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211-090
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. 1 ' , 1 . - d q O Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RE or Items: AN: OVERSIZED: NOTES: Co ❑ Maps: ❑ rayscale Items: liZogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: 1/14P BY: 411SE. Date: a �j / /st Project Proofing BY: Maria Date: 7/ 3///j. /s/ 1(4 P Scanning Preparation I x 30 = 30 + a( = TOTAL PAGES ‘574:50 (Count does not include cover sheet) , BY: Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: S7, (Count does include covers eet) Page Count Matches Number in Scanning Preparation: YES NO BY: al. Date: 7/ 5/(tt /s/ roP Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michel Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc Oo O c U ro IC- (0 2 N N 1` CO 1 CO m aU` N Z 0 o 5 el 0 }I ! c O C� C�cc ct0 cC Q U a� m a o E rn Q D v) m E ? a a g u)o_ 0 0- 2 2 L- 0 a ° LI-46 c 0 H 2 2 1- O H Q m o v c a) �I o 0 Q o 0 0 0 0 J a) y O N N N N N N OI # o d' uo un Cr) 0) 0) 0) U o J co co N N N N Z E a0 a0 a0 co c I • o E — c c c c c c d x = a) Cl) a) a) a) a) E .. I�— < - �"� a 0 0 0 0 0 E 0 LL Q co 0 O W 3 0 N- I,- I-- I,- h h N y a v u) a- .0 J 0 z to co co co co co co0. N 7ti e ca W IX a c �E O N a. Lo CO (00 co co co co N N N N N Z O V) CO CO c0 co CO C•' a W Z J d ✓ 0 0 a) aa)) u) Zo • Qc«�o N o c° ce z° 0 l I a) 7 N o IH a N • ni • « _ CL 0 co o a)-° 0 0 0 0 ,? E N co Z� J 0 0 0 co u) 0 • r _ Na) u, d O OE a a) o V �n N �n U N ocs, 00 J 'o 00 NU) 1 J 0 Q • I''. M C11 ~ N E D N z CO N2 1 1 aC Q F. Y . ZI C U w w w < Z o W > > > > Q y 0 o Z Z .N �, .N .N 0 E J CC7 7 fA N tl) h Z 7 m N CC CY XIX OO OO . ' ,y aOO . . • ao E t f) o co 7 co N N 7 7 7 7 c cooZ c c c c VIII '.O-. SII rn € O I O CO Q J .0 y d N rc H CO O ~ a) 0 r C } d Q Z C W 0 Z N tZ' 3 N O p yo o O m 0 re 0 0 IiEI _rn Q -� a Z Z v ZS c • 0° �_ w o 0 2 , .) 1 \ 1 o o y a) a) i= �a 0 N —I 0 ~ U o To co > E a O wa 0 F' J O 1T Q W J J J W Q > 0 Q 0 0 0 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 ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: August 1,2011 211-090/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 July 28,2011 50-103-20087-63 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1322'FNL,281'FWL,Sec. 12,T12N,R8E, UM July 29,2011 3H-10CL2-02 Top of Productive Horizon: 8. KB(ft above MSL): 28'RKB 15.Field/Pool(s): 708'FNL, 1412'FWL,Sec. 12,T12N, R8E,UM GL(ft above MSL): 67'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 668'FSL, 1897'FWL,Sec. 1,T12N, R8E, UM 8171'MD/6018'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-498655 y- 6000335 Zone-4 8171'MD/6018'TVD ADL 25531 TPI: x-499786 y- 6000949 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-500270 y- 6002325 Zone-4 nipple @ 497'MD/497'TVD 2657 18.Directional Survey: Yes ❑., No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1591'MD/ 1591'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 6667'MD/6024'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 36' 108' 36' 108' 24" 225 sx AS I 9.625" 40# L-80 35' 3024' 35' 3023' 12.25" 1300 sx AS III,100 sx AS I,300 sx Class G 7" 15.5# L-80 33' 3560' 33' 3552' 8.5" 450 sx Class G,200 sx AS I 4.5" 12.6# L-80 3367' 6405' 3365' 6050' 6.125" 225 sx Class G 3.5"x 3.25" 9.2#,6.6# L-80 5381' 6390' 5322' 6051' 4.125" 9 bbls Class G 2.375" 4.7# L-80 6441' ✓ 8171' ''' 6040' 6018' 3" slotted liner 24.Open to production or injection? Yes W No j If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size nd Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) f'L"'`1 4.5" 3380' 3379'MD/3377 TVD Ktg)5354'MD/5296'TVD(liner top) slotted liner from 6465-8171'MD 6037-6018'TVD 26. ACID,FRACTURE,CEMENT QUEEZE,ETC. ` Lt I:L'N DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED r - 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,"gas lift,etc.) August 13,2011 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 8/13/2011 12 hours Test Period-> 386 736 _ 1204 176 Bean 2138 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 172 psi 694 24-Hour Rate-> 700 1497 2341 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED' NONE AUG 16 2011 RBDMS AUG 17 1011 Alias 011&Gas Coos.Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Ancherag8 Submit Original only 28. GEOLOGIC MARKERS(List all formations and markers a itered): 29. FORMATION TESTS NAME MD TVD s Well tested? 0 Yes ❑✓ 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 1591' 1591' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A 6667' 6024' Kuparuk A2 7390' 6029' Kuparuk A3 6667' 6024' Base Kuparu A3 8020' 6007' N/A Formation at total depth: Kuparuk A 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 Nam L. an Title: CTD Engineering Supervisor Q 1 Signature Phone 265-6306 Date Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 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 in o co co O •• 7 n NN coo Cn0 O O O N N II O II NCD II n O a0 o, Q � Q co 0 0 F- m0 ON U °0 -b H_ N 7 II pop -CMO co C co O 0 o CO p C M N g oaJ d JJ ~N U o U - 7 py O•= N Q _ ( = N J r M N COM m CO N M N 0 C l'nMN J N J cin a . Q n co N n M CO M COW COQ m cc �� 0 mm <V f E N 0 Cc) fl U 10 F co r-. 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A KUP 3H-10CL2-02 Conoco lips Well Attributes Max Angle&MD TD- AIa$rta Wellborn APL/UWI Fold Name Well Stat Incl C) MD(ftKB) Act Btm(ftKB) c�xxlccYhhps 501032008763 KUPARUK RIVER UNIT PROD 100721 782073 8171.0 Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date SSSV:NIPPLE _ 180 11/8/2010 Last WO: 42.40 _ 12/6/1987 -„ W,4lI,C ¢ ,Lt2R- �$,B1%,1lZ,G>.1.97,2g Ap}�_-, ..Annotation De h ftKB End Date Annotation Last Mod...End Date 16:1422.-0 Actual_11. m._ pt ( ) Last Tag SLM I 6,139.0 5/24/2011 I Rev Reason SIDETRACKS ninam 8/10/2011 Casing Strings Casing Description String 0--. 'String ID.-.'Top(kKB) 'Set Depth(f...Set Depth(TVD)..'String Wt. Str ng...'String Top Thrd HANGER.23 ` _...� 1 _..L._ _. L_-_ — I- _-_-- l 0 1 LINER CL2-02 2 3/8 1.995 6,441.2 8,171.0 4.70 L-80 STL Liner Details Trip Depth — — (TVD) Top net Nomi... 'fop(MB) (11KB) et Item Desalptbn Comment ID(in) 6,441.2 6,040.0 96.33 BILLET OH Anchored Billet 1.995 6,464.1 6,037.4 95.73 DEPLOY Shorty Deployment Sleeve 1.995 Perforations&Slots i — CONDUCTOR, Shot 36-108Top(TVD) Bhn(TVD) Dens Top(ftKB)BM(ftKB) (ftKB) (NKB) Zone DMe (sh-- Type Comment NIPPLE,497 - 6,465 8,171 6,037.3 6,018.4 7/30/2011 32.0 SLOTS AKernatirg solid/slotted pipe- 0.125`x2.5"@ 4 circumferential 1i4 adjacent rows,3"centers staggered p l; 18 deg,3'non-slotted ends ii SURFACE, 35-3.024 GAS LIFT, .116067 3,266 i I NIPPLE,3,328 (V XO BUSHING, 3,367 tl LOCATOR, 3,369 SEAL ASSY, 1 3,369 IS I 10 WINDOW B, 3,539-3,549 PRODUCTION Post Sidetrack, 33.3,560 CEMENT, 6,026 WHIPSTOCK, 6,043 IPERF,_ 6,039-6,059 WINDOW C, 6,04$-0,053 WHIPSTOCK,_ 6,280 Window CL2, 6,286.6,290 LINER C NTERMEDIATE,- 5,3890 LINER,ER LIN , 11 3,368-6,405 Mandrel Details - - _ — Top Depth Top Port (TVD) Incl OD Valve Latch Rica TRO Run Sb Top ORM) (ftKB) (') Make Model (Ve) Sery Type type (in) (pet) Run Oats Cont... 1 3,286.5 3,285.3 8.07 CAMCO KbC 2 11GAS LIF l DMY BEK 0.000 0.0 6/27/2011 SLOTS, 6,465-8,171 LINER CL2-02, 6441-8,171 TD (3H-10CL2-02), 8,171 MA klikii_iii. 01 0 C CU 0 CU a CDW NiCtimrs EL ca co � U 0 > = c > N ■� C C 0 JN L"Ps im = = I C N .� 3 O Q ca ca o (� Q . o— r VYYcz � o Z m E MhoLO r co t t0 4Z d CO CO N O F' r. o N v LO O O O" L N N V coQ 0 c U O 0 U O N ej d N0) .„ J • 7 r C• 7 C O N J J C9 C....� O m m O O O Q E M M M N > O O Q M M i U co (9 7 (Q @) © U m o o coE d Cl) o 0 0 ? 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V O C >. -x e- O LLcq ConocoPhiIIips Time Log & Summary We/view Web Reporting Report Well Name: 3H-10 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 7/8/2011 12:00:00 PM Rig Release: 8/2/2011 4:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/06/2011 24 hr Summary MIRU on 3H pad. Nipple up BOPE to release top drive. Lay down PDLs.Secure top drive. 00:00 12:30 12.50 0 0 MIRU MOVE MOB P Move Rig from 1E to 3H pad Exception Move 12:30 15:00 2.50 0 0 MIRU MOVE MOB P Arrive on 3H pad, Remove Jeeps, release three sows 15:00 17:00 2.00 0 0 MIRU MOVE MOB P Spot drilling module on well. Spot pits 17:00 18:00 1.00 0 0 MIRU MOVE RURD P R/U scaffolding in cellar 18:00 21:00 3.00 0 0 MIRU MOVE NUND P Nipple up BOP stack and secure 21:00 00:00 3.00 0 0 MIRU MOVE RGRP P PJSM, Lay down PDL's,Secure mast/top drive to lay over mast for Jib Boom Arm repairs Begin NAD Downtime 07/07/2011 Make repairs to Jib Booms&Reinstall.Test for hydraulic operation String new PDL winch cables 00:00 04:30 4.50 0 0 MIRU MOVE RGRP P Continue preping to lay down mast 04:30 08:00 3.50 0 0 MIRU MOVE RGRP P Mast in Head ache rack. Prep for repairs 08:00 12:00 4.00 0 0 MIRU MOVE RGRP P PJSM-with crane operator,Man basket&crew for repairs. Both Jib booms removed. Drillers side was seized-ODS pulled out easier. 12:00 18:00 6.00 0 0 MIRU MOVE RGRP P Continue with Mast/Jib boom repairs. 18:00 00:00 6.00 0 0 MIRU MOVE RGRP P Reinstall Jib Boom Arms, Raise mast 10 degrees and test Boom Hydraulics for proper operation. Lower mast back down into cradle. Begin stringing new cable for PDL winches 07/08/2011 Complete rig up in cellar and Putz,Take on fluids, Stab coil in injector and fill.Total of 39 hours for Mast/Jib repairs. 00:00 02:30 2.50 0 0 MIRU MOVE RGRP P Continue to replace cable on PDL Winches/Bleed air out of Jib Boom swing cylinders 02:30 03:30 1.00 0 0 MIRU MOVE RGRP P PJSM, Raise Mast, Perform mast zonal inspection 03:30 05:00 1.50 0 0 MIRU MOVE RGRP P Secure PLD cables to winches 05:00 12:00 7.00 0 0 MIRU MOVE RGRP P Replace B4 valves and P/U drillers side PDL.Crew change PJSM. Total of 39 hours of Mast repairs. Page 1 of 24 lime Logs Date From To Dur. S. Depth E. Depth Phase Code' Subcode T Comment 12:00 16:30 4.50 0 0 MIRU WHDBO CTOP P ****RIG ACCEPT*** Prepare CT string for stabbing pipe.Start rigging up hardline in cellar&PUTZ.Change out 7"risers on rig floor for Big tool applications. Start loading fluid on pits. 16:30 18:00 1.50 0 0 MIRU WHDBO CTOP P Clean up rig floor and tools from maint.Set up to stab pipe. 18:00 22:00 4.00 0 0 MIRU WHDBO CTOP P Crew Change, PJSM stab coil, Install external coil connector. Pull test to 25K, Install boot on end of wire. Bring Koomy online,function test 22:00 00:00 2.00 0 MIRU WHDBO BOPE P PJSM, Fill Coil,Shut down and hammer up MP flange and 4 1/2 adapter flange 07/09/2011 Complete BOPE Test, Pull BPV, Cut 95'coil to find wire M/U Coil connector 00:00 01:30 1.50 0 0 MIRU WHDBO BOPE P Full BOPE/Plumbing shell test to 3500 Test and Chart Inner reel valve PJSM, Perform slack Mgmt 01:30 06:30 5.00 0 0 MIRU WHDBO BOPE P Start BOPE Test re-test C-9,C-10 06:30 11:00 4.50 0 0 MIRU WHDBO BOPE P Continue with BOP test. 11:00 14:00 3.00 0 0 MIRU WHDBO BOPE P Make up test bar for 3"rams&3.5 VBR's.Continue testing rams& annular.Secure bar with 3"combis for annular test.Secure bar with upper 2"combis for 3.5"VBR test. 14:00 14:30 0.50 0 0 MIRU WHDBO BOPE P Test bar slipped on 3.5"VBR while being held by upper 2"combis. P-test bar looked good other than slip marks, rams closed in correct spot. Re-test 2"combis and they leaked by-pull bar to inspect rams. 14:30 16:00 1.50 0 0 MIRU WHDBO SLPC P While tearing down 2"rams-start cutting coil to find cable. 95 ft trimmed. Meg cable. Inspected 2"PS-found the slip dies dulled but all components intact. 16:00 17:00 1.00 0 0 MIRU WHDBO BOPE T Smooth down slip marks P-test bar &pressure test 2". Leaking by, pull P-test bar and change out 2"bar. 17:00 18:00 1.00 0 0 MIRU WHDBO BOPE T Re-test 2"rams-Pass. BOPE Test complete 18:00 20:30 2.50 0 0 MIRU WHDBO BOPE P PJSM, R/U BPV Lubricator and pull BPV, Lay down and load out (lubricator WHP=800 PSI 20:30 22:30 2.00 0 0 SURPRI WELLPF SLPC P PJSM PT PDL,Tighten all slickline connections install No-Go Swage (Small tools). Choke B not holding, Enerpak guage issues Bleed well to zero/good no flo test 22:30 00:00 1.50 0 0 SURPRI WELLPF SLPC P PJSM, Install CTC connector for 2-3/8"PAC pin-end. Pull test to 38K Page 2 of 24 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07/10/2011 24 hr Summary Head up E-line and test, M/U Bighole Window milling BHA, Start milling window 00:00 01:45 1.75 0 0 SURPRI WELLPF SLPC P M/U E-Line connection to UQC and pressure test to 4K 01:45 02:15 0.50 0 0 SURPRI WELLPF SFTY P Pre Spud with night crew(Wheeler) 02:15 05:15 3.00 0 0 INTRM1 WHPST PULD P M/U BHA#1 with 3.80 Window Mill, 3.80 String Reamer,2 7/8 Extreme motor AKO 0.6, 30'Joint PH-6. Surface test tool 05:15 05:45 0.50 0 311 INTRMI WHPST TRIP P RIH , EDC Open, Displace well to seawater 05:45 07:45 2.00 311 0 INTRMI WHPST RGRP T Gooseneck roller has flat spot above BHI counter. POOH to surface to change out roller. 07:45 10:15 2.50 0 5,956 INTRM1 WHPST TRIP P tag up-zero counter. RIH.-inspect injector pipe @ 800'-good. RIH taking returns to tiger tank. Pumping SW. IA 20/OA 426. 10:15 11:15 1.00 5,956 6,020 INTRM1 WHPST CIRC P Tie in+14 ft&swap well to milling fluid.Shut in&close EDC.Good 1:1 returns during B/U. 11:15 11:45 0.50 6,020 6,020 INTRM1 WHPST SFTY P Hold pre-spud with Gary's crew. 11:45 12:30 0.75 6,020 6,045 INTRM1 WHPST MILL P Weight check-32K. RIH dry tag @ 6041ft. P/U to 6020'Bring pumps up to 2 bpm-free spin 2980 psi. Start seeing WOB @ 6041.4-light motor work,possible cement.Starting to gain more WOB @ 6044',more motor work.Call Pinch point @ 6045.1 12:30 16:30 4.00 6,045 6,048 INTRM1 WHPST MILL P Start time milling from 6045'2.0 bpm, 3130 psi, BHP 3050,WOB 1K, CT weight 14K. Set on auto drill @ 6046.2' 1fph.WOB 2.5K. Metal shavings over shaker. 16:30 20:30 4.00 6,048 6,045 INTRM1 WHPST MILL P Started exiting window.2 bpm,3120, BHP 3050,WOB 2.1K, ROP 1.1fph. 20:30 23:45 3.25 6,045 6,059 INTRM1 WHPST MILL P 6053.2', call BOW/Exit,continue time milling per program, 1 FPH-2 FPH @ 6054 1.92 BPM @ 2943 PSI FS, BHP=3048 23:45 00:00 0.25 6,059 6,059 INTRMI WHPST MILL P Start milling Rathole, 1.92 BPM @ 2950, BHP=3054 07/11/2011 Complete window, P/U Bighole BHA, Drill Ahead. 3.80"window=TOWS 6043'/TOW 6044'/BOW 6054'/RA 6056' 00:00 00:45 0.75 6,059 6,071 INTRMI WHPST MILL P Milling Rat Hole 00:45 02:21 1.60 6,071 6,071 INTRM1 WHPST REAM P Back ream window, Small gas bubble to surface. Bring WHP up to 150 PSI 1.96 BPM @ 2986 PSI FS. BHP=3060, 9.9 ppg EMW. All passes clean. Dry run through window Page 3 of 24 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02:21 02:57 0.60 6,071 6,032 INTRM1 WHPST OWFF P PUH to 6032,Shut down and observe well Initial shut in BHP=3167,WHP=145 BHP Up to 3406 psi(11.0 ppg EMW) after 30 Min,SIWHP=620 PSI 02:57 03:09 0.20 6,032 6,032 INTRM1 WHPST CIRC P Bled down to 350 WHP-Shut in right back up to 550 and climbing. Open EDC,Make high vis spacer prep to Kill well 03:09 03:27 0.30 6,032 6,025 INTRM1 WHPST CIRC P Pump Hi vis 9.2 PPG Spacer 20 BBIs followed by 11.5 KWF 03:27 05:15 1.80 6,023 6,023 INTRMI WHPST OWFF P KWF around, Shut down pump and observe for flow. 18 bbl losses (interface). 05:15 06:15 1.00 6,023 6,023 INTRMI WHPST CIRC P Start with KWF around Ann 3518/ WHP 30 Crew change Stop circulating. Ann 3510/WHP 20/IA 0/OA 200 06:15 08:15 2.00 6,023 6,023 INTRM1 WHPST CIRC P Circ 11.5 KWF at 2 bpm while setting up pweightup to to 12.0#. Shut in. No losses. Start Ann 3517/WHP 38 Stop Ann 3508/WHP 22 IA 0/OA 190 08:15 09:15 1.00 6,023 6,023 INTRM1 WHPST CIRC P Start pumping 12#KWF holding BHP to 3670psi.Choke wide open while circulating(80 bbls)Ann 3711 psi. 100 bbls pumped with 12#KWF all around @ 2bpm. Weighed up additional returns to 12# 09:15 10:15 1.00 6,023 6,023 INTRM1 WHPST OWFF P Start Shut in Static=BHP 3641 / WHP 21 /Choke 0 psi./IA 0/OA 194. 15 minutes-no change. Do a no-flow test 20 minutes-WHP 15/ Choke 0/BHP 3630 psi. All good through choke&needle valve on surface riser. 10:15 12:00 1.75 6,023 104 INTRMI WHPST TRIP P POOH pumping KWF,following kill schedule. 12:00 13:30 1.50 104 0 INTRM1 WHPST PULD P Bump up-No-flow check&PJSM for laying down BHA. Fluid level static- lay down milling BHA.Mill-3.79"go 3.78"no-go.Close swab valves. 13:30 15:30 2.00 0 0 INTRM1 WHPST PULD P Break down BHA#1 &Make up build section BHA#2. 15:30 16:30 1.00 0 82 INTRMI DRILL PULD P P/U build BHA#2 with 3.1 AKO& 3.75"x 4-1/8"Hughes Bi-center. Difficult time getting it past tree. 16:30 16:45 0.25 82 82 INTRM1 DRILL TRIP T RIH with EDC closed pumping Min. rate.-Tool failure Start BHI NPT 16:45 19:30 2.75 82 82 INTRMI DRILL PULD T PJSM-Lay down BHA/Trouble shoot BHA Failure/Make repairs Stab on and surface test tool-Pass End BHI NPT Page 4 of 24 Time Logs Date From To Dur S.Depth--E. Depth Phase Code Subcode T Comment 19:30 21:15 1.75 82 5,969 INTRM1 DRILL TRIP P RIH EDC closed on 12.0 ppg KWF, BHA#3, 3.1 degree motor and Bi-center 21:15 21:21 0.10 5,969 5,697 INTRM1 DRILL DLOG P Gamma tie in for+21.5 21:21 21:27 0.10 5,697 6,021 INTRMI DRILL TRIP P RIH to top of window to displace well to 9.6 flo pro mud 21:27 23:27 2.00 6,021 6,021 INTRM1 DRILL CIRC P Open EDC pump 20 BBI Hi vis spacer followed by new 9.6 Flo Pro, Experienced choke B problems when spacer hit. Nothing unexpected on shaker. Close EDC and RIH to drill 23:27 23:45 0.30 6,021 6,071 INTRM1 DRILL TRIP P Trip in to drill,clean pass through window 23:45 00:00 0.25 6,071 6,087 INTRM1 DRILL DRLG P 6071', Drill Ahead, 1.9 BPM @ 3420 PSI FS,WHP=350, BHP=3595 Midnight 6087 07/12/2011 Drilled 4 1/8"hole to TD at 6390', long wiper trips to surface, killed well with 12.0 PPG 00:00 05:30 5.50 6,087 6,230 INTRM1 DRILL DRLG P Drill Ahead, BHP=3650, 1.93 BPM @ 3490PSI FS.WOB 4K. 05:30 07:00 1.50 6,230 6,230 INTRMI DRILL WPRT P Wiper trip P/U weight 25K-with window tie in.-.5ft correction. Window RA marker @ 6056'& MADD pass. TOWS-6043' TOW-6044' BOW-6054' RA-6056' 07:00 08:45 1.75 6,230 6,283 INTRMI DRILL DRLG P Drilling ahead-2.0 BPM,3600, BHP 3650, ECD 11.8, ROP 20,WOB 3.8K,CT weight 11K 08:45 09:00 0.25 6,283 6,283 INTRM1 DRILL WPRT P Started losing CT weight-weight check-pulling heavy 44K then broke over. BHA wiper. 09:00 12:15 3.25 6,283 6,390 INTRM1 DRILL DRLG P Drill ahead 12:15 12:30 0.25 6,390 6,390 INTRM1 DRILL WPRT P 6390',TD Intermediate hole. Recip up hole pump Lo-Hi vis sweeps PUW=25K, BHP3690 12:30 15:30 3.00 6,390 82 INTRMI DRILL WPRT P Lo-Hi sweep at nozzle, Chase sweep to swab at 2.0 bpm Open EDC above window (3.1 degree motor), maintain 2.0 bpm. Reset counters to BHA, RBIH to lay in beaded liner pilll 15:30 16:30 1.00 82 2,000 INTRM1 DRILL WPRT P Continue in hole, @ 2000'RIH started getting heavy cuttings across shaker. Choke plugging off. Swap to choke A,still have choke plugging and shales across shaker 16:30 18:36 2.10 2,000 5,960 INTRM1 DRILL WPRT P 3275',tag up in GLM. PUH Shut EDC. Pass through GLM @ Min Rate,continue to RIH 18:36 18:48 0.20 5,960 6,000 INTRM1 DRILL DLOG P Tie-in, +17' 18:48 19:12 0.40 6,000 6,390 INTRM1 DRILL WPRT P Continue RIH, pump low/high vis sweeps Page 5of24 Time Logs Date From To Dur S. Death E. Depth Phase Code : Subcode T Comment 19:12 21:12 2.00 6,390 0 INTRM1 DRILL WPRT P POOH chasing sweeps. Above window, open EDC and increase rate to 2.4 bpm,4040 psi pump pressure. 21:12 22:54 1.70 0 5,960 INTRM1 DRILL WPRT P Tag stripper and RIH 22:54 23:06 0.20 5,960 6,000 INTRM1 DRILL DLOG P Tie-in, +18'. Close EDC. 23:06 23:24 0.30 6,000 6,390 INTRM1 DRILL WPRT P Continue RIH, pump liner running pill. 23:24 00:00 0.60 6,390 5,700 INTRMI DRILL DISP P POOH laying in liner running pill, 07/13/2011 PU and ran intermediate liner to TD. Blow down coil and star reel swap for cement job 00:00 01:48 1.80 5,700 0 INTRM1 DRILL DISP P Continue POOH, laying in KWF, paint EOP flags at 5200'EOP and 4900'EOP 01:48 02:00 0.20 0 0 INTRM1 DRILL SFTY P Flow check, PJSM for laying down BHA 02:00 02:54 0.90 0 0 INTRM1 DRILL PULD P Lay down drilling BHA, maintain injector 02:54 03:12 0.30 0 0 INTRM1 CASING SFTY P PJSM 03:12 03:54 0.70 0 0 INTRM1 CASING PUTB P Rig up for liner operations 03:54 06:00 2.10 0 0 INTRM1 CASING PUTB P Start PU 3-1/4"&3-1/2"liner, cleaning all threads and Baker locking the bottom 5 joints. 06:00 10:30 4.50 0 0 INTRMI CASING PUTB P Crew change,continue making up intermediate string 10:30 12:30 2.00 0 1,056 INTRM1 CASING RUNL P Liner in well. PJSM. Make up CoilTrack to Liner,Surface test, Strip onto well, Fill Liner,-7.4 BBIs,Tag up and record. 12:30 15:24 2.90 1,056 5,930 INTRM1 CASING RUNL P Trip in well per program 15:24 15:54 0.50 5,930 5,956 INTRM1 CASING RUNL P Stop at 5929.8.Correct to flag 5955.9'. +26.1, PUW=28K, RIW=20K Pumps online @.25BPM 15:54 16:09 0.25 5,956 6,395 INTRM1 CASING RUNL P 6395', Set down,-6K, PUW=32k, Set back down and circulate bottoms up 1.6 BPM @ 2360 16:09 17:15 1.10 6,395 6,395 INTRM1 CASING CIRC P Circulate bottoms up,get up to 1.75 BPM. At bottoms up got another slug of cuttings that plugged the choke. Cleared out, continued circulating. 17:15 18:42 1.45 6,395 0 INTRM1 CASING TRIP P Release from liner,2.2BPM @ 4K. PUW=22K. TOL=5381', BOL= 6390'. 18:42 19:42 1.00 0 0 INTRM1 CASING PULD P Lay down liner running BHA 19:42 22:06 2.40 0 0 INTRMI CEMEN"CTOP P Circulate out KWF from reel with corrosion inhibitor and fresh water. Blow down coil with rig air. 22:06 00:00 1.90 0 0 INTRMI CEMEN"CTOP P Cut off CTC and install grapple, un-stab coil from injector and secure to reel Page 6 of 24 Time Logs Date ` From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/14/2011 24 hr summary Completed reel swap, PU cementing BHA and RIH,stab into liner top. Pump 9 Bbls 15.8 ppg cement. Bump wiper at correct displacement. Cirulate out excess cement. 00:00 01:30 1.50 0 0 INTRM1 CEMEN"CTOP P Continue with securing reel and removing from rig 01:30 01:48 0.30 0 0 INTRMI CEMEN"SFTY P PJSM with Peak for reel swap 01:48 05:00 3.20 0 0 INTRM1 CEMEN"CTOP P Continue with reel swap to e-free coil. 05:00 08:30 3.50 0 0 INTRM1 CEMEN"CTOP P Install inner reel iron,shim reel, install counters,dress coil for external CTC 08:30 10:00 1.50 0 0 INTRM1 CEMEN"CTOP P PJSM, Install CTC, Pull Test, Fill coil with KWF, Run Volume dart, Pressure test CTC and Inner reel iron. 10:00 11:00 1.00 0 0 INTRM1 CEMEMCIRC P PJSM, Launch Vol. Data dart and pump 5 BBIs,Open back up and confirm dart gone, Data Dart coil vol. 33.1 bbls 11:00 12:30 1.50 0 50 INTRM1 CEMEN"PULD P PJSM-M/U Cementing BHA 12:30 14:00 1.50 50 5,200 INTRM1 CEMEMTRIP P Trip in with BHA#5, Cementing BHA with CTLRT, Make+18'correction 14:00 14:45 0.75 5,200 5,405 INTRMI CEMEN-CIRC P Bring pumps on @.5 BPM @410 PSI 1 for 1, Bring rate up to.75 BPM @ 650PSI PUW=23K, RIW=16K 14:45 15:03 0.30 5,405 5,405 INTRM1 CEMEN"CIRC P See pressure increase of 50PSI @ 5405 ft.Still at 1 for 1 returns. Set down @ 5409. PUH to 28K confirm latch 15:03 15:57 0.90 5,405 5,405 INTRM1 CEMEN'CIRC P Launch 5/8"steel ball to release CTLRT, 1.9 BPM @ 2930 psi. 27.5 BBIs Ball On seat, Shear set @ 3400 PSI Batch up cement 15:57 16:12 0.25 5,405 5,405 INTRM1 CEMEN"CMNT P Batch cement @ 15:45hrs. S/D Pump and line up to cementers. Lead off with 5 Bbl 12.0 ppg Mud push 16:12 16:42 0.50 5,405 5,405 INTRM1 CEMEN"CMNT P PT Cementer to 4K, Pump 5 Bbl Mud Push, Followed by 9 Bbl 15.8 PPG Cement. Shut down and launch peewee dart. Pump 3 BBIs KCI Spacer,Shut down and confirm dart gone. 16:42 17:24 0.70 5,405 5,405 INTRM1 CEMEN"CMNT P Wiper dart hit @ 33.3 bbl. Sheared out @ 3500 PSI, reset out-flow micromotion. Bumped liner wiper @ 50.14 bbl, 1-for-1 returns with cement coming around pipe 17:24 19:36 2.20 5,405 0 INTRM1 CEMEN"CIRC P POOH contaminating cement with 12.0 ppg fluid with 1 ppb Biozan 19:36 19:54 0.30 0 0 INTRM1 CEMEN"SFTY P PJSM for laying down BHA 19:54 20:54 1.00 0 0 INTRMI CEMEN"PULD P Lay down BHA Page 7 of 24 Time Logs Date From To, Dur S.Depth E.Depth Phase Code Subcode T Comment 20:54 00:00 3.10 0 0 INTRM1 CEMEN"BOPE P Flush stack, blow down BOP stack and change out deployment rams. Install 2-3/8"combi rams. 07/15/2011 Change out BOP deployment rams and test. Change out coiled tubing reels. MU milling BHA to mill out shoe and RIH 00:00 01:12 1.20 0 0 INTRM1 CEMEN"BOPE P Continue deployment ram change out. 01:12 02:12 1.00 0 0 INTRMI CEMEN-BOPE P Test upper and lower 2 3/8" deployment rams to 250 and 3500 PSI. 02:12 02:48 0.60 0 0 INTRM1 CEMEN"PRTS P Test cement to 500 WHP. Pressure stabilized at 479 psi after three minutes. Held for 15 minutes.Good test, bled down to zero and check for no flow,good. 02:48 04:18 1.50 0 0 INTRM1 CEMEN"CTOP P Rig up for circulating and blow down. Circulate corrosion inhibitor and displace with fresh water. 04:18 04:42 0.40 0 0 INTRMI CEMEN"SFTY P PJSM with SLB pumping crew 04:42 05:57 1.25 0 0 INTRM1 CEMEN"CTOP P Blow down e-free coil with N2 05:57 08:57 3.00 0 0 INTRM1 CEMEN"CTOP P Cut 20'coil, R/D inner reel iron, Prep coil to install grapple, remove King Pin 08:57 10:57 2.00 0 0 INTRM1 CEMEN"CTOP P Unstab coil,secure to reel, R/U slings to reel 10:57 11:27 0.50 0 0 PROD1 WHPST SFTY P Pre tower/pre job with Peak to swap reels 11:27 14:27 3.00 0 0 PROD1 WHPST CTOP P Swap reels/clean Bombay doors, Prep grapple for install 14:27 15:27 1.00 0 0 PROD1 WHPST CTOP P Make up Inner reel iron, Pressure bulk head, Install grapple 15:27 16:27 1.00 0 0 PROD1 WHPST CTOP P Pull test grapple and re tighten, Remove chain,pull coil through injector, R/D stabbing gear 16:27 18:48 2.35 0 0 PROD1 WHPST CTOP P Trim Coil,Test wire,good test, Dress coil for connector, install Kendle CTC, pull test. 18:48 20:48 2.00 0 0 PROD1 WHPST PULD P MU upper QC and PT to 4000 psi 20:48 21:06 0.30 0 0 PROD1 WHPST SFTY P PJSM 21:06 22:06 1.00 0 0 PROD1 WHPST PULD P MU BHA#8 for milling out shoe& cement 22:06 22:36 0.50 0 0 PROD1 WHPST TRIP P RIH,at 375'pressured up WH and coil due to closed valve on return side. During this pressure up at about 1500 PSI coil pressure the coiltrac tools stopped working,short 22:36 23:12 0.60 0 0 PROD1 WHPST TRIP T POOH,change flow sub in upper QC to fix short,test Coiltrac tools 23:12 00:00 0.80 0 3,200 PROD1 WHPST TRIP P RIH 07/16/2011 Milled out float equipement,shoe and 8'of formation. Function test BOP equipment. 00:00 00:45 0.75 3,200 5,970 PROD1 WHPST TRIP P Continue RIH 00:45 00:57 0.20 5,970 6,000 PROD1 WHPST DLOG P Tie in to K1 marker Page 8 of 24 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:57 05:12 4.25 6,000 5,950 PROD1 WHPST TRIP T During the disscussion of milling realized wrong mill had been run. RIH and tag float equipment at 6369'. POOH,change out mills and RIH. D331 2.73 Go/2.72 no-go. String reamer is 2.74 go/2.73 no-go 05:12 05:24 0.20 5,950 5,978 PROD1 WHPST DLOG T 5950-5978 Tie into K1 Marker for +14, RIH 05:24 05:30 0.10 5,978 6,059 PROD1 WHPST DLOG T Trip in, Log RA Marker in whipstock. On depth @ 6056' 05:30 05:39 0.15 6,059 6,338 PROD1 WHPST TRIP T Continue in well 05:39 09:03 3.40 6,338 6,370 PROD1 WHPST MILL P Mill light cement,Swap well to used 9.6 ppg Ho Pro 09:03 11:45 2.70 6,370 6,380 PROD1 WHPST MILL P Pulled heavy on Landing collar,49K, Multiple stalls,Tagging high, looks like rubber.Tap down with pumps off. Continue to work area,get through mill down to top of shoe @ 6380'. 1.42 BPM @ 2750 PSI FS 11:45 13:00 1.25 6,380 6,380 PROD1 WHPST CIRC P Circulate bottoms up before continuing through float collar 13:00 15:30 2.50 6,380 6,391 PROD1 WHPST MILL P Mill Float collar and cement to shoe 15:30 16:42 1.20 6,391 5,950 PROD1 WHPST WPRT P Perform Bottoms up/ Wiper trip before milling through shoe. PUH to 5453', PUW=26K. 16:42 16:54 0.20 5,950 5,979 PROD1 WHPST DLOG P Tie into K-1 for-3.5'correction, RIH to drill shoe 16:54 17:18 0.40 5,979 6,389 PROD1 WHPST WPRT P Trip in to mill shoe 17:18 18:42 1.40 6,397 6,399 PROD1 WHPST MILL P Mill Shoe, 1.43 BPM @ 2725 PSI FS 18:42 19:54 1.20 6,399 5,400 PROD1 WHPST CIRC P Pump low and high vis sweeps,two sets while reciprocating in liner and CBU 19:54 21:24 1.50 5,400 0 PROD1 WHPST TRIP P Check well for flow/BHP. No-flow. POOH 21:24 21:42 0.30 0 0 PROD1 WHPST SFTY P PJSM 21:42 22:42 1.00 0 0 PROD1 WHPST PULD P Lay down milling BHA. D331 mill 2.71 go/2.70 no-go. String reamer 2.74 Go/2.73 no-go 22:42 23:12 0.50 0 0 PROD1 WHPST BOPE P Function test BOP 23:12 23:24 0.20 0 0 PROD1 DRILL SFTY P PJSM 23:24 00:00 0.60 0 0 PROD1 DRILL PULD P PU drilling BHA#9 with RSM and USR, rebuilt HCC bicenter bit 07/17/2011 Drilled lateral from 6398'to 7432'. 00:00 00:18 0.30 0 0 PROD1 DRILL PULD P Continue PU drilling BHA with HCC bicenter bit, RSM and USR 00:18 01:48 1.50 0 5,970 PROD1 DRILL TRIP P RIH 01:48 02:00 0.20 5,970 5,990 PROD1 DRILL DLOG P Tie-in, +13',20K PUW, 13K RIW 02:00 04:06 2.10 6,399 6,560 PROD1 DRILL DRLG P Tag at 6398'. Start drilling at 1.6 BPM, 3200 CTP, 3500 BHP. Page 9 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:06 04:36 0.50 6,560 6,560 PROD1 DRILL DLOG P Wiper to window,20K PUW, MAD pass from 6450'-6410'for resisitivity that was missed initially(McAnnely Moment) 04:36 05:06 0.50 6,560 6,610 PROD1 DRILL DRLG P Continue drilling, 1.67 BPM,3450 CTP,3530 BHP, 9K RIW 05:06 06:00 0.90 6,610 6,710 PROD1 DRILL DRLG P Continue drilling, 1.67 BPM, 3450 CTP,3530 BHP,9K RIW 06:00 06:30 0.50 6,710 6,710 PROD1 DRILL WPRT P Wiper to window(Shoe),20K PUW 06:30 09:00 2.50 6,710 6,860 PROD1 DRILL DRLG P 6710, Dril Ahead, 1.67 BPM @ 3250 PSI FS,WHP=150 09:00 09:36 0.60 6,860 6,067 PROD1 DRILL WPRT P 6860,Wiper trip with tie in, PUW=25K, 09:36 10:06 0.50 6,067 6,094 PROD1 DRILL DLOG P Tie into whipstock tag @ 6056 for a -4' correction, RIH to log Shoe RA. RA is at 6380.5', BO Intermediate L @ 6390.92',TO intermediate 5381' 10:06 10:30 0.40 6,094 6,860 PROD1 DRILL WPRT P RIH to drill, RIW=15K, BHP=3542 10:30 12:45 2.25 6,860 7,010 PROD1 DRILL DRLG P 6860', Drill Ahead, 1.7 BPM @ 3500 PSI FS, BHP=3656 12:45 13:30 0.75 7,010 7,010 PROD1 DRILL WPRT P Wiper to Shoe. PUW=32K 13:30 15:45 2.25 7,010 7,160 PROD1 DRILL DRLG P 7010', Drill Ahead, 1.7 BPM @ 3430 PSI FS, BHP=3650 15:45 17:39 1.90 7,160 7,160 PROD1 DRILL WPRT T 7160',Wipe to Shoe, PUW=26K, BHP=3660,with sweeps Set down @ 7135, Pass through and set down @ 7148 and stall S/D Pump.50 K not free. RIH to 0 lbs. Pop up off bottom. Bring pumps on still in stall. PUH and work free. Multiple attemts to work through with lessing pump rates. Only 12'off bottom, Ream down and stall at full rate.Work through and PUH at 1.6BPM. Stall going up past 7148. Work till pass through clean 17:39 19:30 1.85 7,160 7,310 PROD1 DRILL DRLG P 7160, Drill ahead, 1.64 BPM @ 3360 FS, BHP 3710 with 75 PSI WHP. 1 for 1 returns 19:30 21:12 1.70 7,310 6,070 PROD1 DRILL WPRT P Pump sweeps,wiper to the top of 3-1/2"liner,23K PUW,open EDC in cased hole, pump sweeps and CBU at 2.45 BPM. Did not observe any significant increase in cuttings. 21:12 21:24 0.20 6,070 6,430 PROD1 DRILL DLOG P Tie in to upper RA and RA in float collar 21:24 22:12 0.80 6,430 7,310 PROD1 DRILL WPRT P Wiper back in hole,tag and stall at 6890',work past. Tag and stall at 7105', reduce rate and work past. 22:12 00:00 1.80 7,310 7,432 PROD1 DRILL DRLG P Continue drilling, 1.68 BPM, 3400 CTP,3700 BHP, 13K RIW 07/18/2011 Drilled lateral o 7610'. Hole instability causing difficulty during wiper trips. Set anchored aluminum billet at 6610'. 00:00 00:24 0.40 7,432 7,460 PROD1 DRILL DRLG P Continue drilling, 1.68 BPM, 3400 CTP,3700 BHP, 13K RIW Page 10 of 24 • Time togs Date From To Dur S.Death'`E.Depth Phase. Code Subcode T Comment 00:24 01:54 1.50 7,460 7,460 PROD1 DRILL WPRT P Wiper to the shoe,22K PUW, 13K RiW. Saw weight and motor work at 7148'up and down 01:54 03:18 1.40 7,460 7,610 PROD1 DRILL DRLG P Continue drilling, 1.70 BPM,3450 CTP, 3700 BHP, 13K RIW 03:18 05:06 1.80 7,610 7,340 PROD1 DRILL WPRT P Wiper to the window chasing low/high vis sweeps,over pull and may be packing off coming up through 7148'. Tripping in hole started to work down through 7148' then started packing off above while at 7340' PUH pumping sweeps. 05:06 06:54 1.80 7,340 5,304 PROD1 DRILL WPRT P Wiper to liner top of liner,Open EDC, circ volume @ 2.2 BPM. No significant increase in cuttings over shakers. 06:54 07:54 1.00 5,304 6,390 PROD1 DRILL WPRT P RIH to shoe,Close EDC 07:54 08:42 0.80 6,390 7,100 PROD1 DRILL WPRT P Continue Running in,start new 9.8 ppg mud down coil 08:42 09:09 0.45 7,100 7,125 PROD1 DRILL WPRT P Work pipe trough tight spots 7100 to 7148.trying to maintain pump rate going down.Set downs at 7111, 7113,7123. Get through down to 7148. PUH and bring pumps on 1.7 BPM to clear up area. Hang up and pack off 7125'. Unable to go up or down. Low returns to surface. 09:09 09:33 0.40 7,125 7,125 PROD1 DRILL WPRT T Stuck and packed off @ 7125, Lower pump rate and WHP to estabish circulation, regain returns.Work pipe -3K to 56K, pull free 09:33 12:51 3.30 7,125 117 PROD1 DRILL TRIP T Trip out of hole following MP schedule, Open EDC @ 6388'.Well unloaded fine shaley material—3500' from surface.Sample to geo not same material as before, perform. Jog at surface 12:51 15:15 2.40 117 0 PROD1 DRILL PULD T PJSM LD BHA#9, Blow down and lay down 15:15 16:30 1.25 0 0 PROD2 STK PULD T Waiting on anchored open hole billet. Decision made to plugback due to unstable shale at fault crossing. 16:30 18:00 1.50 0 0 PROD2 STK PULD T BOT Here,Set up Billet for a 30L well bore exit 18:00 18:30 0.50 0 0 PROD2 STK SFTY T PJSM, crew changeout,valve checklist... 18:30 20:24 1.90 0 0 PROD2 STK PULD T Deploy anchored billet BHA 20:24 21:48 1.40 0 5,950 PROD2 STK TRIP T RIH 21:48 22:00 0.20 5,950 5,975 PROD2 STK DLOG T Tie in, +13' 22:00 22:18 0.30 5,975 6,621 PROD2 STK TRIP T Continue RIH, Close EDC at 6380', 22K PUW, 15K RIW 22:18 00:00 1.70 6,621 0 PROD2 STK TRIP T Set anchor at 5R,top of billet at 6610'. 4K WOB after setting. POOH circulating at 1 BPM, following MPD tripping schedule Page 11 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/19/2011 24 hr Summary Deploy drilling BHA(1 deg AKO with Bi-Center). Sidetrack off billet 6611'to 6615'drilling lateral to 7492'. Pump low/high sweeps after 150'drilled. Every 3rd wiper open EDC pumping low/high sweeps above liner top. 00:00 03:24 3.40 0 0 PROD2 STK PULD T Undeploy billet setting BHA,deploy drilling BHA with 1 deg. motor and Bi-center bit 03:24 05:00 1.60 0 5,980 PROD2 STK TRIP T RIH 05:00 05:06 0.10 5,960 5,987 PROD2 STK DLOG T Tie in for+18'correction 05:06 05:24 0.30 5,987 6,611 PROD2 STK TRIP T RIH,Shut EDC @6300, Dry tag billet @ 6611 05:24 07:24 2.00 6,611 6,615 PROD2 STK KOST T Begin milling billet, 1.66 BPM @ 3378 PSI FS, RIW=14.2, BHP=3495 07:24 08:24 1.00 6,615 6,640 PROD2 STK KOST T Begin drilling 15 FPH, 1.66 BPM @ 3370PS1, BHP=3520 08:24 08:30 0.10 6,640 6,640 PROD2 DRILL DRLG T 6640,drilled 20'rathole,wiper past billet, PUW=23K,all good past billet 08:30 10:06 1.60 6,640 6,790 PROD2 DRILL DRLG T 6640', Drill Ahead, 1.66 BPM @ 3370 PSI FS, BHP=3605 10:06 10:06 0.00 6,790 6,790 PROD2 DRILL WPRT T Wiper to window,23K PUW, 14K RIW 10:06 12:06 2.00 6,790 6,940 PROD2 DRILL DRLG T Continue drilling, 1.64 BPM, 3300 CTP,3630 BHP with 140 WHP. 12:06 12:48 0.70 6,940 6,940 PROD2 DRILL WPRT T Wiper to window,23K PUW 12:48 14:54 2.10 6,940 7,090 PROD2 DRILL DRLG T Continue Drilling, 1.65 BPM,3400 CTP,3670 BHP,90 WHP 14:54 17:09 2.25 7,090 7,090 PROD2 DRILL WPRT T Wiper to top of liner,then back to tie-in.-6'correction. 23K PUW, 14K RIW 17:09 19:39 2.50 7,090 7,240 PROD2 DRILL DRLG T Continue drilling. Raised target ECD at window from 11.5 ppg to 12.0 ppg by increasing choke pressure to 210 psi. 1.63 BPM,3600 CTP, 3770 BHP. 19:39 20:39 1.00 7,240 7,240 PROD2 DRILL WPRT T Wiper trip to window 21.5K PUW. PU above liner top open EDC.Circ. low/high vis pill. 20:39 22:39 2.00 7,240 7,390 PROD2 DRILL DRLG T Continue drilling, 1.63 BPM, 3700 CTP,3860 BHP with 210 WHP 22:39 23:54 1.25 7,390 7,390 PROD2 DRILL WPRT T Wiper trip to window,21.5k PUW 23:54 00:00 0.10 7,390 7,492 PROD2 DRILL DRLG T Continue drilling, 1.63 BPM, 3850 CTP,3910 BHP with 210 WHP 07/20/2011 TD lateral 8140'. Perform wiper trip to swab valves. RBIH to TD.POOH, Laying in liner running pill, KWF to surface. 00:00 00:30 0.50 7,492 7,540 PROD2 DRILL DRLG T Continue drilling, 1.63 BPM, 3850 CTP,3910 BHP with 210 WHP 00:30 03:00 2.50 7,540 7,540 PROD2 DRILL WPRT T Wiper trip to window,21K PUW, Pump low/hi sweeps, PU to TOL pumping low/high sweeps through EDC 1.8 BPM. RBIH,Tag up 7130'. PUH 23K. Reduce pump rate to minmum rate. RIH 03:00 03:30 0.50 7,540 7,610 PROD2 DRILL DRLG T Continue drilling, 1.63 BPM, 3850 CTP,3910 BHP with 210 WHP, 03:30 04:30 1.00 7,610 7,690 PROD2 DRILL DRLG P Back on Planned Time Page 12 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:00 1.50 7,690 7,690 PROD2 DRILL WPRT P Wiper trip back to window 21K PUW, 14K RIW,stacked weight at 7130', lowered pump rate and drifted clean 06:00 07:24 1.40 7,690 7,840 PROD2 DRILL DRLG P Continue driling, 1.6 BPM,3600 CTP,3850 BHP,200 WHP 07:24 09:12 1.80 7,840 7,840 PROD2 DRILL WPRT P Pump sweeps and wiper to shoe, 23K PUW, 13K RIW. Lowered pump rate while RIH from 7100'with no set downs or motor work. 09:12 10:48 1.60 7,840 7,990 PROD2 DRILL DRLG P Continue driling, 1.64 BPM,3620 CTP,3850 BHP,200 WHP 10:48 12:06 1.30 7,990 6,400 PROD2 DRILL WPRT P Wiper to window,23K PUW 12:06 12:18 0.20 6,400 6,425 PROD2 DRILL DLOG P Tie-in,-6' 12:18 13:06 0.80 6,425 7,990 PROD2 DRILL WPRT P Wiper back in hole, 14K RIW 13:06 15:12 2.10 7,990 8,140 PROD2 DRILL DRLG P Continue drilling, 1.65 BPM, 3800 CTP, 3920 BHP with 200 WHP, 15:12 18:27 3.25 8,140 8,140 PROD2 DRILL WPRT P Pump sweeps and wiper to swab valve 18:27 19:27 1.00 0 5,950 PROD2 DRILL WPRT P RBIH 19:27 19:42 0.25 5,950 5,950 PROD2 DRILL DLOG P Tie in depth-15'correction 19:42 21:57 2.25 5,950 8,140 PROD2 DRILL WPRT P RIH 21:57 00:00 2.05 8,140 PROD2 DRILL TRIP P POOH laying in liner running pill. (KWF with beads). KWF to surface Paint EOP flags at 6400'and 4600'. 07/21/2011 PU/MU liner. RIH setting on depth 8130'. POOH. BOPE testing. (State Witnessed by:Chuck Scheve) 00:00 01:00 1.00 PROD2 DRILL TRIP P POOH 01:00 01:15 0.25 PROD2 DRILL SFTY P At surface, Flow check, PJSM 01:15 01:45 0.50 PROD2 DRILL PULD P LD drilling BHA 01:45 02:15 0.50 COMPZ CASING PUTB P Prep floor to MU liner 02:15 04:00 1.75 COMPZ CASING PUTB P PU/Mu 2-3/8"slotted Liner 04:00 06:00 2.00 COMPZ CASING PULD T Wait on BOT.Stuck behind rig move. 06:00 06:30 0.50 COMPZ CASING SFTY P Crew change, PJSM 06:30 07:54 1.40 0 1,661 COMPZ CASING PULD P MU anchored billet and coiltrack tools 07:54 10:36 2.70 1,661 8,162 COMPZ CASING RUNL P RIH with liner string,correct at flag, -33'correction. Weight check 26K PUW, 18K RIW,-5K WOB 10:36 10:54 0.30 8,162 8,152 COMPZ CASING RUNL P Tag bottom, PUH 34K PUW, RBIH to setting depth at 8152'(10'off bottom to put billet at 6530'), 15K and 1.6 WOB. Pump at.3 BPM,3800 CTP set anchor at 20L, 7K WOB. TOL=6539', BOL=7139'MD(final). 10:54 12:54 2.00 8,152 0 COMPZ CASING TRIP P POOH,25K PUW, reset depth when in cased hole 12:54 14:30 1.60 0 0 COMPZ CASING PULD P Lay down liner running tools. Page 13 of 24 Time;Logs Date From To Dur S. Depth`-E. Depth Phase Code ` Subcode T Comment 14:30 15:00 0.50 0 0 PROD3 STK SFTY P PJSM for BOP testing 15:00 00:00 9.00 0 PROD3 STK BOPE P Start BOPE testing State Witnessed By:Chuck Scheve 07/22/2011 Complete BOPE testing(0 failures). PU/MU/RIH drilling BHA.Sidetrack CL1 lateral off billet at 6539'. Drill CL1 lateral to 7470'. Every 3rd wiper open EDC in cased hole pumping low/high sweeps, PUH above liner top. 00:00 01:00 1.00 0 0 PROD3 STK BOPE P Bop testing complete. (0 Failures) 01:00 02:00 1.00 0 0 PROD3 STK SVRG P LD test joint,service Bowen connections on stack, install check valves 02:00 03:00 1.00 0 0 PROD3 STK PULD P PU/MU drilling BHA 03:00 04:15 1.25 72 5,950 PROD3 STK TRIP P RIH 04:15 04:30 0.25 5,950 5,950 PROD3 STK DLOG P Tie in depth, +8'correction 04:30 05:00 0.50 5,950 6,539 PROD3 STK TRIP P RIH 05:00 06:00 1.00 6,539 6,539 PROD3 STK CIRC P Displace KWF with new 10.3 PPG Flo-Pro mud. Increased mud weight to try to eliminate choke pressure during drilling. 06:00 08:30 2.50 6,539 6,570 PROD3 STK KOST P Tag billet at 6539.16'and start time milling, 1.62 BPM, 3300 CTP, 3740 BHP with 200 WHP, 14K RIW. Drift past billet with pump down. 08:30 10:42 2.20 6,570 6,720 PROD3 DRILL DRLG P Continue drilling lateral, 1.7 BPM, 3450 CTP, 3760 BHP,200 WHP, 10:42 11:06 0.40 6,720 6,720 PROD3 DRILL WPRT P Wiper to the shoe,24K PUW, 14K RIW 11:06 12:18 1.20 6,720 6,870 PROD3 DRILL DRLG P Continue drilling, 1.7 BPM,3440 CTP, 3775 BHP,200 WHP 12:18 12:54 0.60 6,870 6,870 PROD3 DRILL WPRT P Wiper to the shoe,22K PUW, 14K RIW 12:54 14:12 1.30 6,870 7,020 PROD3 DRILL DRLG P Resume drilling, 1.7 BPM, 3480 CTP,3775 BHP,200 WHP 14:12 14:36 0.40 7,020 6,400 PROD3 DRILL WPRT P Wiper to shoe,22K PUW 14:36 14:48 0.20 6,400 6,430 PROD3 DRILL DLOG P Tie-in, -5' 14:48 15:06 0.30 6,430 7,020 PROD3 DRILL WPRT P Wiper back in hole, 13K RIW 15:06 17:00 1.90 7,020 7,170 PROD3 DRILL DRLG P Continue drilling, 1.7 BPM, 3500 CTP, 3815 BHP,200 WHP 17:00 18:00 1.00 7,170 7,170 PROD3 DRILL WPRT P Pump low\high vis sweeps. Wiper to window,23K PUW 18:00 19:15 1.25 7,170 7,320 PROD3 DRILL DRLG P Continue drilling, 1.7 BPM,3600 CTP,3871 BHP, 190 WHP 19:15 20:15 1.00 7,320 7,320 PROD3 DRILL WPRT P Wiper trip to window 23K 20:15 21:45 1.50 7,320 7,470 PROD3 DRILL DRLG P Continue drilling, 1.7 BPM,3800 CTP,3893 BHP, 130 WHP 21:45 23:00 1.25 7,470 7,470 PROD3 DRILL WPRT P Wiper trip to window 23K 23:00 23:45 0.75 7,470 7,470 PROD3 DRILL CIRC P Open EDC at shoe, PUH to 5380' pump low/high sweeps circulating bottoms up. Page 14of24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode- T Comment 23:45 00:00 0.25 7,470 7,470 PROD3 DRILL DLOG P Tie in depth to RA marker.-11' correction 07/23/2011 TD CL1 Lateral 8220'.Wiper trip to swab valves. RBIH to TD,lay in liner running pill to window, KWF to surface. 00:00 00:45 0.75 7,470 7,470 PROD3 DRILL WPRT P RIH to drill 00:45 02:00 1.25 7,470 7,620 PROD3 DRILL DRLG P Continue drilling, 1.6 BPM,3770 CTP, 3888 BHP, 135 WHP,9K CTW 02:00 03:00 1.00 7,620 7,620 PROD3 DRILL WPRT P Wiper trip to window, pumped low/high sweeps 10 bbl each. 24K 03:00 05:18 2.30 7,620 7,770 PROD3 DRILL DRLG P Continue drilling, 1.6 BPM,3832 CTP, 3896 BHP, 150 WHP, 9K CTW 05:18 06:12 0.90 7,770 6,400 PROD3 DRILL WPRT P Wiper trip to window,23K PUW 06:12 06:24 0.20 6,403 6,423 PROD3 DRILL DLOG P Tie-in,-8' 06:24 07:06 0.70 6,423 7,770 PROD3 DRILL WPRT P Wiper back in hole, 13K RIW 07:06 08:12 1.10 7,770 7,920 PROD3 DRILL DRLG P Continue drilling, 1.7 BPM,3750 CTP,3880 BHP, 140 WHP 08:12 09:06 0.90 7,920 6,404 PROD3 DRILL WPRT P Wiper trip to window,22K PUW. Pump 5 low/5 high sweeps 09:06 09:18 0.20 6,404 6,425 PROD3 DRILL DLOG P Tie in,-5' 09:18 10:00 0.70 6,425 7,920 PROD3 DRILL WPRT P Wiper back in hole, 13K RIW 10:00 11:30 1.50 7,920 8,070 PROD3 DRILL DRLG P Continue drilling, 1.7 BPM,3800 CTP,3930 BHP, 100 WHP 11:30 12:30 1.00 8,070 6,400 PROD3 DRILL WPRT P Wiper trip to window,22K PUW. Pump 5 low/5 high sweeps 12:30 12:42 0.20 6,400 6,425 PROD3 DRILL DLOG P Tie in,-5' 12:42 13:30 0.80 6,425 8,070 PROD3 DRILL WPRT P Wiper back in hole, 13K RIW 13:30 14:48 1.30 8,070 8,220 PROD3 DRILL DRLG P Continue drilling, 1.7 BPM,3800 CTP, 3930 BHP, 100 WHP 14:48 18:18 3.50 8,220 0 PROD3 DRILL WPRT P TD, pump sweeps and wiper to surface 18:18 20:18 2.00 0 8,220 PROD3 DRILL WPRT P Tag up, RBIH 20:18 20:33 0.25 8,220 0 PROD3 DRILL DLOG P Tie in depth to K1 +11'correction 20:33 00:00 3.45 0 0 PROD3 DRILL TRIP P RIH,Tag TD 8220. POOH laying in liner pill&12.0 ppg KWF to surface 07/24/2011 PU/MU/RIH/Release CL1 liner on bottom 8220'.TOL 6362'. POOH. PU/MU/RIH/set whipstock 6289.88'bit depth,TOWS 6280'. POOH. PU/MU/RIH milling BHA(.6 AKO). Mill window. 00:00 01:30 1.50 0 0 PROD3 DRILL TRIP P At surface. 01:30 01:45 0.25 0 0 PROD3 DRILL SFTY P Flow check, PJSM 01:45 02:15 0.50 0 0 PROD3 DRILL PULD P LD drilling BHA 02:15 02:45 0.50 0 0 COMPZ CASING PUTB P Prep floor to PU liner 02:45 04:45 2.00 0 0 COMPZ CASING PUTB P PU/MU liner 04:45 05:30 0.75 0 1,901 COMPZ CASING PULD P MU Coiltrack Page 15 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 07:24 1.90 1,901 8,233 COMPZ CASING RUNL P RIH. At upper flag correct+21',at lower flag depth was within one foot. Tag TD at 8233',set down 5K WOB, pump at 1.5 BPM,4400 CTP and PU clean. Liner top deployment sleeve at 6362', BOL at 8220'. 07:24 08:48 1.40 8,233 0 COMPZ CASING TRIP P POOH 08:48 09:36 0.80 0 0 COMPZ CASING PULD P Lay down liner running BHA 09:36 10:30 0.90 0 0 PROD4 RPEQP1PULD P MU whipstock BHA#15 10:30 12:00 1.50 0 5,960 PROD4 RPEQP1TRIP P RIH 12:00 12:42 0.70 5,960 6,280 PROD4 RPEQPIDLOG P Tie-in to K1, +12', log CCL, Cementralizer is at 6276'. RIH to bit deptth of 6289.88',TOWS at 6280'. Orient highside, pump at 0.4 BPM and 3600 CTP to set whipstock,3K WOB after setting. 12:42 14:12 1.50 6,280 0 PROD4 RPEQP1TRIP P POOH,24K PUW 14:12 15:00 0.80 0 0 PROD4 RPEQPI PULD P Lay down whipstock setting BHA 15:00 16:00 1.00 0 73 PROD4 WHPST PULD P MU window milling BHA with 0.6 deg motor,2.74"string reamer(2.74 go/2.73 no-go)and 2.74"DSM (2.74go/2.73 no-go) 16:00 17:30 1.50 73 5,950 PROD4 WHPST TRIP P RIH 17:30 17:45 0.25 5,950 5,950 PROD4 WHPST DLOG P Tie in depth. 0 correction 17:45 18:30 0.75 6,250 6,250 PROD4 WHPST CIRC P Swap hole over to used FP mud 18:30 19:00 0.50 6,250 6,280 PROD4 WHPST TRIP P Close EDC. RIH dry tag TOWS. 19:00 00:00 5.00 6,280 6,284 PROD4 WHPST MILL P Start milling window. 1 FPH. 1.5K WOB, 1.6 BPM,3450 CTP,200 WHP,3730 BHP 07/25/2011 Complete window milling.TOWS&window 6281', BOW 6287'. POOH. PU/MU/RIH drilling BHA(1 AKO). Drift window. Swap well to new mud. Drill CL2 lateral. 00:00 01:00 1.00 6,284 6,286 PROD4 WHPST MILL P Continue milling 1 FPH 01:00 03:00 2.00 6,286 6,290 PROD4 WHPST MILL P Increase ROP to 2 FPH. 1.6 BPM, 3428 CTP, .7K WOB,200 WHP, 3730 BHP 03:00 04:48 1.80 6,290 6,301 PROD4 WHPST MILL P Milling rat hole. 5-6 FPH,2.5K WOB, 3550 CTP,200 WHP,3730 BHP 04:48 06:00 1.20 6,301 6,301 PROD4 WHPST REAM P Ream window up and down 3 times, drift with pump down. 06:00 07:30 1.50 6,301 0 PROD4 WHPST TRIP P POOH 07:30 09:24 1.90 0 0 PROD4 WHPST PULD P Undeploy milling BHA. Mill came out 2.73 go/2.72 no-go,string reamer came out 2.74 go/2.73 no-go. 09:24 10:48 1.40 0 0 PROD4 DRILL PULD P Deploy drilling BHA with USR,0.9 deg motor and new Hycalog bit 10:48 11:30 0.70 0 0 PROD4 DRILL SVRG P Service/maintain injector 11:30 12:00 0.50 0 0 PROD4 DRILL PULD P Continue with deployment of drilling BHA Page 16 of 24 Time Logs Date From To Dur S. Deoth E. Death Phase Code Subcode T Comment 12:00 13:18 1.30 0 5,960 PROD4 DRILL TRIP P RIH 13:18 13:30 0.20 5,960 5,985 PROD4 DRILL DLOG P Tie-in,-1'correction. 13:30 13:42 0.20 5,985 6,301 PROD4 DRILL TRIP P Continue RIH 13:42 16:06 2.40 6,301 6,470 PROD4 DRILL DRLG P Drilling ahead,swap to new 10.3 ppg flo-pro, 1.7 BPM,3600 CTP,3720 BHP with 180 WHP 16:06 16:42 0.60 6,470 6,470 PROD4 DRILL WPRT P Wiper to window, log K1 and RA, K1 -1', RA came in at 6287' 16:42 18:27 1.75 6,470 6,622 PROD4 DRILL DRLG P Drilling ahead, 1.7 BPM,3800 CTP, 3740 BHP, 160 WHP 18:27 19:12 0.75 6,622 6,622 PROD4 DRILL WPRT P Wiper trip back to window 21K PUW. Tie into RA marker. No correction 19:12 21:12 2.00 6,622 6,770 PROD4 DRILL DRLG P Drilling ahead, 1.66 BPM,3750 CTP, 3750 BHP, 170 WHP, 12.2K CTW, 12.1 ECD 21:12 21:45 0.55 6,770 6,770 PROD4 DRILL WPRT P Wiper trip to window 21K.Tie in to RA marker. 21:45 23:30 1.75 6,770 6,920 PROD4 DRILL DRLG P Drilling ahead, 1.66 BPM,3949 CTP, 3759 BHP, 152 WHP, 10.7K CTW, 12.1 ECD 23:30 00:00 0.50 6,920 6,920 PROD4 DRILL WPRT P Wiper trip to window 23K PUW.Tie into RA marker.-2'correction. Open EDC circ. bottoms up. PUH to 3-1/2" liner top. 07/26/2011 Continue drilling ahead CL2 lateral. Pumping 10/10 low-high sweeps prior to each wiper trip. 00:00 01:30 1.50 6,920 6,920 PROD4 DRILL WPRT P Circ.bottoms up RIH to drill 01:30 03:15 1.75 6,920 7,070 PROD4 DRILL DRLG P Drilling ahead, 1.66 BPM,3783 CTP, 3790 BHP, 170 WHP, 10.7K CTW, 12.2 ECD 03:15 04:06 0.85 7,070 7,070 PROD4 DRILL WPRT P Wiper trip to window 22K PUW, 04:06 06:06 2.00 7,070 7,220 PROD4 DRILL DRLG P Drilling ahead, 1.66 BPM,3800 CTP, 3840 BHP, 170 WHP, 13K RIW 06:06 06:48 0.70 7,220 6,315 PROD4 DRILL WPRT P Wiper to window,21K PUW 06:48 07:00 0.20 6,315 6,325 PROD4 DRILL DLOG P Tie in,-2' 07:00 07:36 0.60 6,325 7,220 PROD4 DRILL WPRT P Wiper back in hole, 10K RIW 07:36 09:36 2.00 7,220 7,370 PROD4 DRILL DRLG P Drilling ahead, 1.7 BPM, 3800 CTP, 3840 BHP, 170 WHP, 13K RIW 09:36 11:06 1.50 7,370 7,370 PROD4 DRILL WPRT P Wiper to the window,22K PUW 11:06 12:06 1.00 7,370 7,520 PROD4 DRILL DRLG P Drilling ahead, 1.7 BPM, 3800 CTP, 3840 BHP, 170 WHP, 13K RIW 12:06 13:36 1.50 7,520 7,520 PROD4 DRILL WPRT P Wiper trip to window 22K PUW. Chasing low/high sweeps 13:36 15:06 1.50 7,520 7,670 PROD4 DRILL DRLG P Drilling ahead, 1.7 BPM, 3800 CTP, 3840 BHP, 170 WHP, 13K RIW 15:06 16:06 1.00 7,670 7,670 PROD4 DRILL WPRT P Wiper trip to window, 22K 16:06 17:51 1.75 7,670 7,670 PROD4 DRILL WPRT P Pump low/high sweeps 10/10. PUH to liner top for bottoms up.Tie in depth-6ft. 17:51 19:39 1.80 7,670 7,820 PROD4 DRILL DRLG P Drilling ahead. Page 17 of 24 Time Logs Date From To Dur S. DepthE.Depth Phase Code Subcode T Comment 19:39 21:39 2.00 7,820 7,820 PROD4 DRILL WPRT P Wiper trip P/U weight 22K. Discuss with town on TD. 21:39 22:45 1.10 7,820 7,915 PROD4 DRILL DRLG P Drilling ahead-1.65 bpm,4000, BHP 3930, ECD 12.7, ROP 95,WOB 1.7, Ct weight 7K.-7915' BHA wiper due to weight loss and slow ROP. P/U weight 23K. 22:45 23:30 0.75 7,915 7,970 PROD4 DRILL DRLG P Drilling ahead-1.65 bpm,4100, BHP 3940, ECD 12.7 ppg, ROP 85,WOB 1.8K, Ct weight 7.5K. 23:30 00:00 0.50 7,970 7,970 PROD4 DRILL WPRT P Wiper trip-P/U weight 22K. 07/27/2011 TD CL2 Lateral @ 8120'.Wiper trip to swab valves, RIH&lay in liner pill&KWF to surface. P/U 43 jnts of slotted liner with Anchored billet.Set from 8120'-6670'. DGS failure at surface with drilling BHA. Weekly function test of BOPE. 00:00 01:30 1.50 7,970 7,970 PROD4 DRILL WPRT P wiper trip 01:30 03:00 1.50 7,970 8,120 PROD4 DRILL DRLG P Drilling ahead-1.60 bpm,4150, BHP 3950, ECD 12.8,WOB 1.6,Ct weight 8K,WHP 150. Pump 10/10 sweeps. TD hole. 03:00 06:30 3.50 8,120 0 PROD4 DRILL WPRT P Wiper to window-open EDC&wiper trip to swab valves. 06:30 08:00 1.50 0 5,950 PROD4 DRILL WPRT P RBIH 08:00 08:15 0.25 5,950 5,950 PROD4 DRILL DLOG P Tie in depth. 08:15 12:15 4.00 8,120 0 PROD4 DRILL TRIP P Tag TD, POOH laying in liner running pill. KWF with beads, No beads window from surface. 12:15 12:30 0.25 0 0 PROD4 DRILL SFTY P At surface, Monitor well for flow. PJSM 12:30 13:00 0.50 0 0 PROD4 DRILL PULD P LD tools 13:00 13:30 0.50 0 0 COMPZ CASING PUTB P Prep floor to run liner 13:30 14:45 1.25 0 0 COMPZ CASING PUTB P PU/MU liner 14:45 16:00 1.25 0 0 COMPZ CASING PULD P PU/MU anchor-billet and coiltrack, MU to well 16:00 18:00 2.00 0 8,120 COMPZ CASING RUNL P RIH-P/U weight 24K off bottom.Set billet @ 6668'at 180 deg ROHS. Bottom of liner at 8118'. 18:00 20:00 2.00 8,120 61 COMPZ CASING TRIP P POOH pumping KWF. Flow-check at surface. 20:00 21:00 1.00 61 0 COMPZ CASING PULD P PJSM for Laying down&P/U BHA. 21:00 21:30 0.50 0 0 COMPZ CASING BOPE P Weekly function test of BOP's. 21:30 22:30 1.00 0 71 PRODS STK PULD T P/U BHA-BHA comms failed while testing through CT string. Drilling L2-02 lateral(geo sidetrack) to pick up bypassed pay from the L2 lat. 22:30 00:00 1.50 71 0 PRODS STK PULD T Trouble shoot and lay down BHA. DGS sub failed 07/28/2011 Kick off from top of billet from 6667'with BHA#19-1.0 AKO with 2.73 bi-center. Mud swap using 1%lube concentrations. Drilled ahead-ROP 120-150 fph. Page 18 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 6,250 PROD5 STK TRIP T RIH with EDC open. 01:30 03:15 1.75 6,250 6,667 PROD5 STK CIRC T Tie in-2 ft and circ out KWF.Close EDC&RIH dry tag @ 6667' 03:15 06:15 3.00 6,667 6,670 PROD5 STK KOST T P/U weight 23K-Bring pumps up and begin KO from billet @ 150 ROHS.-6666.50' 1.65 bpm,3500, BHP 3737, ECD 12.1, ROP 1fph,WHP 200,CT weight 15K,WOB.5K Aluminum returns over shaker 6667.3' 06:15 06:30 0.25 6,670 6,674 PROD5 STK KOST T Increase ROP to 10 FPH 06:30 06:45 0.25 6,674 6,677 PROD5 STK KOST T Increase ROP to 20 FPH 06:45 07:00 0.25 6,677 6,700 PRODS DRILL DRLG T Drill ahead 1.7 BPM, 3630 CTP,230 WHP, 3800 BHP 07:00 07:06 0.10 6,700 6,700 PROD5 DRILL REAM T Drift ST,Good 07:06 08:21 1.25 6,700 6,820 PRODS DRILL DRLG T Drill ahead 1.7 BPM, 3630 CTP,230 WHP, 3800 BHP. Swap hole to new 10.3 ppg mud. This mud has 1% Lotorq, 1% Lube776, and 1.0 ppb KlaStop. 08:21 09:00 0.65 6,820 6,820 PROD5 DRILL WPRT T Wiper trip to window 22K PUW, 0 correction to RA marker 09:00 10:30 1.50 6,820 6,970 PRODS DRILL DRLG T Drill ahead 1.7 BPM, 3630 CTP,230 WHP, 3800 BHP 10:30 11:00 0.50 6,970 6,970 PRODS DRILL WPRT T Wiper trip to window,22K PUW 11:00 12:15 1.25 6,970 7,117 PRODS DRILL DRLG T Drill ahead 1.7 BPM, 3850 CTP,225 WHP,3810 BHP 12:15 13:15 1.00 7,117 7,117 PROD5 DRILL WPRT T Wiper trip to window,22K PUW, chasing low/high sweeps. 10 bbls each 13:15 14:21 1.10 7,117 7,270 PRODS DRILL DRLG T Drill ahead 1.7 BPM,3880 CTP,225 WHP,3812 BHP 14:21 15:00 0.65 7,270 7,270 PRODS DRILL WPRT P Wiper trip to window, 22K PUW, chasing low high sweeps. 10 bbl each. 15:00 15:45 0.75 7,270 7,270 PRODS DRILL CIRC P Open EDC circ bottoms up 2 BPM, PUH to 5200'. RBIH to window 15:45 16:30 0.75 7,270 7,270 PRODS DRILL WPRT P Close EDC.Tie in depth,-4.5' correction, RIH to TD 16:30 17:45 1.25 7,270 7,420 PRODS DRILL DRLG P Drill ahead 1.64 BPM,3900 CTP, 255 WHP,3849 BHP, 12.3 ECD 17:45 19:00 1.25 7,420 7,420 PRODS DRILL WPRT P Wiper trip to window, 23K PUW 19:00 20:45 1.75 7,420 7,570 PROD5 DRILL DRLG P Drilling ahead-1.60 bpm, 3900, BHP 3880, ECD 12.4,WHP 200,WOB 1.7, ROP 130, CT weight 9K. Pump low/high sweeps 20:45 21:33 0.80 7,570 7,570 PRODS DRILL WPRT P Wiper trip P/U weight 23K 21:33 22:30 0.95 7,570 7,720 PRODS DRILL DRLG P Drilling ahead-1.65 bpm, 3900, BHP 3900, ECD 12.6,WHP 200,WOB 1.3, ROP 150, CT weight 9K. 22:30 00:00 1.50 7,720 7,720 PROD5 DRILL WPRT P Pump sweeps-Wiper trip to cased hole. P/U weight 24K. Page 19 of 24 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 07/29/2011 24 hr Summary Drill to CL2-02 TD at 8171'.Wiper trip to swab valves&stopped to correct depth counter during tie in.Conitue RIH tag TD @ 8175'. POOH pumping liner pill&KWF. Lay down BHA at surface fix Depth counter,choke& shaker.Start P/U liner string. 00:00 01:30 1.50 7,720 7,720 PROD5 DRILL WPRT P RIH-Wiper trip-tie in correction -5ft. 01:30 02:30 1.00 7,720 7,870 PROD5 DRILL DRLG P Drilling ahead-1.65 bpm,3900, BHP 3890, ECD 12.6,WOB 2.1, ROP 144, CT weight 9K. 02:30 04:30 2.00 7,870 7,870 PROD5 DRILL WPRT P Wiper trip-P/U weight 23K 04:30 05:45 1.25 7,870 8,020 PROD5 DRILL DRLG P Drilling ahead-1.65 bpm,3960, BHP 3935, ECD 12.4, ROP 155,WOB 1.9, Ct weight 9K. 05:45 07:45 2.00 8,020 8,020 PROD5 DRILL WPRT P Wiper trip-P/U weight 23K 07:45 08:45 1.00 8,020 8,170 PROD5 DRILL DRLG P Drilling ahead-1.65 bpm,3960, BHP 3935, ECD 12.4, ROP 155,WOB 1.9, Ct weight 9K. 08:45 11:45 3.00 8,170 0 PROD5 DRILL WPRT P TD CL2-02 lateral. Pump low/high sweeps, POOH to swab valves 11:45 13:00 1.25 8,170 5,950 PROD5 DRILL WPRT P RBIH 13:00 13:30 0.50 5,950 5,950 PROD5 DRILL DLOG P Tie in depth, 100'off! 13:30 14:30 1.00 5,950 5,950 PROD5 DRILL RGRP T Repair counter. Broken lovejoy connector. 14:30 14:45 0.25 5,950 5,950 PROD5 DRILL DLOG P Tie in depth to K1 marker,-6' correction 14:45 16:15 1.50 5,950 8,175 PROD5 DRILL WPRT P RIH to TD 16:15 18:45 2.50 8,175 2,000 PROD5 DRILL TRIP P Tag TD. POOH laying in liner running pill&KWF. 2000'from surface choke started plugging off,trap pressure and flush it out. Slugs of polymers&beads over the shakers. (KWF transition fluid). 18:45 19:45 1.00 2,000 71 PROD5 DRILL TRIP P Continue POOH-KWF to surface @ 1850'. By-pass choke due to fluctuation in rate. Flow check at surface. BHI counter out 150ft. 19:45 20:45 1.00 71 0 PROD5 DRILL PULD P PJSM for laying down BHA. Flow check-good. lay down BHA. 20:45 22:45 2.00 0 0 PROD5 DRILL RGRP T Service injector,fix BHI counter, Inspect top drive, replace shaker adjustment bracket&replace choke bean. 22:45 00:00 1.25 0 900 COMPZ CASING PUTB P PJSM-start P/U 51 joints of slotted liner.Safety joint drill-2 minutes 10 seconds. 07/30/2011 Set liner in CL2-02 LAT From 8171 -TOB 6439'. Recover KWF with new mud system of 1%lubes. KOTB from 6438'-cl;ean sidetrack with zero stalls. Continue drilling ahead CL2-01 Lateral. 00:00 01:00 1.00 900 1,750 COMPZ CASING PULD P Finish P/U a total of 51 joints of slotted liner+BHA shorty deplyment sleeve. Page 20 of 24 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:00 03:00 2.00 1,750 6,230 COMPZ CASING RUNL P RIH with EDC closed pumping.3 bpm KWF. Stop at EOP flag @ 4400'-current EOP 4470'. Did not change our depth due to depth problems yesterday.Weight check 27K. Continue to RIH. 03:00 04:00 1.00 6,230 8,171 COMPZ CASING RUNL P RIH-smooth to TD.Tag 8172'5K down.Weight check-30K-RIH tag @ 8171'. Pump 1.4 bpm, P/U weight 25K. Set liner 8171'TOL 6464'. 04:00 04:30 0.50 8,171 6,293 COMPZ CASING TRIP P P/U to window&tie into RA tag." Zero correction". 04:30 06:00 1.50 6,293 0 COMPZ CASING TRIP P POOH pumping KWF. 06:00 06:30 0.50 0 0 COMPZ CASING SFTY P At surface, Flow check.Crew change, PJSM. 06:30 07:30 1.00 0 0 COMPZ CASING PULD P LD tools 07:30 09:00 1.50 0 0 COMPZ CASING SVRG P Service reel, injector head,top drive and depth counter 09:00 10:00 1.00 0 84 PROD6 STK PULD P PU/MU BHA(OH anchored billet) 10:00 11:15 1.25 84 5,950 PROD6 STK TRIP P RIH 11:15 11:30 0.25 5,950 5,950 PROD6 STK DLOG P Tie in depth,-4'correction 11:30 11:45 0.25 5,950 6,462 PROD6 STK TRIP P RIH to TOL 11:45 12:00 0.25 6,462 6,462 PROD6 STK TRIP P Tag TOL 6462'. Set anchor at 6441'. 2700psi. Single slip 160 LOHS 12:00 13:30 1.50 6,462 0 PROD6 STK TRIP P POOH 13:30 13:45 0.25 0 0 PROD6 STK OWFF P At surface, Flow check PJSM 13:45 14:15 0.50 0 0 PROD6 STK PULD P LD tools 14:15 15:00 0.75 0 0 PROD6 STK PULD P PU Drilling BHA(1.0 deg AKO, Bi-Center) 15:00 16:30 1.50 72 5,950 PROD6 STK TRIP P RIH 16:30 16:45 0.25 5,950 5,950 PROD6 STK DLOG P Tie in depth.-4'correction. RIH to TOW 16:45 17:45 1.00 5,950 6,250 PROD6 STK CIRC P Circulate well to new FP 17:45 18:15 0.50 6,250 6,439 PROD6 STK TRIP P Dry tag TOB @ 6439'. P/U and bring pump rate up and start KOTB from 6438'at 180 18:15 21:15 3.00 6,439 6,470 PROD6 STK KOST P KOTB-1.65 bpm, 3400, BHP 3733, WHP 220, ECD 12.1, ROP 1 fph, WOB.6K, Ct weight 15K.Good Al. shaving over shaker at 6439.4'. 6440.65-increase to 3fph.WOB.8K 6441.7-Increase to 10fph WOB.3K 6446.5-Increase to 20 fph WOB.5K 6450-Normal ROP 21:15 23:00 1.75 6,470 6,590 PROD6 DRILL DRLG P P/U weight 23K.-RIH dry drift- clean. Continue drilling ahead. Billet 6438'-6444' 23:00 23:30 0.50 6,590 6,590 PROD6 DRILL WPRT P Wiper trip with tie in+1 23:30 00:00 0.50 6,590 6,639 PROD6 DRILL DRLG P Drilling ahead Page 21 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/31/2011 24 hr Summary Drill CL2-01 Lat to TD of 6890'.Wiper to swab valves and run CCL log.Tag TD-POOH laying in KWF. Run slotted liner from 6890'-6217'. P/U BHA#24 with Baker KB packer and 42-30 Seal assembly. Set&tested KB packer from 5402.5'-5369.5' 00:00 01:00 1.00 6,639 6,740 PROD6 DRILL DRLG P Drilling ahead- 1.65 bpm, 3800, BHP 3780, ECD 12.1, ROP 120,WOB 1.6K, Ct weight 12K. 01:00 01:45 0.75 6,740 6,740 PROD6 DRILL WPRT P Wiper trip-P/U weigth 23K 01:45 03:00 1.25 6,740 6,890 PROD6 DRILL DRLG P Drilling ahead-1.65 bpm, 3700, BHP 3792, ECD 12.2,WHP 160,WOB 1.9, ROP 110,CT weight 13K. TD L2-01 lateral and pump 10/10 sweeps. 03:00 05:30 2.50 6,890 0 PROD6 DRILL WPRT P Wiper trip to swab valves. Open EDC in cased hole&Pump sweep to chase to surface following MPD. Large amounts of cuttings over shakers from-2000'MD. 05:30 07:15 1.75 0 5,950 PROD6 DRILL WPRT P RBIH 07:15 07:30 0.25 5,950 5,950 PROD6 DRILL DLOG P Tie in depth to K1 07:30 08:00 0.50 5,950 5,100 PROD6 DRILL DLOG P PUH to log CCL 5100-5400'for setting packer. Locate top of 3-1/2" liner at 5389'CCL(should have been at 5381'). 08:00 08:45 0.75 5,100 6,890 PROD6 DRILL WPRT P RIH to TD 08:45 11:15 2.50 6,890 6,894 PROD6 DRILL WPRT P Tag TD. POOH laying in liner running pill. KWF with beads. Paint EOP flags 11:15 11:30 0.25 0 0 PROD6 DRILL OWFF P At surface,flow check 11:30 12:30 1.00 0 0 PROD6 DRILL PULD P LD tools 12:30 13:00 0.50 0 0 COMPZ CASING PUTB P Prep floor to PU/MU 2-3/8"liner 13:00 13:15 0.25 0 0 COMPZ CASING SFTY P PJSM,discuss contingency procedures 13:15 14:15 1.00 0 0 COMPZ CASING PUTB P PU/MU liner 14:15 15:45 1.50 717 6,215 COMPZ CASING RUNL P RIH with liner 15:45 16:15 0.50 6,216 6,894 COMPZ CASING RUNL P Tie in depth to EOP flag. +1' correction. RIH 16:15 16:30 0.25 6,894 6,894 COMPZ CASING RUNL P Tag TD. PU 27K. RIH tag TD. Release off liner 4100 CTP 23K PUW. Liner released.TOL=6217', BOL=6890' 16:30 18:00 1.50 6,217 62 COMPZ CASING TRIP P POOH,paint EOP flag. Flow check at surface. 18:00 19:30 1.50 62 0 COMPZ CASING PULD P PJSM-laying down BHA 19:30 20:00 0.50 0 0 COMPZ RPEQP1 SFTY P Secure well&PJSM for KB packer tool with Ball on Seat. BOT, BHI, NAD, CPAI. 20:00 21:00 1.00 0 78 COMPZ RPEQP1 PULD P Torque up all connections and begin P/U BHA#24 with Baker 3"seal assembly, 5/8"ball on-seat, DS nipple&KB liner top packer. Page 22 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 78 5,200 COMPZ RPEQPI TRIP P EDC OPEN-RIH pumping 300ft& start pumping KWF.25 bpm,slowing through restirctions.Stop at EOP flag+3.4'correction. 23:00 23:30 0.50 5,200 5,397 COMPZ RPEQPI PACK P RIH-Weight check @ 5360'.25K. Stop pumping,close the EDC. RIH CT Downweight 17K-WOB zero. Start losing surface weigth @ 5397'- WOB 1.1K.Set down 10K @ 5402'- WOB 9.8K. P/U breakover+1ft=5399.50',WOB negative 0.8K. Pump down backside -good test of seals. Bleed down annular slowly. 23:30 00:00 0.50 5,397 5,402 COMPZ RPEQPI PACK P P/U 1/2 ft to 5399'-Set up down CT string. Pressure up to 2500psi, differntial 1940psi.Set down 10K on surface,WOB 8K.depth 5400.5'. Bleed down CT to 1200psi, Bore 4600psi. Pump down Backside to 2400 psi. BHP 5700psi.5 Minute Good test on KB packer. Bleed down and pressure up CT string to 3500 psi.WOB 8.6K. Tool released @ 3600psi. P/U weight 24K. 08/01/2011 Freeze Protect well from 2300ft to surface. Undeploy leaving 1100 psi on Well. Purge CT string, BOP's& lines with N2. Set BPV&Swap Reels. Injector skate change. 00:00 01:00 1.00 5,402 5,380 1DEMOB WELLPF DISP P Top of KB packer @ 5370' P/U 20ft above packer and circ out KWF. 01:00 03:30 2.50 5,380 60 (DEMOB WELLPF FRZP P POOH pumping SW followed by diesel from 2300'to surface for freeze protecting.taking returns to Tiger tank. 03:30 05:00 1.50 60 0 DEMOB WELLPF PULD P PJSM-Undeploy BHA-setting tool looked good. 1050 psi on well at surface. 05:00 05:30 0.50 0 0 DEMOB WELLPF CIRC P Prep rig floor for corrosion inibitor flush across BOP stack. 05:30 06:30 1.00 0 0 DEMOB WELLPF SFTY P Crew change, PJSM 06:30 08:30 2.00 0 0 DEMOB WELLPF CTOP P Flush rig, blow down CT with N2 08:30 11:00 2.50 0 0 DEMOB WHDBOjNUND P Set BPV 11:00 14:00 3.00 0 0 DEMOB WHDBO CTOP P Unstab CT 14:00 16:00 2.00 0 0 DEMOB WHDBO CTOP P Prepare reel for loading 16:00 18:00 2.00 0 0 DEMOB WHDBOICTOP P Blow down rig, swap reel out. Reel installed. Page 23 of 24 - t Time Logs Date ' From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 0 0 DEMOB WHDBO NUND P Rig up hard line,spacers&shims on reel.Tighten down bolts. Rig down Putz and hard line in celllar. Continue to work on skate change on injector. Install stripper&change out 7"risers back to normal sequence for space out. 08/02/2011 RDMO-Rig release at 04:00.Move to 3H-12. 00:00 04:00 4.00 0 0 DEMOB MOVE NUND P RDMO-D&W still prepping tree& location at 3H-12. Rig release at 0400 hrs.Trucks on location ready to move to 3H-12. Page 24 of 24 Letter of Transmittal lvdal BAKER Date: August 3, 2011 HUGHES To: From: Christine Mahnken Carl Ulrich/ Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3H-10C 3H-10CPB1 3H-10CL1 3H-10CL2 3H-10CL2-01 3H-10CL2-02 a t j — Q O (6) total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes Operations Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes Survey Manager Carl.Ulrich@BakerHughes.com FSr LL,rA, Tr T w' SEAN PARNELL,GOVERNOR ALASKA OIL AND GASn, Liii: Z IA 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSIONANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H-10CL2-02 ConocoPhillips Alaska, Inc. Permit No: 211-090 Surface Location: 1322' FNL, 281' FWL, SEC. 12, T12N, R8E, UM Bottomhole Location: 576' FSL, 1999' FWL, SEC. 1, T12N, R8E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ,9 Danie . Seamount, Jr. k Chair DATED this T day of August, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 28, 2011 Commissioner-State of Alaska `'t Alaska Oil &Gas Conservation Commission ; 333 East 7th Avenue Suite 100 Anchorage, Alaska 99501 A!8,4.,q s• r, Dear Commissioner: Antlleritg0 ConocoPhillips Alaska, Inc. hereby submits a Permit to Drill application for an additional coiled tubing drilling (CTD) lateral out Kuparuk wellbore 3H-10B (PTD# 203-160) using the Nabors CDR2-AC CTD rig. This permit will be in addition to the previously permitted laterals 3H-10C (PTD#211-073), 3H-10CL1 (PTD#211-074), 3H- 10CL2 (PTD#211-075), and 3H-10CL2-01 (PTD#211-076). The objective of the added lateral is to access pay intervals in the A sands that were missed while drilling 3H-10CL2 due to geologic complexity. The Commission granted verbal approval to continue with uninterrupted drilling operations on July 27, 2011 while this application is being processed. e...•-• 9.27.If Attached to this application are the following documents that explain the proposed job operations: - Permit to Drill A.•lication Forms for 3H-10CL2-02 - Updated Wellbore Schematic - Updated Directional Plan - Previously submitted Summary of Operations - Addendum to the Previously submitted Summary of Operations If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, Jill L g ConocoPhillips Alaska Coiled Tubing Drilling Engineer \Iit :, - STATE OF ALASKA i j A ?El) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL A ,$:u 2,36 g ► r. + I , ►_iil1liussion 20 AAC 25.005 '.4,- z i;1 la.Type of Work: . lb.Proposed Well Class: Development-Oil D. Service-Winj ❑ Single Zone ❑✓ . 1c.Specify if well is proposed for: Drill ❑ Re-drill❑✓ 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 . 3H-10CL2-02 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:8100' ' TVDSS: 5949' • Kuparuk River Field . 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1322'FNL,281'FWL,Sec. 12,T12N,R8E, UM ADL 25531 - Kuparuk River Oil Pool' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 720'FNL, 1402'FWL,Sec. 12,T12N,R8E,UM 2657 7/27/2011 Total Depth: 9.Acres in Property: 14.Distance to 576'FSL, 1999'FWL,Sec. 1,T12N,R8E,UM 2560 Nearest Property: 9550' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 66.6 feet 15.Distance to Nearest Well Open Surface:x- 498655 • y- 6000335 • Zone- 4 GL Elevation above MSL: 40 feet to Same Pool: 3H-12,1060' 16.Deviated wells: Kickoff depth: 6670 • ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: 100.6° deg. Downhole:3544 psig. Surface:2960 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.375" 4.7# L-80 ST-L 1600' 6500 ` 5965' 8100' 5949' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 6410' 6274' 6309' 6183' Casing Length Size Cement Volume MD TVD Conductor/Structural 72' 16" 225 sx AS I 108' 108' Surface 2989' 9.625" 1300 sx AS III,100 sx AS I, 3024' 3023' Intermediate 300 sx Class G Production 3528' 7" 450 sx Class G,200 sx AS I 6264' 5902' Liner 3037' 4.5" 115 sx LiteCrete,110 sx Class G 6405' 6269' Perforation Depth MD(ft): Perforation Depth TVD(ft): 6039'-6059',6069'-6089',6124'-6144',6154'-6164',6190'-6200' 5943'-5960',5969'-5987',6018'-6036',6046-6054',6077'-6086' 20.Attachments: Property Plat❑ BOP Sketch❑✓ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑ 21.Verbal Approval: 7/27/2011 Commission Representative: Guy Schwartz Date: 7/27/2011 certify foregoing Contact Jill �on� a�✓9, 22. I herebythat the fore oin is true and correct. �_ clI e ^nc� ., n 1- Printed Name L. Gantt Title CTD Engineering Supervisor Signature /,1� L/. 0/)1_1/,-4/ Phon 263-4021 Date 7/ 8/// EA ,-are LA--wit�G�✓7 _ Commission Use Only Permit to Drill y _ API Number: - Permit Approval See cover letter Number: ±_/ , l�-' (L;% 50- /0 -6, )/ �' 6 �Date: 91 U I i l for other requirements Conditions of approval: If box is checked,well maynot be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 2.,*. 35:00 p s,:. eo ftes4amples req'd: Yes ❑ No 2 Mud log req'd: Yes ❑ No Q Other: h1 / � 2S measures: Yes [� No ❑ Directional svy req'd: Yes 2 No [I] G0 Sr7g- / AP••OVED BY THE COMMISSION ( / DAT Q �. ,COMMISSIONER • / o4z� �+� lI1 Form 10-401 (Revised 7/2009) This permit is va f o s r.m e•• - • approval(20 AAC 25.005(g)) Submit in Duplic �,I' • KRU 3H-10C, CL1, CL2, and CL2-01 — Coiled Tubing Drilling Summary of Operations: Well 311-10B is a Kuparuk C-sand and A-sand production well equipped with 41/2" tubing and 4'/2"production liner. Five proposed A-sand CTD laterals will increase reservoir exposure and offset the planned 3H-12 CTD injection laterals. Prior to rig arrival, a 4'/2"mechanical whipstock will be set at the planned kickoff point of 6045' MD in 311-10B. After setting the whipstock we will down-squeeze around the whipstock to permanently abandon the A-sand and C-sand perfs,which will isolate these zones and help mechanically stabilize the 41/2" liner in the vicinity of the sidetrack point. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the perfs in this manner. The 3H-10C sidetrack will exit the 4'/2" liner at 6045' MD from the mechanical whipstock that was set pre-rig. Initially our BOPE will be equipped for `bighole' CTD operations(i.e. 3"BHA). We will drill through the C- sand into the A-sand with a 41/2"bi-center bit to a depth of 6397' MD. We will then run 620' of 3'%", 6.6 ppf, L-80 liner with TC-II connections from 5777' to 6397'. The 31/4" liner will be cemented in place with 7 bbl of 15.8 ppg cement,which will isolate the C-sand behind pipe. After allowing the cement to set and reconfiguring our BOPE for slimhole operations(i.e. 23/8"BHA), we will drill out the shoe of the 31/4" liner with a 3"bi-center bit targeting the A2 sand east of the existing well with a 2328' lateral (measured from shoe of 3'/4" liner). The lateral will be completed with 2%" slotted liner to the TD of 8725' MD with an aluminum billet at 7150' MD. The 3H-10CL1 lateral will kick off from the aluminum billet at 7150' MD and will target the A3 sand east of the 3H-10B well with a 1660' lateral. The hole will be completed with a 2%" slotted liner to the TD of 8800' MD with the liner top inside the 31/4"liner at 6387' MD. The 3H-10CL2 lateral will kick off from a mechanical whipstock set inside the 3'%" liner at 6230' MD. It will target the A3 sand north of 3H-10B with a 1680' lateral. The hole will be completed with a 23/x" slotted liner to the TD of 7910' MD with an aluminum billet at 6500' MD. The 3H-10CL2-01 lateral will kick off from the aluminum billet at 6500' MD and will target the A2 sand north of the 3H-10B well with a 1445' lateral. The hole will be completed with a 2%" slotted liner to the TD of 7945' MD with the liner rtop inside the 3'/4"liner at 6229' MD. f 7 J f� - /lam' (..L 2_ .-e-,e-r r () After completing the 31-1-10CL2-ul lateral,we will run a 31/4"x 4/" liner-top packer at 5777' to provide further isolation to the C-sand formation that is behind the 31/4"cemented liner. CTD Drill and Complete 3H-10B Laterals: July 2011 Pre-CTD Work 1. Positive pressure and drawdown tests on master valve& swab valve 2. RU e-line. Set 4'%"monobore whipstock at 6045' MD with a highside orientation. RD e-line. 3. RU slickline. Obtain updated static BHP on A-sand. Dummy off all GLMs. RD slickline 4. RU coil. Down-squeeze the A-sand and C-sand perfs with cement. RD coil. 5. RU slickline. Tag top of cement. RD slickline. 6. Prep site for Nabors CDR2-AC, including setting BPV Page 2 of 6 ORIGINAL May 31, 2011, FINAL KRU 3H-10C, CLI, CL2, and CL2-01 — Coiled Tubing Drilling Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE, test. BOPE will be configured for `bighole' CTD operations. 2. 3H-10C Intermediate Hole Section a. Mill 3.80"window with high-side orientation at 6045' MD. b. Drill 3.70"x 41/4"bi-center lateral to TD of 6397' MD c. Run 31/4"blank liner with TC-II connections from TD up to 5777'inside the 41/2" liner d. Swap from e-coil to e-free coil e. Cement 31/4" liner in place with 7 bbl of 15.8 ppg cement using e-free coil 3. 3H-10C Sidetrack(A2 sand, east) a. Swap from e-free to e-coil tubing. Reconfigure BOPE for slimhole drilling; retest BOPE as needed. b. Mill out 31%" shoe at 6397' MD with 2.74"mill c. Drill 2.70"x 3"bi-center lateral to TD of 8725' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 7150' 4. 3H-10CL1 Lateral (A3 sand, east) a. Kick off of the aluminum billet at 7150' MD b. Drill 2.70"x 3"bi-center lateral to TD of 8800' MD c. Run 23/8" slotted liner from TD up into the 31/4"liner at 6387' 5. 31-1-10CL2 Lateral (A3 sand,north) a. Set a mechanical whipstock inside the 31/4"liner at 6230' b. Mill 2.74"window at 6230' c. Drill 2.70"x 3"bi-center lateral to TD of 7910' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 6500' GL 6. 3H-10CL2-01 Lateral(A2 sand, .orth) ' a. Kick o the aluminu . • let at 6500' MD 4 b. Drill 2. 3"bi-cent: 1. -ral to TD of 7945' MD c. Run 2%" slotted liner from TD up to 6220' MD,up inside the 31%" liner (,�. 7. Run 31%"x 4'/2"liner-top packer at 5777' to further isolate the C-sand 8. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production Mud Program: • Will use chloride-based Biozan brine or used drilling mud(8.6 ppg) for milling operations, and chloride- based Flo-Pro mud(8.6 ppg)for drilling operations. We will have to kill the well with weighted brine in order to deploy 31/4" solid liner and 2%" slotted liner in the laterals. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class Il disposal well • Class II drill solids to Grind&Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Existing Casing/Liner Information Surface: 9%",J-55, 36 ppf Burst 3520 psi Collapse 2020 psi Production: 7", L-80, 26 ppf Burst 7240 psi Collapse 5410 psi Liner: 4'/2", L-80, 12.6 ppf Burst 8430 psi Collapse 7500 psi Page 3 of 6 ( P G I 'A W May 31, 2011, FINAL KRU 3H-10C, CL1, CL2, and CL2-01 — Coiled Tubing Drilling Casing Program: • 3H-10C: 3'/4", 6.6#, L-80, TC-II solid liner from 5777' to 6397' MD o Annular capacity (gauge hole) of the—620' of 31/4" liner is 3.5 bbl. o Proposed 7 bbl cement volume provides—100%excess cement compared to gauge hole • 3H-10C: 2%", 4.7#, L-80, ST-L slotted/solid liner from 7150' MD to 8725' MD • 3H-10CL1: 23/8",4.7#, L-80, ST-L slotted/solid liner from 6387' MD to 8800' MD • 3H-10CL2: 23/8" 4.7#, L-80, ST-L slotted/solid liner from 6500' MD to 7910' MD • 3H-10CL2-01: 2%", 4.7#, L-80, ST-L slotted/solid liner from 6220' MD to 7945' MD Reservoir Pressure • The most recent static BHP survey in well 3H-10B was taken August 2010. The commingled A/C-sand reservoir pressure was measured at 2020 psi at 6162' MD, 5985' SSTVD, corresponding to 6.4 ppg EMW. We do not have good data on the differential pressure between the A-sand and the C-sand formations,but we generally expect to encounter increasing pressure as laterals are drilled away from the mother well. Well Control: • Two well bore volumes (-230 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. • Two BOP diagrams are attached. All operations will be conducted with 2" coil tubing,but the BOP configuration will change depending upon BHA and liner diameter. ✓ o The `bighole BHA' BOPE configuration will be used when we're using the 3" OD CoilTrak BHA and when we run 3'%" liner. We will begin drilling operations using this configuration. o The `slimhole BHA' BOPE configuration will be used when we're using the 2%" OD CoilTrak BHA and when we run 2%" liner. We will switch to this BOP configuration prior to drilling out the 3'%" cemented liner shoe. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum potential surface pressure in 3H-10B is 2960 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on two sources: o The first is a recent surface pressure measurement in well 3H-12 showing an estimated formation pressure of 3467 psi at 5971' SSTVD, corresponding to 11.2 ppg formation pressure. o The second is a pressure measurement of 3544 psi at 5924' SSTVD from well 311-09 taken in September 2010, corresponding to an 11.5 ppg gradient. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 3H-I0C, plan#6 2. 3H-10CL1, plan#4 3. 3H-10CL2, plan#4 4. 3 H-10CL2-01,plan#4 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 3H-10C eastern CTD laterals(C&CL 1): —9550' to property line, —920' to well 3H-11 • 31-1-10C northern CTD laterals (CL2&CL2-01): 9550' to property line, 1060' to well 3H-12 Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Page 4 of 6 ORIGINAL May 31,2011, FINAL KRU 3H-10C, CL1, CL2, and CL2-01 — Coiled Tubing Drilling Hazards • Mud loss to the exposed C-sand formation is the most significant problem expected while drilling the bighole portion of 3H-10C. If losses to the C-sand are extensive it could become difficult to maintain adequate borehole pressure on the shale sections penetrated,which could interfere with running 3'/4" liner and cementing it in place. • A significant pressure differential (2000 psi)exists between well 3H-10 and the 3H-12 injection well to the north. Well 3H-12 has been on flowback to reduce this differential,but significant opportunity still exists for particularly the northern laterals to encounter increased formation pressure. v' • There has been MI gas injection in the vicinity of 3H-10B, so it is possible that an influx will yield significant quantities of gas. • Well 31-1-10B has 180 ppm measured H2S as of November 2010. Well 3H-09 is located 25' to the right ,/ side and 3H-11 is 90' to the left side of the 3H-10B surface location. Well 3H-09 does not have any measured H2S since it is an injector. Well3H-11has 245 ppm H2S as of November 2009 but it is shut-in due to high water cut. The maximum H2S level on the pad is 625 ppm from well 3H-16A(10/5/09)but it also is shut-in due to ann-corn issues. All H2S monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling(MPD) techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. 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(i.e. slimhole)will be accomplished utilizing the 23/8"pipe/slip rams. Pressure deployment of the 3" BHA(i.e. bighole)will be accomplished utilizing the 3"pipe/slip rams. The annular / preventer will act as a secondary isolation during deployment and not as a stripper. Well 31-1-10B will have to be killed prior to deploying slotted liner. When running 2%" liner the 23/8"pipe/slip rams will be used for well control, and when running 31/4"liner the rams will be equipped with variable-bore rams (2%"to 3'/2" range) for well control. 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 1979 psi at 6045' MD(5948' TVD, 5882' SSTVD), or 6.4 ppg EMW. . • Expected annular friction losses while circulating: 363 psi (assuming annular friction of 60 psi/1000 ft due to the 4'/2"tubing) • Planned mud density of 8.6 ppg equates to 2660 psi hydrostatic bottom hole pressure at 5948' TVD. Mud hydrostatic pressure alone is expected to be sufficient to overbalance formation pressure near the 3H-10B motherbore. But increased reservoir pressure may be encountered as the laterals are drilled away from the mother bore. • While circulating 8.6 ppg mud,bottom hole circulating pressure is estimated to be 3023 psi or 9.8 ppg ✓ EMW without holding any additional surface pressure. This alone is sufficient to overbalance expected formation pressure in 31-1-10B. 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 be employed for improved borehole stability,but not necessarily for well control. • When circulation is stopped,—360 psi of additional surface pressure will have to be applied to maintain the same borehole pressure as during drilling operations. Page 5 of 6K r � Y!t - May 31, 2011, FINAL KRU 3H-10CL2-02 — Coiled Tubing Drilling Addendum to Summary of Operations All general information relating to the CTD drilling program at 31-1-10B outline in the previously submitted Summary of Operations is relevant to 311-10CL2-02 as well. The updated information that is lateral specific is noted below. Summary of Operations Additional lateral, 3H-10CL2-02, is being added to the 3H-10B coiled tubing drilling (CTD) program after the drilling of 3H-I0C, 3H-IOCLI, 3H-10CL1-01, and 3H-10CL2 has already taken place. While drilling 3H- 10CL2, geologic complexity resulted in a portion of the lateral being drilled out of zone. Therefore, the objective of added lateral 3H-10CL2-02 will be to access portions of the reservoir that were originally planned to be drilled with 3H-10CL2. The 3H-10CL2-02 lateral will kick off from the aluminum billet at 6670' MD from the 3H-10CL2 lateral and target the A2/A3 sands with a 1430' lateral. The hole will be completed with a 23/8" slotted liner to the TD of 8100' MD with an aluminum billet at 6500' MD. Drilling operations will then proceed with the next lateral, 3H-10CL2-01. Remaining Work 1. 3H-10CL2-02 Lateral (A2/A3 sand, north) a. Kick off of the aluminum billet at 6670' MD W b. Drill 2.70" x 3"bi-center lateral to TD of 8100' MD or • c. Run 2%" slotted liner with an aluminum billet from TD up to 6500' 2. 3H-10CL2-01 Lateral(A2 sand, north) d. Kick off of the aluminum billet at 6500' MD D 14- e. Drill 2.70"x 3"bi-center lateral to TD of 7945' MD f. Run 2%" slotted liner from TD up to 6220' MD, up inside the 3'/4" liner Casing Program 3H-10CL2-02: 23/8",4.7#, L-80, ST-L slotted/solid liner from 6500' MD to 8100' MD Directional — See attached directional plan: 3H-IOCL2-02,plan#5 — 3H-10CL2-02: 9550' to property line, 1060' to well 314-12 Page 6 of 6 ORIGINAL July 27, 2011, FINAL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H-10 3H-10CL2-02 Plan: 3H-10CL2-02_wp05 Standard Planning Report 27 July, 2011 rI BAKER HUGHES ORIGINAL vs-' ConocoPhillips or its affiliates I I I Fa P.' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-10 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level ' Project: Kuparuk River Unit MD Reference: 3H-10B:@ 66.60ft(3H-10B:) Site: Kuparuk 3H Pad North Reference: True Well: 3H-10 Survey Calculation Method: Minimum Curvature Wellbore: 3 H-10CL2-02 Design: 3 H-10CL2-02_wp05 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 3H Pad r Site Position: Northing: 6,000,110.73 ft Latitude: 70°24'41.531 N From: Map Easting: 498,655.44ft Longitude: 150°0'39.416 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: -0.01 ° Well 3H-10 Well Position +NI-S 0.00 ft Northing: 6,000,335.43 ft Latitude: 70°24'43.741 N +E/-W 0.00 ft Easting: 498,655.44 ft . Longitude: 150°0'39.417 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 3H-10CL2-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 7/1/2011 16.53 79.90 57,366 Design 31-1-10CL2-02 wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,650.29 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) I 0.00 0.00 0.00 90.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/S +E/-W Rate Rate Rate TFO (ft) (0) (0) (ft) (ft) (ft) (°/100ft) (°/100ft) (1100ft) (0) Target I 6,650.29 92.76 39.63 5,958.52 601.26 1,120.35 0.00 0.00 0.00 0.00 6,670.00 93.00 37.18 5,957.53 616.69 1,132.58 12.47 1.22 -12.43 -84.34 6,745.00 85.20 41.68 5,958.70 674.55 1,180.16 12.00 -10.39 6.00 150.00 6,820.00 93.90 44.01 5,959.29 729.48 1,231.10 12.00 11.59 3.10 15.00 6,900.00 86.54 37.84 5,958.98 789.86 1,283.45 12.00 -9.20 -7.71 220.00 7,120.00 89.78 11.63 5,966.18 987.82 1,374.59 12.00 1.47 -11.92 276.50 7,245.00 87.34 26.43 5,969.34 1,105.62 1,415.21 12.00 -1.95 11.84 99.50 7,320.00 95.05 31.07 5,967.78 1,171.29 1,451.23 12.00 10.29 6.19 31.00 7,465.00 94.82 13.61 5,955.20 1,304.39 1,505.92 12.00 -0.16 -12.04 270.00 7,590.00 87.26 26.57 5,952.93 1,421.43 1,548.75 12.00 -6.05 10.37 120.00 7,720.00 90.04 11.22 5,956.01 1,544.01 1,590.70 12.00 2.13 -11.81 280.00 7,815.00 100.60 15.54 5,947.22 1,635.89 1,612.51 12.00 11.12 4.55 22.00 7,930.00 86.80 15.54 5,939.82 1,746.19 1,643.18 12.00 -12.00 0.00 180.00 8,100.00 87.00 35.97 5,949.12 1,898.27 1,716.54 12.00 0.12 12.02 90.00 I 7/27/2011 5:28:19PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips or its affiliates F1` ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-10 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-10B:@ 66.60ft(3H-10B:) Site: Kuparuk 3H Pad North Reference: True Well: 3H-10 Survey Calculation Method: Minimum Curvature Wellbore: 3H-10CL2-02 Design: 3 H-10CL2-02_wp05 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) 6,650.29 92.76 39.63 5,958.52 601.26 1,120.35 1,120.35 0.00 0.00 6,000,936.43 499,775.79 TIP 6,670.00 93.00 37.18 5,957.53 616.69 1,132.58 1,132.58 12.47 -84.34 6,000,951.85 499,788.01 KOP 6,700.00 89.88 38.98 5,956.77 640.29 1,151.07 1,151.07 12.00 150.00 6,000,975.45 499,806.51 6,745.00 85.20 41.68 5,958.70 674.55 1,180.16 1,180.16 12.00 150.05 6,001,009.70 499,835.60 3 6,800.00 91.58 43.39 5,960.24 715.04 1,217.30 1,217.30 12.00 15.00 6,001,050.18 499,872.75 6,820.00 93.90 44.01 5,959.29 729.48 1,231.10 1,231.10 12.00 14.95 6,001,064.62 499,886.55 4 6,900.00 86.54 37.84 5,958.98 789.86 1,283.45 1,283.45 12.00 -140.00 6,001,124.98 499,938.90 5 7,000.00 87.96 25.91 5,963.80 874.52 1,336.10 1,336.10 12.00 -83.50 6,001,209.63 499,991.56 7,100.00 89.47 14.01 5,966.05 968.32 1,370.16 1,370.16 12.00 -82.93 6,001,303.41 500,025.63 7,120.00 89.78 11.63 5,966.18 987.82 1,374.59 1,374.59 12.00 -82.66 6,001,322.91 500,030.07 6 7,200.00 88.20 21.10 5,967.59 1,064.48 1,397.10 1,397.10 12.00 99.50 6,001,399.55 500,052.59 7,245.00 87.34 26.43 5,969.34 1,105.62 1,415.21 1,415.21 12.00 99.33 6,001,440.68 500,070.71 7 7,300.00 93.00 29.83 5,969.18 1,154.10 1,441.13 1,441.13 12.00 31.00 6,001,489.15 500,096.63 7,320.00 95.05 31.07 5,967.78 1,171.29 1,451.23 1,451.23 12.00 31.01 6,001,506.35 500,106.74 8 7,400.00 94.98 21.43 5,960.77 1,242.68 1,486.44 1,486.44 12.00 -90.00 6,001,577.72 500,141.96 7,465.00 94.82 13.61 5,955.20 1,304.39 1,505.92 1,505.92 12.00 -90.84 6,001,639.42 500,161.45 9 7,500.00 92.71 17.25 5,952.90 1,338.05 1,515.21 1,515.21 12.00 120.00 6,001,673.07 500,170.74 7,590.00 87.26 26.57 5,952.93 1,421.43 1,548.75 1,548.75 12.00 120.24 6,001,756.43 500,204.29 10 7,600.00 87.47 25.39 5,953.38 1,430.41 1,553.12 1,553.12 12.00 -80.00 6,001,765.41 500,208.67 7,700.00 89.60 13.58 5,955.95 1,524.48 1,586.40 1,586.40 12.00 -79.95 6,001,859.47 500,241.96 7,720.00 90.04 11.22 5,956.01 1,544.01 1,590.70 1,590.70 12.00 -79.64 6,001,879.00 500,246.25 11 7,800.00 98.93 14.84 5,949.76 1,621.62 1,608.64 1,608.64 12.00 22.00 6,001,956.60 500,264.21 7,815.00 100.60 15.54 5,947.22 1,635.89 1,612.51 1,612.51 12.00 22.28 6,001,970.86 500,268.09 12 7,900.00 90.40 15.54 5,939.09 1,717.30 1,635.15 1,635.15 12.00 -180.00 6,002,052.26 500,290.73 7,930.00 86.80 15.54 5,939.82 1,746.19 1,643.18 1,643.18 12.00 -180.00 6,002,081.15 500,298.77 13 8,000.00 86.83 23.95 5,943.72 1,811.91 1,666.77 1,666.77 12.00 90.00 6,002,146.86 500,322.37 8,100.00 87.00 35.97 5,949.12 1,898.27 1,716.54 1,716.54 12.00 89.53 6,002,233.20 500,372.15 TD 7/27/2011 5:28:19PM Page 3 COMPASS 2003.16 Build 69 ORG1NAL • r- ConocoPhillips or its affiliates VC ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-10 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-108:@ 66.60ft(3H-10B:) Site: Kuparuk 3H Pad North Reference: True Well: 3H-10 Survey Calculation Method: Minimum Curvature Wellbore: 3H-10CL2-02 Design: 3H-10 CL2-02_wp05 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3H-10CL2-02 T1 0.00 0.00 5,958.00 772.80 1,268.01 6,001,107.93 499,923.46 70°24'51.341 N 150°0'2.244 W • -plan misses target center by 1.37ft at 6876.98ft MD(5958.02 TVD,771.92 N,1269.06 E) -Point 3H-10CL2-02 T6 0.00 0.00 5,939.00 1,681.74 1,634.00 6,002,016.71 500,289.57 70°25'0.279 N 149°59'51.509 W -plan misses target center by 8.56ft at 7865.56ft MD(5940.56 TVD,1684.15 N,1625.93 E) -Point 31-I-10CL2,L2-01 Polygc 0.00 0.00 0.00 519.44 551.70 6,000,854.72 499,207.18 70°24'48.850 N 150°0'23.244 W -plan misses target center by 5986.15ft at 6650.29ft MD(5958.52 TVD,601.26 N,1120.35 E) -Polygon Point 1 0.00 519.44 551.70 6,000,854.72 499,207.18 Point 2 0.00 130.51 1,039.84 6,000,465.74 499,695.20 Point 3 0.00 420.58 1,187.79 6,000,755.76 499,843.19 Point4 0.00 1,098.72 1,510.66 6,001,433.77 500,166.15 Point 5 0.00 1,734.83 1,692.53 6,002,069.78 500,348.11 Point 6 0.00 2,007.88 1,791.48 6,002,342.79 500,447.10 Point 7 0.00 2,114.82 1,485.42 6,002,449.77 500,141.09 Point8 0.00 1,048.58 923.61 6,001,383.74 499,579.15 Point 9 0.00 519.44 551.70 6,000,854.72 499,207.18 3H-10CL2-02 T3 0.00 0.00 5,970.00 1,154.54 1,430.61 6,001,489.60 500,086.11 70°24'55.095 N 149°59'57.475 W -plan misses target center by 9.38ft at 7295.43ft MD(5969.40 TVD,1150.13 N,1438.86 E) -Point 3H-10CL2 Fault 1(copy: 0.00 0.00 5,957.00 1,399.65 1,390.65 6,001,734.69 500,046.20 70°24'57.505 N 149°59'58.645 W -plan misses target center by 137.86ft at 7510.68ft MD(5952.46 TVD,1348.21 N,1518.47 E) -Polygon Point 1 5,957.00 1,536.51 724.55 6,001,871.65 499,380.19 Point 2 5,957.00 1,399.65 1,390.65 6,001,734.69 500,046.20 Point3 5,957.00 1,089.73 1,865.77 6,001,424.71 500,521.22 Point4 5,957.00 1,399.65 1,390.65 6,001,734.69 500,046.20 3H-10CL2-02 T5 0.00 0.00 5,956.00 1,552.95 1,591.80 6,001,887.94 500,247.36 70°24'59.013 N 149°59'52.747 W -plan hits target center -Point 3H-10CL2-02 T2 0.00 0.00 5,966.00 991.23 1,368.23 6,001,326.31 500,023.71 70°24'53.489 N 149°59'59.305 W -plan misses target center by 6.95ft at 7121.47ft MD(5966.19 TVD,989.27 N,1374.89 E) -Point 3H-10CL2-02 T4 0.00 0.00 5,952.00 1,323.05 1,521.89 6,001,658.08 500,177.42 70°24'56.752 N 149°59'54.798 W -plan misses target center by 10.80ft at 7487.40ft MD(5953.58 TVD,1326.00 N,1511.62 E) -Point 3H-10CL2-02 T7 0.00 0.00 5,949.00 1,896.21 1,715.32 6,002,231.15 500,370.93 70°25'2.388 N 149°59'49.123 W -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (,') 6,280.00 5,985.27 3-1/2" 3-1/2 4-1/8 8,100.00 5,949.12 2-3/8" 3 3 7/27/2011 5:28:19PM Page 4 COMPASS 2003.16 Build 69 OR ! N , _ 1.' ConocoPhillips or its affiliates VS ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-10 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H-10B:@ 66.60ft(3H-10B:) Site: Kuparuk 3H Pad North Reference: True Well: 3H-10 Survey Calculation Method: Minimum Curvature Wellbore: 3 H-10CL2-02 Design: 3 H-10CL2-02_wp05 I Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 6,650.29 5,958.52 601.26 1,120.35 TIP 6,670.00 5,957.53 616.69 1,132.58 KOP I 6,745.00 5,958.70 674.55 1,180.16 3 6,820.00 5,959.29 729.48 1,231.10 4 6,900.00 5,958.98 789.86 1,283.45 5 7,120.00 5,966.18 987.82 1,374.59 6 7,245.00 5,969.34 1,105.62 1,415.21 7 7,320.00 5,967.78 1,171.29 1,451.23 8 7,465.00 5,955.20 1,304.39 1,505.92 9 7,590.00 5,952.93 1,421.43 1,548.75 10 7,720.00 5,956.01 1,544.01 1,590.70 11 7,815.00 5,947.22 1,635.89 1,612.51 12 7,930.00 5,939.82 1,746.19 1,643.18 13 8,100.00 5,949.12 1,898.27 1,716.54 TD 1 I 7/27/2011 5:28:19PM Page 5 • COMPASS 2003.16 Build 69 ORIGINAL • o W \ i 1 co J /111 I 1 00 r W, I 1 Ln I N 14,g X Il./ f. 8 O ti ISI, O `\ ._...... -O h pp m - O rn CT I \ 1 1 _• FO I I I I 1 r' / M;441 .. 0 _ _ _ h I I I 1 „ l lso Z —M 1 I 1� / / "0 s....., .-. 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U pV #O W a co o CD CD N'7'd" o 0 =O ZOj/co 7k (00 -' •-' v)N 1n O N [O v (V O U co co Q CO cr., p c- M I to N/;�) co O N V co M cm a) U)t 1� M o OO) a ( s N ORIGiNAL Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, July 27, 2011 9:29 AM To: 'Long, Jill W Cc: 'Eller, J Gary' Subject: RE: Request for Verbal Approval: 3H-10CL2-02 Jill, You have verbal approval to add the lateral 3H-10CL2-02 as shown in the attached diagram. Submit a PTD as soon as possible per 20 AAC 25.015 (b). Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Long, Jill W [mailto:Jill.W.Long@conocophillips.com] Sent: Wednesday,July 27, 2011 8:42 AM To: Schwartz, Guy L(DOA) Subject: Request for Verbal Approval: 3H-10CL2-02 Guy- To follow up to our phone call yesterday evening, ConocoPhillips' requests verbal approval to add an additional lateral to the current 3H-10 CTD program. The unplanned lateral is requested in order to pick up pay that was missed while drilling 3H-10CL2 due to unexpected geologic faults and dips. This new, added lateral will be named 3H-10CL2-02. The attached schematic should help visually describe where the lateral would be added. Please give me a call if you have any questions. Thanks, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-230-7550 Fax: 918-662-6330 7/27/2011 Ns. S zv N N.0 T L O` C 3 O mm I 71 0) .t.. U O m V co a) 48 -o N r p. to U C E C m al N 222 O _C �C m m t N -0 0_ y a 01 C a_ ivo o mY C oCD L n o - a) N N a) d O_ E 7 U C 5 m o 7 Q) N J - a 0 0 C C (6 co o N m a J di a) ms d y 1° U = • p• o .r i C 'O = O • T M C O o O L _ 3 •a O m a IS` 0 N J N U o m � N = j -1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME ' � C/ / c PTD# 2 / /Coq-o, -o, V Development Service Exploratory Stratigraphic Test Non-Conventional Well • o FIELD: Vtr 0-1 ' �L- 1 L POOL: f 2_.. �-C �L ( Q�a u 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 (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to 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. 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