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Home My WebLink About213-005 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. Qj 3 - ®0 5 Well History File Identifier Organizing (done) ❑ Two-sided III 11/11111 III II III ❑ Rescan Needed III 11111111111111 RES N DIGITAL DATA OVERSIZED (Scannable) of r Items: ❑ Diskettes, No. ❑ Maps: Grey Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: , BY: Alaft Date: 4, /s/ Project"ect Proofing 1 11111111 III IIII • BY: Date: a a Ll- 1 /s/ ad Scanning Preparation 1 x 30 = 30 + 1 ( = TOTAL PAGES i1-s' (Count does not include cover sheet) BY: Maria Date: a /s/ rrr■■y�� Production Scanning III 111111111111111 Stage 1 Page Count from Scanned File: Lf 1 (Count does include cover eet) Page Count Matches Number in Scanning Pre aration: YES NO 9 9 P BY: dig= Date: JL/ JIL/_ Is! 041) Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III I il III ReScanned 1 1111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III IIII III c) I I o j Ico m 1 1 I� E 1 /z ,z/ z Z E E O co ,� } } } N E E > I. to U co co .�U a al u) VN 5 >- c Q N 0 > 1 a) U (` C >, = U) U) a CO 0) < Z 7 O a + L L o `\ F. Co- c c es E o 0 a Q c w S g m m a d a !I 03 0 p ea 10. I N L U U J di 4111111b J IU O N a a a 0) a) o a O O I y c « 2 2 a J N Z U C a 0) a 0) a) 0 W MI Z o E a� a- + m o Z �a Cl) a a) 0 ca a c / Z Z v) o = E .c E to 0 O o E :: Ce Q Eo g� �� I-� U es 0 iL I CD t O. J U a) 2 M M c c, cn a N li J « N N N N N O N 0 W E w y v v a v M Z ur rn IX 0 as V V N N 0 '0 a E W O C C C C C 0 p) U) a)Z J I Z1Ia a) a a) a) m o a V c°� o f 0 0i0 0 0 0 o I E J E Z V U N )) to as II I'I co ,o = II R co � o E a J 0. O `) 'I 2 U U G O III ZI C M M M M 1 , III O 0 ,- U E /Z Ell o tr. 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U a o 0 0 J - / Ti 2- t • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Q Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: January 20,2013 2•3005 3.Address: 6.Date Spudded: 13.API Nunyber: P.O.Box 100360,Anchorage,AK 99510-0360 January 17,2013 50-029-21683-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2229'FNL,2255'FEL,Sec. 17,T13N,RO9E,UM January 19,2013 3Q-06AL1 Top of Productive Horizon: 8. KB(ft above MSL): 59'RKB 15.Field/Pool(s): 1275'FNL,688'FWL,Sec. 18,T13N,RO9E,UM GL(ft above MSL): 17'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1199'FNL,265'FWL,Sec. 18,T13N,RO9E,UM 11131'MD/6331'TVD Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-516081 y- 6025843 Zone-4 11131'MD/6331'TVD ADL 25512 TPI: x-508545 y- 6026784 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-508122 y- 6026860 Zone-4 1908'MD/1825'TVD 2553 18.Directional Survey: Yes 0 No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1582'MD/1548'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 _9749'MD/6338'TVD 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 38' 115' 38' 115' 24" 1875#Poleset 9.625" 36# J-55 37' 5068' 37' 3684' 12.25" 1275 sx AS III,325 sx Class G 7" 26# J-55 35' 9400' 35' 6332' 8.5" 385 sx Class G,175 sx AS I 4.5" 11.6# L-80 9027' 9411' 6086' 6338' 6" scab liner 2.375" 4.6# L-80 9358' 11130' 6305' 6331' 3" Slotted liner 7,....7.1o, 3 24.Open to production or injection? Yes No r If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 9041' 9027'MD/6086' TVD 9359'-11130'MD 6305'- 6331'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. RECEIVEDWas hydraulic fracturing used during completion? Yes❑ No El DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED '�� 4 - FEB 15 2013 fl . '- `'i AOGCC 27. PRODUCTION TEST Date First Production. Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No lal Sidewall Cores Acquired? Yes ❑ No Q 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 laboratory analytical results per 20 AAC 25.071. NONE RBDMS FEB 15 MI e. p Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 76. 7,4).'3 G 29. GEOLOGIC MARKERS(List all formations and mariscrs encountered): 30. FORMATION TESTS NAME MD TVD Well tested? El Yes Q 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 1582' 1548' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A 10698' 6326' N/A Formation at total depth: Kuparuk A 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.Gary Eller @ 263-4172 Email: J.Garv.Elleraconocophillips.com Printed Name Lamar Gantt Title: CTD Engineering Supervisor Signature (t A ti . . . Phone 263-4021 Date 2//4/�� INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23:If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP 3Q-06AL1 Conoco Phillips " , Well Attributes Max Angle&MD TD Alaska.if1C Wellbore API/UWI Field Some Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) <.n.rxoNMllps 500292168360 KUPARUK RIVER UNIT PROD 11,130.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date °••Well Conll9:DEVIATED-30-O6ALI 1/23/20131:56:19 PM SSSV:TRDP 175 12/25/2004 Last WO: 11/20/2012 41.71 2/4/1987 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SIDETRACK TO A,AL1 osborl 1/23/2013 Casing Strings HANGER,34 Casing Description String 0... String ID_.Top(ftKB) Set Depth(f...Set Depth(TV D)... String WL. String... String Top Thrd AL1 Liner 23/8 1.995 9,357.8 11,130.0 4.60 L-80 STL ' ± (off main w ffEI Liner Details Top Depth (ND) Top Inc! Nonni... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 9,357.8 -DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 Perforations&Slots CONDUCTOR, Shot 38-775 Top(ND) Btm(TVD) Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 9,359.0 11,130.0 Lower Kalubik, 1/19/2013 32.0 SLOTS SLOTTED LINER SAFETY VLV, JI Unit D,C-4, 1.908 1 °I Kuparuk River, 3Q-O6AL1 Notes:General&Safety End Date Annotation 1/20/2013 NOTE:WELL SIDETRACKED TO A,AL1;AL1 EXITS OFF THE MAIN WELLBORE GAS LIFT, 3,157 I SURFACE, 4 37-5.068 L GAS LIFT, G 5.659 1 GAS GAS L _ 6.35IFT 6 m� GAS LIFT. .. 8,912 NIPPLE,8,970 LOCATOR, 9.019 SEAL ASSY, 9.020 11 F CMT SOZ, -' 9.100.9,104 WHIPSTOCK, WINDOW x,393 �Nand(el Details Top _._ ... Porc PRODUCTION - S... (ND) Inc! OD Valve Latch Size TRO Run Post Srt, N...Top(ftKB) (ftKB) (°) Make Model (in) Sew Typo Type OH (psi) Run Date Corn... 35-9,400 IPERF, 1 3,157.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/20/2012 SCAB LINER. 2 5,659.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/20/2012 9,027-9,411 SLOTS, 3 7,314.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/20/2012 9,359-11,130 AL1 Liner 4 8,356.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/20/2012 (off mein *tabors). 5 8,911.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/5/2012 9,355 8-11,130 TD(3111-08AL1), 11,130 ...4 A Liner(off - 1,3 9,750-71,307 07 J v.3 0 I co 0- N1 CU CO 0 O N EiS b 2O_ Bo 00 co - r O co rn L 0 0°)rn b c is M N m r/ E Q 0 9 O N - N p cM cD-6O IL—1) O) d Q F_m - U CO _ _ O C co U c C v 0 'co J= Q CO N Q O 2 0 Q O O CD Q � Y i c - °gy m CV b 2 co _� - C)00 J 0,, c (r W NN O �0)`Q .O V CO NJ r V O � 0O\ ,,\\ N W (�W /0/�0� V V (n �/ O N O O QS L/ Y W O N : S1 EO- -) 0 D. 0_ -� 0 O 7X UM O_. 0 't c< O▪c) `' cEa� Z coo o .E-� cow ° U� X �w LL or N v N N N N N N N Q O cam) 00 C) C) CO CO V 4 0 i 2 Co 4) M a) td a 0 C il N / I CZ \.... ./.:: E -' ,.:, `'. a U I — III III II CZ co V C N V (�� N ix m V r a O 0 O\ _o - N 'O N N In Lo C r c L co co 2 Xk b a,00) x0 u) co L-' '2G 0 a•-M _ CO `t U-O i In CD to Cn�� No� iN0 a N N N� N/a\ L d co `/ 'O 0.).4. c r 0 Cr 0 7 6)m f0 N'O N N YCl N U O O M 0 a� W= 0f0 Z co ■ W 1��= `W2 gi E3 1 C ....... ca L 0 cn a o w Q.a i 4 W w Q Q z co cu s .- U' Cl) -C 'E r-' -C V wc O O a M = - C v o O .. 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Depth Phase Code Subcode T Comment 12/31/2012 24 hr Summary Move rig from 1 R-29 to 3Q-06 18:00 00:00 6.00 MIRU MOVE MOB P Move rig from 1R-29 to 3Q-06 01/01/2013 Move Rig from 1 R-29 to 3Q-06A and spot modules. 00:00 03:30 3.50 0 0 MIRU MOVE MOB P Move Rig from 1R-29 to 3Q-06A 03:30 04:30 1.00 0 0 MIRU MOVE MOB P Prep location for rig spotting. 04:30 05:30 1.00 0 0 MIRU MOVE MOB P Spot Drilling module over well. 05:30 07:30 2.00 0 0 MIRU MOVE MOB P Spot Pit module. 07:30 10:00 2.50 0 0 MIRU MOVE MOB P Start pre-spud check list and frozen lines in cellar. 10:00 13:00 3.00 0 0 MIRU MOVE NUND P Nipple up BOPE. 13:00 13:30 0.50 0 0 MIRU WHDBO NUND P Grease tree ***Rig Accept at 1300 hrs*** 13:30 13:45 0.25 0 0 MIRU WHDBO SFTY P PJSM-with FMC for pullling BPV and load equipment. 13:45 15:00 1.25 0 0 MIRU WHDBO BOPE P Pull BPV and UD equipment. 15:00 00:00 9.00 0 0 MIRU WHDBO BOPE P PJSM-Pull BHI checks and perform shell test. Start BOPE testing 01/02/2013 Finish BOP test,test PDL's,and TT line.change pack-off,and swap out R9 circ.valve.Set TOWS at 9380ft. POOH and LD WS setting BHA. 00:00 03:00 3.00 0 0 MIRU WHDBO BOPE P Continue to test BOP. BOPE testing complete 03:00 05:00 2.00 0 0 MIRU WHDBO FRZP P PJSM, RD from BOPE testing. Freeze protect lines and pump 05:00 06:00 1.00 0 0 MIRU WHDBO SFTY P Crew change, PJSM 06:00 06:00 0.00 0 0 SLOT WHDBOSFTY P 06:00 07:00 1.00 0 0 PROD1 RPEQP1 PULD P Prepare floor to pick up BHA 07:00 07:15 0.25 0 0 PROD1 RPEQP1SFTY P PJSM, 07:15 08:15 1.00 0 0 PROD1 RPEQP1OWFF P Bleed well 875psi.to Opsi,flush stack 08:15 08:30 0.25 0 0 PROD1 RPEQP1SFTY P PJSM 08:30 10:00 1.50 0 0 PROD1 RPEQPI PULD P PU/MU BHA#1 10:00 12:45 2.75 75 9,235 PROD1 RPEQP1TRIP P RIH Page 1 of 14 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:45 13:00 0.25 9,235 9,260 PROD1 RPEQP1 DLOG P Tie in depth to K1 +5'correction 13:00 13:15 0.25 9,260 9,393 PROD1 RPEQP1WPST P Offline with pumps. Record up/down weight.38k up, 18k riw Close EDC RIH to set depth 9393'MD. PU 33.5K 13:15 13:21 0.10 9,393 9,380 PROD1 RPEQP1WPST P Set Whipstock HS toolface.2800psi CTP, 1054psi diff psi.wob increased 3k,set down 1.5k looks good.all indications good set.TOWS 9380'. 13:21 16:51 3.50 9,380 0 PROD1 RPEQP1TRIP P POOH 38k CTW swapping hole to 9.4ppg power pro drill mud. 16:51 17:06 0.25 0 0 PROD1 RPEQP1OWFF P At surface,Monitor well for flow, PJSM 17:06 17:36 0.50 0 0 PROD1 RPEQPI PULD P LD BHA. 17:36 18:06 0.50 0 0 PROD1 WHPST SVRG P Service Injector head 18:06 18:36 0.50 0 0 PROD1 WHPST PULD P M/U Milling BHA. 18:36 19:45 1.15 0 0 PROD1 WHPST PULD P Deploy milling BHA. 19:45 21:45 2.00 0 9,240 PROD1 WHPST TRIP P RIH-with first window milling BHA. 9'2 3/8"Pup jt 2 3/8"X-Treme Motor 2.790"Diamond string mill 2.800"Diamond Window Mill 21:45 22:00 0.25 9,240 9,267 PROD1 WHPST DLOG P 9240ft-Tie into the K1 marker correction of+2ft. 22:00 22:30 0.50 9,267 9,382 PROD1 WHPST TRIP P Cont. RIH, Dry tag 9382.4ft 22:30 23:00 0.50 9,382 9,383 PROD1 WHPST CIRC P Circ bottoms up to clear up a returns 23:00 00:00 1.00 9,383 9,384 PROD1 WHPST MILL P OB milling 1.48bpm at 3372psi. BHP 4000,WHP 256. IA 388,OA 394. 01/03/2013 Complete two run dual string window exit. mill down to 9398" 00:00 02:30 2.50 9,384 9,386 PROD1 WHPST MILL P Continue milling window as per plan. 1.49bpm at 3720psi. BHP 4000, WHP 254. IA 461,OA 424. 02:30 03:00 0.50 9,386 9,386 PROD1 WHPST MILL P OB milling window. Looks like we contacted the 7 inch at 6.1 ft into milling. 1.49bpm 500psi differental BHP 4000 WHP 254 IA 540 OA 475 03:00 03:15 0.25 9,386 9,386 PROD1 WHPST MILL P Notice WOB falling off and differental staying up at 450psi. P/U and ream once.Call to town decide to finish milling the 1/2 ft by time milling to let the reamer to work on the 4 1/2 tubing. Page 2of14 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 03:15 03:45 0.50 9,386 9,387 PROD1 WHPST MILL P RBIH,start time milling 2 tenths off bottom. 03:45 04:15 0.50 9,387 9,387 PROD1 WHPST REAM P Back ream milling area at 60fph three times. . 04:15 04:30 0.25 9,387 9,000 PROD1 WHPST TRIP P PUH 04:30 04:45 0.25 9,000 9,000 PROD1 WHPST OWFF P Check well for flow. after 7 minutes shut in WHP build up to 25psi. 04:45 06:45 2.00 9,000 1,908 PROD1 WHPST TRIP P POOH following MP schedule. 06:45 07:30 0.75 1,908 0 PROD1 WHPST TRIP P Open EDC,flush SSSV. PU above close SSSV.Test good. POOH 07:30 07:45 0.25 0 0 PROD1 WHPST SFTY P FLow check, PJSM 07:45 08:45 1.00 0 0 PROD1 WHPST PULD P LD BHA.weight up mud system to 9.6ppg 08:45 09:45 1.00 0 0 PROD1 WHPST SVRG P Injector head maintenance. 09:45 10:15 0.50 0 0 PROD1 WHPST SFTY P PJSM-P/U BHA#3 10:15 10:30 0.25 0 0 PROD1 WHPST PULD P Stab onto tools with coil.Test MWD, and Tag up to set counters. 10:30 13:00 2.50 0 9,240 PROD1 WHPST TRIP P RIH-Second window milling BHA#3 9ft pup jt Weatherford 2 3/8"2.0°fixed bend motor 2.79"OD fat radius mill 13:00 13:15 0.25 9,240 9,267 PROD1 WHPST DLOG P 9240ft-Tie into the K1 marker correction of+1.5ft 13:15 13:30 0.25 9,267 9,387 PROD1 WHPST TRIP P Continue RIH 13:30 13:45 0.25 9,387 9,387 PROD1 WHPST MILL P Dry tag at 9387ft. PUW 36k 13:45 17:15 3.50 9,387 9,389 PROD1 WHPST MILL P OB milling-1.5 bpm at 3500psi, BHP 4027,WHP 250, IA 464,OA 468 17:15 20:27 3.20 9,389 9,393 PROD1 WHPST MILL P Continue milling-9388.7ft sample showing formation cuttings. 20:27 20:57 0.50 9,393 9,398 PROD1 WHPST MILL P Drilling formation with WOB, 1.46 BPM @ 3542 PSI FS, BHP=4010, WHP=250 PSI 20:57 21:33 0.60 9,398 9,398 PROD1 WHPST REAM P Start back reaming passes, PUW=33K, HS 30L,30R. had bobble on HS and 30R pass @ 9389.8. make additional HS pass looks good 21:33 00:00 2.45 9,398 2,716 PROD1 WHPST TRIP P Trip out of well.Call out SLB N2 @ 23:30 to be on locaction @ 1:30 01/04/2013 Blow down coil and swap out, R/U new inner reel iron 00:00 01:00 1.00 2,716 85 PROD1 WHPST TRIP P Trip out(cont.), roll coil to water 01:00 01:30 0.50 85 0 PROD1 WHPST PULD P At surface,trap 1100PSI and shut SSSV, PJSM while flow checking well,Mill out©2.79 No Go 01:30 02:00 0.50 0 0 PROD1 DRILL CTOP P M/U nozzle and prep for N2 reel blowdown and coil unstab. 02:00 03:30 1.50 0 0 PROD1 DRILL CTOP T Stand by for SLB N2 pumpers to arrive on location. Initial call out @ 11:30 2 Hr call out Page 3 of 14 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 03:30 04:42 1.20 0 0 PROD1 DRILL CTOP P SLB N2 on location,watch safety orientation video, hold planning meeting, MIRU N2 pumper, PT to 3500 PSI. Purge CT string with N2. and bleed off 04:42 05:30 0.80 0 0 PROD1 DRILL CTOP P PJSM, R/U cable to unstab coil and secure to spool 05:30 06:00 0.50 0 0 PROD1 DRILL CTOP P Unstab Coil from INJH and secure to reel. 06:00 09:30 3.50 0 0 PROD1 DRILL CTOP P PJSM-Prep reel for lowering,Set up INJH for brass changeout. 09:30 12:30 3.00 0 0 PROD1 DRILL CTOP P PJSM-Lower reel to truck and picking up the new reel 12:30 16:30 4.00 0 0 PROD1 DRILL CTOP P PJSM-Secure reel to rig. 16:30 16:45 0.25 0 0 PROD1 DRILL CTOP P PJSM-Test a-line.Continuity test 51 ohms.>2000 meg ohms.good test. 16:45 18:00 1.25 0 0 PROD1 DRILL CTOP P Install inner reel iron and bulk head. 18:00 23:00 5.00 0 0 PROD1 DRILL CTOP P Crew change out, PJSM continue inner reel iron install, Intall pressure bulkhead and test,M/U grapple and pull test. Remove banding and protective covering from spool. 23:00 00:00 1.00 0 PROD1 DRILL CTOP P PJSM,Stab coil into injector and horse head 01/05/2013 Completed reel swap, Found ice plug in coil during filling ops damaging wire, Blow down coil and prep to swap 00:00 01:00 1.00 0 0 PROD1 DRILL CTOP P Coil stabbed, Install boot on E-Line, CIO pack offs,valve check list,fill pit with fresh water 01:00 01:18 0.30 0 0 PROD1 DRILL CTOP P Stab on well fill coil with fresh water reversing 01:18 02:48 1.50 0 0 PROD1 DRILL CTOP T At—14 BBIs in coil pressured up. Pump shut down, all surface equipment cheched out good. Popped off and tested wire test @ 30 Ohmes. Pull junction box apart in reel wire still testing @ 30 Ohmes. Call out rig electrician.Turn on all heat we can get on reel 02:48 04:12 1.40 0 0 PROD1 DRILL CTOP T Electricial verified all past tests. Open up junction box and test wire. No good.Ohmes numbers indicate short at wire mid point.Cut 25 pipe and retest. No good 04:12 04:24 0.20 0 0 PROD1 DRILL CTOP T Boot end of coil,stab on and pump to see if coil has thawed 04:24 06:54 2.50 0 0 PROD1 DRILL CTOP T Pump normal way—.8 coil is frozen, Tarp coil and crank up the heat. 06:54 07:09 0.25 0 0 PROD1 DRILL CTOP T Pump to see if coil is free not successful 3 bbls away it locked up. Keep 130psi on ice plug. 07:09 09:09 2.00 0 0 PROD1 DRILL CTOP T Pumping 0.5bpm 250psi unfrozen coil Page 4 of 14 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 09:09 09:30 0.35 0 0 PROD1 DRILL CTOP T Finish filling coil with fresh water. Bleed pressure,Check a-line.32 ohms test from the downhole end. Test from up hole end is 27. Roughly making the break somewhere around 7864ft. 09:30 13:30 4.00 0 0 PROD1 DRILL CTOP T Call SLB N2 for reel blowdown.On weather hold due to wind for crane work. 13:30 15:00 1.50 0 0 PROD1 DRILL CTOP T PSJM-Blowdown reel to tiger tank. 15:00 18:00 3.00 0 0 PROD1 DRILL CTOP T PSJM-Bleed pressure,and rig down inner reel iron and bulkhead. 18:00 20:30 2.50 0 0 PROD1 DRILL CTOP T Rig up line to blow air through coil with 300 PSI compressor.Started seeing air from compressor at DH end within 4 minutes of starting air 20:30 00:00 3.50 0 0 PROD1 DRILL CTOP T Pull back coil and sucure to ro spool, R/U spool lifting equipment 01/06/2013 Swap out CT String, Pull CT into injector, Unable to purge coil with air 00:00 02:00 2.00 0 0 PROD1 DRILL CTOP T Continue rigging up reel to pick 02:00 10:00 8.00 0 0 PROD1 DRILL CTOP T Stand by on weather to load next reel in Deadhorse 10:00 10:15 0.25 0 0 PROD1 DRILL CTOP T PJSM-with Peak and crew for swapping reels. 10:15 11:30 1.25 0 0 PROD1 DRILL CTOP T New reel loaded. 11:30 14:30 3.00 0 0 PROD1 DRILL CTOP T PJSM-Install hubs onto reel. 14:30 21:00 6.50 0 0 PROD1 DRILL CTOP T Reel is in, PJSM-Install inner reel iron and bulkhead,Test wireline,51 ohmes/550 Mhoes both ends good 21:00 22:15 1.25 0 0 PROD1 DRILL CTOP T PJSM, Pull test internal grapple connector, Pull ct through injector 22:15 22:21 0.10 0 0 PROD1 DRILL CTOP T Test reel E-Line,good test, polarity verified 22:21 00:00 1.65 0 0 PROD1 DRILL CTOP T Blow air through coil, unable to get air through coil,tarp down reel, attempt to blow through every 30 minutes 01/07/2013 Thaw coil, perform slack mgmt, Head up e-line,M/U Build section BHA, RIH 00:00 07:00 7.00 0 0 PROD1 DRILL CTOP T Continue thawing coil/purge with air. Install counters, new packoffs 07:00 09:15 2.25 0 0 PROD1 DRILL CTOP T After morning call we discussed pumping a 5 bbl methanol spear into the reel to check if it is still froze. 09:15 10:00 0.75 0 0 PROD1 DRILL CTOP T Town called and say go ahead with pumping methanol.Called downhole pumpers to be dispatched to the rig. 10:00 10:15 0.25 0 0 PROD1 DRILL CTOP T PSJM-with downhole pumpers. Blow air through cement line to verify ice free. Rig up pumpers to cement line. 10:15 11:00 0.75 0 0 PROD1 DRILL CTOP T PJSM-Load 6 bbls of neat methanol into the coil with DHP. 300psi, 0.25bpm Page 5 of 14 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 11:00 13:00 2.00 0 0 PROD1 DRILL CTOP P Fill coil pumping 0.3bpm at 400psi taking meoth returns out to the tiger tank. 13:00 15:00 2.00 0 0 PROD1 DRILL BOPE P PT inner reel iron, pack-off,and inner reel valve and chart.and remove parachute off of reel. 15:00 16:00 1.00 0 0 PROD1 DRILL CTOP P Perform slack management.Cut 15ft of coil to find wire. 16:00 18:00 2.00 0 0 PROD1 DRILL CTOP P PJSM-Install CTC to 4000psi,pull test to 36k, rehead BHI upper quick. 18:00 19:30 1.50 0 0 PROD1 DRILL CTOP P Install nozzle,stab onto well with Swabs closed Pump forward one coil volume to tiger tank while swapping coil over to 9.6ppg drilling mud. 19:30 20:00 0.50 0 0 PROD1 DRILL OWFF P Open well to check pressure 508 psi, bleed pressure and monitor well for flow at the shaker getting returns. Shut in against choke well head pressure built up to 385psi. Looks like the SSSV is not holding. 20:00 22:00 2.00 0 0 PROD1 DRILL PULD P PJSM-Load PDL with tools, Deploy BHA 22:00 00:00 2.00 0 5,900 PROD1 DRILL TRIP P RIH with build BHA#4:2.5°ako motor with Hughes bi-center bit 01/08/2013 Encountered motor stall @ 9,409', unable to successfully clear stall condition. POOH BHA#4, PUD BHA#4. PD BHA#5. RIH with BHA#5,drill build section from 9,409 to 9,462'. POOH w/BHA#5, PUD.MU&PD BHA#6, RIH w/BHA#6. Drill ahead L1 lateral to 9,490'. 00:00 00:54 0.90 5,900 9,240 PROD1 DRILL TRIP P Trip in well 00:54 01:30 0.60 9,240 9,260 PROD1 DRILL DLOG P Log tie into K1, Missed K1 on first pass, PUH to 9210 and relog, +28' correction,close EDC, PUW=31 K 01:30 01:42 0.20 9,260 9,398 PROD1 DRILL TRIP P RIH to drill,set down at bottom of window 9390.8 @ 18 FPM, PUH roll pumps,shut down pumps before attempting to go through window popped right through @ 15 FPH 01:42 02:06 0.40 9,398 9,409 PROD1 DRILL DRLG P 9398 on bottom, 1.5 BPM @ 3300 PSI FS, BHP=3999,WHP=300, Drilling ratty,seem to be slip sticking. 02:06 02:24 0.30 9,409 9,409 PROD1 DRILL DRLG P Encounter motor stall, Unable to clear stall, PUH out of window dry. Motor still locked up.try unsuccessfully to clear stalled condition 02:24 05:18 2.90 9,250 65 PROD1 DRILL TRIP T Open EDC and trip out of well following MP schedule,Jet SSSV on way out Start BHI NPT 05:18 07:18 2.00 65 0 PROD1 DRILL PULD T At surface,Close SSSV and observe for flow.SSSV not holding. PJSM PUD BHA#4. Found bit plugged with rubber from motor(61.8 hrs on motor). Cleared rubber from bit for rerun. 07:18 09:06 1.80 0 62 PROD1 DRILL PULD T PJSM PD BHA#5, Check counters. Surface test,tag stripper Page 6 of 14 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:06 11:48 2.70 62 9,210 PROD1 DRILL TRIP T RIH,stop and check saddle bolts- Inner reel iron hold downs 11:48 12:00 0.20 9,210 9,250 PROD1 DRILL DLOG T Log tie in to K-1 for+8'correction, Shut EDC PUW=32K 12:00 12:12 0.20 9,250 9,408 PROD1 DRILL TRIP T RIH to drill,good trip through window, Bobbles but no set downs End BHI N PT 9 Hrs 12:12 14:54 2.70 9,409 9,462 PROD1 DRILL DRLG P Tag up at 9408 and stall,restart and drill ahead, 1.5 BPM @ 3580 PSI FS,WHP=280, BHP=4040 14:54 17:12 2.30 9,462 0 PROD1 DRILL TRIP P Call for end of build section,POOH for lateral BHA.Open EDC,continue OOH w/BHA#5,tag and space out. 17:12 19:24 2.20 0 0 PROD1 DRILL PULD P PJSM to PUD BHA#5,crew change, continue PUD BHA#5. Finish injector service,function test BOP. 19:24 20:30 1.10 0 0 PROD1 DRILL PULD P MU BHA#6, PD BHA#6 20:30 23:00 2.50 0 9,220 PROD1 DRILL TRIP P RIH w/BHA#6 23:00 23:15 0.25 9,220 9,462 PROD1 DRILL DLOG P Tie in to K1, plus 8ft correction. Close EDC, RIH to window,tag 9391 @ 20 fpm,try 30 fpm,continue in hole,Tie in to RA,9387.5 23:15 00:00 0.75 9,462 9,490 PROD1 DRILL DRLG P Drilling ahead @ 9,462. 1.4 BPM @ 3,472 PSI FG, BHP=4555 PSI, WOP 1.2K. 01/09/2013 Drilling ahead L1 lateral from 9,490'to 9,915',start pumping new mud swap,continue drilling ahead from 9,915'to 10,491'. 00:00 02:18 2.30 9,490 9,615 PROD1 DRILL DRLG P Drilling ahead @ 9,490. 1.4 BPM @ 3,330 PSI FG, BHP=4150 PSI, WOP 1.2K. 02:18 02:57 0.65 9,615 9,615 PROD1 DRILL WPRT P Wiper trip#1, PU#33K,Made mad pass. RBIH. 02:57 05:03 2.10 9,615 9,765 PROD1 DRILL DRLG P Drilling ahead @ 9,615. 1.4 BPM @ 3,550 PSI FG, BHP=4120 PSI, WOP 1.17K. 05:03 05:57 0.90 9,765 9,765 PROD1 DRILL WPRT P Wiper trip#2, PU#35. RBIH 05:57 07:45 1.80 9,765 9,915 PROD1 DRILL DRLG P 9765', Drill ahead, 1.42 BPM @ 3300PSI FS, BHP=4100 PSI 07:45 08:30 0.75 9,915 9,915 PROD1 DRILL WPRT P Wiper to window, 9405 with tie in for +.5'correction, Start pumping new mud 08:30 10:30 2.00 9,915 10,065 PROD1 DRILL DRLG P 9925',drill ahead, 1.4 BPM @ 3571 PSI FS, BHP=4110, RIW=15.7K with DHWOB=1.4K, New mud at bit 10:30 11:12 0.70 10,065 10,065 PROD1 DRILL WPRT P Wiper trip to 9515, PUW=33K 11:12 13:18 2.10 10,065 10,215 PROD1 DRILL DRLG P 10065', Drill Ahead, 1.35 BPM @ 3750 PSI FS, BHP=4050,WHP=125 13:18 14:12 0.90 10,215 10,215 PROD1 DRILL WPRT P Wiper to 9520', PUW=34K 14:12 16:00 1.80 10,215 10,365 PROD1 DRILL DRLG P 10215',drill ahead, 1.37 BPM @ 3800 PSI FS, BHP=4077 16:00 17:12 1.20 10,365 10,365 PROD1 DRILL WPRT P Wiper trip to window with tie in for no correction, PUW=33K Page 7 of 14 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 17:12 20:00 2.80 10,365 10,445 PROD1 DRILL DRLG P 10365',Drill Ahead, 1.4 BPM @ 3820 PSI FS, RIW=16.5K, WHP=160, BHP=4135,still dropping,trying to keep angle up, pick up off bottom to swap to high line power,continue drilling, ratty stuff, lots of near stalls. 20:00 20:03 0.05 10,445 10,445 PROD1 DRILL DRLG P Drilling,GEO-drop to 86 degrees, appear to be in"C"sand, lost rig power,swap back to generator power. 20:03 00:00 3.95 10,445 10,491 PROD1 DRILL DRLG P 10,445,drill ahead, 1.38 BPM @ 3804 PSI FS, RIW=15K, BHP=4136, ratty drilling,average ROP 10'per hour. 01/10/2013 Drilling ahead L1 lateral from 10,491 to 11,256'. 00:00 01:30 1.50 10,491 10,515 PROD1 DRILL DRLG P Continue drilling ahead, 1.38 BPM @ 3,800 PSI,WOB=2.9K BHP=4075, ratty drilling. 01:30 02:30 1.00 10,515 10,515 PROD1 DRILL WPRT P Wiper trip#1 to window, PUW= 33K, RBIH. 02:30 06:00 3.50 10,515 10,665 PROD1 DRILL DRLG P GEO=drop to 84 degrees,drilling ahead, 1.39 BHP @ 3980 PSI, BHP=4150 PSI,WOB=1.5K 06:00 07:12 1.20 10,665 10,665 PROD1 DRILL WPRT P Wiper to 9520, PUW=34K 07:12 09:30 2.30 10,665 10,815 PROD1 DRILL DRLG P 10665', Drill ahead, 1.4 BPM @ 3680 PSI FS, BHP=4150, RIW=15.4, DHWOB=.8K 09:30 11:12 1.70 10,815 10,815 PROD1 DRILL WPRT P Wiper to window with tie in for-7' correction, PUW=34K 11:12 14:12 3.00 10,815 10,965 PROD1 DRILL DRLG P 10815',Drill Ahead, 1.4 BPM @ 3670PSI FS, BHP=4200, RIW=14K, DHWOB=1K 14:12 15:36 1.40 10,965 10,965 PROD1 DRILL WPRT P Wiper to 9520 with 5/5 sweeps, PUW=33K 15:36 18:18 2.70 10,965 11,115 PROD1 DRILL DRLG P 10965', Drill Ahead, 1.37 BPM @ 3700 PSI FS, BHP=4220, DHWOD=I.5K 18:18 19:00 0.70 11,115 11,115 PROD1 DRILL WPRT P Wiper to 9520, PUW=34K 19:00 21:42 2.70 11,115 11,185 PROD1 DRILL DRLG P 11115', Drill Ahead, 1.37 BPM @ 3780 PSI FS, BHP=4279, DHWOB=1.1 K. GEO hold 89 degrees. 21:42 00:00 2.30 11,185 11,256 PROD1 DRILL DRLG P GEO=hold 87 degrees,drill ahead, inc not dropping,several stalls,not dropping. Drill ahead 1.40 BPM @ 3760 PSI, BHP=4275 PSI, DHWOB=2K. 01/11/2013 Drilling ahead AL1 lateral from 11,256'to 11,423',with 150'wiper trips to window,drilling became ratty with low ROP. Decision made from town to POOH,check bit and change to bent motor. 00:00 00:45 0.75 11,256 11,265 PROD1 DRILL DRLG P Continue drilling ahead, 1.38 BPM @ 3982 PSI FS, BHP=4315, DHWOB=I.5K Page 8 of 14 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 00:45 03:00 2.25 11,265 11,265 PROD1 DRILL WPRT P Wiper trip to window,Tie in to RA, -1ft. PUW=34K. RBIH.GEO=now wants 88 degress 03:00 06:00 3.00 11,265 11,297 PROD1 DRILL DRLG P Drilling ahead, 1.39 BPM @ 3850 PSI FS, BHP=4268 PSI, DHWOB=0.8K, ratty drilling,several stalls last two hours. 06:00 06:24 0.40 11,297 11,297 PROD1 DRILL WPRT P BHA Wiper, PUW=33.5K 06:24 10:42 4.30 11,297 11,309 PROD1 DRILL DRLG P 11297', Drill Ahead, 1.35 BPM @ 3650 PSI FS, BHP=4230 10:42 10:54 0.20 11,309 11,309 PROD1 DRILL WPRT P 11309 BHA Mini wiper, PUW=33K 10:54 16:00 5.10 11,309 11,408 PROD1 DRILL DRLG P 11309', Drill Ahead, 1.3 BPM @ 3520 PSI FS, BHP=4275 16:00 18:30 2.50 11,408 11,408 PROD1 DRILL WPRT P Wiper trip to 9035,jet 4 1/2 scab liner, PUW=34K. RBIH,tag @ 9,410 several times,roll pump,continue in hole. 18:30 19:30 1.00 11,408 11,423 PROD1 DRILL DRLG P 11,408', Drill ahead, 1.33 BPM @ 3690 PSI FS, BHP=4280 PSI, DHWOB=2.1K.GEO=wants max build force. 19:30 23:00 3.50 11,423 0 PROD1 DRILL TRIP P Decision made from town to POOH for bent motor and new bit. POOH to 500',open EDC, continue OOH. 23:00 00:00 1.00 0 0 PROD1 DRILL PULD P Tag up,space out, PUD BHA#6. 01/12/2013 Drill ahead from 11,423'to called TD @ 11,660'. Pumped 10 bbl low/high vis sweeps to surface. RBIH.Tie-in to K1 for corrected TD,set down three times 11,597',getting sticky,decide to POOH laying in 12.4 ppg completion fluid in open hole. Flag EOP @ 7,700 and 9,600'.Continue OOH laying in KWF. 00:00 01:00 1.00 0 0 PROD1 DRILL PULD P Continue PUD BHA#6. Bit had significant wear,picture in 3Q-06 folder on S:Drive. 01:00 01:30 0.50 0 0 PROD1 DRILL PULD P Reconfigure BHA 01:30 03:00 1.50 0 0 PROD1 DRILL PULD P PJSM and PD BHA#7 03:00 06:15 3.25 0 11,423 PROD1 DRILL TRIP P RIH with BHA#7 to 11,423',tie into K1 for+10' 06:15 09:03 2.80 11,423 11,575 PROD1 DRILL DRLG P 11,423',drilling ahead, 1.35 BPM @ 4030 PSI FS, BHP=4280 PSI, DHWOP=1.35K 09:03 11:09 2.10 11,575 11,575 PROD1 DRILL WPRT P 11575',wiper to window, PUW=34K 11:09 14:33 3.40 11,575 11,660 PROD1 DRILL DRLG P 11575',drill ahead, 1.35 BPM @ 3910 PSI FS, BHP=4254 14:33 14:57 0.40 11,660 11,660 PROD1 DRILL WPRT P 11660,Call TD, PUH while pumping 10/10 sweeps, PUW=34K 14:57 20:00 5.05 11,660 72 PROD1 DRILL WPRT P Sweeps coming out on bottom, Chase to swabs, PUW=34K.Tag up, set depth. 20:00 22:30 2.50 72 11,596 PROD1 DRILL TRIP P RBIH.Tie-in to K1=+6 correction, close EDC @ 9,263',continue in hole,tag three times 11,596'. Pulling hard,decide not to try to go to bottom. Page 9 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 11,596 7,772 PROD1 DRILL TRIP P OOH laying in 12.4 ppg completion fluid in open hole.Overpull&appear to be packing off at 11,457'MD, pressure very high. Better now,but some drag.Continue OOH laying pill, paint 9,600 EOP flag,paint 7,700 EOP flag.Continue OOH laying KWF. 01/13/2013 Pull up to swab,Shut down for Phase 3 Weather 00:00 02:30 2.50 7,772 72 PROD1 DRILL TRIP P Continue OOH laying in 12 ppg KWF to surface,on surface,check well for flow,well on slight vacuum. Phase three weather conditions called field wide in Kuparuk 02:30 00:00 21.50 72 72 COMPZ CASING PULD T Stand by at surface for phase three weather conditions, continue to monitor well for hole fill,every hour circulate through coil. 01/14/2013 SB for Phase 3 00:00 00:00 24.00 72 72 COMPZ CASING PULD T Stand by at surface for phase three weather conditions,continue to monitor well for hole fill,every hour circulate through coil. 01/15/2013 Phase 3 lifted 10am.Safeout rig,clearing snow drifts,engine vents,ice build up in derrick ect..Grease choke,stack and tree valves.Start BOPE testing(1500hrs),Complete(2130hrs)0 Failures.State Witness Waived by:Jeff Jones _ 00:00 10:00 10.00 0 0 COMPZ CASING PULD T Stand by at surface for phase three weather conditions,continue to monitor well for hole fill,every hour circulate through coil. 10:00 10:30 0.50 0 0 COMPZ CASING SFTY T Weather conditions lifted to Phase 2. Crew change PTM 10:30 14:30 4.00 0 0 COMPZ CASING SFTY T Safe out rig, clearing snow,cleaning vents,assure all is in safe working order 14:30 15:30 1.00 0 0 COMPZ CASING BOPE P Grease stack,choke,and tree valves 15:30 22:30 7.00 0 0 COMPZ CASING BOPE P Start BOPE testing ***State Witness waived by:Jeff Jones**** 22:30 00:00 1.50 0 0 COMPZ CASING SVRG P Rig down test joint/Blow down testing lines. Service Bowen connections on stack,Service injector head. Prepare floor to PU liner 01/16/2013 PU/MU A Lateral liner. Run#1 41 jnts 2 3/8"slotted liner releasing on depth. Run#2 5 jnts with OH anchored billet, setting single slip 340 deg TF. BOL-11307',TOL-9750',with liner break @ 9940'. PU/MU/RIH drilling BHA(.8 ako).Swap well back to drill mud(New System). 00:00 02:45 2.75 0 0 COMPZ CASING PUTB P PU/MU 4ljnts 2 3/8"slotted liner 02:45 04:45 2.00 1,412 9,100 COMPZ CASING RUNL P RIH 04:45 05:00 0.25 9,100 9,100 COMPZ CASING DLOG P Correct depth+7'to EOP flag. Record up weight 36K Page 10 of 14 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T_ Comment 05:00 05:30 0.50 9,100 11,307 COMPZ CASING RUNL P RIH to 11307' 05:30 05:45 0.25 11,307 11,307 COMPZ CASING RUNL P At 11307 offline with pumps.weight check 40K. PU 25'. Online with pumps 3800psi. RIH to release depth 11307'.PU 35K PUW.5K Lost on PUW. Liner released. Line up to pump across top. 05:45 08:51 3.10 11,307 0 COMPZ CASING RUNL P POOH to K1 marker,Gamma tie-in, zero correction,POOH. Flag EOP @ 9,000. Continue OOH BHA#8. 08:51 09:36 0.75 0 0 COMPZ CASING PULD P Flow check, PJSM. LD BHA#8,prep floor for liner. 09:36 10:54 1.30 0 0 COMPZ CASING PULD P PJSM. PU 5 jts liner, 1 pup,MWD. Prep floor, move PDL.Test MWD, stab on injector,tag stripper,Open EDC. 10:54 14:18 3.40 0 9,939 COMPZ CASING RUNL P RIH w/anchor billet on BHA#9. Close EDC,continue in hole,correct at flag+6.69 ft, PUW=35K,tie-in gamma-1 ft correction, RIH to slight tag @ 9,939'. Bring pump online,set anchor billet with slip at 340 deg TF. Release from setting tool @ 3,400 psi. Note: Downhole short occurred while releasing. No communication with tool string. 14:18 17:03 2.75 9,939 0 COMPZ CASING RUNL P POOH w/BHA#9 17:03 18:48 1.75 0 0 COMPZ CASING PULD P LD BHA#9 18:48 20:48 2.00 0 0 PROD2 STK PULD T PU BHA 10. Found short in BHI's drilling head. Rewire. Indication of fluid penetration. 20:48 22:33 1.75 72 9,225 PROD2 STK TRIP P RIH 22:33 22:48 0.25 9,225 9,370 PROD2 STK DLOG P Tie in depth to K1. +4.5'correction 22:48 00:00 1.20 9,370 9,370 PROD2 STK DISP P Swap well over to Drill mud.(9.6 ppg Flo-Pro) 01/17/2013 KO anchored billet 9749'.Drill AL1 lateral. 00:00 00:45 0.75 9,370 9,749 PROD2 STK KOST P RIH dry tag billet 9749'. PU online with pumps 1.38 bpm 3600 ctp,481 diff off bottom psi. 160 whp, 16k ctw, RIH to start KO.Stall X 2.Clean PU 00:45 03:45 3.00 9,749 9,762 PROD2 STK KOST P RIH Start milling billet,Set Auto driller 1 fph for 1' 2 fph for 1' 3 fph for 1' 10 fph for 5' 20 fph for 5' 03:45 04:15 0.50 9,762 9,790 PROD2 STK KOST P Drill ahead 1.35 bpm, 3800 ctp, 1-2k wob, 190 whp. 04:15 04:30 0.25 9,790 9,730 PROD2 STK REAM P PU drift billet 35K puw.W/O pumps. Looked good, RIH to drill Page 11 of 14 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:30 06:00 1.50 9,790 9,930 PROD2 DRILL DRLG P Drill Ahead 1.35 bpm,3973 ctp, 18k ctw, 182 whp,4138 bhp 06:00 06:51 0.85 9,930 9,930 PROD2 DRILL WPRT P Wiper#1 PUW=34K 06:51 13:21 6.50 9,930 10,080 PROD2 DRILL DRLG P Drill Ahead 1.35 bpm,3,950 ctp, 15.5k ctw, 190 whp,4152 bhp. GEO=91 deg,change to 92 deg. Continue drilling ahead,ratty drilling, several stalls in spots. 13:21 14:12 0.85 10,080 10,080 PROD2 DRILL WPRT P Wiper#2, PUW=33K 14:12 17:45 3.55 10,080 10,230 PROD2 DRILL DRLG P Drill Ahead 1.34 BPM @ 4052 psi 14.5 K ctw, 151 whp,4172 bhp. GE0=92 deg. 17:45 18:45 1.00 10,230 10,230 PROD2 DRILL WPRT P Wiper#3, PUW=31k Tie in depth to RA marker.+.5'correction. RBIH 18:45 20:45 2.00 10,230 10,380 PROD2 DRILL DRLG P Drill ahead 1.5 bpm,4038 ctp, 11k ctw,91 whp,4184 bhp 20:45 21:15 0.50 10,380 9,430 PROD2 DRILL WPRT P Wiper trip back to window 33k puw 21:15 21:45 0.50 9,430 10,380 PROD2 DRILL WPRT P RBIH 21:45 00:00 2.25 10,380 10,500 PROD2 DRILL DRLG P Drill Ahead 1.3 bpm,3983 ctp,81 whp,4161 bhp, 13k ctw 01/18/2013 Drill AU lateral to 10621'. Slow ROP's. POOH for Bit inspection. Excessive wear on bit,swap out bit RBIH. Continue drilling AU lateral. 00:00 04:27 4.45 10,500 10,526 PROD2 DRILL DRLG P Drill Ahead 1.3 bpm,3983 ctp,81 whp,4161 bhp, 13k ctw.ROP 2-10 fph 04:27 04:51 0.40 10,526 10,526 PROD2 DRILL WPRT P 4 stalls,Clean PU's,Crude tracers in returns. Increase MP 50psi.pull 500' wiper trip.scheduled wiper to be at 10530'.31k puw 04:51 05:45 0.90 10,526 10,526 PROD2 DRILL WPRT P Wpier trip#2 to 10,000'. PUW=34K. RBIH. 05:45 09:45 4.00 10,526 10,621 PROD2 DRILL DRLG P Drill ahead, 1.33 BPM @ 3,970 PSI 86 WHP, BHP 4260 BHP, 14 K CTW, ROP=20-40.GE0=89 deg. Decision made by town to change bit. 09:45 13:39 3.90 10,621 0 PROD2 DRILL TRIP P POOH w/BHA#10,open EDC @ 9359',continue OOH. 13:39 16:09 2.50 0 0 PROD2 DRILL PULD P PUD BHA#10,LD Hycalog bit,side of bit balled up,some wear on leading edge, pictures in 3Q-06 data folder. PJSM.MU BHA#11.PD BHA #11 16:09 18:39 2.50 0 9,225 PROD2 DRILL TRIP P RIH w/BHA#11 18:39 18:54 0.25 9,225 9,225 PROD2 DRILL DLOG P Tie n depth to K1.+4'correction 18:54 19:24 0.50 9,225 10,621 PROD2 DRILL TRIP P Close EDC RIH To TD 19:24 21:45 2.35 10,621 10,800 PROD2 DRILL DRLG P Drill Ahead 1.38 bpm,4072 ctp,4163 bhp, 13k ctw,2.5k wob. Drill an extra 30' 21:45 22:15 0.50 10,800 10,300 PROD2 DRILL WPRT P Wiper trip 500'. 22:15 22:30 0.25 10,300 10,800 PROD2 DRILL WPRT P RBIH Page 12 of 14 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 22:30 00:00 1.50 10,800 10,880 PROD2 DRILL DRLG P 'Drill Ahead 1.38 bpm,4172 ctp,4163 'bhp, 13k ctw,2.5k wob. 01/19/2013 TD AL1 lateral 11130'. POOH tyo swab valves. RBIH to TD. Lay in 12.4ppg KWF(Formate)w/beads to window,w/o beads to surface. PU/MU/RIH AL1 liner 53jnts slotted liner. Release on bottom.TOL-9357'. 00:00 01:00 1.00 10,880 10,950 PROD2 DRILL DRLG P Drill Ahead 1.38 bpm,4172 ctp,4163 bhp, 13k ctw,2.5k wob. 01:00 01:30 0.50 10,950 10,450 PROD2 DRILL WPRT P 500'wiper trip 33k puw 01:30 01:45 0.25 10,450 10,950 PROD2 DRILL WPRT P RBIH 01:45 04:00 2.25 10,950 11,100 PROD2 DRILL DRLG P Drill Ahead 1.38 bpm,4172 ctp,4163 bhp, 13k ctw,2.5k wob. 04:00 04:45 0.75 11,100 11,130 PROD2 DRILL DRLG P Pump 10 brls low/high sweeps.Cont. drilling ahead 04:45 08:00 3.25 11,130 0 PROD2 DRILL WPRT P TD AL1 Lateral 11,130'. POOH to swab valves.34k puw.Tag stripper, reset depth. 08:00 11:15 3.25 0 11,131 PROD2 DRILL TRIP P RBIH.Tie-in to Gamma+5.5 correction,continue in hole,tag corrected TD. 11:15 14:30 3.25 11,131 0 PROD2 DRILL TRIP P Recip bit until KWF 12.4 ppg out of bit. POOH,laying in beaded KWF, paint EOP flag @ 9,200',continue OOH laying in KWF,paint EOP flag @ 7,500',continue OOH laying in KWF. 14:30 16:00 1.50 0 0 PROD2 DRILL PULD P On surface,check well for flow, PJSM. LD BHA#11. 16:00 21:15 5.25 0 0 COMPZ CASING PUTB P PU/MU BHA#12,bullnose,53 jts slotted liner,shorty deployment sleeve. 21:15 23:30 2.25 1,816 9,311 COMPZ CASING RUNL P RIH 23:30 23:45 0.25 9,311 9,316 COMPZ CASING DLOG P Tie in depth to EOP flag.+4' correction,wt chk 36k 23:45 00:00 0.25 9,316 11,133 COMPZ CASING RUNL P RIH to TD 01/20/2013 Swap well to SW and freeze protect. Undeploy BHA,set BPV, RDMOB 00:00 00:45 0.75 11,133 9,358 COMPZ CASING TRIP P Liner on bottom,weight chk 45k. RBIH 5k down,online with pumps. 4000psi, PU 37k puw,liner reased on bottom. Remove liner length from BHA.TOL-9358' 00:45 02:15 1.50 9,350 9,350 COMPZ CASING DISP P Swap well to seawater 02:15 02:30 0.25 9,350 9,225 COMPZ CASING DLOG P Tie in depth to K1,0 correction 02:30 04:30 2.00 9,225 0 COMPZ CASING TRIP P POOH,freeze protect well.2000' 04:30 04:45 0.25 0 0 COMPZ CASING SFTY P At surface, 1245 psi whp. PJSM 04:45 07:30 2.75 0 0 COMPZ CASING PULD P Undeploy BHA,crew change, PJSM. Line up BO PDL, LD BHA,organize rig floor. 07:30 08:30 1.00 0 0 DEMOB WHDBO NUND P Jet BOPE equipment. PU lubricator install BPV. Pump inhibitor,flush and purge coil/rig. Page 13 of 14 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 08:30 14:00 5.50 0 0 DEMOB WHDBO DMOB P Blow down CT reel and rig lines to tiger tank. Rig down MP line and misc. lines in cellar. 14:00 00:00 10.00 0 0 DEMOB WHDBO DMOB P Continue to prep rig for move to 3C-pad.Nipple down BOPE, R/D SSSV remote panel. Lift and secure BOPE Rig Release: Midnight Page 14 of 14 MS 1111 APR 1, 2013 BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes 1 (mandatory) WELL NAME 3Q-06A;3Q-06AL1 RUN NUMBER 2J3-OD n�j (mandatory) '2-2— .1 G— FIELD Kuparuk BH SALESMAN Anyanwu,Okechukwu(OKEY) (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: January 15,2013 TODAYS DATE: 4/3/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digital il ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSONATTENTION #OF PRINTS #Ur I'HIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. 1 1 I • I I I I NSK Wells Aide,NSK 69 I ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I 1 1 I 1 I I I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 B I I 1 I 1 I I I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I I 1 I 1 I I I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT i I I 1 I I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 Letter of Transmittal r& u BAKER Date: January 29, 2013 HUGHES To: ' From: ` 1 Christine Mahnken Carl Ulrich/Michael Soper 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): 39_-06"- ,.-I 2— • t E.3 3Q-u6 A L1✓a 1 3 . C 1,5--) C--------- (2) 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. 1 Michael Soper, Baker Hughes, Project Engineer ) Michael.Soper @BakerHughes.com , Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich @BakerHughes.com _ �w�\..,—_sA THE STATE Alaska Oil and Gas ��y�_ 'a"' �f�LAs� Conservation Commission ' t tv GOVERNOR SEAN PARNELL 333 West Seventh Avenue °FALASY'� Anchorage, Alaska 99501-3572 Main: 907.279.1433 Lamar Gantt Fax: 907.276.7542 Wells Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field,Kuparuk River Oil Pool, 3Q-06AL1 ConocoPhillips Alaska, Inc. Permit No: 213-005 Surface Location: 2229' FNL, 2255' FEL, SEC. 17,T13N,RO9E, UM Bottomhole Location: 1202' FNL, 269' FWL, SEC. 18, T13N, RO9E, UM Dear Mr. Gantt: 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 3Q06A, Permit No 212-183,API 50-029- 21683-01-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, /(991....4 Cathy P. oerster Chair DATED this 87d y of January,2013. cc: Department of Fish&Game,Habitat Section w/o end.(via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION �l PERMIT TO DRILL JAN 14 2013 ?ua lln-Iv'5 20 MC 25.005 �+� la.Type of Work: lb.Proposed Well Class: Development-Oil p• Service-Winj ❑ .Single Zone �Cf�1 c.Specify l : Drill ❑ Lateral g Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ 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• 3Q-06AL1 c 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11125'• TVDSS: 6272' • Kuparuk River Field 4a. Location of Well(Governmental Section): �7.Property Designation(Lease Number): Surface:2229'FNL,2255'FEL,Sec. 17,T13N,RO9E,UM- ADL 25512• Kuparuk River Oil Pool. Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1292'FNL, 1628'FWL,Sec. 18,T13N, RO9E, UM 2553 1/15/2013 • Total Depth: 9.Acres in Property: p 14.Distance to 1202'FNL,269'FWL,Sec. 18,T13N,RO9E,UM 1.289- asyy 11"'Z`1' Nearest Property: 11190- 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: •59 feet 15.Distance to Nearest Well Open Surface:x- 516081 y- 6025843 Zone- 4. GL Elevation above MSL: • 17 feet to Same Pool: 3Q-08A,2130 16.Deviated wells: Kickoff depth: •9750 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: • 97• deg Downhole:4885 psig• Surface:4253 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 1753' 9372' 6256' 11125' 6272' 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) 9747 6564 9562 6437 9429', 9431' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 1875#poleset 115' 115' Surface 5037' 9.625" 1275 sx AS III,325 sx CI G 5068' 3684' Intermediate Production 9617' 7" 385 sx Class G, 175 sx AS I 9652' 6499.5' Liner 362' 4.5" scab liner 9040' 6094' Perforation Depth MD(ft): Perforation Depth ND(ft): 9382'-9422' 6316'-6344' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program 0. Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 - 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Victoria Ferguson Date: 1/11/2013 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 t&s Email J.Gary.Eller@a.conocoohiliios. m Printed Name Lamar Gantt Title Wells Engineering Supervisor Signature k„,„.„, g• 1664 Phone 263-4021 Date ii J4//3 Commission Use Only Permit to Drill API Number: Permit Apprpval_j� See cover letter Number: a 13 O 0 5 50-0,Q3 - a.1G 83 -6 0-00 I Date: \\\1D for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: d Other: Samples req'd: Yes ❑ No Mud log req'd: Yes❑ No El 5t p Tr-5/ 4-p)(9/ $ / H2S measures: Yes RI No ❑ Directional svy req'd: Yes C✓( No Spacing exception req'd: Yes ❑ No 0 Inclination-only svy req'd: Yes LI No pg Approved by: P �' MMISSION �e nfiAtOt , Date: — / R —1 Form 10-401(Revis 10/2012) This permit is valid for 2 o h o e d to of approval(20 AAC 25.005(g)) - ' 0 vt-r /l/13 f., �,% \��ti Conoco Phillips p Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 14, 2013 RECEIVED Commissioner-State of Alaska JAN 14 2013 Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 AOGCC Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a Permit to Drill (PTD) application to drill and complete KRU 3Q-06AL1 from Kuparuk well 3Q-06A(PTD#212-183). Verbal authorization was provided via e-mail from AOGCC Engineer Victoria Ferguson on 1/11/2013 for drilling this lateral, although inclement weather has prevented this drilling operation from commencing yet. The addition of this 3Q-06AL1 lateral was needed because geologic complexity prevented the 3Q-06A(212-183)from achieving its geologic objectives. The 3Q-06AL1 and the 3Q-06A sidetrack will both serve as a"Development— Oif'wells. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary(revised for 3Q-06AL1, with revisions shown in blue font) — Permit to Drill application form for 3Q-06AL1 — Copy of the e-mail granting verbal authorization to continue with drilling operations — Directional plans for 3Q-06AL1 — Proposed wellbore schematic If you have any questions or require additional information please contact me at my office 907-263-4172. Sincerely, J. G N Iler Conoco•hillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Sidetrack .r �NAtN ■ Drilling �� &Wells 3Q-06A Drilling Program Summary 2AC Update for Addition of 3Q-06AL1 Lateral (blue font) 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 Attachment 1: Directional Plan for 3Q-06A&AL1 6 Attachment 2: Current Well Schematic for 3Q-06 6 Attachment 3: Proposed Well Schematic for 3Q-06A&AL1 CTD Sidetrack 6 Page 1 of 6 ORIGINAL Updated January 14,2013 PTD Apple___lion for KRU 3Q-06A & AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) KRU 3Q-06A is a proposed CTD sidetrack from the 3Q-06 motherbore. It will be classified as a"Development- Oil'well. The 3Q-06AL1 lateral is being added to pick up bypassed due to geologic complexity. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Both the 3Q-06A and 3Q-06AL1 will target the Al sand in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 3Q-06A sidetrack. 3. Blowout Prevention Equipment Information (Requirements of 20 AA C 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4800 psi. Using a maximum potential formation pressure of 4885 psi, the maximum potential surface pressure is 4253 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure Well 3Q-06 has been shut in since 2006 due to casing damage. It has a static BHP from August 2012 that measured 3960 psi at 9277' MD, 6251'TVD for an EMW of 12.2 ppg. The workover that was conducted in November 2012 used 12.6 ppg mud to maintain formation over-balance. Since the well has been shut in for such a long period of time and we are drilling west away from any other existing wells, our expectation is that we will encounter similar formation pressure while drilling the 3Q-06A CTD sidetrack. Maximum potential formation pressure is based on the October 2012 pressure measurement from the 3M-26 injector to the south. It had a formation pressure of 4938 psi at 6389'TVD for a gradient of 14.9 ppg. In well 3Q-06 this equates to a maximum potential formation pressure of 4885 psi (9382' MD, 6321'ND) and a maximum potential surface pressure of 4253 psi assuming a gas gradient to surface. Potential Gas Zones No specific gas zones will be drilled, but 3Q pad is located in an area of active miscible gas injection. It is likely that an influx can produce a significant amount of gas. Potential Causes of Hole Problems The major expected downhole risk in the 3Q-06A sidetrack is hole stability due to interbedded shales in the A-sand and the underlying Miluveach shale. We will mitigate hole instability by maintaining a minimum ECD target of 12.4 ppg EMW at the window while drilling the CTD sidetrack, as well as using mud additives that minimize chemical instability. A second downhole risk is having adequate weight transfer to drill to the planned TD of 13,990' MD. We will mitigate that risk by maintaining very low doglegs in the sidetrack and maintaining mud lubricity. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) 3Q-06A and 3Q-06AL1 will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 Updated January 14,2013 PTD Appl,..r.tion for KRU 3Q-06A & AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Sidetrack Liner Liner Liner Liner Name Top MD Btm Top Btm Liner Details MD SSTVD SSTVD 3Q-06A 9750' 11,306' 6279' 6275' 23/8', 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3Q-06ALI 9372' 11,125' 6256' 6272' 23/", 4.7#, L-80, ST-L slotted liner up inside 4'h" scab liner Existing Casing/Liner Information Category OD Wt Grade Cxn Top Btm Top Btm Burst Col. (ppf) MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 0' 115' 0' 115' n/a n/a Surface Csg 9%" 36 J-55 BTC 0' 5068' 0' 3695' 3520 2020 Prod Csg 7" 26 J-55 BTC 0' 9652' 0' 6504' 4980 4320 Scab Liner 4W 11.6 L-80 BTC 9049' 9411' 6100' 6341' 8430 7500 Tubing 3W 9.3 L-80 grd Mod 0' 9040' 0' 6094' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.6 ppg) • — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.6 ppg). This mud weight alone will not hydrostatically overbalance formation pressure in the 3Q-06 motherbore, but overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The SSSV in well 3Q-06 has ceased to function properly, so the well will be loaded with —12.4 ppg over-balancing completion fluid while picking up liner. — Emergency Kill Weight fluid: Two well bore volumes (-170 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing pressure over- balance to the formation. In the 3Q-06A sidetrack we will target a constant BHP of 12.4 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Page 3 of 6 ORIGIL J Updated January 14,2013 PTD Apple. don for KRU 3Q-06A & AL1 Pressure at the 3Q-06A Window(9382' MD, 6321' TVD, 6262' SSTVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12.2 ppg) 4003 psi 4003 psi Mud Hydrostatic(9.6 ppg) 3155 psi 3155 psi Annular friction (i.e. ECD, 0.095 psi/ft) 891 psi 0 psi Mud + ECD Combined 4046 psi 3155 psi (no choke pressure) (overbalanced (underbalanced -40 psi) -850 psi) Target BHP at Window(12.4 ppg) 4076 psi 4076 psi Choke Pressure Required to Maintain 30 psi 920 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3Q-06 is an A-sand producer that has been shut in for several months due to problems with sand production. A rig workover was recently conducted (sundry approval 312-313)to replace the 2%"tubing and to install a 4'/2" scab liner across the damaged 7" casing adjacent to the A-sand perforations. The 4'/2" scab liner will be cemented in place in the next few days, effectively plugging the existing perforations in 3Q-06. The 3Q-06A sidetrack will be drilled west of 3Q-06 to increase reservoir exposure and improve waterflood sweep in the Al sand. It will exit the 4%2" scab liner and 7" casing at 9382' MD and will target the Al sand west of the existing well. It was drilled to a TD of 11,660' MD. The hole will be completed with a 2%'slotted liner to 11,306' MD with an aluminum billet at 9750' MD. The 3Q-06AL1 lateral will be drilled west of 3Q-06 to increase reservoir exposure and improve waterflood sweep in the Al sand. It kick off from the 3Q-06A sidetrack at 9750' MD and will target the Al sand. The " hole will be completed with a 2%" slotted liner to the TD of 11,125' MD with the final liner top located inside the 4Y" liner at 9372' MD. Pre-CTD Work 1. MIRU slickline. Dummy all GLMs. Run whipstock dummy inside 3%2"tubing. 2. MIRU a-line. Shoot squeeze perfs in the 4%2" scab liner. 3. MIRU coiled tubing. Lay in a balanced cement plug inside the 4%2" scab liner. Apply squeeze pressure. Wait on cement to set. Page 4 of 6 Updated January 14, 2013 ORIGINAL PTD Appl..tion for KRU 3Q-06A & AL1 4. Under-ream cement out of 4%" scab liner to TD. 5. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3Q-06A Sidetrack(Al sand, west) a. Set whipstock in the 4'/z" scab liner at 9382' MD b. Mill 2.80"window through 4%2' scab liner and 7"casing at 9382' MD c. Drill 2.70"x 3" bi-center sidetrack to TD of 11,660' MD d. Run 2%" slotted liner to 11,306'with an aluminum billet at 9750' MD. The well will be loaded with over-balancing completion fluid while picking up slotted liner. 3. 3Q-06AL1 Lateral (Al sand, west) a. Kick off from billet at 9750' MD b. Drill 2.70"x 3" bi-center sidetrack to TD of 11,125' MD c. Run 2%" slotted liner from TD up to 9372' inside the 4%" scab liner. The well will be loaded with over-balancing completion fluid while picking up slotted liner. 4. Freeze protect. 5. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. MIRU slickline. Install gas lift design. Perform static BHP survey. 3. Put well on production. Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Page 5 of 6 OnICItsl g ' I Updated January 14,2013 PTD Appl..,,..tion for KRU 3Q-06A & AL1 Liner Running — Well 3Q-06 is equipped with a SSSV which will be used to isolate formation pressure while picked up jointed, slotted liner. If the SSSV fails, fluid of sufficient density to over-balance the formation will be used to provide formation over-balance while picking up slotted liner. See the"Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — 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.. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — There are no other affected owners — Please see attached directional plans for each lateral. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to nearest property line and nearest well in the same pool. Distance Distance to Sidetrack Directional to Unit Nearest Name Plan Boundary Well Nearest Well 3Q-06A 05 11,190' 2130' 3Q-08A 3Q-06AL1 02 11,190' 2130' 3Q-08A Attachment 1: Directional Plan for 3Q-06A &AL1 Attachment 2: Current Well Schematic for 3Q-06 Attachment 3: Proposed Well Schematic for 3Q-06A &AL1 CTD Sidetrack Page 6 of 6 nmrirlAt Updated January 14, 2013 Allsup-Drake, Sharon K From: Schwartz, Guy L (DOA) [guy.schwartz @alaska.gov] Sent: Saturday, January 12, 2013 5:30 PM To: Eller, J Gary Cc: Ferguson, Victoria L (DOA); Gantt, Lamar L; Allsup-Drake, Sharon K; DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]Re: Verbal Authorization to Drill KRU 3Q-06AL1 (212-183) Gary , Per our phone conversation you have approval to proceed with the change in kickoff depth for 3Q-06AL1 as proposed below. Regards, Guy Schwartz Sent from my iPhone On Jan 12, 2013, at 3:51 PM, "Eller, J Gary" <J.Gary.Elleraconocophillips.com>wrote: Victoria, Guy—Just to keep you abreast of what is transpiring, we have just TD'd the KRU 3Q-06A(212-183) at 11,661' MD. It appears that the target Al sand has thinned and degraded in quality to the point where there is no longer any reason to drill any further west. So we're now looking at drilling the 3Q-06AL1 lateral from 9800'-9900' to no further than 11,300' MD just to pick up pay that was bypassed in the 3Q-06A. We will run liner in the 3Q-06A tonight and likely kick off the AL1 lateral tomorrow(1/13/13). I will still plan on providing you with a completed 10-401 for 3Q-06AL1 on Monday. -Gary Eller From: Ferguson, Victoria L(DOA) [mailto:victoria.ferquson @alaska.govl Sent: Friday, January 11, 2013 11:38 AM To: Eller, J Gary Cc: Schwartz, Guy L(DOA) Subject: [EXTERNAL]RE: Verbal Authorization to Drill KRU 3Q-06AL1 (212-183) Gary, You have verbal approval to proceed with 3Q-06AL1. Please submit a complete 10-401 on Monday,01/14/2013. Thanx, Victoria From: Eller, J Gary [mailto:J.Gary.Eller @conocoohillios.com] Sent: Friday, January 11, 2013 10:42 AM To: Ferguson, Victoria L(DOA) Subject: FW: Verbal Authorization to Drill KRU 3Q-06AL1 (212-183) Victoria—I should have copied you on this in the first place, but I was not sure whether Guy 1/14/2013 t ,, is in today or not. Please call if we need to discuss. Thanks. -Gary Eller From: Eller, J Gary Sent: Friday, January 11, 2013 10:25 AM To: 'Schwartz, Guy L(DOA)' Cc: Allsup-Drake, Sharon K; Gantt, Lamar L Subject: Verbal Authorization to Drill KRU 3Q-06AL1 (212-183) Guy—Greetings! I want to give you a heads up that it appears that we will want to add a lateral to the KRU 3Q-06A sidetrack(212-183) due to geologic complexity. This lateral would be named 3Q-06AL1 and it would kick off from the 3Q-06A sidetrack that we are currently drilling. We're currently working on a directional plan, but tentatively we would TD 3Q-06A at 11,700' MD. We would then run slotted liner in 3Q-06A with a billet placed at—10,300' MD for kicking off the 3Q-06AL1. Proposed TD of the 3Q- 06AL1 would be 14,000' MD just like the 3Q-06A. Like most of our unplanned CTD laterals at Kuparuk, this one would have the same geologic objective as the previous laterals and in map-view would look very similar to what the AOGCC has already approved. It's hard to say with confidence, but we could be ready to spud this lateral by Sunday 1/13/13, so we request verbal authorization to continue uninterrupted drilling ops. I should be able to get you a directional plan and 10-401 by close of business on Monday. In the meantime I have attached a proposed wellbore schematic diagram. Thanks much. Please call if you have any questions. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 1/14/2013 o.$),Er) Yo" m N co 2 m cu p J O Bo Lc) O CO a 0 Q/��,� 0 co H co L N © V D ■ ��co I- LL co C_ a_ N H O vi i,) a -`moo a cu Ca 0 U a c 0 o —X E 2 m o= co co - to D v m� o rno a lb- w ©C) m m U� w U ifi a)0 CO �-' C)C] a), 0 E O- J 0100 a a� -J co E D 7X E� n �V (D a C� U 0.) f6_ z 07 O E O U) O U X Ll CO L_ _7 Ca- EN N N N N N O N - Q O Y Y N- CO m M M M M co co V V O re 1 0 0 i , CL , �i!f as -a•Fl 1 PI iii - 111 i U CD o 1! n 7 . .0 0 v _ro L 7 ^ N O ? V li 0 ~ m O a a_ L Lo 2 C N N a) ,, w Lo _ r❑ to- 4 N L 'V 006) X E N a) t/1 ia CC)�` Q.5-m - co 'C 'O O #al CO �}r N CD O.-- N LX) O LO© N N O O L - O) (O 1 N v 'f') N C) O C 1-C) aco O p)'En 60 6) lJ N 'N O V d N w co Fa C LL H a O cc0 U) z ORIGINAL ConocoPhilli ps Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3Q Pad 3Q-06 3Q-06AL1 Plan: 3Q-06AL1_wp02 Standard Planning Report 12 January, 2013 r' 1 BAKER HUGHES ORIc; AL 1.-' Baker Hughes ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3Q-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 30-06 @ 59.00ft Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-06 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-06AL1 Design: 3 Q-06AL 1_wp02 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 3Q Pad Site Position: Northing: 6,025,873.14 ft Latitude: 70°28'54.757 N From: Map Easting: 515,959.89ft Longitude: 149°52'10.513 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.12° Well 3Q-06 Well Position +NI-S 0.00 ft Northing: 6,025,843.37 ft Latitude: 70°28'54.462 N +E/-W 0.00 ft Easting: 516,081.28 ft Longitude: 149°52'6.944 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 17.30 ft Wellbore 3Q-06AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 11 (1 (nT) BGGM2011 12/15/2012 15.92 80.04 57,392 Design 30-06AL1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,740.19 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -22.00 0.00 0.00 280.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°1100ft) (°/100ft) (°/100ft) (°) Target 9,740.19 92.67 270.18 6,279.34 939.26 -6,585.45 0.00 0.00 0.00 0.00 9,750.00 92.59 270.20 6,278.89 939.29 -6,595.25 0.84 -0.82 0.20 165.98 9,820.00 97.07 264.80 6,272.99 936.26 -6,664.89 10.00 6.40 -7.71 310.00 9,920.00 91.21 256.67 6,265.76 920.20 -6,763.20 10.00 -5.86 -8.13 234.50 10,045.00 91.18 269.18 6,263.14 904.84 -6,886.97 10.00 -0.02 10.00 90.00 10,195.00 89.80 284.11 6,261.84 922.15 -7,035.53 10.00 -0.92 9.96 95.20 10,395.00 89.61 264.11 6,262.89 936.42 -7,234.00 10.00 -0.10 -10.00 269.40 10,595.00 89.63 284.11 6,264.23 950.69 -7,432.47 10.00 0.01 10.00 90.00 10,745.00 88.22 269.18 6,267.06 968.00 -7,581.01 10.00 -0.94 -9.96 264.50 10,945.00 89.70 289.13 6,270.73 999.65 -7,777.43 10.00 0.74 9.97 86.00 + 11,125.00 89.71 271.13 6,271.67 e 1,031.17 -7,953.90 10.00 0.01 -10.00 270.00 1/12/2013 8:07:54PM Page 2 COMPASS 2003.16 Build 69 0 I G t 0 ✓ Baker Hughes Irr- ConocoPhillips HUGHES s Planning Report BA Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3Q-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-06 @ 59.00ft Site: Kuparuk 3Q Pad North Reference: True Well: 30-06 Survey Calculation Method: Minimum Curvature Welibore: 3Q-06AL1 Design: 30-06AL1_wp02 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +Ni-S +El-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°I1o0ft) (°) (ft) (ft) 9,740.19 92.67 270.18 6,279.34 939.26 -6,585.45 6,648.50 0.00 0.00 6,026,768.30 509,494.47 TIP ' 9,750.00 92.59 270.20 6,278.89 939.29 -6,595.25 6,658.16 0.84 165.98 6,026,768.31 509,484.67 KOP 9,800.00 95.80 266.35 6,275.24 937.79 -6,645.08 6,706.97 10.00 -50.00 6,026,766.70 509,434.86 9,820.00 + 97.07 264.80 6,272.99 936.26 -6,664.89 6,726.21 10.00 -50.28 6,026,765.13 509,415.05 Start 10 DLS 9,900.00 92.39 258.29 6,266.39 924.53 -6,743.68 6,801.78 10.00 -125.50 6,026,753.23 509,336.29 9,920.00 91.21 256.67 6,265.76 920.20 -6,763.20 6,820.24 10.00 -126.04 6,026,748.86 509,316.78 4 10,000.00 91.20 264.67 6,264.07 907.25 -6,842.06 6,895.65 10.00 90.00 6,026,735.74 509,237.96 10,045.00 91.18 269.18 6,263.14 904.84 -6,886.97 6,939.47 10.00 90.17 6,026,733.23 509,193.05 5 10,100.00 90.68 274.65 6,262.24 906.67 -6,941.91 6,993.89 10.00 95.20 6,026,734.95 509,138.12 10,195.00 89.80 284.11 6,261.84 922.15 -7,035.53 7,088.78 10.00 95.29 6,026,750.21 509,044.47 6 10,200.00 89.79 283.61 6,261.86 923.34 -7,040.39 7,093.77 10.00 -90.60 6,026,751.40 509,039.61 10,300.00 89.69 273.61 6,262.31 938.30 -7,139.13 7,193.61 10.00 -90.60 6,026,766.14 508,940.85 10,395.00 89.61 264.11 6,262.89 936.42 -7,234.00 7,286.71 10.00 -90.55 6,026,764.06 508,845.99 7 10,400.00 89.61 264.61 6,262.92 935.93 -7,238.98 7,291.53 10.00 90.00 6,026,763.55 508,841.02 10,500.00 89.61 274.61 6,263.60 935.25 -7,338.85 7,389.76 10.00 90.00 6,026,762.66 508,741.16 10,595.00 89.63 284.11 6,264.23 950.69 -7,432.47 7,484.64 10.00 89.93 6,026,777.90 508,647.51 8 10,600.00 89.58 283.62 6,264.27 951.89 -7,437.33 7,489.63 10.00 -95.50 6,026,779.09 508,642.65 10,700.00 88.64 273.66 6,265.83 966.89 -7,536.06 7,589.46 10.00 -95.50 6,026,793.87 508,543.90 10,745.00 88.22 269.18 6,267.06 968.00 -7,581.01 7,633.93 10.00 -95.34 6,026,794.89 508,498.95 9 10,800.00 88.61 274.67 6,268.58 969.84 -7,635.94 7,688.35 10.00 86.00 6,026,796.61 508,444.02 10,900.00 89.35 284.64 6,270.36 986.59 -7,734.38 7,788.20 10.00 85.85 6,026,813.14 508,345.55 10,945.00 89.70 289.13 6,270.73 999.65 -7,777.43 7,832.86 10.00 85.67 6,026,826.11 508,302.48 10 11,000.00 89.70 283.63 6,271.02 1,015.15 -7,830.18 7,887.50 10.00 -90.00 6,026,841.50 508,249.71 11,100.00 89.71 273.63 6,271.55 1,030.13 -7,928.92 7,987.34 10.00 -89.97 6,026,856.26 508,150.94 11,125.00 89.71 271.13 6,271.67 1,031.17 -7,953.90 8,012.12 10.00 -89.92 6,026,857.24 508,125.97 TO at 11125.00 1/12/2013 8:07:54PM Page 3 COMPASS 2003.16 Build 69 • ✓ Baker Hughes ConocoPhilli s p Planning Report Alaska S HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3Q-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-06 @ 59.00ft Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-06 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-06AL1 Design: 3Q-06AL1_wp02 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 3Q-06A_Fault0l 0.00 0.00 0.00 908.60 -6,768.46 6,026,737.24 509,311.54 70°29'3.367 N 149°55'26.053 W -plan misses target center by 6264.26ft at 10045.00ft MD(6263.14 TVD,904.84 N,-6886.97 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 3Q-06A_Fault03 0.00 0.00 0.00 956.15 -7,481.41 6,026,783.25 508,598.57 70°29'3.828 N 149°55'47.028 W -plan misses target center by 6264.42ft at 10600.00ft MD(6264.27 TVD,951.89 N,-7437.33 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 30-06AL1_T1 0.00 0.00 6,265.00 942.66 -6,795.39 6,026,771.24 509,284.55 70°29'3.702 N 149°55'26.846 W -plan misses target center by 28.65ft at 9948.16ft MD(6265.17 TVD,914.39 N,-6790.74 E) -Point 3Q-06A_Fault04 0.00 0.00 0.00 1,055.04 -7,886.22 6,026,881.25 508,193.58 70°29'4.797 N 149°55'58.939 W -plan misses target center by 6271.33ft at 11028.64ft MD(6271.18 TVD,1021.20 N,-7858.17 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 3Q-06AL1_T2 0.00 0.00 6,262.00 954.25 -7,065.38 6,026,782.25 509,014.56 70°29'3.814 N 149°55'34.789 W -plan misses target center by 25.00ft at 10229.38ft MD(6261.97 TVD,929.52 N,-7069.11 E) -Point 3Q-06AL1_T5 0.00 0.00 6,272.00 1,063.17 -7,946.21 6,026,889.26 508,133.59 70°29'4.876 N 149°56'0.704 W -plan misses target center by 32.19ft at 11118.64ft MD(6271.64 TVD,1031.01 N,-7947.54 E) -Point 3Q-06A Polygon(copy) 0.00 0.00 0.00 780.47 -6,254.71 6,026,610.24 509,825.52 70°29'2.112 N 149°55'10.937 W -plan misses target center by 6287.09ft at 9900.00ft MD(6266.39 TVD,924.53 N,-6743.68 E) -Polygon Point 1 0.00 780.47 -6,254.71 6,026,610.24 509,825.52 Point 2 0.00 1,000.57 -6,289.25 6,026,830.24 509,790.51 Point3 0.00 1,468.74 -8,719.51 6,027,293.11 507,359.49 Point 4 0.00 1,878.22 -10,824.86 6,027,698.00 505,253.47 Point 5 0.00 1,381.25 -10,860.91 6,027,201.00 505,218.50 Point6 0.00 1,193.33 -9,958.22 6,027,015.05 506,121.50 Point 7 0.00 737.32 -7,608.94 6,026,564.17 508,471.53 Point 8 0.00 561.28 -6,649.21 6,026,390.22 509,431.54 Point 9 0.00 584.40 -6,232.12 6,026,414.24 509,848.54 Point 10 0.00 780.47 -6,254.71 6,026,610.24 509,825.52 3Q-06AL1_T3 0.00 0.00 6,264.00 989.96 -7,392.33 6,026,817.25 508,687.57 70°29'4.162 N 149°55'44.408 W -plan misses target center by 47.07ft at 10561.74ft MD(6264.02 TVD,943.52 N,-7400.00 E) -Point 3Q-06A_Fault02 0.00 0.00 0.00 914.28 -7,082.47 6,026,742.25 508,997.56 70°29'3.420 N 149°55'35.291 W -plan misses target center by 6261.99ft at 10212.22ft MD(6261.90 TVD,926.09 N,-7052.29 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 3Q-06AL1_T4 0.00 0.00 6,269.00 1,021.52 -7,649.28 6,026,848.25 508,430.58 70°29'4.469 N 149°55'51.968 W -plan misses target center by 50.19ft at 10821.84ft MD(6269.08 TVD,972.03 N,-7657.67 E) -Point 3Q-06A_Fault05 0.00 0.00 0.00 1,295.15 -8,847.76 6,027,119.26 507,231.62 70°29'7.147 N 149°56'27.234 W -plan misses target center by 6340.55ft at 11125.00ft MD(6271.67 TVD,1031.17 N,-7953.90 E) -Rectangle(sides W1,000.00 H1.00 D0.00) 1/12/2013 8:07:54PM Page 4 COMPASS 2003.16 Build 69 ORIG i ,$ L ✓ Baker Hughes IFE' ConocoPhillipss Planning Report BAKER Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3Q-06 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3Q-06 @ 59.00ft Site: Kuparuk 3Q Pad North Reference: True Well: 3Q-06 Survey Calculation Method: Minimum Curvature Wellbore: 3Q-06AL1 Design: 3Q-06AL1_wp02 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 115.00 56.00 16" 16 20 5,068.00 3,635.88 9 5/8" 9-5/8 9-5/8 11,125.00 6,271.67 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,740.19 6,279.34 939.26 -6,585.45 TIP 9,750.00 6,278.89 939.29 -6,595.25 KOP 9,820.00 6,272.99 936.26 -6,664.89 Start 10 DLS 9,920.00 6,265.76 920.20 -6,763.20 4 10,045.00 6,263.14 904.84 -6,886.97 5 10,195.00 6,261.84 922.15 -7,035.53 6 10,395.00 6,262.89 936.42 -7,234.00 7 10,595.00 6,264.23 950.69 -7,432.47 8 10,745.00 6,267.06 968.00 -7,581.01 9 10,945.00 6,270.73 999.65 -7,777.43 10 11,125.00 6,271.67 1,031.17 -7,953.90 TD at 11125.00 1/12/2013 8:07:54PM Page 5 COMPASS 2003.16 Build 69 6 te ! . ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3Q Pad 3Q-06 3Q-06AL1 3Q-06AL1_wp02 Travelling Cylinder Report 12 January, 2013 rrit1 BAKER HUGHES ■-- ConocoPhillips or its affiliates IF 1°- ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-06 Project: Kuparuk River Unit TVD Reference: 3Q-06 @ 59.00ft Reference Site: Kuparuk 30 Pad MD Reference: 3Q-06 @ 59.00ft Site Error: 0.00ft North Reference: True Reference Well: 3Q-06 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3Q-06AL1 Database: EDM Alaska Prod v16 Reference Design: 3Q-06AL1_wp02 Offset ND Reference: Offset Datum Reference 3Q-06AL1_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,740.19 to 11,125.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,308.80ft Error Surface: Elliptical Conic Survey Tool Program Date 1/12/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 40.00 9,200.00 3Q-06 GyroData(3Q-06) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 9,300.00 9,300.00 3Q-06(3Q-06) BOSS-GYRO Sperry-Sun BOSS gyro multishot 9,380.00 9,740.19 3Q-06A(30-06A) MWD MWD-Standard 9,740.19 11,125.00 30-06AL1_wp02(3Q-06AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ("1 ("1 115.00 115.00 16" 16 20 5,068.00 3,694.88 9 5/8" 9-5/8 9-5/8 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3Q Pad 3Q-05-3Q-05-3Q-05 Out of range 3Q-06-3Q-06A-3Q-06A 9,750.00 9,750.00 0 00 1.01 -0.89 FAIL-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/12/2013 5:55:44PM Page 2 of 5 COMPASS 2003.16 Build 69 rl1 .. ; , ConocoPhillips or its affiliates Ird" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3Q-06 Project: Kuparuk River Unit TVD Reference: 3Q-06 @ 59.00ft Reference Site: Kuparuk 3Q Pad MD Reference: 3Q-06 @ 59.O0ft Site Error: 0.00ft North Reference: True Reference Well: 3Q-06 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 30-06AL1 Database: EDM Alaska Prod v16 Reference Design: 3Q-06AL1_wp02 Offset TVD Reference: Offset Datum Reference Depths are relative to 3Q-06 @ 59.00ft Coordinates are relative to:3Q-06 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.12° Ladder Plot I - I I I I I 60 1 1 I I I I L_ J J J J J 45— I . C I I O I I a 30— -- - 0 0 9 ... J J J J J tf C N U 15- 1 I 1 I 1 I 1 I 1 1 I I I I ■ 0 1 I 11 I 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND — 3Q-06,3Q-06A,3Q-06AVO CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/12/2013 5:55 44PM Page 5 of 5 COMPASS 2003.16 Build 69 OR1GU\irL. 1, 1, • y m 1 4. . g m bill P'" r. .. fE N ri °__ G -r/L] E' p f 1_ __T __ I' 8 c) // i ; fu z i 4$6 y V -I 8 II 4. Ve o t q 8 O a F. i 8 l m iR U - 3 g I 1 e F I a g ¢ gg.,, r w I 8 a J - `p I Si ° O Iii II _ w a - � E F' O 3 4 -- - •• i� o il gaa E' g E g o Z _1 r G E.-0.S ¢H v,nm�mm�H 0-- Q F I e cS.,1•7ry Nv��t4`�"..N,r5,� t a _ S rz 3 8 m y C 0 - m to- gi a 'ateQ Q •-C.,N CV N N a. / J ° aa°8a x'$0$08888888 $ Y Y 0 0— p o 0 0 0 0 0 0 0 0 / 3� 3 W.�a,q' $vo`a,8j a min 3"-J q r°,,9N s, yymo,g,o A „t m --- 8 tel E Q a O 'rtic gaq�v,goW� y two 2A2.°„°:12gq8, m - $ 8 o°°�m 2 a CL LI zI a a 2 8888$$$880 5....�. e $ 0 u �oi .q2RRW o44` V E 1 $ O N V r ER ,o,-m m level eeS ueeW C ?o (uif J SL)igdala ieoivaA aria F ORiNAL TRANSMITTAL LETTER CHECKLIST WELL NAME 1<Ru, 3 - OG 41_ l PTD# x130°5 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: «(Ap/}r2cAI .j'iJ ` POOL: 1'(u3c.AtJ1\ i2i'vLJ-� Kyaa lRHJ J- 01.1 Check Box for 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 K ilk. 3Q - O A (If last two digits in Permit No. al). 8 3 API No. 50-6�9 -1 , . API number are al�g 3-O(- od. 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 produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for(name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 To v) a) 0 n c N - - a) ° u a) a) 6 O C C 7 Tv C L O 0 a U O n 2 N I n U O 0 N N O) a) co c a co V O a co c o -c) a)O z N -a E a) a) a) n ai • a c c c o m O o Q o o d c° @ co :- O N .5)C C O L C 3 m n w > U c o n c@ o_ co Z N 'a a) T C 0 _a o a) a te 3 o •Cl)) a) ° >, o_ n ai = -o (o a) a) 2 5 -o c ui n > > w 0 o E m a O O a 3 0 c S1 a c °- j n = o)To � D c 0 = c vi 0 n _ u) Q O . 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