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210-171
Image Project Well HistoryFile Cover Page g XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. al. Q - 17/ Well History File Identifier don Two-sidedJIIIIOrganizing� e> ❑ Ill111111 IIII ❑ Rescan Needed III II'I II 1 Jill III II, RE AN DIGITAL DATA OVERSIZED (Scannable) C for Items: ❑ Di kettes, No. ❑ Maps: Greyscale Items: Other, No/Type:CNo' a„ ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 6/2114 /s! r4p Project Proofing 1111111 VIII VIII BY: Cri\Lari0 Date: Ic ` Is! nqf Scanning Preparation ' x 30 = 30 + .2I = TOTAL PAGES 57 (Count does not include cover sheet) BY: Date: 10 . Is! ii Production Scanning III 1111111111111111 Stage 1 Page Count from Scanned File: J' (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: 1/YES NO gyp/ BY: 40__ Date: /14 /s! Mr° Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Is/ Scanning is complete at this point unless rescanning is required. 1 1 111111 11111 11 111 ReScanned Ill IIIIIiiIiJl 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked II (11111111 1111111 III o .� c I m 1 co o n �_ N Z � a cc I, A o p >- cm 9y C7 C7 C7 p Et'. z U) >. co E a a 2 co o 0 a) g of 2 2 c lc Zo U 0 0 >> ppm a co c 2 1- 2n. rn �1 a m � S m i O 0 > .- .- J co 4. u N N O O O O F, 1 Z E c N 2 a) C C C C C C w E d E co Il a Y OU 0 0 0 0 0 0 0 0 Ii - C- w V coCa 0. co co co co M co O co co o ^ r- r- N- n n g y Z i U y rn rn rn rn rn rn a•+ J 111 O C 2 a)O M M M N N Z Ce U m co co ao a) co co v W 2 9 J a) U v 0o Z c d o o • 0 I z H cn re Z O C y = I N o J a m ! A = m saN o ZI 2 o N N w QE a) rno o N U) In V170 E JN ti U 44t 0) m G H G > C.4 I li Z CO ce• - ,i c v/ ce < m II Y o I I I Q o a � zlw i Q m 0 o - Z 2 .N .N .y co v 0 co Q' ce cc co Z 7 C C C C C p i� N a) O O O O O 1 • co E E 'V 0 o o c� m c Cc7 z a.D Ce Z a) N c c c_ m w 0 p p — — — p os Z o p Z o m `m O £ oft T ;•••-• p J w u) .0 w m z E o c13 E) ~ d N R 7 N 2 } } 3 N 1 ZO O « W O Z d O 0 O Q C a7 .. £ y Z > p O O v c o)C Q in Z Q v co \w ^ WOi LL d Zy (� d , O co ` C=J 1- d - 0,., rn rn m - 0 m E E m p w Q a m rn..' o. p o 0 o p d O t c a) o o G CL 0 I� 3 J 0 H ` W J J J W — Q 0 <CL 0 U WA& BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME IB-19L1 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 01/17/2011 TODAYS DATE: 03/31/2011 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. RECEIVED (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? APR 0 2011 Maio Caw COMPANY FIELD FINAL ( CD digital/ 680 ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #OF I'KIN I #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. 1 NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCc 1 1 I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 � 4 Chevron/KRU REP T 1 I 1 I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I 1 State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 CC)Anchorage,Alaska 99501-3510 jib C`-'— I 1 1 aOt _ 1 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development E • 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.: January 17,2011 • 210-171 / 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 January 3,2011 50-029-22475-60 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 501'FNL,351'FEL,Sec.9,T11N,R10E, UM January 7,2011 1B-19L1 • Top of Productive Horizon: 8.KB(ft above MSL): J1 34'RKB t 15.Field/Pool(s): 215'FSL, 1993'FWL,Sec.9,T11N,R10E,UM GL(ft above MSL): .102'AMSL . $nil Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 201'FSL, 1956'FWL,Sec.9,T11N,R10E,UM 9593'MD/6286'ND Kuparuk River Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-550089 . y- 5969647 • Zone-4 • 9773'MD/6316'TVD • ADL 25651,25648 TPI: x-547194 y- 5965064 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-547156 y- 5965050 Zone-4 nipple @ 1892'MD/1769'ND 469,466 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) 1800'MD/1700'ND 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 • 8386'MD/6260'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE ' AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 42' 121' 42' 121' 24" 195 sx AS I 7.625" 29.7# L-80 41' 5313' 41' 4053' 9.875" 790 sx AS III,310 sx Class G 5.5" 17# L-80 39' 8279' 39' 6181' 6.75" 225 sx Class G 5" 18# L-80 8279' 8928' 6181' 6704' 6.75" included above 2-3/8" 4.6# L-80 8385' '' 9593' / 6260' 6286' 3" slotted liner 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MDITVD) 3.5" 8288' none 8737'-9592'MD 6285'-6286'ND alternating solid/slotted liner 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cement retainer @ 8570' 13 bbls 15.8 Class G AS.....t C.4,1- Si z • C 3.5-rf 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) January 30,2011 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 2/2/2011 18 hours Test Period--> 763 1488 608 176 Bean 2141 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 140 psi 1175 24-Hour Rate-> 943` 2020 803 24' 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+ND 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 lahorat20(gngjy)ji al resul 0 1. VED ' l NON£' _;4, ; FEB 16 2011 RBDMS FEB 16 2011 . --***---liosiss Off &Gas Cons.Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE3 9 '( S-u�fMII original only/0.5.11.4 28. GEOLOGIC MARKERS(List all formations and marke,,...ncountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ 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 1800' 1700' needed,and submit detailed test information per 20 AAC 25.071. Top B 8418' 6282' Top B/Base C sand 8753' 6281' Top B 9730' 6302' N/A Formation at total depth: Kuparuk B 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: JamesJOhlinger @ 265-1102 y,G. Printed Na V. a Title: Alaska Wells Manager J Signature Phone 263-4619 Date )�1�) 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 .. -e�,r KUP 1 B-19L1 �-,,,Mw .W' n 4'I'ftt1. ±t r' �.+S S �KJ�� ., Welt Attributes Max Angle&MD I TD P-- 37 Wellbore APBUWI Field Name Well Status Incl(") MD(ftK6) Act Btm((MB) ' tacvlhm o 500292247560 �KUPARUK RIVER UNIT _ 4,1404) 103/6 86/0.28 9-77"5.0 _ Comrnent H2S(ppm) iDate Annotation End Date KB-Grd(ti) Rig Release Date SSSV:NIPPLE 65 1 8/6/2009 Last WO- 1 2l.2011 40 81 5 5 1994 .N.44.Cener-t-1 112'Y1.01,t 10.33.93 AM — .-. . Schenlaec Amra[___ Annotation [Depth(Man End Date 'Annotation Last Mod End Date Last Tag:RKB 8,450.0 12/13/2010 Rev Reason:Sidetrack Laterals,GLV C/O 1 Imosbor 1/29/2011 Casing Strings -.. - _ --_ Casi Description String0... StringID...TopftKB Set Depth f Set Depth VD StringWt...StringStringTop Thrd ..� � rt9 i l ) P (... P ( )... ... Liner L7 23/8 / 1995._. 8,385.1 9,593.0 6,286.3 460 L-80 STL Liner Details I Top Depth. slYi Si„ta4eeHfcA178 11 ,�,. - (ND) Top Incl Nomi... _Top(ftKB) WM) C) Item Description Comment ID(In) 4 8,385.1 6,259.8 38.29 DEPLOY DEPLOYMENT SLEEVE(2.626"OD,1.995"ID,GS profile x STL) 1.995 Perforations&Slots ai Iiirt Shot Top(TVD) Btm(TVD) Dens Top(ftKB) Bim(ftKB) (ftK6) (ftKB) Zone Date (ah- Type Comment 8,737.0 9,592.0 6,285.1 6,286.2 1/7/2011 32.0 SLOTS Alternating solid/sloped pipe- 0.125"x2.5"@ 4 circumferential tial rows,3"centers staggered 42-121 . 18 deg,3'non-slotted ends IF Notes:General&Safety NIPPLE,1,891 End Date Annotation WROP,1,891i. 611012()10ll NOTE:View Schematic w Alaska Schematic9.0 1/18/2011 NOTE:CTD LATERALS 1B-19L1,L1-01,L1-02 - - —� - 111/ GASLIFT, 3,157 11. GAS LIFT, __— 5,081 .. IF 3 SURFACE, ''. 41-5,313 GAS 16..1:;16 1 Isk 6.516 w. GAS L,523IFT, 7 rrGAS LIFT _ V. 8,116 NIPPLE.8,167--'- ''--- a. Er 7.1 �--, LOCATOR, ___.. -:'' 6,274 SEALASSY,_____.. 8,275 WHIPSTOCK. `k. x sy 3" n `. ..�C)` g � ::. ?r. 8,368 IMandreiDetails ,;,^� :' ..,z; w,,- Top Depth Top Pmt WHIPSTOCK, (TVD) Incl OD Valve Latch Stze TRO Run 8.386 '' SOI Tog(ftKB) (HKB) (�) Make Model (In) Beim Type Type (in) (W9 Run We Can... (PERF, -. 2604.4 50.62 CAMCO KBG-2 ligGAS LIFT GLV DK-1 0.156 1,240.0 1262011 8,372-8,416 [ I 1 3,15/A FRAC,8,372 2 5,081 0 3,901 7 49.40 CAMCO KBG-2 GAS LIFT GLV :DK 1 0156 1,215.0 1/26/2011 PRODUCTION 5.5x.5", 3 6,515.8 4,900.9 40.41 CAMCO KBG-2 GAS LIFT GLV DK-1 0.188.1,228.01/262011 39$,928 4 7,522.7 5,636.2 42.69 CAMCO KBG-2 III GAS LIFT GLV DO-1 0.188 1,207.0 1/27/2011 5 8,115.7 6,059.6 43.88 CAMCO KBG-2 1 GAS LIFT OV BIM 0.188 0.0 1/27/2011 SLOTS, 8,737-9,592 swumtt 4.11:0U Liner Lt, H H 6,3Liner 93 9,773 M N co M m g C N J J c0 N N O 2 J io p p q Oto to F- O J N O v m o CO rn g o w co 0 mom N N 2 a7 0 in N U O - t` 10 C N O CO E Q D in ^, ,- v 0 O CO CV @ll a0 O 04 g C CV C6 co lij C) EN H -0,._ 2 N •o n g w t. c0 m E `‘\ o co D \ • I— a7 a J 3 v Q co O Q O N J Q CO 4t E C N A i m of U X A 0 N N N N N O �i ,J /://.7c 0 ii 3 I inDc i � � //// moo . 4 . :, . , , ,..1/4 3Lc I � o / Qo , CO73 CL LO H COCD Q co Q 11—C i!gi r , . . _ . ,,,, _ Ji N Pit- i\ a xr 0 n. i5 a CZ l9VI o oll Irt V(b ±', .moco i. 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In V[[ �y of to m m m M C cc N U) N O M C (O (O N O d' 0 Qj .>+ O 8 ,982 ° 0 0 0 0 O O O O C O O N O —_ U) M C 0 (O m N U) (O ° C N O M (D m N U) 00 M N P /6 U O C >� �, �' N N CO. M M C C C (O U) U) u7 U) UJ U) N N P s*4 2 d _ _0 C) C mm m m m m Cr; m m m m m m m m m m m 0 U 0 a. f!J � `'S 0 fA 1B-19 Pre-Rig Well Work •DATE 'SUMMARY 12/1/10 PULLED PACKOFF @ 1891' RKB. PULLED SOV @ 8116' RKB& REPLACED WITH DV. PULLED BALL& ROD & RHC PLUG BODY @ 8167' RKB. MIT'd IA, GOOD. TAGGED @ EST. 8691' RKB. IN PROGRESS. 12/2/10 DRIFTED TBG WITH 19' x 2.70" DUMMY WHIPSTOCK TO 8275'. READY FOR E-LINE. 12/3/10 PERFORMED MIT 24 ARM CALIPER LOG FROM A TAG DEPTH OF 8694'TO SURFACE. WELLBORE DEBRIS AND ENCOUNTERED AT TAG DEPTH. METAL SHAVINGS RETRIEVED OF TOOL STRING AT SURFACE. 12/13/10 SET WEATHERFORD 2.5 INFLATABLE RETAINER AT 8570 RKB, PUMPED 13 BBLS 15.8 CEMENT THROUGH RETAINER AND 2 BBLS ON RETAINER. TARGET TOC AT 8450 RKB, WELL IS FREEZE PROTECTED TO 3000 FT. 12/15/10 RAN 19' DUMMY WHIP STOCK, TAG @ 8531' SLM. 12/23/10 PRE-CTD PT& DD TEST MV-PASSED; SSV-PASSED; SV-PASSED • ConocoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 1B-19 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 12/31/2010 12:00:00 PM Rig Release: 1/17/2011 6:00:00 PM Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 12/28/2010 24 hr Summary Preform rig maintenance while waiting on weather at 2X pad. 00:00 00:00 24.00 MIRU MOVE OTHR T Wait on weather 12/29/2010 00:00 00:00 24.00 MIRU MOVE MOB T Waiting on weather at 2X pad. 12/30/2010 Moved rig from 2Z-23 to 1B-19 00:00 06:00 6.00 MIRU MOVE MOB T Blow down rig,Order trucks to move. 06:00 10:00 4.00 MIRU MOVE MOB P Order trucks for rig move 10:00 15:30 5.50 MIRU MOVE MOB P Load shop,MU rigs to sows,pull rig off well 15:30 17:00 1.50 MIRU MOVE MOB P Mobilize rig to 1B 17:00 18:00 1.00 MIRU MOVE MOB P Crew Change, 18:00 00:00 6.00 MIRU MOVE MOB P Spot rig over 1B-19, RU 12/31/2010 MIRU,pump slack and rehead CT,test BOP 00:00 01:30 1.50 MIRU MOVE MOB P MIRU 01:30 04:00 2.50 MIRU MOVE NUND P NU BOP Stack 04:00 06:00 2.00 MIRU MOVE RURD P Complete post rig checklist 06:00 07:00 1.00 MIRU MOVE CIRC P Load seawater onto rig. 07:00 10:30 3.50 MIRU MOVE CIRC P Change stripper rubber.Circulate SW thorughout rig to warm up. Displace CT with SW. Reverse circulate down CT for slack management. Pressure test inner reel valve and Stripper 10:30 12:00 1.50 MIRU MOVE CTOP P Lift off well,Cut back CT 2',finding E-line.MU CTC,pull test 30K. BHI MU drilling head, 12:00 00:00 12.00 MIRU WHDBO BOPE P Start BOP testing.AOGCC witnessing waived by Bob Noble+ O ***Rig Accept** 01/01/2011 Completed BOP testing. Picked up BHA#1 and discovered short in E-line,Cut 875'of coil, Pumped Slack and rehead CT and E-line. 00:00 01:00 1.00 MIRU WHDBO BOPE T C15 Nabors 1 hour Non billable rig repair rate Page 1 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 04:00 3.00 MIRU WHDBO BOPE P Pull BPV Nabors billable operating rate 04:00 06:00 2.00 MIRU WHDBO BOPE T Change out B8 HCR Nabors 2 hours non-billable rig repair rate 06:00 07:30 1.50 MIRU WHDBO BOPE P Pressure test Tiger tank line and PDL. 07:30 08:30 1.00 PROD1 RPEQPI DISP P Open well to bleed WHP to Tiger tank.270 psi.Well continues to build up pressure. 08:30 08:45 0.25 PROD1 RPEQP1SFTY P PJSM, 08:45 10:30 1.75 PROD1 RPEQPI PULD P Deploy BHA 1,dummy whipstock 10:30 12:30 2.00 PROD1 RPEQPI PULD T Diagnose short 12:30 17:00 4.50 PROD1 RPEQP1SLPC T Short in Eline.start cutting CT back to find short 17:00 20:48 3.80 PROD1 RPEQP1SLPC T Cut total of 880'of Coil and e-line. Dress end of CT and e-line for slack management, no e-line movement. Confirm e-line is good. 20:48 21:48 1.00 PROD1 RPEQP1SLPC T Install CTC and pull test 21:48 22:48 1.00 PROD1 RPEQP1SLPC T Install Inteq Coil-trac UQC 22:48 00:00 1.20 PROD1 RPEQP1PULD T Deploy BHA#1, Dummy WS run 01/02/2011 Ran dummy whipstock to 8550 tag and displaced well to used flo-pro. Wait on weather from 0600 00:00 02:12 2.20 0 8,250 PROD1 RPEQPI TRIP P RIH taking returns to TT 02:12 02:30 0.30 8,250 8,280 PROD1 RPEQPI DLOG P Tie in to K1 marker,+1.5' 02:30 02:42 0.20 8,280 8,550 PROD1 RPEQP1TRIP P Continue RIH(17K RIVV)and tag at 8550' 02:42 05:42 3.00 8,550 0 PROD1 RPEQP1TRIP P POOH displacing well to used 9.6 ppg flo-pro, 37K PUW 05:42 05:54 0.20 0 0 PROD1 RPEQP1 OWFF P At surface. Flow check. 05:54 00:00 18.10 0 0 PROD1 RPEQP1OTHR T Phase 3,wait on weather 01/03/2011 Wait on weather until 0500. Set whipstock at 8386'TOWS,Milled window. 00:00 05:00 5.00 0 0 PROD1 RPEQPI OTHR T Waiting on weather, Phase 3 conditions between KRU and Deadhorse are preventing the BOT hand from traveling to the rig 05:00 06:00 1.00 0 0 PROD1 RPEQP1PULD P Lay down dummy whipstock BHA 06:00 06:30 0.50 0 0 PROD1 RPEQPI SFTY P Crew change PJSM 06:30 08:30 2.00 0 0 PROD1 RPEQP1PULD P PU/MU tools and 3-1/2"x 5"BOT TT Whipstock 08:30 11:00 2.50 0 8,290 PROD1 RPEQP1TRIP P RIHw/whipstock 11:00 11:15 0.25 8,290 8,278 PROD1 RPEQPI DLOG P PUH,Tie in depth to K1,Correct+4 11:15 11:30 0.25 8,278 8,484 PROD1 RPEQP1DLOG P RIH for CCL log, PUH for CCL log 11:30 12:45 1.25 8,484 8,484 PROD1 RPEQP1DLOG T CCL not working. Diagnose. Page 2 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:45 13:15 0.50 8,484 8,326 PROD1 RPEQPI DLOG P PUH 11 FPM for CCL log 13:15 13:30 0.25 8,326 8,386 PROD1 RPEQP1TRIP P RIH to 8425'. PUH 33K, to 8399'bit ,? depth,8386 TOWS.Close EDC, Onlie with pumps,Set WS 30K CTW,CTP 2800.Set down 1.5K.WS set. 13:30 15:30 2.00 8,386 0 PROD1 RPEQP1TRIP P POOH 15:30 15:48 0.30 0 0 PROD1 RPEQP1SFTY P At surface, monitor well for flow. PJSM 15:48 16:48 1.00 0 0 PROD1 RPEQPI PULD P Lay down BHA 16:48 17:48 1.00 0 0 PROD1 WHPST PULD P PU milling BHA,straight motor, string mill,window mill. 17:48 19:48 2.00 0 8,270 PROD1 WHPST TRIP P RIH 19:48 20:00 0.20 8,270 8,300 PROD1 WHPST DLOG P Tie-in,+6.5' 20:00 00:00 4.00 8,386 8,393 PROD1 WHPST MILL P Dry tag WS at 8386', PUH and start pump at 1.3 BPM,3500 CTP,390 DP at motor. Started seeing motor work at 8388'but no WOB until 8389.26'. Start at 1 FPH 90 PSI motor work and 0.1K WOB. Slowly increase WOB to 2K and motor work to 300 psi at 1 FPH 01/04/2011 Complete window exit. Drill build to 8650', Log RA marker @ 8393.5,TOW=8389, BOW=8396 00:00 03:00 3.00 8,393 8,397 PROD1 WHPST MILL P Continue milling window, 1.3 BPM, 3500 CTP, 1 -2K WOB and 250 psi motor work. Appear to have exited at 8394'. Continue at 1 FPH until reamer had exited 03:00 04:42 1.70 8,397 8,401 PROD1 WHPST MILL P Milling rat hole, increased ROP to 2 FPH for four feet. 04:42 05:06 0.40 8,401 8,406 PROD1 WHPST MILL P Mill formation 05:06 07:06 2.00 8,406 8,406 PROD1 WHPST MILL P Ream window, Motor work at 8390'. Backream. Motor work not getting better.Thinking we are seeing the fishing slot. 07:06 07:21 0.25 8,406 8,406 PROD1 WHPST MILL P Dry run through window. Looks good 07:21 08:51 1.50 8,406 0 PROD1 WHPST TRIP P POOH 08:51 09:06 0.25 0 0 PROD1 WHPST OWFF P At surface, PJSM, monitor well for flow 09:06 10:36 1.50 0 0 PROD1 WHPST PULD P LD BHA 10:36 12:36 2.00 0 72 PROD1 DRILL PULD P P/U Build BHA with 2.5+AKO and 2.7"Bi-center-Had to work in through wellhead. 12:36 15:06 2.50 72 8,406 PROD1 DRILL TRIP P RIH with EDC closed pumping through bit @.3bpm Tie in with+8ft correction. P/U weight 31K. RIH through window.Slight bobble through window, not a tag. Page 3 of 15 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 15:06 17:42 I 2.60 8,406 8,475 PROD1 DRILL DRLG P Begin drilling build section-1.40 bpm,3400psi, BHP 3870, ECD 12.1, WOB 1K,Ct weight 15K, ROP 30, Rate out 1.25 bpm.Start fluid swap. 17:42 18:36 0.90 8,475 8,475 PROD1 DRILL WPRT P High DLS 50+. PUH to tie in K1 to RA.Confer with town discuss DLS. Tie into K1 for no correction. Log RA marker @ 8393.5'.Top of whipstock 8386',TOW=8389, BOW=8396 18:36 21:42 3.10 8,475 8,595 PROD1 DRILL DRLG P Drill ahead 1.39 BPM @ 3250 PSI FS, RIW=14.5K BHP=3769PSI 21:42 22:42 1.00 8,595 8,625 PROD1 DRILL DRLG P Drill Ahead,AVg DLS=54.7 for last 150' ROP=38FPH 22:42 23:00 0.30 8,625 8,625 PROD1 DRILL WPRT P Wiper trip to window, PUW=32K 23:00 00:00 1.00 8,625 8,650 PROD1 DRILL DRLG P 8625, Drill Ahead 1.38 BPM @ 3150PSI FS BHP=3846 01/05/2011 Complete Build to 8912', Change out to Lateral BHA#5, 1.1 degree motor 00:00 01:06 1.10 8,650 8,692 PROD1 DRILL DRLG P 8650',drill ahead 1.38 BPM @ 3216PSI FS BHP=3863 01:06 01:18 0.20 8,692 8,692 PROD1 DRILL WPRT P BHA wiper, Hard to get Differential pressure Slightly sticky P/U's 36-37K 01:18 01:24 0.10 8,692 8,692 PROD1 DRILL DRLG P 8692 Drilling ahead, 3.2K WOB. Hard/Unable to get drilling 01:24 01:42 0.30 8,692 8,692 PROD1 DRILL WPRT P Wiper to window,tight spot @ 8483' TF Change PUW=37K 01:42 01:54 0.20 8,692 8,800 PROD1 DRILL DRLG P 8692',Drill ahead 28 FPH 1.38 BPM @3192 PSI FS BHP=3847 01:54 04:54 3.00 8,800 8,860 PROD1 DRILL DRLG P 8800, ROP low and erratic, Pump 20 BBIP ill with Drill Zone added. MBT.2 Ib/BBI within specs but could be balled up from silts/clays, pill at nozzel @ 8910 04:54 06:54 2.00 8,860 8,873 PROD1 DRILL DRLG P Continue drilling ahead with irractic ROP from 10-90 fpm. 06:54 07:24 0.50 8,873 8,873 PROD1 DRILL WPRT P Noticed weight loss, P/U and started pulling heavy 42K. Dragging at bit, cleaned up after 50'. Pumped another drillzone sweep while Pulling wiper trip-clean. 07:24 10:54 3.50 8,873 8,912 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3400, ECD 12, ROP 50,WOB 1.2K, Ct weight 9K.Accerite&ankerite in samples, slow ROP 10:54 13:54 3.00 8,912 72 PROD1 DRILL TRIP P TD build section POOH for BHA change. P/U weight 32K.-Clean through window. 13:54 15:54 2.00 72 0 PROD1 DRILL PULD P PJSM-Undeploy Build BHA Page 4 of 15 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:54 17:30 1.60 r 0 72 PROD1 DRILL PULD P PSJM-deploy 1.1 AKO with Bi-center for L1 Lateral drilling BHA#5 17:30 19:42 2.20 72 8,265 PROD1 DRILL TRIP P Trip in well,Set down @3135 GLM, PUH,orient 180 degrees continue in well 19:42 19:54 0.20 8,265 8,286 PROD1 DRILL DLOG P Log GR tie in for a+1'correction, Close EDC Continue into well 19:54 20:24 0.50 8,286 8,912 PROD1 DRILL TRIP P Trip into well,Good pass through window clean run to bottom 20:24 00:00 3.60 8,912 9,000 PROD1 DRILL DRLG P 8912', Drill ahead 1.39 BPM @ 3147 PSI FS RIW=12k,WOB=2.2k. Ratty drilling with low ROP Midnight depth 9000' 01/06/2011 Drilled 9000 to 9654', Encountered fluid loss @9610-30 BPH.Total losses for 24 hours= 170 bbls 00:00 01:54 1.90 9,000 9,060 PROD1 DRILL DRLG P 9000',Drill ahead 1.39 BPM @ 3147 PSI FS RIW=12k,WOB=2.2k. Ratty drilling with low ROP 01:54 02:42 0.80 9,060 9,060 PROD1 DRILL WPRT P 9060',Wiper to window PUW=28K 02:42 06:57 4.25 9,060 9,210 PROD1 DRILL DRLG P 9060', Drill ahead 1.38 BPM @ 3281 PSI FS BHP=3873, RIW=11.3K with 1.6K WOB 06:57 08:27 1.50 9,210 9,210 PROD1 DRILL WPRT P Wiper trip-33K-Pull into cased hole to adjust binding inside reel. Clean through window. 08:27 11:57 3.50 9,210 9,310 PROD1 DRILL DRLG P Drilling ahead-1.35 bpm,3600, BHP 3850, ECD 12, ROP 9,WOB 2.2K, CT weight 11K-ROP increased @ 9255'to 70 fph 11:57 12:42 0.75 9,310 9,358 PROD1 DRILL DRLG P BHA Wiper due to motor stall-P/U weight 41K-dropped to 32K after 20'. Drilling ahead-ROP 90 fph. 12:42 13:42 1.00 9,358 8,200 PROD1 DRILL WPRT P Wiper trip to window-P/U weight 32K -BHI counter stopped working while tripping out, pull into cased hole and circulate-EDC open 13:42 14:42 1.00 8,200 8,300 PROD1 DRILL CIRC T Work on Injector Counter-repaired- Close EDC. RIH clean through window.Tie in+4ft 14:42 15:12 0.50 8,300 9,358 PROD1 DRILL TRIP P RIH-Wiper trip 15:12 18:00 2.80 9,358 9,442 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3600 psi, BHP 3950, ECD 12.3, ROP 60, WOB 1.3K, Ct weight 12K.9385'- stack a little weight-BHA wiper 39K off bottom-drill ahead. 18:00 18:15 0.25 9,442 9,442 PROD1 DRILL WPRT P Wiper trip while sorting out Alarm. Hi HPU temp 18:15 19:45 1.50 9,442 9,510 PROD1 DRILL DRLG P 9442', Drill ahead 1.38 BPM @ 3600 PSI FS, BHP=3944 Page 5 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:57 1.20 9,510 9,510 PROD1 DRILL WPRT P 9510 Wiper to window PUW=32K 20:57 22:03 1.10 9,510 9,610 PROD1 DRILL DRLG P 9510', Drill ahead 1.38 BPM @ 3624PSI FS RIW=9.9K,WOB=1.8K, BHP=4006 22:03 22:21 0.30 9,610 9,622 PROD1 DRILL DRLG P 9610 drilling ahead, Lost returns 1.38 BPM @ 3624 PSI FS. .2 BPM returns BHP went from 3953 to 3843, PUW=39K.A little heavy but not sticky.Went back to drilling returns healing slowly 22:21 22:57 0.60 9,622 9,654 PROD1 DRILL DRLG P 9322'Drill Ahead, losses @.6 BPM 1.38 @ 3600 PSI FS,BHP=3843 RIW-6K,WOB=1.7k, ROP=60 FPH PUW=40K 22:57 23:45 0.80 9,654 8,435 PROD1 DRILL WPRT P 9654',wiper to window PUW=32K, -.5 BPM losses 23:45 00:00 0.25 8,435 8,890 PROD1 DRILL WPRT P RBIH,Midnight depth 8890' 01/07/2011 Complete wiper to surface, RIH to TD, Lay in liner pill and KWF, P/u Liner 00:00 00:24 0.40 8,890 9,654 PROD1 DRILL WPRT P Wiper to window(cont.) Clean trip out and in 00:24 02:54 2.50 9,654 9,715 PROD1 DRILL DRLG P 9654', Drill Ahead 1.38 BPM @ 3595 PSi FS, .75 BPM returns BHP=3882, ECD=11.95 02:54 03:00 0.10 9,715 9,715 PROD1 DRILL DRLG P BHA Wiper, PUW=38K 03:00 04:15 1.25 9,715 9,773 PROD1 DRILL DRLG P 9715', Drill Ahead 1.36 BPM @ 3350PS1 FS Returns=.76 BHP=3870, EDC=11.7 04:15 06:30 2.25 9,773 8,350 PROD1 DRILL WPRT P 9773'TD, Low/Hi sweeps coming - 1/ out,Wipe to swab PUW=33k. 1.36 BPM @ 3330 FS .85 BPM Returns BHP=3663 06:30 06:45 0.25 8,350 8,350 PROD1 DRILL LOT P SBHP @ window=start WHP 650 psi, BHP 3755. 15 minute shut in complete=WHP 80, BHP 2890 psi. Slowly leaking down. 06:45 08:45 2.00 8,350 72 PROD1 DRILL WPRT P POOH to swab valves prior to liner run. have a comms failure to BHA @ 7483'-continue to POOH to surface. 64 bbls losses while POOH 08:45 11:45 3.00 72 0 PROD1 DRILL PULD T Bump Up, PJSM break off injector from BHA to inspect Upper connector. Holding MPD @ 550 psi- 1/4 bpm.Short found to be in lower BHA. Complete undeploying. DBV sub had loose inner connections. BHI Downtime 11:45 12:15 0.50 0 0 PROD1 DRILL CIRC P Crew change-M/U new BHA- PJSM Page 6 of 15 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:15 14:00 1.75 0 68 PROD1 DRILL PULD T Deploy New BHA 9 1.1 AKO with Bi-center. No REZ tool.Total of 50 bbls injected during tool swap. BHI Downtime 14:00 18:42 4.70 68 9,773 PROD1 DRILL TRIP P RIH with EDC open-Tie in+2 ft correction-RIH through window to TD-Wipe up to bottom of build-RIH to TD to spot liner pill. 18:42 22:06 3.40 9,773 70 PROD1 DRILL TRIP P POOH laying in 11.5PPG beaded liner running pill,(30BBL) followed with 11.5 PPG KWF, Paint EOP flags @ 8200&6900 22:06 23:00 0.90 70 0 PROD1 DRILL PULD P On surface, Flow check well. PJSM, Lay down BHA#6 L1 Lateral BHA 23:00 23:19 0.32 0 0 PROD1 DRILL BOPE P Bi Weekly function test on BOPE 23:19 23:59 0.68 0 250 COMPZ CASING PUTB P PJSM„Pick up 30 Jts 2 3/8"slotted liner 12 Joints Blank liner Perform BOP safety joint drill-Good drill 01/08/2011 Setdown with L1 Liner @ 9598, POOH shorten liner and set @ 9593,TOL 8385 00:00 01:18 1.30 250 1,354 COMPZ CASING PUTB P Continue to pick up L1 Liner 01:18 02:33 1.25 1,354 1,397 COMPZ CASING PULD P Make up coiltrack to liner,Slide injector to toolstring,Surface test tool 02:33 04:33 2.00 1,397 8,296 COMPZ CASING RUNL P RIH with L1 Liner EDC Closed, .25 BPM 04:33 04:39 0.10 8,296 8,297 COMPZ CASING RUNL P At upper flag,Correct+1'. PUW=33K Continue in hole,Clean trip through window 04:39 06:09 1.50 8,297 9,596 COMPZ CASING RUNL P Set down,just above thief zone/ fault work pipe to index guide shoe. Worked string with multiple speeds, total attempts 22.Tag 9595'Set down 12K @ 9596'. 06:09 06:51 0.70 9,596 9,596 COMPZ CASING RUNL P Crew change, P/U slowly during hand-over. Pump down CT to fill hole &CT.9400'-RIH&try 3 more attempts. No luck. 06:51 09:51 3.00 9,596 1,400 COMPZ CASING TRIP T Set up and pump across the top- POOH to lay down joints. 09:51 11:03 1.20 1,400 1,340 COMPZ CASING PULL T Flo-check @ surface-lay down& break out BHA. 11:03 12:03 1.00 1,340 1,340 COMPZ CASING SFTY P Service top drive and hold PJSM for laying down liner 12:03 13:33 1.50 1,340 800 COMPZ CASING PULL T lay down liner(total 16 joints).safety joint drill. 13:33 16:27 2.90 800 1,250 COMPZ CASING PUTB T P/U 11 joints of solid&2 pups. P/U Coiltrack assembly.Strip over tool. 16:27 18:21 1.90 1,250 8,151 COMPZ CASING RUNL T Trip in well with BHA#8, L1 Liner 18:21 18:51 0.50 8,151 9,593 COMPZ CASING RUNL T Correct At flag for no correction PUW=32K,Continue in well Page 7 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:51 19:03 0.20 9,593 9,593 COMPZ CASING RUNL T Tag bottom,Wt Chk 36K,set back down and pump off GS spear. PUW=31K BOL=9593 TOL=8385 19:03 21:03 2.00 9,593 35 COMPZ CASING TRIP P Trip out of well, Remove liner length from counters 21:03 21:39 0.60 35 0 COMPZ CASING PULD P At surface, Flow check well, PJSM lay down Liner running tools 21:39 22:39 1.00 0 75 PROD2 RPEQP1 PULD P P/U Whipstock, BHA#9-Upper whipstock P/U coil track,Skid injector and make up coil surface test tool,Open EDC i8- 22:39 00:00 1.35 75 6,150 PROD2 RPEQP1TRIP P Trip in well with Whipstock, EDC Open L j"6 01/09/2011 Set whipstock @ 8379.9,TOWS=8367 CTM.Mill widow from 8370.6 to 8376 CTM.Suspend drilling ops due to ULSD supply issues 00:00 00:30 0.50 6,150 8,270 PROD2 RPEQP1TRIP P Trip in with Whipstock(cont) 00:30 00:45 0.25 8,270 8,291 PROD2 RPEQP1 DLOG P GR tie in for+1'correction Close EDC, PUW=33K /r1) Continue in well SI 00:45 00:51 0.10 8,291 8,380 PROD2 RPEQP1WPST P 8379.9,Whipstock set depth, kicij"P Oriented 20R Hydraulic setting tool shifted @ 2500PSI Set down 3K 00:51 02:45 1.90 8,380 65 PROD2 RPEQP1TRIP P Trip out of well 02:45 03:30 0.75 65 0 PROD2 RPEQP1 PULD P On surface, Flow check well. PJSM, Lay down BHA#9 Whipstock setting tools 03:30 04:15 0.75 0 61 PROD2 WHPST PULD P P/U Window milling BHA#10. Straight BOT motor New 2.80 widow mill, Re reun string mill 2.79 No Go,2.8 Go 04:15 06:15 2.00 62 8,300 PROD2 WHPST TRIP P Trip in hole EDC open.Tie in+2.5' 06:15 08:00 1.75 8,300 8,300 PROD2 WHPST CIRC P Circulate out KWF with Milling fluid. Stop pumps,close EDC.Total losses=56 bbls of KWF.Currently 284 bbls on board. 08:00 08:30 0.50 8,300 8,371 PROD2 WHPST MILL P RIH-dry tag pinch point 8371.5' 1K Down. P/U weight 30K, bring pumps onlione @ 1.20 bpm.3050psi. Pinch point 8370.8'with pumps on.Clean ditch magnets. 08:30 10:00 1.50 8,371 8,373 PROD2 WHPST MILL P Start milling window. 1.20 bpm,3000 psi, BHP 3670psi, ECD 11.4. rate out 1.1 bpm. Set 1 fph.-IA 340,OA zero 10:00 14:00 4.00 8,373 8,376 PROD2 WHPST MILL P Getting fine metal cutting back over shakers. Increase ROP to 1.5 fph. 1.20 bpm,3360 psi, BHP 3640, WOB 1.45.Good weight drop off when exiting window. Page 8 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:00 17:00 3.00 8,376 8,386 PROD2 WHPST MILL P Exit window @ 8376'Continue milling 1.5 fph until string mill exits window. Mill additional 10'. Increase formation in samples 5-10%. Backream two passes,very little motor work&dry tag @ 8 fpm. 17:00 18:18 1.30 8,386 8,370 PROD2 WHPST REAM P Tagged early on dry tag @ 8372.4'. 3K. P/U and ream pass area again. Clean Drift Second run down @ 15 fpm. Back ream up slowly during hand-over. 18:18 20:24 2.10 8,370 55 PROD2 WHPST TRIP P POOH following MP schedule 20:24 22:00 1.60 55 0 PROD2 WHPST PULD P At surface, PJSM, PUD BHA#10 widow mill Mill came out 2.80 string reamer 2.79 22:00 00:00 2.00 0 0 PROD2 DRILL OTHR T Suspend Drilling Ops due to Pipeline out of service No ULSD coming to slope 01/10/2011 Resume Drilling, RIH with Build section BHA 2.4 AKO, Log K1 and Tie in RA @ 8375.5', Drill ahead 00:00 06:00 6.00 0 0 PROD2 DRILL OTHR T usoend Drilling Oos due to Pipeline out of service 1 7‘. '1 Potential Potential Diesel shortage. 1^' 06:00 11:00 5.00 0 0 PROD2 DRILL OTHR T Continue waiting for direction on potential fuel shortage. 11:00 11:30 0.50 0 0 PROD2 DRILL SFTY P PJSM with crew to discuss plan forward&normal safety measures still being in place. Commence with Deployment of BHA. 11:30 13:00 1.50 0 71 PROD2 DRILL PULD P P/U build BHA with 2.4 AKO and bi-center bit. 13:00 15:54 2.90 71 8,386 PROD2 DRILL TRIP P RIH pumping.3 bpm.Tie in @ 8270' +0.5 ft. RIH through window. P/U weight 31K. Clean through window. 15:54 18:54 3.00 8,386 8,436 PROD2 DRILL DRLG P Drilling ahead-1.38 bpm,3300, BHP 3730,WOB.8, ROP 20, rate out 1.2 bpm. New mud @ bit. 18:54 19:24 0.50 8,436 8,436 PROD2 DRILL WPRT P Wipe up hole through window and log K1 Marker for+.5'correcrtion. RBIH and log RA Marker in Whipstock. RA marker @ 8375.5'corrected. TOWS=8368, BOW=8376, RBIH to drill 19:24 00:00 4.60 8,436 8,566 PROD2 DRILL DRLG P 8436', Drill Ahead 1.38 BPM @ 3200 PSI FS BHP=3793 No fluid losses,Slow ratty drilling -25 FPH Midnight depth 8566,Avg DLS 45.85 01/11/2011 Drilled build to 8655',trip for BHA and continue drilling lateral to 9212. Lost 220 Bbls.for the day 00:00 00:30 0.50 8,566 8,590 PROD2 DRILL DRLG P 8436', Drill Ahead 1.38 BPM @ 3200 PSI FS BHP=3793 No fluid losses, Slow ratty drilling -25 FPH Page 9 of 15 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:30 00:48 0.30 8,590 8,590 PROD2 DRILL WPRT P Wiper to window, PUW=32K Clean wiper up and down 00:48 02:42 1.90 8,590 8,655 PROD2 DRILL DRLG P 8590', Drill Ahead 1.34 BPM @ 3218PSI FS BHP=3860. 02:42 05:12 2.50 8,655 72 PROD2 DRILL TRIP P 8655', EOB, PUW=32K POOH following MPD. 05:12 06:42 1.50 72 0 PROD2 DRILL PULD P PJSM-Undeploying BHA#11 06:42 08:00 1.30 0 72 PROD2 DRILL PULD P Deploy BHA#12 with 1.0 AKO& Bi-center bit for lateral section. 08:00 11:00 3.00 72 8,270 PROD2 DRILL TRIP P Trip in well, EDC Open 11:00 11:06 0.10 8,270 8,284 PROD2 DRILL DLOG P Log GR tie in, +1',correction,Close EDC PUW=30K 11:06 11:27 0.35 8,284 8,655 PROD2 DRILL TRIP P Continue tripping in to drill,Clean pass through window 11:27 13:09 1.70 8,655 8,810 PROD2 DRILL DRLG P 8655', Drill Ahead 1.36 BPM @ 3700 PSI FS BHP=3902 13:09 13:45 0.60 8,810 8,810 PROD2 DRILL WPRT P Wiper to window PUW=32K 13:45 15:21 1.60 8,810 8,960 PROD2 DRILL DRLG P 8810', Drill ahead 1.36 BPM @ 3600PSI FS BHP=3887. Started taking losses 20 BPH 15:21 16:09 0.80 8,960 8,960 PROD2 DRILL WPRT P Wiper to window, PUW=32.5K 16:09 18:33 2.40 8,960 9,110 PROD2 DRILL DRLG P 8960', Drill ahead / 1.36 BPM @ 3600 PSI FS Maintaining-20 BPH losses 18:33 19:39 1.10 9,110 9,110 PROD2 DRILL WPRT P Wiper trip to window,32K PUW,Tie -in, +2'. Wiper in hole was clean 19:39 21:33 1.90 9,110 9,212 PROD2 DRILL DRLG P Continue drilling, 13.5K RIW, 1.4 BPM,3800 CTP,3900 BHP, losing 15 BPH 21:33 22:33 1.00 9,212 9,212 PROD2 DRILL WPRT P At 9212 stalled and having dificulty getting started again,45K PUW, 15 -20 BPH losses. After 4 attempts to drill ahead decided to do a wiper trip to window. 22:33 00:00 1.45 9,212 9,214 PROD2 DRILL DRLG P Continue drilling, 13.5K RIW, 1.4 BPM,3800 CTP,3900 BHP, losing 15+BPH 01/12/2011 Drilled to TD at 9772', Lost 88 bbls to formation. 00:00 04:54 4.90 9,214 9,360 PROD2 DRILL DRLG P Continue drilling, 13.5K RIW, 1.4 BPM,3800 CTP,3900 BHP, losing- 15 BPH 04:54 06:06 1.20 9,360 9,360 PROD2 DRILL WPRT P Wiper to window 06:06 09:36 3.50 9,360 9,510 PROD2 DRILL DRLG P 9360'Drill Ahead 1.39 BPM @ 3629 PSI FS BHP=3899 Losses-20 BPM 09:36 11:12 1.60 9,510 9,510 PROD2 DRILL WPRT P Wiper to window with tie in,+4' correction PUW=33K Page 10 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:12 13:42 2.50 9,510 9,617 PROD2 DRILL DRLG P 9510', Drill Ahead 1.30 BPM @ 3629 PSI FS BHP=3851, Loss still—20 BPH 13:42 17:00 3.30 9,617 9,660 PROD2 DRILL DRLG P 9617', Drilling ahead,Consult with town, unable to get tool to drop inc. last target may not be obtainable. Drill ahead 180 degree TF 17:00 18:18 1.30 9,660 9,660 PROD2 DRILL WPRT P Wiper trip to window PUW=32.5 K 18:18 21:00 2.70 9,660 9,750 PROD2 DRILL DRLG P Continue drilling ahead, 1.4 BPM, "Sr1/47 3900 CTP, 3950 BHP, 14K RIW i 21:00 21:30 0.50 9,750 9,772 PROD2 DRILL DRLG P Pump low/high vis sweeps while 1 continue to drill to TD at 9772' • 21:30 00:00 2.50 9,772 0 PROD2 DRILL WPRT P Wiper to the swab valve 01/13/2011 Displaced well to KWF, ran liner to 9772'and set anchored liner top aluminum billet at 8680'. Start testing BOP. Lost 133 Bbls of 11.5 PPPG KWF to formation. 00:00 02:00 2.00 0 8,250 PROD2 DRILL WPRT P Wiper to the swab and back 02:00 02:18 0.30 8,250 8,280 PROD2 DRILL DLOG P Tie-in, +0.5' 02:18 03:18 1.00 8,280 9,771 PROD2 DRILL WPRT P Continue wiper to TD 03:18 06:48 3.50 9,771 65 PROD2 DRILL DISP P POOH, lay in liner running pill(30 Bbls)and KWF to surface. Paint EOP flags at 8500'and 7100' 06:48 07:48 1.00 65 0 PROD2 DRILL PULD P At surface, Flo Check well, PJSM to lay down lateral drilling BHA#12 07:48 08:33 0.75 0 0 COMPZ CASING PULD P Rig up floor to run liner 08:33 10:33 2.00 0 1,092 COMPZ CASING PUTB P M/U Eller guide shot with 33 joints of slotted liner and anchored aluminum billet 10:33 12:18 1.75 1,092 1,092 COMPZ CASING PULD P M/U anchored billiet to liner,M/U coil track to billit,Secure in deployment rams.M/U injector to coil track and surface test 12:18 14:33 2.25 1,092 8,253 COMPZ CASING TRIP P Trip in well with liner 14:33 15:33 1.00 8,253 9,770 COMPZ CASING TRIP P Correct to EOP flag for No correction Shut EDC, PUW=31 K 15:33 15:51 0.30 9,770 9,348 COMPZ CASING TRIP P 9770.6, Set dowm, Pump to set anchor,TF @ 190 setting tool shifted @ 3800 PSI Trip out of hole 15:51 15:57 0.10 9,348 8,255 COMPZ CASING DLOG P Log tie in for+2'correction TOL@ ll 8679 BOL=9771 sr.T subtract liner length from counters L,: • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 PROD3 WHDBO BOPE P Test BOP equipment,Chuck Sheve on sight to witness test. 01/14/2011 Completed testing BOP equipment. PU drilling BHA,kick off aluminum billet at 8679'and drill ahead. Lost 37 �5t' Bbls.of KWF and 81 Bbls of Flo-Pro to formation. je 00:00 05:30 5.50 0 0 PROD3 WHDBO BOPE P Continue with BOP test.- I 05:30 08:30 3.00 0 0 PROD3 WHDBO CIRC P Roll coil back to KWF, Blow down chokes,Open well and fill hole.Well dead when we opened it.25 BBIs to fill. Flow check well 08:30 09:48 1.30 0 72 PROD3 STK PULD P PJSM,P/U BHA#14 L1-02 Lateral/ drill off billet 1.0 Install checks,skid injector and make up to coil track surface test tool 09:48 12:00 2.20 72 8,270 PROD3 STK TRIP P Trip in well with EDC open 12:00 12:06 0.10 8,270 8,284 PROD3 STK DLOG P Log tie in for+2 12:06 13:54 1.80 8,284 8,325 PROD3 STK CIRC P RIH to 8325 circ out KWF 13:54 14:12 0.30 8,325 8,679 PROD3 STK TRIP P Close EDC,Clean trip through window.Trio in to drill oast billet 14:12 18:12 4.00 8,679 8,689 PROD3 STK KOST P Drytag Billet @ 8679',PUW=31 K 1.37 BPM @ 3700 PSI FS, 1.07 BPM Returns BHP=3835 170R TF 8678.6 start / '_�2 time milling L Motor work @ 8679.3 Time mill per procedure 18:12 20:36 2.40 8,689 8,830 PROD3 DRILL DRLG P PUH past billet and drift dry going down. Continue drilling ahead, 1.4 BPM,3500 CTP, 3760 BHP, losing 7 BPH. 20:36 21:12 0.60 8,830 8,830 PROD3 DRILL WPRT P Wiper to window,32K PUW 21:12 00:00 2.80 8,830 8,900 PROD3 DRILL DRLG P Continue drilling ahead. 1.4 BPM, 3600 CTP,3750 BHP, losses still at —7 BPH 01/15/2011 Drilled to 9123', unable to build angle,tripped for 1.3 Deg. motor. Continue drilling ahead. Lost 209 Bbls to formation. 00:00 02:18 2.30 8,900 8,980 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3600 CTP, 3750 BHP, losses still at —7 BPH 02:18 03:12 0.90 8,980 8,980 PROD3 DRILL WPRT P Wiper to window, 32K PUW 03:12 04:57 1.75 8,980 9,043 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3650 CTP,3850 BHP, losses still at —7 BPH 04:57 05:42 0.75 9,043 9,065 PROD3 DRILL DRLG P Drilling ahead, Unable to get BHA to build inclination 1.39 BPM @ 3440 PSI FS, TF=0, BHP=3855 Page 12 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:42 06:12 0.50 9,065 9,065 PROD3 DRILL DRLG P Confer with town geo, DD's Co Reps, on site geo still unable to get inclination increase. Tried different speeds 10R to 10 L tool faces.Test HOT to end stop. Plan to continue on trying to build 06:12 08:57 2.75 9,065 9,065 PROD3 DRILL DRLG P Drilling ahead and stalled, Still no build.tried multiple ROP&WOB.Varied pump rates, Continue drilling BHP=3860, PUW=37K 08:57 11:42 2.75 9,065 9,123 PROD3 DRILL DRLG P Last 50 feet try control drilling, maintaining weight Increasing speed. Flat line on inclination 11:42 14:12 2.50 9,123 65 PROD3 DRILL TRIP P Trip out to increase AKO and new bit. Unable to gain inclination. 14:12 16:12 2.00 65 0 PROD3 DRILL PULD P At surface, PJSM, PUD BHA#14 Swap out HOT, FVS,Motor,and Bit 16:12 17:42 1.50 0 72 PROD3 DRILL PULD P PD Lateral drilling BHA#15 1.2+AKO, FVS, HOT Rebuilt Hughes Bi Center Skid injector over coil track and make up Surface test tool 17:42 19:12 1.50 72 8,250 PROD3 DRILL TRIP P RIH 19:12 19:24 0.20 8,250 8,290 PROD3 DRILL DLOG P Tie-in,+3' 19:24 19:42 0.30 8,290 9,123 PROD3 DRILL TRIP P Continue RIH 19:42 21:24 1.70 9,123 9,185 PROD3 DRILL DRLG P Continue drilling ahead, 15K RIW, 1.4 BPM,3800 CTP,3900 BHP, losing—7 BPH 21:24 22:42 1.30 9,185 9,185 PROD3 DRILL WPRT P Return rate dropped to.3 BPM,3550 BHP at 1.4 BPM, PUH,36K PUW. BHP and return rate slowly improving. Wiper to window 22:42 00:00 1.30 9,185 9,255 PROD3 DRILL DRLG P Continue drilling ahead, 15K RIW, 1.4 BPM,3800 CTP,3800 BHP, losing—30 BPH 01/16/2011 Drilled to 9635',wiper to the swab,disp.well to KWF. Lost 292 Bbls Flo-Pro and 21 Bbls. KWF to formation 00:00 01:18 1.30 9,255 9,335 PROD3 DRILL DRLG P Continue drilling ahead, 15K RIW, 1.4 BPM, 3800 CTP,3850 BHP, losing—25 BPH 01:18 02:36 1.30 9,335 9,335 PROD3 DRILL WPRT P Wiper to window,33K PUW, 02:36 04:30 1.90 9,335 9,485 PROD3 DRILL DRLG P Continue drilling ahead, 15K RIW, 1.3 BPM,3700 CTP,3875 BHP, losing—25 BPH 04:30 05:18 0.80 9,485 8,400 PROD3 DRILL WPRT P Wiper to window,33K PUW, losses at—25 BPH 05:18 05:24 0.10 8,400 8,414 PROD3 DRILL DLOG P Log Tie in to RA marker for+2' correction 05:24 06:06 0.70 8,414 9,485 PROD3 DRILL WPRT P Wipe back to bottom Page 13 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:06 08:48 2.70 9,485 9,615 PROD3 DRILL DRLG P 9485', Drill Ahead 1.36 BPM @ 3950 PSI FS Still loosing—15-20 BPH BHP=3925 08:48 10:12 1.40 9,615 9,615 PROD3 DRILL WPRT P 9615.Wt chk,getting sticky hard to get back to drilling,suspect going out of C-4, wipe up hole while waiting on bottoms up sample got to 9071 Sample showed no shales, 10:12 12:30 2.30 9,615 9,635 PROD3 DRILL DRLG P 9615', Drill ahead 1.34 BPM @ 3627 PSI FS, BHP=3869 Ratty Drilling able to get going fairly easy 12:30 13:18 0.80 9,635 8,685 PROD3 DRILL WPRT P 9635,Start wiper to window, Fairly (f)7i certain this is TD PUW=32K Tight spots @ 9615, 9610,and 9607 13:18 14:00 0.70 8,685 9,635 PROD3 DRILL WPRT P Called TD,turned around before passing billet Start sweeps, Stacked out @ 9625. Poor hole conditions below 9600, made it to bottom 9635 14:00 17:00 3.00 9,635 0 PROD3 DRILL WPRT P Wiper to swab, low hi vis sweeps coming around PUW=37K 17:00 18:48 1.80 0 8,250 PROD3 DRILL WPRT P RIH 18:48 19:06 0.30 8,250 8,280 PROD3 DRILL DLOG P Tie in at K1,+12' 19:06 19:54 0.80 8,280 9,630 PROD3 DRILL WPRT P Continue RIH 19:54 22:36 2.70 9,630 0 PROD3 DRILL DISP P Lay in 39 Bbls. liner running pill and KWF to surface while POOH. Painted EOP flags at 8100'and 6900'. 22:36 22:54 0.30 0 0 PROD3 DRILL SFTY P PJSM, monitor well for flow 22:54 00:00 1.10 0 0 PROD3 DRILL PULD P Lay down drilling BHA after flushing and blowing it down 01/17/2011 Ran 2 3/8"slotted liner to 8623',deployment sleeve at 8257'. Displaced well to seawater and freeze protect with 25 Bbls.diesel. Set BPV. RDMO. Lost 84 Bbls KWF to formation. 00:00 00:24 0.40 0 0 COMPZ CASING SFTY P PJSM for liner operations 00:24 02:06 1.70 0 1,366 COMPZ CASING PULD P PU liner string with bull nose shoe, 30 joints slotted,6 joints solid,6 joints slotted and deployment sleeve 02:06 02:42 0.60 1,366 1,409 COMPZ CASING PULD P PU Inteq tools and MU injector to well 02:42 04:30 1.80 1,409 8,209 COMPZ CASING TRIP P RIH with liner 04:30 05:00 0.50 8,209 9,623 COMPZ CASING TRIP P Correct to EOP flag, +0.70' correction,continue RIH 05:00 05:12 0.20 8,257 8,240 COMPZ CASING TRIP P Set liner at 9623'and release. j?%'' deployment sleeve at 8257' Page 14 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:12 06:27 1.25 8,240 8,240 COMPZ CASING DISP P Open EDC and displace KWF from well with high vis spacer and SW 06:27 07:57 1.50 8,240 4,100 COMPZ CASING TRIP P POOH 07:57 09:27 1.50 4,100 2,400 COMPZ CASING TRIP P 4100',Attemp to pump diesel down cement line, Determined line to be frozen. PJSM start thawing operations 09:27 10:45 1.30 2,400 42 COMPZ CASING TRIP P Continue out of well laying in freeze protect diesel 10:45 12:00 1.25 42 0 COMPZ CASING PULD P PJSM PUD liner running tools 12:00 13:00 1.00 0 0 DEMOB WHDBO NUND P Set BPV, Lay down lubricator 13:00 15:30 2.50 0 0 DEMOB WHDBO NUND P Stab back on,send end of diesel from coil to tiger tank. Blow down CT 15:30 16:30 1.00 0 0 DEMOB WHDBO DMOB P PJSM,Start prepping to lay over mast, Remove QTS and 3'lubricator from injector. Install'topdrive lock arms 16:30 18:00 1.50 0 0 DEMOB WHDBO DMOB P Continue with RD operations. Rig released at 18:00 Page 15 of 15 Page 1of1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, January 07, 2011 8:18 AM To: 'Ohlinger, James J' Subject: RE: 1B-19L1 CTD completion mod (PTD 210-171) James, The proposed change doesn't impact the PTD status as you are within 500' of the permitted KO point. I agree with the change ... I would not rename the wells as we discussed. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ohlinger, James J [mailto:James.J.Ohlinger@conocophillips.com] Sent: Thursday, January 06, 2011 5:11 PM To: Schwartz, Guy L(DOA) Subject: 1B-19 CTD completion As mentioned on the phone, we're going to drill the L1-01 and L1-02 from a second window. See schematic, Page 1 is the new completion with 2 whipstocks. TD Locations are the same. James Ohlinger CTD Engineer ConocoPhillips AK, Inc. 907-265-1102 office 907-748-1051 cell 1/7/2011 CO * w 00 (D rn C-7.1. � v m p7 N 0 3 v R3 03 0 N) cn m �l CO CO a) lG O X N v v (T • W 7- CO IV A 03 CO /- 0T1 5. Oo � (It 7 0 ' N � p - - O 7-.) O TSN Cl CO CO D xIt � 00 opcn W 5 c co 1-- It � U N cn r r- cTcT 3 0 I I I `VIII o 14::1:10 01 ...I.II 0 t ` [ 7 W_ 4-51 > > - ,,�:y j J L 1 L l t l illifIII ✓ m �u n k \,, v ! . -c, co > w • v 7 a) T "" N n (D o co A X 3 m cn CO C, cn_ ! 71'444 7 U1 0 . , / / W W W W W W /,� //-{ 5 O (D N N N N /// / / p� w 0 co W j �� W N 7 01 co ' po o I-' 1 0 N o o �. 1 1 o o 0 m m 3G) co m (� _v W _ � �\ rn 3 w �•• p' N v j a -co • ‘\�` 7 N III • \\ \‘‘‘‘ o. 1 I N 5. al • cin p rn cD • `, K N N 0 CD CO [ W _a N v 0 -I U1 v N co ' CO vo �Nb 3N v 30 ' $ v I F t II XIgrn co n S CDm rn (D(� U' 01 03 v CO0 jav IJ � 1 N # � N 0 ANN v (n -' W 7' Oo - A co r- 0736 -0 7 (0 = N ,,, 0 N - O x co X a 0 co-o .-0 00 o co 1CT: Co4CD OJ C7- CD N 03 N O OD r PC< ^ 0 >, i co 13 III1 i i 0 0 A"l "1 1 7 J tD 0- * R , n 4 v 1 —I CI T -cs co > // Cn� CD 4, III 7 w r. Q0-0 //t 5' N O X CD O CO //' // C 6 03 07 W !HH!co 0 so ON N 3D 3j X o _ w Y-' N 7 n 01 \ o0 3 m o 0o -o o r 0 OD 3 I O W O o (� - C (D w v m 3 0 0o m @ x \ �' = rn 3 0o 0 N O_ —I CO CDS I CO oiii N I o (/f 7' 112,3- \ ' 3 N 0 IV !1 CO 00 I I 00 \coo O C7 in I A P N 01 C 'a It \ COiv 35. coco O I I I I .\ 01 N N II I ( I 0 o) Co W _ N I0 II o co II II 0 o I 3b I 31 eh N 3 0 fli nt 1) SEAN PARNELL,GOVERNOR ALASKA IL [E. El R\ SEA �tOIL ANI) GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1B-19L1 ConocoPhillips Alaska, Inc. Permit No: 210-171 Surface Location: 501' FNL, 351' FEL, SEC. 9, T11N, R10E, UM Bottomhole Location: 170' FSL, 1951' FWL, SEC. 9, T11N, R10E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1B-19, Permit No 194- 064, API 50-029-22475-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 'ncerely, 4.9 Daniel T. Seamount, Jr. Chair DATED this day of December, 2010. 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 FC F J /ED November 29,2010 DEC 0 1 2010 Commissioner- State of Alaska Alaska au & (gas ;Ans.Coary°s*II Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill tri-laterals out of the Kuparuk Well 1B-19 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in December 2010. The CTD objective will be to drill C-sand Tri-laterals(1B- 19L1, 1B-19L1-01, and 1B-19L1-02), 1 to the west and 2 to the east targeting the C1-C4. The original A-sand perforations will be plugged pre-CTD by setting an inflatable cement retainer in the 5"liner, and plug off the existing A-sand perforations(8595'-8634' RKB). Attached to this application are the following documents: — Permit to Drill Application Form for 1B-19L1, 1B-19L1-01, and 1B-19L1-02 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, James Ohlinger Coiled Tubing Drilling Engineer STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 0 1 2010 PERMIT TO DRILL 20 AAC 25.005 Alaska Oii &Gas Cons.Commission 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone 0' 1 c.SA i l w IPI proposed for: Drill ❑ Re-drill E 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 : 1B-19L1 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10093' ND: 6210' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:501'FNL,351'FEL,Sec.9,T11N,R10E,UM ' ADL 25651,25648 Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit 13.Approximate Spud Date: 104'FNL,2604'FWL,Sec. 16,T11N, R10E,UM 469,466 12/15/2010 Total Depth: 9.Acres in Property: 14.Distance to 170'FSL, 1951'FWL,Sec.9,T11N, R10E, UM 2560 �ire Nearest Property: 25850' i ' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:ie)feet 15.Distance to Nearest Well Open Surface:x- 550089' y- 5969647' Zone- 4 GL Elevation above MSL: 34 feet to Same Pool: 1B-04,1295' 16.Deviated wells: Kickoff depth: 8400 ft. 17.Maximum Ar"-'-'-�^-^.ssy+rgs in psi see mac 254100__ . Maximum Hole Angle: 104° deg Downhole;2$00Ps`'/g 4'''' /lL•68urface:3498-ppsig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 1415' 8660' 6190' 10093' 6210' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 8945 6719 8845 6616 Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" 195 sx AS I 121' 121' Surface 5272' 7.625" 790 sx ASIII,310 sx Class G 5313' 4053' Intermediate Production 8279' 5.5 225 sx Class G 8279' 6181' Liner 649' 5 8928' 6704' Perforation Depth MD(ft): Perforation Depth ND(ft): 8372'-8416',8595-8634' 6253'-6287',6425-6450' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑ 21.Verbal Approval: Commission Representative: Date: /V700 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-1102 Printed Name V. Cawvey Title Alaska Wells Manager Signature \i"....40,,,,,1 Phon 265-6306 Date It/Wfc.)16) Commission Use Only Permit to Drill ./ API Num . Permit Approval See cover letter Number: 50-�i 2���7 _ . -7C-60-6t GDate: � ,,, I !for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: v 3500p SL. So C .4- Samples req'd: Yes ❑ L_1 No Mud log req'd: Yes ❑./ No [.�''' s Other: / 'H2S.measur@s: Yes 2 No ❑ Directional svy req'd: Yes Q No ❑ ZSOO (Scr AHn.J- 1 tc.s • „ ZAPPROVED BY THE COMMISSION /I/7/ DATE: r--) 1 6 t i ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is va id o the t of approval(20 AAC 25.005(8)) Submit in Duplicate /Z.6./a 7-24,4, IA (-4.-2'' Permit to Drill Summary of Operations KRU 1B-19L1, 1B-19L1-01, and 1B-19L1-02 Laterals Coiled Tubing Drilling Overview: Well 1B-19 was originally drilled and completed in 1994 as a single A & C sand gas lift producer. This well is located in an area of the Kuparuk reservoir where the C-sand is thin and amalgamated, and the reservoir rock properties are lower than average C-sand values. The result of this lower reservoir quality is lower than expected oil recovery as oil resource is not being adequately produced from this low throughput well. Despite hydraulic fracture stimulation treatments in both the A- and C-sand, this well has a history of wellbore freezing events. As of September 2010, the well has been shut in because of wellbore freezing as a result of low productivity.The RWO has pulled the original 3-1/2"tubing and 2-7/8"GLM's and installed a 3-1/2"tubing/GLM completion. The prior completion was mechanically sound and the sole purpose of the RWO is to support CTD access. The sidetrack will utilize a thru-tubing whipstock to mill through the 5"liner. The top of the whipstock is planned for 8,385' MD. The first CTD lateral will kick off in the C4 and land in B3 silt,turning to the west while inverting lateral back into C4 pay. Continue lateral section to the east while slowly dropping through the C-sand with TD at 10093'(base ,- C1). The second lateral will turn up to crest in the C4,then drop through the C-sand to TD at 9,650' (base C1). The third lateral will turn up to crosscut the C4, and TD at 9,625' (top C4). Approximately 3,325 ft of total hole will be drilled and the productive intervals will be completed with slotted liners. The 1B-19L1 is planned for a 2-3/8"slotted liner with a liner-top aluminum billet for the KOP for the L1-01 lateral • at—8,660'MD. The 1B-19L1-01 is planned for a 2-3/8"slotted liner with a liner-top aluminum billet for the KOP for the L1-02 lateral at—8,980'MD. The 1B-19L1-02 will be completed with 2-3/8"slotted liner from TD to —8200'MD in the original well bore. Operational Outline Pre-Rig Work • Slickline: Tag PBTD, dummy whipstock drift • Slickline: Caliper 5"casing 3l0 �3`l3 • CTU: Cement plug/squeeze existing A-sand perfs "' � • Slickline: Tag TOC,pressure test • E-Line: Set 3-1/2"x 5"Thru-tubing whipstock / • O: Set BPV, prepare Wellsite for rig arrival // Page 2 of 5 11/30/2010 ORIGINAL Permit to Drill Summary of Operations Cont. KRU 1B-19L1,1B-19L1-01,and 1B-19L1-02 Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU BOPE and test 2. Set top of whipstock at 8,385' ELM 3. Mill 2.80"window at 8,385' in the 5' liner 4. 1B-19L1 Lateral a. Drill a 2.70"x 3"bi-center lateral to a TD of 10,093' MD b. Run the 2%" slotted liner to TD with an aluminum liner top billet at 8,660' MD. r 5. 1B-19L1-01 Sidetrack a. Kick off of the aluminum liner top billet at—8,660' MD b. Drill a 2.70"x 3"bi-center lateral to a TD of 9,650' MD c. Run the 2%" slotted liner from TD with an aluminum liner top billet at 8,980' MD. 6. 3J-15L1-02 Sidetrack a. Kick off of the aluminum liner top billet at—8,980' MD b. Drill a 2.70"x 3"bi-center lateral to a TD of 9,625' MD c. Run the 2%" slotted liner from TD up to 8,191' (inside the 3-1/2" tubing, below the nipple) Post-Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system Mud Program • Chloride-based Biozan brine(8.9 ppg)for milling operations, and chloride-based Flo-Pro mud (-9.40 ppg) for drilling operations. • 1B-19 does have a 3-1/2"Wireline retrievable SSSV nipple, but will not be applicable for CTD operations, therefore the a completion fluid (11.8 ppg Na-Bromide)will be utilized to kill the well for liner running. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind &Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Top Btm Liner Details Other Details MD MD 1B-19L1 8,660 10,093 2%",4.7#, L-80, ST-L slotted Unanchored aluminum billet 1B-19L1-01 8,980 9,650 2%",4.7#, L-80, ST-L slotted Unanchored aluminum billet 1B-19L1-02 8,270 9,625 2%",4.7#, L-80, ST-L slotted Page 3 of 5 11/30/2010 ORIGINAL Permit to Drill Summary of Operations Cont. KRU 1B-19L1,1B-19L1-01,and 1B-19L1-02 Existing Completion Details: Category OD Weight Grade Top Btm Burst Collapse (ppf) MD MD psi psi Conductor 16" 65 H-40 0 121 1640 670 Surface 7 b/g" 29.7 L-80 0 5313 6,890 4,790 Casing 5'/" 17 L-80 0 8279 7,740 6,290 Liner 5" 18 L-80 8279 8928 10,140 10,490 Tubing 3'/" 9.3 L-80 0 8287 10,160 10,540 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive �,,`.i° to the rig. sL , • BOP diagram is attached for operations with 2"coil tubing. 35W P /_ • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 391frOlsi Maximum potential surface pressure is 2200 psi assuming a gas gradient to surface based on the potential pressure of an equivalent 8.8 ppg mud weight. • The annular preventer will be tested to 250 psi and 2500 psi. t/ Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1B-19L1 25,850' 1B-19L1-01 24,950' 1B-19L1-02 24,950' • Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset 1B-19L1 1295' 1B-04 1B-19L1-01 1090' 1E-08 1B-19L1-02 1180' 1E-10 Logging MWD directional, resistivity, and gamma ray will be run over the entire open-hole sections. Reservoir Pressure 1B-19 is currently completed in both the C and A sands, and had a static bottom hole pressure of 2673 psi (8.2 ppg EMW). The existing A-sand perfs will be plugged off by an inflatable cement retainer. 1B-04 is an injector, and measured 2165 psi (6.7 ppg EMW) on Nov-09. 1E-08 has also been shut in from injecting water and it measured 2$D2psi (8.8 ppg EMW, Feb '10). Similar pressures are expected as the laterals are drilled. Page 4 of 5 11/30/2010 ORIGINAL Permit to Drill Summary of Operations Cont. KRU 1B-19L1,1B-19L1-01,and 1B-19L1-02 Hazards • Pressure is expected to increase along wellbore. Maintain sufficient ECD to overbalance. A 9.4 ppg mud system and annular friction will supply enough pressure to overbalance the expected reservoir pressure. Choke pressure can be applied to if higher pressures are encountered as we near the surrounding injectors. • Well 1B-19 has 65 ppm H2S as measured on June'10, 1B-16 had the maximum H2S level at 80 ppm on the 1B pad as measured on Sept. '10. All H2S monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by +."-- using 9.40 ppg drilling fluid in combination with annular friction losses and if needed applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows for the use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. Well 1B-19 does have a SSSV, however is not applicable to CTD operations so the well will have to be loaded with completion fluid prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following charts show the different pressure parameters in both"pumps on" and "pumps off'conditions. Drilling Conditions: Pressure at the Window Using MPD(FloPro) Pumps On Pumps Off (1.5 bpm) _ Formation Pressure 2673 psi 2673 psi Mud Hydrostatic(9.40 ppg) 3010 psi 3010 psi Annular Friction 800 psi 0 psi Mud+Annular Friction 3810 psi 3010 psi (no choke pressure) (overbalanced (overbalanced —1137 psi) —337 psi) Target Pressure (11.8 ppg) 3800 psi 3800 psi Choke Pressure Required/ 0 psi 790 psi to Maintain 11.8 ppg ,/ Example: Using the 1B-19 SBHP from Nov. '10 with a reservoir pressure of 2673 psi at 6250 TVDss(8.2 ppg EMW). While drilling and circulating at 1.5 bpm with 2"e-coil, head from the 9.40 mud (3010 psi), plus an estimated 800 psi of annular friction (assuming friction of 95 psi/1000 ft)will provide 3810 psi BHP (11.9 ppg EMW) and overbalance the reservoir by—1137 psi. When circulation is shut down, the mud will still be overbalanced to the reservoir pressure. However maintaining —790 psi at surface when the pumps are shut down will maintain a constant 11.8 ppg EMW to promote wellbore stability. Page 5 of 5 11/30/2010 ORIGINAL 1J 9 0 E o l 0, II 0 I oco a cv Lo c0 a co I CD N N _ I I I I U O (V C 9 (7 N o up U o ,- v co m o I N N I n io NC N 9 N o N II r � Cn F- 13 N , ,C N @ r` _ -. N m w I r = co 0 " a H a w m O m 2 I E w E 0 CD o E w, \ v C J p Q co c w co * E E N E e' - co co - OD of U X A Q N N N N Y // i i ro co co co M m Cn // i _E7 1 // VA L U 0 N V1 / CD M III // 0 - — 0 G 11 x1 I L. o III 3 III CL o � o to0c I C9o ao J J °� (i) -(1 ti �2 co oo N N L MI m It �Y Y a� aMo, o o CO Mr I N N _ '- Q' '6 1 V Cl 0 -0 CO W 1. Co N M in r- N c0 C (D N N (O V0) CO m r * 0 � CO LO O � U co O.� . (0 -CV < ��011 CO N co V o Y 0 m ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1B Pad 1B-19 1B-19L1 Plan: 1 B-19L1 wp10 Standard Planning Report 23 November, 2010 T1i BAKER HUGHES ORIGINAL r ✓ ConocoPhillips Fri ConocoPhillips Planning Report BAKER Alaska - HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1B-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1B-19 @ 102.00ft(1B-19) • Site: Kuparuk 1B Pad North Reference: True Well: 1B-19 Survey Calculation Method: Minimum Curvature Wellbore: 1B-19L1 t Design: 1 B-19L1_wp10 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 1B Pad Site Position: Northing: 5,969,646.72ft Latitude: 70°19'40.290 N From: Map Easting: 549,457.39ft Longitude: 149°35'56.057 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38° Well 1B-19 Well Position +N/-S 0.00 ft Northing: 5,969,646.84 ft Latitude: 70°19'40.250 N +E/-W 0.00 ft Easting: 550,088.64 ft Longitude: 149°35'37.627 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 1B-19L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2010 1/14/2011 16.96 79.87 57,356 Design 1B-19L1 wp10 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,168.70 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (ft) (ft) (ft) (0) 0.00 0.00 0.00 282.00 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) (°/100ft) (°) Target 8,168.70 43.10 203.30 5,995.86 -4,523.89 -2,233.40 0.00 0.00 0.00 0.00 8,385.00 39.88 206.25 6,157.88 -4,654.00 -2,293.32 1.74 -1.49 1.36 149.84 8,400.00 41.83 206.25 6,169.22 -4,662.80 -2,297.66 13.00 13.00 0.00 0.00 8,507.04 90.00 206.25 6,211.63 -4,747.89 -2,339.62 45.00 45.00 0.00 0.00 8,707.04 104.00 116.25 6,180.83 -4,916.72 -2,285.13 45.00 7.00 -45.00 284.00 8,807.04 103.35 69.87 6,155.90 -4,921.69 -2,191.06 45.00 -0.65 -46.38 275.00 8,877.04 90.37 40.89 6,147.38 -4,882.52 -2,134.75 45.00 -18.54 -41.40 248.00 8,927.04 86.53 18.71 6,148.75 -4,839.43 -2,110.06 45.00 -7.67 -44.37 260.00 9,237.04 89.25 316.71 6,161.41 -4,551.40 -2,172.97 20.00 0.88 -20.00 271.00 9,657.04 87.93 232.69 6,174.08 -4,519.89 -2,554.84 20.00 -0.31 -20.01 268.00 9,892.04 86.40 279.73 6,186.40 -4,574.33 -2,776.39 20.00 -0.65 20.02 93.00 / 10,093.00 80.80 239.65 6,209.74 -4,608.93 -2,968.77 20.00 -2.78 -19.94 260.00 ✓ 11/232010 12.12:51PM Page 2 COMPASS 2003.16 Build 69 1GJN� L N.-' ConocoPhillips FA' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1B-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1B-19 @ 102.00ft(1B-19) Site: Kuparuk 1B Pad North Reference: True Well: 1B-19 Survey Calculation Method: Minimum Curvature Wellbore: 1B-19L1 Design: 1B-19L1 wp10 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) 1°1 1°1 (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 8,168.70 43.10 203.30 5,995.86 -4,523.89 -2,233.40 1,244.02 0.00 0.00 5,965,108.58 547,885.71 TIP 8,200.00 42.63 203.70 6,018.80 -4,543.42 -2,241.89 1,248.27 1.74 149.84 5,965,089.00 547,877.35 8,300.00 41.14 205.05 6,093.25 -4,604.23 -2,269.43 1,262.56 1.74 149.54 5,965,028.01 547,850.22 8,385.00 39.88 206.25 6,157.88 -4,654.00 -2,293.32 1,275.58 1.74 148.55 5,964,978.09 547,826.66 KOP 8,400.00 41.83 206.25 6,169.22 -4,662.80 -2,297.66 1,278.00 13.00 0.00 5,964,969.26 547,822.38 End of DLS 13 8,500.00 86.83 206.25 6,211.44 -4,741.58 -2,336.50 1,299.62 45.00 0.00 5,964,890.23 547,784.07 8,507.04 90.00 206.25 6,211.63 -4,747.89 -2,339.62 1,301.35 45.00 0.00 5,964,883.90 547,780.99 4 8,600.00 99.28 165.28 6,203.78 -4,837.97 -2,348.94 1,291.73 45.00 -76.00 5,964,793.76 547,772.28 8,700.00 103.98 119.52 6,182.53 -4,913.53 -2,291.17 1,219.52 45.00 -79.48 5,964,718.60 547,830.54 8,707.04 104.00 116.25 6,180.83 -4,916.72 -2,285.13 1,212.95 45.00 -89.21 5,964,715.45 547,836.60 5 8,800.00 103.69 73.11 6,157.54 -4,923.87 -2,197.55 1,125.80 45.00 -85.00 5,964,708.89 547,924.22 8,807.04 103.35 69.87 6,155.90 -4,921.69 -2,191.06 1,119.90 45.00 -95.81 5,964,711.11 547,930.70 6 8,877.04 90.37 40.89 6,147.38 -4,882.52 -2,134.75 1,072.96 45.00 -112.00 5,964,750.65 547,986.74 7 8,900.00 88.58 30.71 6,147.59 -4,863.93 -2,121.34 1,063.71 45.00 -100.00 5,964,769.33 548,000.02 8,927.04 86.53 18.71 6,148.75 -4,839.43 -2,110.06 1,057.78 45.00 -99.91 5,964,793.90 548,011.14 End of DLS 45 9,000.00 86.89 4.10 6,152.95 -4,768.23 -2,095.70 1,058.54 20.00 -89.00 5,964,865.19 548,025.02 9,100.00 87.71 344.09 6,157.71 -4,669.38 -2,105.94 1,089.10 20.00 -88.16 5,964,963.96 548,014.12 9,200.00 88.80 324.11 6,160.78 -4,579.92 -2,149.38 1,150.19 20.00 -87.21 5,965,053.12 547,970.09 9,237.04 89.25 316.71 6,161.41 -4,551.40 -2,172.97 1,179.19 20.00 -86.59 5,965,081.48 547,946.31 9 9,300.00 88.83 304.13 6,162.47 -4,510.67 -2,220.79 1,234.44 20.00 -92.00 5,965,121.89 547,898.22 9,400.00 88.29 284.13 6,165.00 -4,470.01 -2,311.56 1,331.68 20.00 -91.79 5,965,161.94 547,807.19 9,500.00 87.96 264.12 6,168.30 -4,462.85 -2,410.74 1,430.18 20.00 -91.28 5,965,168.43 547,707.98 9,600.00 87.87 244.11 6,171.98 -4,490.07 -2,506.37 1,518.06 20.00 -90.62 5,965,140.58 547,612.54 9,657.04 87.93 232.69 6,174.08 -4,519.89 -2,554.84 1,559.28 20.00 -89.89 5,965,110.44 547,564.27 10 9,700.00 87.51 241.28 6,175.79 -4,543.25 -2,590.80 1,589.59 20.00 93.00 5,965,086.83 547,528.48 9,800.00 86.75 261.29 6,180.85 -4,575.14 -2,684.91 1,675.01 20.00 92.66 5,965,054.32 547,434.59 9,892.04 86.40 279.73 6,186.40 -4,574.33 -2,776.39 1,764.66 20.00 91.65 5,965,054.52 547,343.12 11 9,900.00 86.12 278.16 6,186.92 -4,573.10 -2,784.23 1,772.59 20.00 -100.00 5,965,055.70 547,335.27 10,000.00 82.98 258.31 6,196.51 -4,576.10 -2,883.21 1,868.78 20.00 -99.90 5,965,052.04 547,236.32 ` 10,093.00 80.80 239.65 6,209.74 - -4,608.93 -2,968.77 1,945.65 20.00 -97.99 5,965,018.64 547,150.99 TD / 11/232010 12:12:51PM Page 3 COMPASS 2003.16 Build 69 IY\ IGINAL • �•' ConocoPhillips FEE ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1B-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1B-19 @ 102.00ft(1B-19) Site: Kuparuk 1B Pad North Reference: True Well: 1B-19 Survey Calculation Method: Minimum Curvature Wellbore: 1B-19L1 Design: 1 B-19L1_wp10 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1B-19L1 t1 0.00 0.00 6,175.00 -4,865.08 -2,357.10 5,964,766.60 547,764.30 70°18'52.398 N 149°36'46.393 W -plan misses target center by 29.94ft at 8623.04ft MD(6199.71 TVD,-4859.27 N,-2341.23 E) -Point 1B-19L1 t3 0.00 0.00 6,162.00 -4,507.96 -2,221.70 5,965,124.59 547,897.30 70°18'55.911 N 149°36'42.445 W -plan misses target center by 1.85ft at 9301.93ft MD(6162.51 TVD,-4509.59 N,-2222.39 E) -Point 1B-19L1 t2 0.00 0.00 6,146.00 -4,897.55 -2,139.29 5,964,735.60 547,982.30 70°18'52.080 N 149°36'40.038 W -plan misses target center by 7.45ft at 8864.84ft MD(6147.71 TVD,-4891.38 N,-2143.12 E) -Point 1B-19L1 t5 0.00 0.00 6,210.00 -4,608.97 -2,968.45 5,965,018.61 547,151.31 70°18'54.915 N 149°37'4.231 W -plan hits target center -Point 1B-19L1 Fault 1 0.00 0.00 0.00 -4,763.63 -2,722.46 5,964,865.61 547,398.31 70°18'53.395 N 149°36'57.052 W -plan misses target center by 6020.55ft at 8168.70ft MD(5995.86 TVD,-4523.89 N,-2233.40 E) -Polygon Point 1 0.00 -4,763.63 -2,722.24 5,964,865.61 547,398.53 Point 2 0.00 -4,571.01 -2,661.93 5,965,058.61 547,457.54 Point 3 0.00 -4,385.34 -2,608.61 5,965,244.61 547,509.62 Point 4 0.00 -4,571.01 -2,661.93 5,965,058.61 547,457.54 1B-19L1 t4 0.00 0.00 6,180.00 -4,575.03 -2,660.19 5,965,054.60 547,459.31 70°18'55.250 N 149°36'55.238 W -plan misses target center by 4.72ft at 9776.42ft MD(6179.54 TVD,-4570.62 N,-2661.81 E) -Point 1B-19L1 Polgyon 0.00 0.00 0.00 -4,712.67 -3,014.15 5,964,914.61 547,106.31 70°18'53.895 N 149°37'5.563 W -plan misses target center by 6049.42ft at 8168.70ft MD(5995.86 TVD,-4523.89 N,-2233.40 E) -Polygon Point 1 0.00 -4,712.67 -3,014.15 5,964,914.61 547,106.31 Point 2 0.00 -4,781.68 -3,014.61 5,964,845.60 547,106.31 Point 3 0.00 -4,693.60 -2,721.99 5,964,935.63 547,398.31 Point 4 0.00 -4,725.82 -2,538.18 5,964,904.64 547,582.31 Point 5 0.00 -4,918.47 -2,444.45 5,964,712.64 547,677.32 Point 6 0.00 -5,008.20 -2,335.03 5,964,623.65 547,787.32 Point 7 0.00 -5,002.38 -2,157.97 5,964,630.65 547,964.32 Point 8 0.00 -4,896.59 -1,973.24 5,964,737.66 548,148.33 Point 9 0.00 -4,743.50 -1,983.23 5,964,890.67 548,137.32 Point 10 0.00 -4,529.02 -2,052.82 5,965,104.66 548,066.30 Point 11 0.00 -4,387.94 -2,212.90 5,965,244.65 547,905.30 Point 12 0.00 -4,389.07 -2,494.94 5,965,241.64 547,623.30 Point 13 0.00 -4,515.00 -2,960.83 5,965,112.61 547,158.31 Point 14 0.00 -4,712.67 -3,014.15 5,964,914.61 547,106.31 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 5,313.10 3,951.96 7-5/8" 7-5/8 9-7/8 10,093.00 6,209.74 2 3/8" 2-3/8 3 11/232010 12:12:51PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL ✓ ConocoPhillips FAP— ' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1B-19 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1B-19 @ 102.00ft(1B-19) Site: Kuparuk 1B Pad North Reference: True Well: 1B-19 Survey Calculation Method: Minimum Curvature Wellbore: 1B-19L1 Design: 1B-19L1_wp10 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,168.70 5,995.86 -4,523.89 -2,233.40 TIP 8,385.00 6,157.88 -4,654.00 -2,293.32 KOP 8,400.00 6,169.22 -4,662.80 -2,297.66 End of DLS 13 8,507.04 6,211.63 -4,747.89 -2,339.62 4 8,707.04 6,180.83 -4,916.72 -2,285.13 5 8,807.04 6,155.90 -4,921.69 -2,191.06 6 8,877.04 6,147.38 -4,882.52 -2,134.75 7 8,927.04 6,148.75 -4,839.43 -2,110.06 End of DLS 45 9,237.04 6,161.41 -4,551.40 -2,172.97 9 9,657.04 6,174.08 -4,519.89 -2,554.84 10 9,892.04 6,186.40 -4,574.33 -2,776.39 11 10,093.00 6,209.74 -4,608.93 -2,968.77 TD 11/23/2010 12:12:51 PM Page 5 COMPASS 2003.16 Build 69 mr « n `W. /W g M2 rO /r CN ON •S . n N p` a .11 a :o N A P oa I n a ( N r + p s 8 ar o: ¢¢ 0 r p �o25!A`1,43 W P/ .N• -F :O > G y to N 'S LL =i '5 Y .O a ztz ,, W411,30 0 N ^ v\ O N b 1P r ,\s VI men O)• Or• C/ - G „ Y-1 0a• i 0 P_�l O rn Jeco m 'o O r R. mp o I- og . r O a4 E p " op p p O O O N 8 P h N 8 " o N 8 h N N 8 o N a Lll EP 1 ' v Y i Y y�y W I 4 Y Y [ N CO m (u3/8 CO(+) ON/(-)LfOS 0 44 J m r 0 a. 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'-------- ' \\N\\\\‘\ \\*.\ Y iii 11111:11/41;0411 14;j„,?),)--I,141)).):::: : . !;; ii; einallgetWANgii - WO (!)3 7, i „Adi ; ;i nffiummumummm oN _ 100\ \\\\' ,\\- —_._._.___ //, ic° N t 011\C\ \‘\ __ft-----------.__—___________________ /1,1111 M .3 AWN\\\\\\*\\ _,---. 7//11 //// / .-E! ;:- Fr \\\ \ \N ---- -'_-____---------____-____________________ , //pi / \ \ N *- -_-_______________________.--------.---------------=__-_ -_ . 0"7 n N 4*--O 6------- *''/ / 2.2-v1 ~ ia % ORIGINAL � Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N Lubricator rs.\-\V Riser Annular/ Blind/Shear 2"Pipe/Slip(CT) Pump into Lubricator � �J �� above BHA rams 1 rChoke 1 Ii 2-3/8"Pipe/Slip(BHA) I' Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) ' II Kill > ii/\J L><><J H Blind/Shear IN 2"Pipe/Slip(CT) 1' II 7 r Choke 2 II Swab Valves 41 IN Wing Valves J Tree Flow Cross 1 Surface Safety Valve BOPE: 7-1/16", 5M psi,TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union ORIGINAL Page 1 offr / Schwartz, Guy L (DOA) From: Ohlinger, James J [James.J.Ohlinger@conocophillips.com] Sent: Monday, December 06, 2010 9:47 AM To: Schwartz, Guy L(DOA) Subject: RE: 1B-19L1 CTD (PTD 210-171) Thanks, I'm trying to get a copy of the PTD from Sharon currently. 3500 is fine, I had that in my notes. For the MASP, the max pressure in the area is 1 E-08 (currently shut-in Injector)that measured 2802 psi (8.8 ppg EMW) in Feb-10. That calculates to roughly 2175 psi at surface with a .1 psi/ft. From: Schwartz, Guy L(DOA) [mailto:guy.schwartz©alaska.gov] Sent: Monday, December 06, 2010 9:34 AM To: Ohlinger, James 3 Subject: FW: 1B-19L1 CTD (PTD 210-171) James, I also changed the BOP test pressure to 3500 psi. on the PTD ( the procedure stated 3000 psi). We like to have the BOP test pressure at 3500 psi unless there is a good reason to change it. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Monday, December 06, 2010 9:21 AM To: 'Ohlinger, James J' Subject: 1B-19L1 CTD (PTD 210-171) James, 1)The PTD states MASP of 3000 psi... Can you look at the Max anticipated reservoir pressure and MASP values and get back to me. The values on the PTD application don't look right. 2)Also, the well will not be suspended when you finish the pre-rig work as the C sand will still be active. I changed the pre-rig sundry to reflect that. You are just plugging the A sand perfs.. 3) Can you elaborate on the plugging operation? Just says you are setting an IBP retainer.. no volumes of cement or any details. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 12/6/2010 Page 1 of 2 Schwartz, Guy L (DOA) From: Ohlinger, James J [James.J.Ohlinger@conocophillips.com] Sent: Monday, December 06, 2010 9:47 AM To: Schwartz, Guy L(DOA) Subject: RE: 1B-19L1 CTD (PTD 210-171) 3) Can you elaborate on the plugging operation? Just says you are setting an IBP retainer.. no volumes of cement or any details. Prep Wellbore for Cement Retainer to isolate existing A-sand perfs 1. MIRU CTU; • MU Weatherford Inflatable Cement Retainer BHA(IRPP) • Tag PBTD and correct to RKB. Fill the hole with heated seawater or KCl water(-120° to 140° F, circulating 11/2 to 2 wellbores volumes)while waiting on cement to mix. Hole volume at 8,707' RKB (last Slickline tag) is—80 bbls. • RIH to Retainer setting depth of 8570' RKB, shut in choke and test for injection. • Drop the ball to set the retainer. Start pumping ball at 1 bpm, when close to ball seating cut rate to minimum(0.5-0.75 bpm). Stop pumping at± 1000 psi CT pressure and hold pressure for 5 minutes to allow element to conform to casing wall. • Increase pump pressure by 500 psi and hold for 5 minutes. • Repeat 500 psi increase and hold for 5 min until ball seat shears • Perform injection test(adjust cement volume accordingly) • Cement Volume =20000 x BPM x (5.61/Injection Rate Pressure) 2. RU cementers. Batch mix a pumpable 15 bbls of 15.8 ppg cement(2.5 bbl capacity in the 5"casing from 8,570' —8,707' RKB, leaving 12.5 bbls for excess). Cement specs: 15.8 ppg density, thickening time of 6-7 hours, and fluid loss of 75-90 ml/30mins. Assume BHT(circulating) = 150° F and BHT (static)= 160° F. • Bring pod up to weight and shear thoroughly. QC cement weight and obtain mixed sample for on-site COP Wells Supervisor. Send samples of mix water and dry field sample to lab for UCA test. • A sand (11/08/10): 2673 psi= 8.2 ppg EMW • Monitor annulus pressures while pumping and bleed off as necessary. Max IA& OA pressure should be 1000 psi respectively. 3. Pump the following down the coil at 0.5 — 1.0 bpm. a) water spacer for PT(do not use friction reducer, J313 will clabber cement) b) 15 bbl neat 15.8 ppg cement c) 5-10 bbl of spacer water d) 1.5#Biozan gel for cement clean out 4. Pick up to shear mechanical disconnect and close check valves after 13 bbls of cement is below the i1/Armin Page 2 of 2 IRPP, and lay in remaining—2 bbls of cement on top of retainer. RBIH contaminating cement down to 8450'. Make 2 contamination runs pumping Biozan out the bottom of the stinger. Wash out of the hole pumping SSW, switch to diesel to freeze protect the top 2000'. POOH. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) 12/6/2010 TRANSMITTAL /LETTER CHHECKLIST WELL NAME [ ( — I ( L I PTD# 2—(C) I 7 I v Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: L �� 6 --at„, POOL: gt t,� ti 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 / (3 ` l�f (If last two digits in � Z API number are Permit No. ly ,API No. 50��� � - 2 7�' - C 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 I inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 o = aIr co D O > n D - ° a 3 C) o = -n ,•T 3 co CD N r Go a CD -, o r"03 o 7 O • ° N N O N ,. V �m y.C° N O (15 CN O O ° D, R-5O j Sti 7O N c, Cco co ' xi •. CD 0 O 0 `g 0 CO 4.) W CJ C.) 4) W CJ (A) W N N N N N) N N N N) N -. -.I -. -. -. - -. - -. CO CO V CO CT A GJ N -> _ 3 CO 0) V C) (Cl A C.) N) -. O CO 00 V 0) (Cl A G) N -. O CO 07 1 CA (Cl A C..) N) -O0 V M n � � 0 'U K C * C) 03 00 O 7 D -« > C) C) C) C) 'V) 0 -0 > ;* C) -0 'O O � C0 * * * C r' b Z ,? 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