:24 01:42 1.30 9,165 9,165 PROD2 DRILL WPRT P Wiper to window,29K PUW, 14K RIW 01:42 05:12 3.50 9,165 9,315 PROD2 DRILL DRLG P Continue Drilling, 1.4 BPM,3600 CTP,4360 BHP,75 WHP. Mud swap at 9290' 05:12 07:00 1.80 9,315 9,315 PROD2 DRILL WPRT P Wiper trip to window.0.5'correction. 07:00 10:00 3.00 9,315 9,465 PROD2 DRILL DRLG P Drill ahead averaging 50-FPH. 1.4 BPM. 3800-psi CTP. 280-psi WHP. 4402-psi BHP. 1.9k#WOB. 10k# CT Weight. 10:00 11:30 1.50 9,465 9,465 PROD2 DRILL WPRT P Wiper trip to window,29K#PUW, 14K#RIW. 11:30 11:34 0.08 9,465 9,466 PROD2 DRILL DRLG P Drill ahead. 1.4 BPM. 3800-psi CTP. 280-psi WHP. 4402-psi BHP. 1.9k#WOB. 10k#CT Weight. Drilled 1-ft and received notice from security that entire Kuparuk field in Phase 3 weather conditions. Annouce to rig Phase 3. 11:34 23:59 12.42 9,466 7,899 PROD2 DRILL CIRC T Pull up hole into cased hole and open EDC. Circulate 1.4-BPM and reciprocate pipe periodcally. Limit rig activity to necessary work only. Conduct safety meeting in conference room with all rig personnel to discuss situation. Wait on weather. Nabors regular day rate for weather standby. 11/18/2010 Waited on weather until Phase conditions lessened and clear to resume work. Pulled out of hole and pressure undeployed drilling BHA#12 for BOPE test. Tested BOPE. Pressure deployed drilling BHA#13 and tripped in hole to continue drilling the AL1. 00:00 08:00 8.00 7,899 7,899 PROD2 DRILL CIRC T Wait on weather. Nabors regular day rate for weather standby. 08:00 09:48 1.80 7,899 0 PROD2 DRILL TRIP P POOH for BOP test 09:48 10:00 0.20 0 0 PROD2 DRILL SFTY P PJSM undeploy BHA 10:00 11:30 1.50 0 0 PROD2 DRILL PULD P Undeploy BHA#12(lateral drilling BHA) 11:30 20:30 9.00 0 0 PROD2 DRILL BOPE P Testing BOPE-all passed. 20:30 20:45 0.25 0 0 PROD2 DRILL SFTY P PJSM for pressure deploy. Page 11 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:45 2.00 0 0 PROD2 DRILL PULD P Pressure deploy lateral drilling BHA#13. 22:45 00:00 1.25 0 5,367 PROD2 DRILL TRIP P RIH with drilling BHA#13. 11/19/2010 Drilled AL1 Lateral to TD at 10,010.3'. Laid in liner pill(9.8-ppg Flo Pro with Alpine Beads)from TD to window. Tested SSSV,and POOH to lay down drilling BHA#13 and pick up AL1 liner assembly#1. 00:00 00:25 0.43 5,367 7,570 PROD2 DRILL TRIP P Continue RIH drilling BHA#13. 00:25 00:34 0.16 7,570 7,604 PROD2 DRILL DLOG P Gamma tie-in(+17'correction). 00:34 01:24 0.84 7,604 9,466 PROD2 DRILL TRIP P RIH drilling BHA#13. 01:24 02:58 1.57 9,466 9,615 PROD2 DRILL DRLG P Drill ahead AL1 lateral averaging 95-FPH. 1.4 BPM. 3900-psi CTP. 175-psi WHP. 4418-psi BHP. 1.25k#WOB. 11k#CT Weight. 02:58 04:46 1.80 9,615 9,615 PROD2 DRILL WPRT P Wiper trip to 7988'. 04:46 06:16 1.50 9,615 9,765 PROD2 DRILL DRLG P Drill ahead AL1 lateral averaging 95-FPH. 1.4 BPM. 3900-psi CTP. 140-psi WHP. 4450psi BHP. 1.5k# WOB. 9k#CT Weight. 06:16 08:28 2.20 9,765 9,765 PROD2 DRILL WPRT P Wiper to window,30K PUW, 15K RIW 08:28 10:10 1.70 9,765 9,916 PROD2 DRILL DRLG P Drill ahead, 12K RIW, 1.4 BPM, 3900 CTP, 140 WHP,4450 BHP 10:10 12:22 2.20 9,916 9,916 PROD2 DRILL WPRT P Wiper to window,29K PUW,tie in, 15K RIW 12:22 13:34 1.20 9,916 10,010 PROD2 DRILL DRLG P Drill ahead, 12K RIW, 1.4 BPM, 3900 CTP, 140 WHP,4450 BHP. *** TD hole at 10,010'MD***. Pump 10 Bbls Low Vis/10 Bbls High Vis sweeps. 13:34 16:46 3.20 10,010 72 PROD2 DRILL WPRT P Wiper to the swab valve 16:46 19:38 2.87 72 10,010 PROD2 DRILL WPRT P RBIH to tag TD. Time out beaded liner pill to exit BHA at turnaround. 19:38 22:23 2.75 10,010 1,950 PROD2 DRILL WPRT P POOH laying in beaded liner pill to window. Continue POOH to SSSV pumping 9.7 ppg mud. 22:23 22:57 0.58 1,950 86 PROD2 DRILL OWFF P Close SSSV trapping 928-psi MP below it. Open choke bleeding WHP to 0-psi. Test SSSV monitoring WHP and no-flow at surface. Monitor well for 30-min:SSSV holding tight. 22:57 23:21 0.40 86 86 PROD2 DRILL TRIP P POOH. 23:21 23:27 0.10 86 86 PROD2 DRILL OWFF P At surface. Check well for no flow. 23:27 23:39 0.20 86 86 PROD2 DRILL SFTY P Conduct PJSM for laying down drilling BHA#13. 23:39 23:57 0.30 86 86 PROD2 DRILL PULD P Lay down drilling BHA#13. 11/20/2010 Set AU liner:top of liner 7960.5'; bottom of liner on TD at 10010.3'. 00:00 01:00 1.00 86 0 PROD2 DRILL PULD P Continue laying down drilling BHA _#13. 01:00 01:15 0.25 0 0 COMPZ CASING SFTY P Conduct PJSM for picking up AL1 liner assembly#1. Page 12 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:15 02:45 1.50 0 1,367 COMPZ CASING PUTB P Make up AL1 liner assembly#1. 02:45 03:00 0.25 1,367 1,367 COMPZ CASING SFTY P Conduct PJSM for picking up liner running tools. 03:00 03:45 0.75 1,367 1,411 COMPZ CASING PULD P Make up liner running tools and CT for BHA#14 03:45 06:00 2.25 1,411 9,994 COMPZ CASING RUNL P RIH AL1 liner assembly#1. 06:00 06:12 0.20 9,994 9,970 COMPZ CASING RUNL P Tagged TD at 9994 with no depth correction, pump at 1 BPM,4000 CTP to release from liner 06:12 08:36 2.40 9,970 0 COMPZ CASING RUNL T POOH pumping down backside while in open hole. Switch to down CT,tie in,+17', paint EOP flag at 7100'and continue POOH 08:36 08:48 0.20 0 0 COMPZ CASING SFTY T PJSM 08:48 10:30 1.70 0 0 COMPZ CASING PULD T Close SSSV,flow check well. When OOH realized liner was still attached. Check out GS and PT Coiltrack tools. 10:30 10:42 0.20 0 0 COMPZ CASING SFTY T PJSM 10:42 12:54 2.20 0 7,950 COMPZ CASING RUNL T MU BHA and RBIH with liner BHA with a Knuckle Joint above GS (BHA #15). 12:54 13:54 1.00 7,950 9,995 COMPZ CASING RUNL T Weight check at window,30.5K PUW(-2.88 WOB), 17K RIW(-.82 WOB)Continue RIH 13:54 14:24 0.50 9,995 9,995 COMPZ CASING RUNL P Set down at 9995 with no depth correction,35K PUW(-0.9 WOB), 12.5K set down weight(+5.20 WOB). Pump at 1.4 BPM,4400 CTP,780 DP. Pick up at 29K PUW (+2.0 WOB) 14:24 18:30 4.10 9,995 0 COMPZ CASING RUNL P POOH,tie-in, +16'(This puts liner bottom at 10010', liner top at 8644'), paint flag at 7100'EOP. POOH. Close SSSV. Tag stripper. Check for flow. Unstab,wash, LD liner running tools. RU for liner run. 18:30 18:45 0.25 0 0 COMPZ CASING SFTY P PJSM for picking up AL1 liner assembly#2(BHA#16). 18:45 20:00 1.25 0 683 COMPZ CASING PUTB P Make up AL1 liner assembly#2 (BHA#16). 20:00 20:15 0.25 683 683 COMPZ CASING SFTY P PJSM for making up liner running tools(BHA#16). 20:15 20:30 0.25 683 728 COMPZ CASING PUTB P Make up liner running tools(BHA #16). 20:30 22:00 1.50 728 7,950 COMPZ CASING RUNL P RIH AL1 liner assembly#2(BHA #16). Stop at flag and correct depth (+17'correction). Continue RIH. 22:00 22:15 0.25 7,950 8,646 COMPZ CASING RUNL P Weight check at window,32.0K PUW(-1.9 WOB), 16.5K RIW(-0.23 WOB). Continue RIH. Page 13 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:30 0.25 8,646 8,646 COMPZ CASING RUNL P Set down at 8646.22'. Set down weight 2k#(RIH 11k:CT wt when set down 9.0k#)(+6.30 WOB). Pump at 1.4 BPM,4400 CTP, 1110 DP. Pick up at 29.1K PUW(-1.0 WOB). 22:30 00:00 1.50 8,646 900 COMPZ CASING RUNL P POOH,tie-in, +0.0', Liner top at 7960'. Continue POOH. 11/21/2010 Set Baker extended-tray monobore whipstock at 7944'for dual string AL2,AL2-01 exit. Performed first window milling run to 7,950'. 00:00 00:30 0.50 900 66 COMPZ CASING TRIP P Continue POOH. Tag stripper. Close SSSV. Check for flow. Unstab,wash, LD liner running tools. 00:30 00:45 0.25 66 66 COMPZ CASING SFTY P PJSM for laying down liner running tools. 00:45 01:15 0.50 66 0 COMPZ CASING PULD P Again confirm no-flow. Lay down liner running tools. 01:15 02:00 0.75 0 72 PROD3 RPEQP1PULD P Pick up Baker extended tray mono-bore whipstock. Make up Baker#10 setting tool. Open EDC. Open SSSV. 02:00 03:45 1.75 72 7,941 PROD3 RPEQP1TRIP P RIH whipstock assembly(BHA#17) li pumping 0.3 BPM through open EDC. 03:45 04:00 0.25 7,550 7,960 PROD3 RPEQPI DLOG P Log down 3-fpm through 7550'-7605' (+14.5'correction). Perform weight check:28k#up, 16k#down. RIH. 04:00 04:15 0.25 7,960 7,951 PROD3 RPEQP1WPST P Stop at 7960'and pull up to setting depth 7950.76'. Orient 0-deg high-side and closed EDC. Come online and set whipstock at 7941', TOWS. Set down 2-3k#on whipstock to confirm slips set. 04:15 06:06 1.85 7,941 0 PROD3 RPEQP1TRIP P POOH. 06:06 06:54 0.80 0 0 PROD3 RPEQPI PULD P Lay down whipstock BHA 06:54 07:54 1.00 0 0 PROD3 WHPST PULD P PU milling BHA#18 07:54 08:42 0.80 0 0 PROD3 WHPST TRIP P Calibrate choke 08:42 10:18 1.60 0 7,500 PROD3 WHPST TRIP P RIH 10:18 10:36 0.30 7,500 7,550 PROD3 WHPST DLOG P Tie-in, +16' 10:36 10:48 0.20 7,550 7,944 PROD3 WHPST TRIP P Cont.to RIH 10:48 18:06 7.30 7,944 7,950 PROD3 WHPST MILL P Dry tag at 7944,29K PUW,bring pump online at 1.4 BPM,3700 CTP, 383 DP, 4250 BHP with 130 WHP, 15.6K RIW. Start time milling at 7943.6'. 18:06 18:48 0.70 7,950 7,950 PROD3 WHPST REAM P Made 3 reaming passes from TOW 1-fpm maintaining 0-deg orientation and pull up for dry drift. Dry drift window. Painted flag at 7948.8'. 18:48 20:30 1.70 7,950 0 PROD3 WHPST TRIP P POOH for second milling assembly. 20:30 21:00 0.50 0 0 PROD3 WHPST SFTY P Tag up and monitor well for no-flow. Conduct PJSM for pressure undeploy/deploy milling BHA's. Page 14 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 0 0 PROD3 WHPST PULD P Pressure undeploy first window milling assembly. 23:00 23:12 0.20 0 0 PROD3 WHPST SFTY P PSJM for pressure deploy second window milling assembly. 23:12 00:00 0.80 0 0 PROD3 WHPST PULD P Pressure deploy second window milling assembly(BHA#19). 11/22/2010 Pressure deployed second window milling assembly and milled window,continuing into formation 30'passed TOWS to 7974'. Incurred 3.0-hours BHI trouble time for failed EDC after pressure deploy of planned second window milling assembly. 00:00 00:15 0.25 0 0 PROD3 WHPST PULD P Continue pressure deploy second window milling assembly(BHA#19). 00:15 01:15 1.00 0 0 PROD3 WHPST PULD T Troubleshoot possible problem with EDC. 01:15 01:30 0.25 0 0 PROD3 WHPST SFTY T PJSM for change of scope to pressure undeploy second window milling assembly. 01:30 03:06 1.60 0 0 PROD3 WHPST PULD T Pressure undeploy second window milling assembly. Found failed EDC once OOH. 03:06 03:15 0.15 0 0 PROD3 WHPST SFTY T PSJM for pressure deploy second window milling assembly(BHA#20). 03:15 04:15 1.00 0 0 PROD3 WHPST PULD T Pressure deploy second window III p Y milling assembly(BHA#20). 04:15 05:00 0.75 0 0 PROD3 WHPST PULD P Pressure test the EDC. 05:00 07:00 2.00 0 7,500 PROD3 WHPST TRIP P RIH. 07:00 07:18 0.30 7,500 7,550 PROD3 WHPST DLOG P Tie-in, +16' 07:18 08:18 1.00 7,550 7,950 PROD3 WHPST TRIP P Continue RIH,started having trouble with Coiltrak tools,trouble shoot and determine DPS is not sending valid data. Bring pump online and slowly creep in hole from 7948'. 1.4 BPM, 4020 CTP, 130 WHP,4275 DHP(appears to be working, bore psi and Dp are not)zero WOB(also appears to be working)17.4K 08:18 12:30 4.20 7,950 7,952 PROD3 WHPST MILL P Start time milling procedure, 12:30 14:54 2.40 7,952 7,955 PROD3 WHPST MILL P WOB and DP started trending down at 7951.6'(1.7'),continue at 1 FPH. 1.4 BPM, 3915 CTP, 130 WHP, 4235 DHP,0 WOB, 16K RIW 14:54 18:24 3.50 7,955 7,974 PROD3 WHPST MILL P Increase ROP to 4 FPH, 14.3 RIW for 1.1 WOB. 1.4 BPM,4030 CTP, 125 WHP. Continue to increase ROP to 5-8 FPH to maintain 200 PSI motor work and 2K WOB, Formation sand in sample from 7958'. 18:24 20:12 1.80 7,974 7,960 PROD3 WHPST REAM P Ream up and down through window from TOWS to 2'below window. (Dn 15-deg ROHS,up 15-deg R, 30-deg L,&60-deg R). Dry drifted window to 7960'. All smooth through reaming and dry drift. 20:12 20:18 0.10 7,960 7,615 PROD3 WHPST TRIP P PUH to log gamma. Page 15 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:18 20:24 0.10 7,615 7,596 PROD3 WHPST DLOG P Log up through gamma 7615'-7596'. (+1'correction). 20:24 22:18 1.90 7,596 0 PROD3 WHPST TRIP P POOH. 22:18 22:33 0.25 0 0 PROD3 WHPST SFTY P PSJM for pressure undeploy second window milling assembly(BHA#20). 22:33 00:00 1.45 0 0 PROD3 WHPST PULD P Pressure undeploy second window milling assembly(BHA#20). 11/23/2010 Deploy Drilling BHA#20 with 1.1 degree motor. Drill from 7974 to 8725 00:00 01:30 1.50 0 0 PROD3 WHPST PULD P Continue pressure undeploy second window milling assembly with Open EDC(BHA#20). BHI prep/reconfigure BHA(1.1-deg motor and replacement DPS)to pick up tools. [Note:Deploy checklist step#22:0-psi WHP,835-psi on MP to 800-psi stable. Step#31 800-psi. Step#87 900-psi.] Mill OOH go/no-go:2.80/2.79. 01:30 01:42 0.20 0 0 PROD3 DRILL SFTY P PJSM for pressure deploy drilling BHA(BHA#21). 01:42 02:42 1.00 0 72 PROD3 DRILL PULD P Pressure deploy drilling BHA(BHA #21). 02:42 04:18 1.60 72 7,575 PROD3 DRILL TRIP P RIH. 04:18 04:24 0.10 7,575 7,603 PROD3 DRILL DLOG P Log down through gamma(+16' correction). 04:24 04:36 0.20 7,603 7,974 PROD3 DRILL TRIP P RIH 04:36 09:30 4.90 7,974 8,125 PROD3 DRILL DRLG P Drill ahead AL2 lateral. 3764 CTP; 153 WHP; 1.41-BPM; 14.3k#pipe weight; 1.18k#WOB. 09:30 09:45 0.25 8,125 7,590 PROD3 DRILL WPRT P Wiper trip 09:45 10:00 0.25 7,590 7,990 PROD3 DRILL DLOG P RIH Tie in Gamma,0'correction. Log RA marker @ 7949.5'. BTM of window @ 7952,top of whip stock @ 7943' 10:00 10:15 0.25 7,990 8,125 PROD3 DRILL WPRT P RBIH 10:15 14:15 4.00 8,125 8,275 PROD3 DRILL DRLG P Drill Ahead,3988 CTP, 1.40 BPM, _ 4976 BHP 14:15 14:45 0.50 8,275 8,275 PROD3 DRILL WPRT P Wiper to 7980'. RBIH 14:45 16:45 2.00 8,275 8,425 PROD3 DRILL DRLG P Drill ahead,3986 CTP, 1.40 BPM, 104 WHP 16:45 17:45 1.00 8,425 8,425 PROD3 DRILL WPRT P Wiper to 7978 17:45 18:57 1.20 8,425 8,575 PROD3 DRILL DRLG P 8425', Drill Ahead 1.37 BPM @ 3750 PSI FS BHP=4307, PUW=29K 18:57 19:45 0.80 8,575 8,575 PROD3 DRILL WPRT P 8575,Wiper to window with tie in to RA for zero correction,Continue back to bottom. Good trip out and in 19:45 23:00 3.25 8,575 8,725 PROD3 DRILL DRLG P 8575,Drill Ahead 1.41. BPM @3762 PSI FS BHP=430, RIW=13.6K Page 16 of 23 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 23:00 00:00 1.00 8,725 8,725 PROD3 DRILL WPRT P 8725,Wiper to window PUW=31K 11/24/2010 Hard Drilling through Ankerite 8740 to 8802,Swap out mud. 1542'on system 00:00 01:00 1.00 8,725 8,764 PROD3 DRILL DRLG P 8725', Drill Ahead 1.39 BPM @ 3758 PSI FS BHP=4278, RIW=13.6 01:00 02:45 1.75 8,764 8,770 PROD3 DRILL DRLG P BHA Wiper, ROP dropped, Hard Drilling has that Ankorite look 02:45 08:45 6.00 8,770 8,783 PROD3 DRILL DRLG P Swap out mud 1542'@.7%drill solids. Drill ahead. 08:45 19:18 10.55 8,783 8,802 PROD3 DRILL DRLG P Wt.Ck @ 28k. Lower pump rate to 1.20 bpm @ 3502 psi. 19:18 20:18 1.00 8,802 8,875 PROD3 DRILL DRLG P Got through Ankerite, ROP 60-100 FPH 1.42@ 3855 PSI FS BHP=4282,WHP=150 20:18 21:24 1.10 8,875 8,875 PROD3 DRILL WPRT P Wipe to window PUW=28K 21:24 23:36 2.20 8,875 9,025 PROD3 DRILL DRLG P 8875', Drill Ahead 1.4 BPM @ 3867 FS BHP=4280. RIW=14.5K,WOB=1.8, Initial ROP=75 FPH 23:36 00:00 0.40 9,025 8,350 PROD3 DRILL WPRT P Wiper to window with tie into RA 11/25/2010 Hard drilling in Ankerite,Called TD @ 9348,Condition hole. POOH for Liner. Perform BOPE Function test 00:00 00:18 0.30 8,350 7,975 PROD3 DRILL WPRT P On wiper trip from 9025. 00:18 00:24 0.10 7,975 7,987 PROD3 DRILL DLOG P Tie into RA marker on whipstock. No correction 00:24 00:54 0.50 7,987 9,025 PROD3 DRILL WPRT P Continue wiper trip to bottom.Clean trip out and in. 00:54 02:42 1.80 9,025 9,175 PROD3 DRILL DRLG P 9025', Drill Ahead 1.40 BPM @ 3863 PSI FS BHP=4254 02:42 04:12 1.50 9,175 9,175 PROD3 DRILL WPRT P Wiper to window PUW=30K Clean trip. No overpulls or set downs 04:12 06:00 1.80 9,175 9,325 PROD3 DRILL DRLG P 9175', Drill ahead 1.4 BPM @ 3870 PSI FS ROP 80-120 FPH 06:00 07:45 1.75 9,325 9,325 PROD3 DRILL WPRT P Wiper to window,29k off btm.clean, no over pulls. 07:45 14:45 7.00 9,325 9,347 PROD3 DRILL DRLG P 9325',drill ahead. 1.40 BPM @ 3900 psi ROP back down to 2.0. Have disccusions W/town&Geo's 14:45 15:15 0.50 9,347 9,347 PROD3 DRILL DRLG P Get call from town. Decided to stop drilling ankerite&line the hole w/ anchored billet top to kick off above. Pump 10 bbls to/Hi vis pill 15:15 17:00 1.75 9,347 7,908 PROD3 DRILL WPRT P Get Sweep around the corner, pull wiper up to window chasing out. Once at window,continue pumping BTM's up. 17:00 17:15 0.25 7,908 7,990 PROD3 DRILL DLOG P RBIH,tie into RA. Page 17 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 17:15 17:51 0.60 7,990 9,348 PROD3 DRILL WPRT P RIH, tag btm. ***TD hole at 9348' MD*** 17:51 20:27 2.60 9,348 93 PROD3 DRILL TRIP P Trip out laying in beaded liner running pill Paint EOP flags @ 8300&7000 20:27 20:57 0.50 93 93 PROD3 DRILL SFTY P PJSM,Trap pressure,shut SSSV, bleed off above SSSV and monitor for flow, good no flow test 20:57 21:57 1.00 93 0 PROD3 DRILL PULD P lay down drilling BHA#23 21:57 22:15 0.30 0 0 PROD3 DRILL BOPE P Function test BOPE 22:15 22:30 0.25 0 0 COMPZ CASING SFTY P PJSM, P/U AL2 Liner&anchor-billet 22:30 23:45 1.25 0 0 COMPZ CASING PUTB P M/U Liner 23:45 00:00 0.25 0 0 COMPZ CASING SFTY P PJSM,P/U Coil track and anchored billet 11/26/2010 Run AL2 Liner 9227-8480, P/U drilling BHA,Time drill past TOL,drill to 8930 00:00 01:45 1.75 0 809 COMPZ CASING PULD P Continue making up anchored billet and coil track,Strip onto well, surface test tool 01:45 03:30 1.75 809 7,791 COMPZ CASING RUNL P RIH with liner, EDC is open 03:30 03:45 0.25 7,791 7,808 COMPZ CASING RUNL P Correct to EOP flag+16.5 Shut EDC, PUW=31K, RIH 03:45 03:51 0.10 7,808 8,320 COMPZ CASING DLOG P 8320,slow down to logging speed and tie into RA for 0'correction 03:51 04:15 0.40 8,320 9,228 COMPZ CASING RUNL P 9227.4,with TF @ 190 degrees, Pump on see good indication of set @ 4400 PSI Set down 3.5 K. looks good, POOH. Liner set 8480'-9228'. Anchor billet at 8480'. 04:15 06:30 2.25 9,228 0 COMPZ CASING TRIP P Start out of hole 06:30 06:45 0.25 0 0 COMPZ CASING SFTY P Conduct Pressure Un-deploy pre-job safety meeting. 06:45 09:00 2.25 0 0 COMPZ CASING PULD P Pressure un-deploy. Lay down liner running BHA#22. 09:00 11:15 2.25 0 0 PROD4 STK PULD P Pick-up Drilling BHA#23. Pressure deploy. 11:15 12:45 1.50 0 7,570 PROD4 STK TRIP P RIH 12:45 13:15 0.50 7,570 8,480 PROD4 STK DLOG P 7550'to 7592'. Tie into formation+14' correction. RBIH dry tag top of billet @ 8480'. 13:15 16:03 2.80 8,480 8,487 PROD4 STK KOST P Pick-up. pumps on 1.44 bpm @ 3936 psi. tool face @ 150R. RIH time drill top of billet. Have a stall. shut down pump&pick off. Pumps up,stack less wt this time,time drill @ 1ft/hr to start.get past billet, ROP up to 100,continue drilling. 16:03 17:39 1.60 8,487 8,630 PROD4 DRILL DRLG P 7 feet past TOB, Drill ahead 1.45 BPM @ 3901 FS ROP=70 FPH BHP=4390 Page 18 of 23 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:39 18:39 1.00 8,630 8,630 PROD4 DRILL WPRT P Wiper to window PUW=28K 18:39 20:09 1.50 8,630 8,760 PROD4 DRILL DRLG P 8630',Drill Ahead 1.4 BPM @ 3825 FS BHP=4383 20:09 21:15 1.10 8,760 8,760 PROD4 DRILL WPRT P 8760,Wiper to window PUW=28k 21:15 22:45 1.50 8,760 8,930 PROD4 DRILL DRLG P 8760', Drill Ahead 1.45 BPM @ 3960 PSI FS BHP=4439, RIW=15.3K 22:45 00:00 1.25 8,930 8,737 PROD4 DRILL WPRT P Wiper to window with tie into RA, +2.5 correction 11/27/2010 Drill Ahead from 8930 to 9732. Poor hole conditions 9475 to 9587 00:00 00:06 0.10 8,737 8,930 PROD4 DRILL WPRT P Continue wiper trip 00:06 01:36 1.50 8,930 9,080 PROD4 DRILL DRLG P 8930', Drill Ahead 1.45 BPM @ 3938PSI FS RIW=14.2K, BHP=4420 01:36 02:48 1.20 9,080 9,080 PROD4 DRILL WPRT P Wiper trip to window, PUW=29K 02:48 04:24 1.60 9,080 9,230 PROD4 DRILL DRLG P 9080', Drill Ahead 1.45 BPM @ 3959PS1 FS BHP=4431 04:24 05:45 1.35 9,230 9,230 PROD4 DRILL WPRT P 9230,Wiper to window, PUW=29K 05:45 07:30 1.75 9,230 9,380 PROD4 DRILL DRLG P Drill ahead 1.43 BPM @ 3983 psi. BHP @ 4557 07:30 08:30 1.00 9,380 7,975 PROD4 DRILL WPRT P Wiper to window. PUW=31k and smooth. 08:30 08:34 0.08 7,975 7,985 PROD4 DRILL DLOG P @ 7975'Tie into RA marker. 08:34 09:14 0.68 7,985 9,380 PROD4 DRILL TRIP P RBIH 09:14 12:44 3.50 9,380 9,530 PROD4 DRILL DRLG P 9380'Drill ahead 1.41 BPM,4030 psi. BHP @ 4374 psi. ROP @ 77. ROP fell off to 30 from-9450 to 9530'as we crossed over ugly shale. 12:44 14:59 2.25 9,530 9,530 PROD4 DRILL WPRT P 9530'wiper trip up to window Slight motor work coming up 9475-9485 14:59 19:17 4.30 9,530 9,680 PROD4 DRILL DRLG P 9530'drill ahead. Drilling strictly for geo data now to determine where we're at. Drill up, inclination at the bit is 96 deg. 1.40 BPM @ 3960 psi. BHP @ 4418 psi. ROP @ 19 19:17 21:53 2.60 9,680 9,680 PROD4 DRILL WPRT P Wiper to window, PUW 31K. Slight bobbles in 9480 on way up Major problems in shale at 9475 to 9587-set downs with no motor work. Fairly clean pick ups after set downs.Trap pressure and shut down pumps to get through 21:53 23:58 2.09 9,680 9,732 PROD4 DRILL DRLG P 9680', Drill Ahead 1.37 @ 3960PSI FS RIW=5.2K BHP=4480 NBI=100 Midnight Depth=9732 11/28/2010 Drilled ahead 8930 to 9732.Cut shale 9475 to 9587.Difficult to get through on wiper trips,Call TD, Run Liner Page 19 of 23 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 9,732 9,830 PROD4 DRILL DRLG P Continue drilling ahead for data. Made decision to TD AL2-01 lateral at 9830'MD. 02:30 04:00 1.50 9,830 8,500 PROD4 DRILL WPRT P 9830,Wipe to window with tie in. PUW=30K slight over pull at 9475 coming up, Correct-.5' 04:00 09:15 5.25 8,500 0 PROD4 DRILL TRIP P Ops Meeting. Not going to go back down through shales. Line up and pump to-high vis sweeps from 8450 up.Mix and pump beaded liner pill. Paint window&TD flags. POOH,but at—1500'see much shale returns at surface,clogging up the choke some. 09:15 10:00 0.75 0 0 PROD4 DRILL SFTY P Shut in SSSV, monitor well for flow while conduct pre job. 10:00 11:00 1.00 0 0 PROD4 DRILL PULD P Un deploy, Lay down drilling BHA #23. 11:00 11:15 0.25 0 0 COMPZ CASING SFTY P Conduct pre-job for running liner. 11:15 13:15 2.00 0 0 COMPZ CASING PUTB P PU BHA#24&liner with anchor-billet. 13:15 15:15 2.00 0 7,145 COMPZ CASING RUNL P RIH W/AL2-02 liner BHA,stop at window flag,correct depth+16. 15:15 16:00 0.75 7,145 9,374 COMPZ CASING RUNL P RIH with liner shoe to 9374'. Top of billet @ 8974'set anchor.set down 2k.pooh. 16:00 16:30 0.50 9,374 7,985 COMPZ CASING DLOG P PUH @ 7985'Tie in. 16:30 18:15 1.75 7,985 76 COMPZ CASING TRIP P POOH to surface. 18:15 19:45 1.50 76 0 COMPZ CASING PULD P Tag up.open EDC,space out, PJSM LD BHA#24 from liner run 19:45 22:15 2.50 71 71 PRODS STK PULD T P/U BHA 25 W 1.5 degree motor and Hycalog Bi Center. Pressure deploy, surface test,strip on well 22:15 00:00 1.75 71 6,600 PROD5 STK TRIP T Trip in well EDC open,Stop @ 600'. closed EDC and test. Continue tripping in 11/29/2010 Drill past TOL billet @ 8974',Swap mud,drill ahead to 9910 00:00 00:24 0.40 6,600 7,575 PROD5 STK TRIP T Trip in hole continued 00:24 00:30 0.10 7,575 7,600 PRODS STK DLOG T Gamma tie in fora+15.5'correction, continue in well 00:30 01:06 0.60 7,600 8,975 PRODS STK TRIP T Continue in well,dry tag TOB @ 8974.9 01:06 04:06 3.00 8,975 9,004 PRODS STK KOST T P/U, Kick on pumps 1.44 BPM @ 4102 psi FS Start time milling procedure @ 8973.2. TF=25L 04:06 04:30 0.40 9,004 9,004 PRODS STK REAM T Time drilled down to 8986 then drilled to 9004 Pull up and dry drift billet. Looks good PUW=29K, BHP=4434 Page 20 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:00 1.50 9,004 9,160 PROD5 DRILL DRLG T 9004, Drill ahead, Started Mud swap 1.44 BPM @ 4153PSI FS BHP=4414 06:00 07:45 1.75 9,160 9,160 PROD5 DRILL WPRT T Wiper to window,29k pu wt. 07:45 09:45 2.00 9,160 9,310 PROD5 DRILL DRLG T Drill ahead. 1.40 BPM @ 4030 psi. FS. BHP=4396 09:45 11:15 1.50 9,310 9,310 PRODS DRILL WPRT T Wiper up to window,29k pu wt. 11:15 13:00 1.75 9,310 9,460 PRODS DRILL DRLG T Drill ahead, 1.39 BPM @ 4005 psi. BHP=4373 13:00 15:00 2.00 9,460 9,460 PRODS DRILL WPRT T Wiper up to window.30k off btm and smooth. 15:00 16:15 1.25 9,460 9,610 PRODS DRILL DRLG T Drill ahead. 1.41 BPM @ 4140 psi BHP=4412 16:15 18:30 2.25 9,610 9,610 PRODS DRILL WPRT T Wiper up to window 18:30 20:15 1.75 9,610 9,760 PRODS DRILL DRLG T 9610, Drill Ahead 1.41 BPM @ 3918 PSI FS BHP=4420 20:15 22:21 2.10 9,760 9,760 PRODS DRILL WPRT T Wiper to window, PUW=29K Clean wiper in and out 22:21 23:51 1.50 9,760 9,910 PROD5 DRILL DRLG P 9760, Drill Ahead 1.42 BPM @ 3863PSI FS BHP=4406, RIW=11.1 K WOB=1.3K 23:51 00:00 0.15 9,910 PRODS DRILL WPRT P Wipe to window, PUW=29K 11/30/2010 Continued drilling.Started losing returns at 10058',296 Bbls.to formation. TD AL2-02 at 10350'. Lay in liner running pill. 00:00 02:27 2.45 9,910 9,910 PROD5 DRILL WPRT P 9910',wipe to window with tie in Correct+.5. Clean trip in and out 02:27 03:45 1.30 9,910 10,023 PRODS DRILL DRLG P 9910',Drill Ahead. 1.4 BPM @ 4000 psi FS. BHP=4499 03:45 04:00 0.25 10,023 10,023 PRODS DRILL WPRT P 10,023'Motor stall,shut down pump, puh. Lose returns to 0.5 bpm out, 1.40 bpm in. Pull wiper up to 9920' 04:00 04:30 0.50 10,023 10,058 PRODS DRILL DRLG P 10,023'Drill Ahead, 1.40 BPM @ 4300 psi. Returns @ 0.6 psi. DD would like to get to 10,065'for log. 04:30 06:15 1.75 10,058 7,878 PROD5 DRILL WPRT P 10,058'lose all returns,pull wiper. Having trouble maintaining BHP, adjust to get BHP right.@ 9375' 1.62 BPM @ 4228 psi 4181 BHP. Returns @ 0.57 bpm. Order more fluids. 06:15 07:45 1.50 7,878 7,700 PROD5 DRILL WPRT P 7878'In cased hole.Circulate @ min rate.Still have-0.75 BPM losses. Not enough mud on location to continue drilling. Keep pipe slowly moving while waiting on plan forward. Fluids should be here @ noon. Page 21 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:45 09:00 1.25 7,660 7,660 PROD5 DRILL WPRT P 7700'Still 0.75 BPM loss. Decide to lower ECD from 12.9 to 12.3 ppg. Rate in 1.02 bpm,rate out 0.57 bpm. Reduced loss by 0.25 BPM.Slowly ease down to 12.0 ppg EMW. Now @ 0.4 bpm loss.Get btms up and check for crude or gas in returns. 09:00 09:30 0.50 7,660 7,660 PROD5 DRILL WPRT P Have btms up, no gas or crude in returns.Kick up pump rate to 1.42 BPM while still holding 3058 psi or 12.0 ppg ECD. Have 0.3 BPM loss. 09:30 10:45 1.25 7,660 10,058 PROD5 DRILL WPRT P Close EDC, RBIH to drill 10:45 13:21 2.60 10,058 10,203 PROD5 DRILL DRLG P 10058', Drill Ahead 1.29 BPM @ 3091 PSI FS, .9 Returns BHP=4160, 13:21 16:39 3.30 10,203 10,203 PROD5 DRILL WPRT P Stalled out,hard to get drilling, Pull wiper PUW=30K 16:39 18:30 1.85 10,203 10,350 PROD5 DRILL DRLG P 10203',Drill ahead,went right back to bottom and drilled. 1.3 BPM @ 3300 PSI FS.91 returns. BHP=4259, RIW=9.8K. Geologist called TD at 10350' 18:30 20:00 1.50 10,350 7,970 PROD5 DRILL WPRT P Pump low/high vis sweeps,wiper to window 20:00 20:12 0.20 7,970 8,000 PROD5 DRILL DLOG P Tie in to RA marker,+1'correction 20:12 23:12 3.00 8,000 7,900 PRODS DRILL WPRT P RBIH,Tag at 10350', PUH laying in 35 Bbls liner running pill 23:12 00:00 0.80 7,900 4,000 PROD5 DRILL TRIP P POOH 12/01/2010 Ran liner in two sections,from 10350'to liner top at 7924' 00:00 01:00 1.00 4,000 0 PROD5 DRILL TRIP P Continue POOH. Close SSSV 01:00 01:18 0.30 0 0 PROD5 DRILL SFTY P PJSM 01:18 02:00 0.70 0 0 PROD5 DRILL PULD P Lay down drilling BHA#25 02:00 02:30 0.50 0 0 COMPZ CASING PULD P RU floor for liner operations 02:30 02:42 0.20 0 0 COMPZ CASING SFTY P PJSM 02:42 04:24 1.70 0 1,439 COMPZ CASING PUTB P PU BHA#26 with lower liner string, 43 Joints slotted and Inteq BHA 04:24 04:54 0.50 1,439 1,439 COMPZ CASING PULD P PJSM,Strip on well,test tools, open EDC 04:54 05:24 0.50 1,439 1,439 COMPZ CASING PULD T Strip off to replace torn 0-ring on union,and strip back on. Re test tool 05:24 07:54 2.50 1,439 1,439 COMPZ CASING PULD T Data acquisition problems.Obtain Cerberus authorization to continue to aquire coil life data 07:54 09:24 1.50 1,439 7,824 COMPZ CASING RUNL P Open SSSV, RIH BHA#26 AL2-02 Lower Liner 09:24 09:30 0.10 7,824 7,839 COMPZ CASING RUNL P Correct to flag+14.5,continue in well. Close EDC,wt check @ window 32K Page 22 of 23 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:30 10:30 1.00 7,839 10,351 COMPZ CASING RUNL P Tag Bottom, Pumps on 1.45 BPM @ 4500 PUW=32K 10:30 10:57 0.45 10,351 8,954 COMPZ CASING TRIP P Start out of well 10:57 11:09 0.20 8,954 7,579 COMPZ CASING DLOG P Tie into Gamma for-1 foot. Delete liner length from counters, BOL=10350',TOL(Lower section)= 8956' 11:09 12:51 1.70 7,579 6,845 COMPZ CASING TRIP P POOH, Paint 6800'EOP flag 12:51 13:45 0.90 45 0 COMPZ CASING PULD P At surface,close SSSV,monitor for flow, remove liner running BHA 13:45 15:00 1.25 0 0 COMPZ CASING PUTB P PJSM, P/U AL2-02 upper liner BHA #27 15:00 16:00 1.00 0 0 COMPZ CASING PULD P R/D tongs and liner running equipment,M/U coil track. Surface test tool and strip on well. Equalize across SSSV and pump open 16:00 18:18 2.30 0 8,958 COMPZ CASING RUNL P RIH with upper section of AL2-02 Liner,Wt.check at window,30K. Correct depth at flag. 18:18 19:18 1.00 8,958 7,400 COMPZ CASING DISP P 1K WOB,Tag liner top and stack 9K WOB, pump at 1.3 BPM and 4200 CTP to release,26K PUW,-500 WOB. Top of liner=7925', BOL= 8956'(upper section). Open EDC, Displace flo-pro with SW 19:18 21:00 1.70 7,400 0 COMPZ CASING TRIP P POOH, FP well with diesel from 2500' 21:00 23:00 2.00 0 0 COMPZ CASING PULD P Undeploy liner running BHA, 1100 WHP 23:00 00:00 1.00 0 0 DEMOB WHDBO NUND P Set BPV 12/02/2010 Set BPV, RDMO, rig released at 0600 00:00 01:00 1.00 DEMOB WHDBO NUND P Continue with BPV install, 01:00 04:00 3.00 DEMOB WHDBO NUND P Flush stack and blow down coil and surface equipment 04:00 06:00 2.00 DEMOB WHDBO NUND P Nipple down, RDMO. Rig released at 0600 Page 23 of 23 scirmE AinsEA 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, 3K-08AL1 ConocoPhillips Alaska, Inc. Permit No: 210-149 Surface Location: 1259' FSL, 317' FWL, SEC. 35, T13N, R9E, UM Bottomhole Location: 2123' FSL, 2549' FWL, SEC. 34, T13N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 3K-08A, Permit No 210- 148, API 50-029-21621-01. 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, aniel T. Seamount, Jr. Chair DATED this I day of October, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ECEIV ALASKA OIL AND GAS CONSERVATION COMMISSION P.i r.; Y 010 PERMIT TO DRILL 20 AAC 25.005 AIM Oil&Gas Cons.Celtratien 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj Q . Single Zone Q - 1 c.Specit llefteglosed for: Drill ❑ Re-drill il Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 3K-08AL1 ` 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10000' ' ND: 6501' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1259'FSL,317'FWL,Sec.35,T13N, R9E, UM • ADL 25519,25520 • Kuparuk River Oil Pool - Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1272'FSL, 1435'FWL,Sec.34,T13N,R9E, UM 25519,25520 11/18/2010 Total Depth: 9.Acres in Property: 14.Distance to 2123'FSL,2549'FWL,Sec.34,T13N, R9E,UM 2560 Nearest Property: 11050 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: , 69 feet 15.Distance to Nearest Well Open Surface:x- 529306 . y- 6008254 • Zone- 4 GL Elevation above MSL: 40 feet to Same Pool: 3K-10 ,1950' 16.Deviated wells: Kickoff depth: 8500 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle: 101° deg Downhole:4898 psig Surface:4246 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 2040' 7960' 6440' 10000' 6501' slotted/solid 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) 8501 6924 none 8386 6833 none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 1540 sx Poleset 110' 110' Surface 4244' 9.625" 1200 sx AS IV,300 sx CI G 4244' 3758' Intermediate Production 8475' 7" 335 sx Class G, 175 sx AS I 6903' 6903' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7916'-7934',8090'-8120',8130'-8185',8230'-8240' 6474'-6488',6607'-6630',6638'-6680',6714'-6722' 20.Attachments: Property Plat❑ BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: ,/ 22. I hereby certify that the foregoing is true and correct. Contact Gary Eller @ 263-4172 p j��' �'' Printed Na V. Cawvey Title Alaska Wells Manager • , "-l/c:7‘"". Signature 2. Phon 265-6306 Date l d/ Zald Commission Use Only �/ V Permit to Drill � //', API r: Permit Approval See cover letter Number: 2-/t) /1747' 50-c12-( `167(' (_/1"( Date: 10Ii 1 J'0 for other requirements ■ Conditions of approval: If box is checkedwell may not be used to explore for,test,or produce coalbed m hane,gas hydrates,or gas contained in shales: 2 4-56 p 3 - /3 ? /e S� //// S mples req'd: Yes ❑ No L Mud log req'd: Yes ❑ No [ Other: kZszo f„, Ann.w1.*4_ (sit measures: Yes AEI No ❑A Directional svy req'd: Yes `L'J No ❑ — a 1 Ti rit.�Tt o/O et�`cd i et, i'ti 4.ccc3r4 '.t/ Alo 2 G3 — /4 ZT /'G.z...4.Yed APPROVED BY THE COMMISSION /) // �� DATE: " ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for $ •ws •;W 1 . ... oval(20 AAC 25.005(g)) _ . ,SS�u✓bmit in Duplicate /0•P/4 f 00/>720,,,, ,v 6.--/L KRU 3K-08A, AL1, AL2, AL2-01 —Coiled Tubing Drilling Summary of Operations: Well 3K-08 is a Kuparuk A-sand and C-sand injection well equipped with 3'/2"tubing x 7"casing. Four proposed A-sand CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling,the existing C`sand perfs in 3K-08 will be squeezed with cement and the A-Sand perfs will be plugged with a positive plug plus a cement cap. After squeezing the existing C-sand perfs with cement, a mechanical whipstock will be placed in the 3'/2"tubing at the first kickoff point. The 3K-08A sidetrack will make a 2-string exit through the 3'/2"tubing and 7"casing at 7965' MD. It will target the A2 sand north of the existing well with a 2035' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,000' MD with a liner top aluminum billet at 8500' MD. The 3K-08AL1 lateral will kick off from the aluminum billet at 8500' MD and will target the A3 sand north of the existing well with a 1500' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,000' MD with the final liner top located just inside the 3'/2" liner at 7960' MD. The 3K-08AL2 lateral will make another 2-string exit through the 3'/2"tubing and 7"casing at 7945' MD. It will target the A2 sand southwest of the existing well with a 2255' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,200' MD with a liner top aluminum billet at 8850' MD. The 3K-08AL2-01 lateral will kick off from the aluminum billet at 8850' MD and will target the A3 sand southwest of the existing well with a 1400' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,250' MD with the final liner top located just inside the 3'/2" liner at 7935' MD. CTD Drill and Complete 3K-08 Laterals: November 2010 Pre-Rig Work 1. Positive pressure and drawdown tests on master valve& swab valve 2. Load tbg&IA. MIT-IA. MIT-OA. Test packoffs—T&IC. 3. RU slickline. Obtain updated static BHP on A/C-sand. 4. Set CA-2 positive plug in the 2.25"D-nipple at 8020' MD to plug off A-sand perfs. 5. Close the sliding sleeve at 7989'. Pressure test tubing to confirm CA-2 plug integrity. 6. Re-open sliding sleeve at 7989'. Pull dummy injection valve at 7871' MD. RD slickline. 7. RU e-line. Shoot squeeze perfs thru the 3'/2"tubing and 7"casing at 7945', 7965', & 7995' ELM. RD e-line. 8. RU coil. Lay in cement on top of plug isolating A-sand. Squeeze the C-sand perfs with cement. RD coil. 9. RU slickline. Tag cement top. Pressure test cement squeeze. 10. RU coil. Drill out cement from the 31/2"tubing using special clearance bi-center bit down to the 2.813"sliding sleeve at 7989' MD. RD coil. 11. RU slickline. Run whipstock dummy. Stroke flow-sleeve and pressure test SSSV following cement squeeze operations. RD slickline. 12. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3K-08A Sidetrack(A2 sand, north) a. Set a mechanical whipstock at 7965' b. Mill a 2.80"2-string window at 7965' c. Drill 2.70"x 3"bi-center lateral to TD of 10,000' MD Page 2 of 5 ORIGINAL September 30,2010, FINAL KRU 3K-08A, AL1, AL2, AL2-01 —Coiled Tubing Drilling d. Run 2%"slotted liner with an aluminum liner-top billet from TD up to 8500' 3. 3K-08AL1 Lateral(A3 sand,north) a. Kick off of the aluminum billet at 8500' MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,000' MD c. Run 2%"slotted liner from TD with an liner-top billet inside 3''A"tubing at 7960' 4. 3K-08AL2 Lateral(A2 sand, southwest) a. Set a mechanical whipstock at 7945' b. Mill a 2.80"2-string window at 7945' c. Drill 2.70"x 3"bi-center lateral to TD of 10,200' MD d. Run 2%"slotted liner with an aluminum liner-top billet from TD up to 8850' 5. 3K-08AL2-01 Lateral(A3 sand, southwest) a. Kick off of the aluminum billet at 8850' MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,250' MD c. Run 2%"slotted liner from TD up to 7935' MD, up inside the 3'/2"liner 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pu11 BPV 2. Obtain static BHP 3. Flow back well to production. It is unlikely that this flowback will extend beyond 2 weeks before the well is converted to injection. 4. Conduct MIT-IA 5. Put well on injection Mud Program: • Will use chloride-based Biozan brine or used drilling mud(10.0 ppg)for milling operations,and chloride- based Flo-Pro mud(10.0 ppg)for drilling operations. The SCSSV installed in 3K-08 should allow us to deploy 2%"slotted liner without having to kill the well. 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. Casing Program: • 3K-08A: 2%", 4.7#, L-80, ST-L slotted/solid liner from 8500' MD to 10,000' MD • 3K-08ALI: 2%",4.7#, L-80, ST-L slotted/solid liner from 7960' MD to 10,000' MD • 3K-08AL2: 2%",4.7#,L-80, ST-L slotted/solid liner from 8850' MD to 10,200' MD • 3K-08AL2-01: 2%", 4.7#,L-80, ST-L slotted/solid liner from 7935' MD to 10,250' MD Existing Casing/Liner Information Surface: 9%",J-55, 36 ppf Burst 3520 psi Collapse 2020 psi Production: 7", J-55, 26 ppf Burst 4980 psi Collapse 4320 psi Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Page 3 of 5 OR I G t N L September 30,2010, FINAL KRU 3K-08A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Reservoir Pressure • The most recent static BHP survey in well 3K-08 was taken September 2010 after several months of shut-in. The measured A-sand reservoir pressure was 4194 psi at 6565' SSTVD, corresponding to 12.3 ppg EMW. We generally expect to encounter similar pressure as the laterals are drilled away from the mother well. Well Control: • Two well bore volumes(-180 bbl)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 5000 psi. Maximum potential surface pressure in 3K-08 is 4246 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on a pressure measurement of 4898 psi at 8065' MD(6519' SSTVD)taken in well 3K-08 in early 2009. Since that time well 3K-08 has been left shut-in to allow pressure in the area to deplete, and the most recent survey from September 2010 showed that formation pressure had decreased to 4194 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 3K-08A, plan#3 2. 3K-08AL1, plan#3 rr 3. 3K-08AL2, plan#3 4. 3K-08AL2-01, plan#3 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 3K-08 northern CTD laterals(A&ALl): 11,050' to property line,—1950'to well 3K-10 • 3K-08 southwestern CTD laterals(AL2 &AL2-01): 13,300' to property line,—950' from well 3N-18 Hazards • Shale stability is a potential problem,particularly in the build section where the AS shale will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 70°hole angle. • There has been no injection into the target fault block nor has the 3K drillsite ever been equipped to inject MI gas. Therefore, it is unlikely that an influx could yield significant quantities of gas. • Well 3K-08 has no measured H2S since it is an injection well. Well 3K-26 is located 13' to the right side and 3K-27 is 13' to the left side of the 3K-08 surface location. Well 3K-26 has no measured H2S since it is also an injector, and 3K-27 has 100 ppm H2S as of Dec-09. The maximum H2S level on the pad is 250 ppm from well 3K-12 (8/31/10). All H2S monitoring equipment will be operational. Page 4 of 5 0RIGINAL September 30,2010, FINAL KRU 3K-08A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow 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 installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%"BHA will be accomplished utilizing the 2%"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. The SCSSV in well 3K-08 will enable us to deploy slotted liner without having to kill the well. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 4120 psi at 7965' MD(6442' SSTVD), or 12.3 ppg EMW. • Expected annular friction losses while circulating: 797 psi (assuming annular friction of 100 psi/1000 ft due to the 31/4"tubing) • Planned mud density of 10.0 ppg equates to 3350 psi hydrostatic bottom hole pressure at 6442' SSTVD • While circulating 10.0 ppg mud, bottom hole circulating pressure is estimated to be 4147 psi or 12.4 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 3K-08. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability,but not necessarily for well control. • When circulation is stopped,—800 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. Quarter-Mile Injection Review The following wells lay within one-quarter mile of the proposed 3K-08 CTD laterals. • 3N-18(active producer)—This wellbore is located—950' to the northwest of wells 3K-08AL2 and 3K- 08AL2-01. It is a selective completion in the Kuparuk A-sand and C-sand, although the C-sand perfs were squeezed with cement in 2003. The Kuparuk sands are isolated by cemented 7"casing. • 3N-18L1 (active producer)—This CTD lateral was drilled in 2003, and is—950' to the northwest of wells 3K-08AL2 and 3K-08AL2-01. It is tied into the 3N-18 motherbore, so it also isolates the Kuparuk sands via cemented 7"casing. • 3N-18L1-PB1 (plugback)—This CTD plugback was drilled in 2003, and is—950' to the northwest of wells 3K-08AL2 and 3K-08AL2-01. It suffered from collapsing shales during drilling, so there should be no risk of injection out of zone via the 3K-08 CTD laterals. Page 5 of 5 d AL September 30,2010, FINAL 0 a m - Cn j 7 w -c N m Cn O C m c a as to a co CO as b N 0 c0 Ch 0 CO m 0 10 Qoo g� �o g��, Qg � J )-o m COs ym `m 0 0 O m O N O — COO O - c J Cs J — a J = m .Q O N II Zr, 11 N -0 11 m 11 N <F- J < � J < 0 J J 0 c < I- 'Li z Z C W £ o ° as 2 _ O .n 0 N 0 - N y Li-) 0- - 0 0 ro co O �o r (P oo o)C V 0 0 1-- O O eo cn 'U N O a > �' a) E °�°N- m m `m mo s-' i', 1111:::::: ro Cf) al W 7 = �a E ti m Q°o U �` a Lo W CA 2' m O c1 O'C V O xx 0 d OOD L7co U a 6 O-O U Co W mO C V x M m 2 m-= co U F- 0) 0 r) ti 0 0 CO 0 OF N N N m m N N `0 co co -°co as CO r h ti N I: M M C) 0 r0 M c� CV N N o a no i O o i Ai ,- ,. r3 :1111 0 CI 0 t \ / / II III 'V m N a o m CO N- c m In °-m °n) m m o a Q m0 to o m ° a N , N N m . • 2 2 o `O N d (0 * °. U O 't o co i0 w w � .- da a _ my N � DI V N _ .c.,:,,, .0a) aN0 r co M 0 m L (V N R O L. cL Cn 0 0_ m Q co O CA 2 C0 ORG1NAL ConocoPhilhi s Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K-08 3K-08AL1 Plan: 3K-08AL1_wp03 Standard Planning Report 24 September, 2010 rani BAKER HUGHES rr GINAL r-' ConocoPhillips ■f" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3K-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-08 @ 69.00ft(3K-08) Site: Kuparuk 3K Pad North Reference: True Well: 3K-08 Survey Calculation Method: Minimum Curvature Wellbore: 3K-08AL1 Design: 3 K-08AL 1_wp 03 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 3K Pad Site Position: Northing: 6,008,428.74ft Latitude: 70°26'2.781 N From: Map Easting: 529,306.18ft Longitude: 149°45'39.930 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.23° Well 3K-O8 Well Position +N/-S 0.00 ft Northing: 6,008,253.70 ft Latitude: 70°26'1.059 N +E/-W 0.00 ft Easting: 529,305.94 ft Longitude: 149°45'39.957 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 3K-08AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1 (°) (°) (nT) BGGM2010 11/15/2010 16.95 79.91 57,359 Design 3K-08AL1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,400.00 � Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 30.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 8,400.00 87.78 8.45 6,582.69 -85.26 -4,177.08 0.00 0.00 0.00 0.00 8,510.00 100.98 8.45 6,574.31 22.99 -4,160.99 12.00 12.00 0.00 0.00 8,585.00 100.84 17.62 6,560.09 94.65 -4,144.39 12.00 -0.18 12.22 90.00 8,655.00 99.99 26.12 6,547.41 158.48 -4,118.77 12.00 -1.21 12.14 95.00 8,755.00 94.77 37.02 6,534.53 242.79 -4,066.90 12.00 -5.22 10.90 115.00 9,005.00 94.13 67.10 6,514.66 394.23 -3,872.60 12.00 -0.26 12.03 90.00 9,105.00 96.11 78.99 6,505.70 423.24 -3,777.51 12.00 1.98 11.88 80.00 9,205.00 92.70 90.53 6,497.99 432.31 -3,678.40 12.00 -3.41 11.54 106.00 9,305.00 91.40 78.59 6,494.40 441.77 -3,579.10 12.00 -1.30 -11.94 264.00 9,580.00 90.09 45.61 6,490.73 568.66 -3,339.43 12.00 -0.48 -11.99 268.00 9,710.00 88.20 30.13 6,492.68 670.96 -3,259.88 12.00 -1.45 -11.91 263.00 10,000.00 88.53 64.94 6,501.22 863.67 -3,049.32 12.00 0.11 12.00 90.00 9/24/2010 11:14:52AM Page 2 COMPASS 2003.16 Build 69 in c 11N � L 'yr' f ConocoPhillips IC' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3K-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-08 @ 69.00ft(3K-08) Site: Kuparuk 3K Pad North Reference: True Well: 3K-08 Survey Calculation Method: Minimum Curvature Wellbore: 3K-08AL1 Design: 3 K-08AL 1_wp03 i i Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 8,400.00 87.78 8.45 6,582.69 -85.26 -4,177.08 -2,162.38 0.00 0.00 6,008,152.04 525,129.64 TIP/KOP 8,500.00 99.78 8.45 6,576.11 13.26 -4,162.44 -2,069.73 12.00 0.00 6,008,250.61 525,143.90 8,510.00 100.98 8.45 6,574.31 22.99 -4,160.99 -2,060.59 12.00 0.00 6,008,260.34 525,145.30 2 8,585.00 100.84 17.62 6,560.09 94.65 -4,144.39 -1,990.22 12.00 90.00 6,008,332.06 525,161.62 3 8,600.00 100.68 19.44 6,557.29 108.63 -4,139.71 -1,975.78 12.00 95.00 6,008,346.05 525,166.24 8,655.00 99.99 26.12 6,547.41 158.48 -4,118.77 -1,922.14 12.00 95.34 6,008,395.98 525,186.99 4 8,700.00 97.68 31.05 6,540.50 197.51 -4,097.50 -1,877.70 12.00 115.00 6,008,435.09 525,208.10 8,755.00 94.77 37.02 6,534.53 242.79 -4,066.90 -1,823.19 12.00 115.76 6,008,480.48 525,238.52 5 8,800.00 94.75 42.44 6,530.79 277.26 -4,038.25 -1,779.01 12.00 90.00 6,008,515.07 525,267.03 8,900.00 94.55 54.47 6,522.65 343.24 -3,963.80 -1,684.64 12.00 90.45 6,008,581.33 525,341.22 9,000.00 94.16 66.50 6,515.02 392.27 -3,877.18 -1,598.88 12.00 91.43 6,008,630.69 525,427.63 9,005.00 94.13 67.10 6,514.66 394.23 -3,872.60 -1,594.88 12.00 92.35 6,008,632.68 525,432.21 6 9,100.00 96.02 78.39 6,506.23 422.26 -3,782.38 -1,525.50 12.00 80.00 6,008,661.06 525,522.30 9,105.00 96.11 78.99 6,505.70 423.24 -3,777.51 -1,522.22 12.00 81.00 6,008,662.05 525,527.17 7 9,200.00 92.88 89.95 6,498.23 432.33 -3,683.40 -1,467.29 12.00 106.00 6,008,671.51 525,621.24 9,205.00 92.70 90.53 6,497.99 432.31 -3,678.40 -1,464.81 12.00 106.86 6,008,671.51 525,626.23 8 9,300.00 91.47 79.19 6,494.52 440.81 -3,584.01 -1,410.25 12.00 -96.00 6,008,680.38 525,720.58 9,305.00 91.40 78.59 6,494.40 441.77 -3,579.10 -1,406.97 12.00 -96.41 6,008,681.36 525,725.48 9 9,400.00 90.98 67.20 6,492.42 469.66 -3,488.47 -1,337.50 12.00 -92.00 6,008,709.61 525,815.99 9,500.00 90.49 55.21 6,491.13 517.74 -3,401.01 -1,252.13 12.00 -92.24 6,008,758.03 525,903.26 9,580.00 90.09 45.61 6,490.73 568.66 -3,339.43 -1,177.24 12.00 -92.39 6,008,809.19 525,964.63 10 9,600.00 89.79 43.23 6,490.75 582.95 -3,325.43 -1,157.87 12.00 -97.00 6,008,823.52 525,978.57 9,700.00 88.35 31.32 6,492.38 662.36 -3,264.99 -1,058.87 12.00 -97.00 6,008,903.17 526,038.70 9,710.00 88.20 30.13 6,492.68 670.96 -3,259.88 -1,048.88 12.00 -96.80 6,008,911.78 526,043.77 11 9,800.00 88.24 40.93 6,495.48 744.06 -3,207.68 -959.47 12.00 90.00 6,008,985.08 526,095.67 9,900.00 88.34 52.94 6,498.48 812.19 -3,134.79 -864.02 12.00 89.66 6,009,053.49 526,168.29 • 10,000.00 88.53 64.94 • 6,501.22 863.67 -3,049.32 -776.70 12.00 89.30 6,009,105.30 526,253.55 TD 9/24/2010 11:14:52AM Page 3 COMPASS 2003.16 Build 69 ` .,! G ! NAL ConocoPhillips /G' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3K-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-08 @ 69.00ft(3K-08) Site: Kuparuk 3K Pad North Reference: True Well: 3K-08 Survey Calculation Method: Minimum Curvature Wellbore: 3K-08AL1 Design: 3K-08AL1_wp03 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3K-08AL1 t2 0.00 0.00 6,514.00 356.56 -3,835.45 6,008,595.16 525,469.49 70°26'4.556 N 149°47 32.510 W -plan misses target center by 48.78ft at 9029.30ft MD(6512.81 TVD,403.09 N,-3850.05 E) -Point 3K-08A,AL1 fault 2 0.00 0.00 0.00 430.81 -4,148.21 6,008,668.16 525,156.48 70°26'5.284 N 149°47'41.689 W -plan misses target center by 6514.84ft at 9200.00ft MD(6498.23 TVD,432.33 N,-3683.40 E) -Polygon Point 1 0.00 430.81 -4,148.21 6,008,668.16 525,156.48 Point 2 0.00 314.55 -3,825.34 6,008,553.18 525,479.78 Point 3 0.00 -6,180.30 -3,528.77 6,002,060.19 525,801.83 Point 4 0.00 314.55 -3,825.34 6,008,553.18 525,479.78 3K-08A,AL1 fault 1 0.00 0.00 0.00 229.78 -4,400.03 6,008,466.17 524,905.47 70°26'3.306 N 149°47'49.076 W -plan misses target center by 6537.77ft at 8963.94ft MD(6517.69 TVD,376.70 N,-3909.58 E) -Polygon Point 1 0.00 229.78 -4,400.03 6,008,466.17 524,905.47 Point 2 0.00 115.59 -4,097.01 6,008,353.19 525,208.91 Point 3 0.00 -9.74 -3,755.89 6,008,229.21 525,550.49 Point 4 0.00 115.59 -4,097.01 6,008,353.19 525,208.91 3K-08AL1 t3 0.00 0.00 6,501.00 903.64 -3,083.19 6,009,145.13 526,219.53 70°26'9.940 N 149°47'10.441 W -plan misses target center by 50.91ft at 9991.59ft MD(6501.00 TVD,860.04 N,-3056.90 E) -Point 3K-08A,AL1 Polygon 0.00 0.00 0.00 -115.33 -3,873.32 6,008,123.16 525,433.49 70°25'5.915 N 149°47'33.614 W -plan misses target center by 6523.94ft at 9205.00ft MD(6497.99 TVD,432.31 N,-3678.40 E) -Polygon Point 1 0.00 -115.33 -3,873.32 6,008,123.16 525,433.49 Point 2 0.00 -499.31 -3,887.81 6,007,739.17 525,420.51 Point 3 0.00 -370.38 -4,384.36 6,007,866.13 524,923.50 Point 4 0.00 33.58 -4,361.79 6,008,270.14 524,944.48 Point 5 0.00 353.07 -4,221.54 6,008,590.15 525,083.46 Point 6 0.00 704.28 -3,491.10 6,008,944.19 525,812.45 Point 7 0.00 1,060.97 -3,144.68 6,009,302.20 526,157.43 Point 8 0.00 845.68 -2,816.48 6,009,088.22 526,486.44 Point 9 0.00 307.24 -3,235.61 6,008,548.20 526,069.47 Point 10 0.00 115.25 -3,759.41 6,008,354.17 525,546.48 Point 11 0.00 -115.33 -3,873.32 6,008,123.16 525,433.49 3K-08AL1 t1 0.00 0.00 6,554.00 128.58 -4,099.39 6,008,366.17 525,206.48 70°26'2.312 N 149°47'40.252 W -plan misses target center by 30.33ft at 8634.07ft MD(6551.09 TVD,139.79 N,-4127.43 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 4,244.00 3,688.74 9 5/8" 9-5/8 12-1/4 10,000.00 6,501.22 2 3/8" 2-3/8 3 9/24/2010 11:14:52AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL • 4. ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3K-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3K-08 @ 69.00ft(3K-08) Site: Kuparuk 3K Pad North Reference: True Well: 3K-08 Survey Calculation Method: Minimum Curvature Wellbore: 3K-08AL1 Design: 3K-08AL1_wp03 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,400.00 6,582.69 -85.26 -4,177.08 TIP/KOP 8,510.00 6,574.31 22.99 -4,160.99 2 8,585.00 6,560.09 94.65 -4,144.39 3 8,655.00 6,547.41 158.48 -4,118.77 4 8,755.00 6,534.53 242.79 -4,066.90 5 9,005.00 6,514.66 394.23 -3,872.60 6 9,105.00 6,505.70 423.24 -3,777.51 7 9,205.00 6,497.99 432.31 -3,678.40 8 9,305.00 6,494.40 441.77 -3,579.10 9 9,580.00 6,490.73 568.66 -3,339.43 10 9,710.00 6,492.68 670.96 -3,259.88 11 10,000.00 6,501.22 863.67 -3,049.32 TD 9/24/2010 11:14:52AM Page 5 COMPASS 2003.16 Build 69 t -7 1I'L D4 t a i 1 ; I rn I s Ng--Z 8 • I T: , I ° 1 o N s 8 I I q j a c . 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(11!it/0 g 1) (±)tpioNv(-)qpios A , 03 0 CO Y cy) ORIGINAL • '16.- ConocoPhillips E1 Conoco Phltlips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Site Kuparuk 3K Pad Project: Kuparuk River Unit TVD Reference: 3K-08 @ 69.00ft(3K-08) Reference Site: Kuparuk 3K Pad MD Reference: 3K-08 @ 69.00ft(3K-08) Site Error: 0.00ft North Reference: True Reference Well: 3K-08 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3K-08AL1 Database: EDM Alaska Prod v16 Reference Design: 3K-08AL1_wp03 Offset TVD Reference: Offset Datum Reference 3K-08AL1_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,400.00 to 10,000.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,193.10ft Error Surface: Elliptical Conic Survey Tool Program Date 9/23/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 7,900.00 3K-08(3K-08) GCT-MS Schlumberger GCT multishot 7,900.00 8,400.00 3K-08A_wp03(3K-08A) MWD MWD-Standard 8,400.00 10,000.00 3K-08AL1_wp03(3K-08AL1) MWD MWD-Standard Casing Points 1 Measured Vertical Casing Hole Depth Depth Diameter Diameter I (ft) (ft) Name (•') (•') 4,244.00 3,757.74 9 5/8" 9-5/8 12-1/4 10,000.00 6,570.22 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 3K Pad 3K-04-3K-04-3K-04 Out of range 3K-08-3K-08-3K-08 9,250.00 7,500.00 757.06 128.54 645.09 Pass-Major Risk 3K-08-3K-08A-3K-08A wp03 8,400.00 8,400.00 0.00 0.30 -0.22 FAIL-No Errors 3K-08-3K-08AL2-3K-08AL2wp03 9,250.00 7,500.00 757.06 128.54 645.09 Pass-Major Risk 3K-08-3K-08AL2-01 -3K-08AL2-01_wp03 9,250.00 7,500.00 757.06 128.54 645.09 Pass-Major Risk 3K 11 3K 11 3K 11 Out of range 3K-13-3K-13-3K-13 Out of range 3K-15-3K-15-3K-15 Out of range 3K-35-3K-35-3K-35 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/29/2010 12:15:56PM Page 2 of 8 COMPASS 2003.16 Build 69 nRIG1NAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing • L. — Lubricator Riser Annular/ Blind/Shear 2"Pipe/Slip(CT)L Pump into Lubricator above BHA rams ���Q • r Choke 2-3/8"Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) Kill ► eJ LL7Q�Q� �7 ��• ► Blind/Shear 2"Pipe/Slip(CT) Choke 2 . Swab Valves Wing Valves Tree Flow Cross Surface Safety Valve BOPE: 7 1/16", 5M psi, TOT Choke Line: 2-1/16'; 5M psi Master Valve Kill Line: 2-1/16", 5M psi C Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, CO62 Union rt$ 511NAL ‘ : TRANSMITTALL LETTER CHECKLIST WELL NAME kJ/0 3 i r 1 PTD# ?-/�. / `� Development Service Exploratory Stratigraphic Test Non-Conventional /Well • FIELD: C�y�Cfi� ``L � `POOL: /�L'� /�' ! ,I-1?-1 / F>/ (1 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 -1( � �—C)� i /1 (If last two digits in , ,2 - Z �>Z> c..../ API number are ( - ` ' between 60-69) Permit No. h/ API No. 50-(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 m u) co p , N a cn 0 O o m , , _ 3 , Q ui 0 0 L_ c C N O 7 E co y ° a c a) a °' o = E 2 a o • L a O w o c U) a 0 7 = O O aa) w a) a E O N a) c E m n T. a O N O U L E U a (0 2 M .3 a n Y ° a .L... v N = N co ° n 3 co O cs Z O O C 6 O 3 0- n N C ° p Y = ` L V p CO U .- — O = 7 c o 0) o Y a _3 @ m ° co J D (0 N c O- - ° > U) O 2 E ° CO o a) ° ° N 0 Fs E U 5 w 9 (O V) 0 U N co o w a. a) U) L C Y N c N C . T (n C co O CO • N a7 cc) O N 3 M a) O O. 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