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211-164
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V ¢ IZO D p W O Z N 0 } 1 3 , > o a E E 73 Z 0 co Z Q' w `" LL J Z Q �. .N V Y 09 W o O C 0 O .\ Z N as J �f U _ > E E E 0 !,j ~ a a1 -,5 .3 a' O O- 0 0 O N 0 N t C a°) o o a 11 ce I o F 3 3o1-L� W � < 0 ¢� 0 BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 3H-34L1-02 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: 2/2/2012 TODAYS DATE: 02/24/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur NHiN i S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. 1 1 1 I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC 1 1 1 I I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP I 1 I 1 I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP 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 Anchorage,Alaska 99501-3510 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 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test LI 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: February 3,2012 211-164/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 January 30,2012 50-103-20643-62 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 932'FNL,282'FWL,Sec. 12,T12N,R8E,UM February 1,2012 3H-34L1-02 Top of Productive Horizon: 8.KB(ft above MSL): 64'RKB 15.Field/Pool(s): 1908'FSL,2074'FWL,Sec. 1,T12N,RO8E, UM GL(ft above MSL): 36'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2161'FSL, 1867'FEL,Sec. 1,T12N,RO8E, UM 8938'MD/6144'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498655 y- 6000725 Zone-4 8938'MD/6144'TVD ADL 25531 TPI: x-500446 y- 6003565 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-501785 y- 6003818 Zone-4 1899'MD/1816'TVD 2657 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) 1675'MD/1617'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/CCL 7268'MD/6088'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 28' 114' 28' 114' 24" 170 sx cement 10.75" 45.5# L-80 28' 3977' 28' 3518' 13.5" 1578 sx LiteCRETE,380 sx DeepCRETE 7.625" 29.7# L-80 25' 6891' 25' 5947' 9.875" 532 sx Class G 4.5" 12.6# L-80 6583' 7300' 6233' 5393' 6.75" 28 bbls Class G 2.375" 4.7# L-80 7053' 8938' 6047' 6144' 3" slotted liner 24.Open to production or injection? Yes ❑ No 0 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) 4.5 x 3.5 6639' 6583'MD/5771'TVD slotted liner 7054'-8938'MD 6047'-6144'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) not applicable shut-in 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. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laborato _ -. .+ . RECEIVED _ja NONE RSDMS MAR 0 21012 MAR 0 2 2012 Ir;'T '? S Gas Cons.Commission i Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ,,,,,�chc�ra,$ bmit original only f. q-3-12_ � 1KM_ C 28. GEOLOGIC MARKERS(List all formations and r, s encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes E 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 1675' 1617' needed,and submit detailed test information per 20 AAC 25.071. top of Kuparuk A sand 7068' 6056' Kuparuk A2 sand 7090' 6069' bottom of A2 sand 7336' 6083' N/A Formation at total depth: Kuparuk A 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: Jill Long @ 263-4093 Printed Nam Gantt��,, Title: Alaska CTD Manager Signature `t/f C- 0441,1! Phone 263-4021 Date 3- 1 / 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 , KUP 3H-34L1-02 ConocoPhilhps Drib.._,, Well Attributes Max Angle&MD TD Alaska,Inc. - Wellbore API/IJWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(0168) torncom�wps'�, 501032064362 KUPARUK RIVER UNIT PROD 96.17 7,266.99 8,938.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -' SSSV:TRDP Last WO: 11/25/2011 Well Confer-3H-341_1-02 2/23/201211'53'.03 AM ' - --- ----- — - --- Schematic-Actual Annotation Depth(SKB) End Date Annotation Last Mod...End Date Last Tag:RKB 7,223.0 12/27/2011 Rev Reason:GLV C/O ninam 2/23/2012 Casing Strings HANGER,23 f 'Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd LINER L1-02 23/8 1.992 7,053.2 8,938.0 4.70 L-80 STL 1 7 Liner Details Top Depth (ND) Top Incl Nomi... Top(RKB) (ftKB) (°) kern Description Comment ID(in) 7,053.2 6,046.7 50.07 Deploy Sleeve Shorty Deployment Sleeve 7,516.1 6,104.1 71.74 Deploy Sleeve Shorty Deployment Sleeve Perforations&Slots Shot Top(ND) Btm(ND) Dens Top(ftKB) Btm(ftKB) (RKB) (RKB) Zone _ Date (sh... Type Comment 7,054 7,516 6,047.2 6,104.0 2/2/2012 32.0 SLOTS Il 7,517 8,938 6,104.4 6,143.6 2/2/2012 32.0 SLOTS CONDUCTOR, 28-107 I SAFETY VLV, j o 1.899 GAS LIFT, c_ 2.738 II ll SURFACE. 29-3.977 GAS LIFT, 4.206 GAS LIFT, 5.171 GAS LIFT, _ _ 1 r-- 5 982 GAS LIFT, 6,514 NIPPLE.0.573 LOCATOR, 6,620 SEAL ASSY. 8,821 MULE,6,639 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Sian TRO Run Stn Top(ftKB) (RKB) dl Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 2,738.4 2,504.2 37.30 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,305.0 2/21/2012 NTERMEDIATE, 2 4,206.2 3,705.1 33.56 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,286.0 2/20/2012 250.891 4 3 5,170.6 4,545.7 27.34 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,268.0 2/20/2012 SLOTS. 7,0547.5161 LINER, 4 5,981.6 5,254.8 26.33 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,251.0 2/20/2012 1.111,111.6'583-7,350 5 6,514.3 5,694.0 42.08 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 2/20/2012 SLOTS, 7,517-8,935 LINER L102, 7,053-8,938I ,053-0:TD 1 1. (3H-34L1-02), \ 8.938 big \ 31 \ ( . ( in \ , #,: ,)) .. /\/ !; e ))2 3;; {(( 7`® §{�\ I.2 c2 4<: i$\\ \ Cl.) / co { 2 f[, . \eN \ \\\ & R / \ g y -r § c § 2 } }{{ \ § \ co ,\\ / ;\_ � \ \ a \ \ } \ / ) \ 2 a \ g �,=a H ƒ \\ .< \ / § — \ e 4 \ X j . @ \ $ 0 co \ \ _ \ \ H = x . \ / \ § § § § § § / \ \ k \ / % 3 \ ) 722 \ G 22 / i ./,..... i � 22 g 4 Gs, \ , ,tea z ® ■ CO.. ` ���m ° r ( w -- U 2 � \ $ 2 / / co � ® 0e 0 0 \0.5 / EG � � t > 0 } / j x « § / \ aj2 } � _ } ( � m - e m + I mf / \\ \ \ \ 2 U n � � ,� 3H-34 Pre and Post Rig Summary DATE SUMMARY 12/18/11 PULL BPV, GAUGED WELL 10 2.78", TAGGED BTM 6874' SLM. JOB INPROGRESS 12/19/11 SET 3.5"X-LOCK IN X-NIPPLE @ 6572' RKB, PULLED SOV FROM STA#5 @ 6514' RKB AND REPLACED WITH SPG ON RK LATCH, MITIA TO 2500 PSI **PASS**, ATTEMPT TO RECOVER DROPPED X-LOCK FROM 4.5" LINER @ 6874' SLM. JOB IN PROGRESS 12/20/11 RETRIEVE X-LOCK FROM 4.5" LINER, BAILED MUD FROM 6874' SLM TO 6914' SLM. READY FOR COIL CLEAN OUT. 12/25/11 RIGGED DOWN CTU 4 AT 1J PAD, TRAVEL TO 3H-34, RIG UP CTU. JOB IN PROGRESS 12/26/11 PERFORMED FCO TO HARD TAG AT 7228' CTMD. GOOD 1:1 RETURNS, F/P TBG. JOB IN PROGRESS. READY FOR S/L 12/27/11 GAUGED TUBING &4 1/2" LINER W/2.80"TO TAG @ 7223 RKB. CLEAN DRIFT W/2.65" DUMMY WHIPSTOCK(17.25' OAL)TO 7212' RKB. READY FOR E-LINE. 12/28/11 LOGGED CEMENT BOND LOG AND GAMMA/CCL CORRELATION FROM A TAG DEPTH OF 7230'TO A DEPTH OF 6450'. LOG WAS CORRELATED TO SPERRY MWD LOG. TUBING TAIL FOUND AT A DEPTH OF 6635'. 12/30/11 T-POT( PASSED ), T-PPPOT( PASSED), IC-POT( PASSED), IC-PPPOT( PASSED). 12/31/11 PRE CTD, PT SV, MV,SSV( PASSED ) DDT SV, MV, SSV( PASSED ) DDT SSSV ( PASSED). 1/7/12 ATTEMPTED TO SET ORIENTED WHIPSTOCK WITH ECCENTRIC WEIGHT BARS. UNABLE TO ACHIEVE ORIENTATION TOLERANCE OF+/-5 DEGREES OF HIGH SIDE ON FIRST RUN. CLOSEST ORIENTATION WAS -8.3 DEG (LOHS). WILL MAKE ADJUSTMENT TO ECCENTRIC WEIGHTS AND REATTEMPT TOMORROW. 1/8/12 SET TOP OF WHIPSTOCK AT 7060' ORIENTED -1.4 DEGREES FROM HIGH SIDE OF HOLE. CCL TO TOP OF WHIPSTOCK OFFSET 19.5', CCL STOP DEPTH 7040.5'. 2/19/12 DRIFTED TBG W/3 1/2 BAIT SUB, 5' STEM, AND 2.79 GAUGE RING AND SET ON LINER TOP FOR CATCHER @ 7058' RKB. PULLED SPG @ 6514' RKB. PULLED DV'S @ 5982'AND 5171' RKB ( KOT'S COMING BACK W/METAL SHAVINGS ). DRIFTED TBG DOWN TO X NIPPLE @ 6573' RKB W/BLB AND 2.62 MAGNET. IN PROGRESS. 2/20/12 PULLED 1.5" DV'S 2738' RKB AND 4206' RKB SET 1.5 GLV @ 4206' RKB @ 5171' RKB AND 5982' RKB.SET 1/4"X 1.5"ORFICE @ 6514' RKB**OPEN POCKET**IN PROGRESS 2/21/12 SET GLV @ 2738' RKB. PULLED CATCHER ASS'Y FROM 7058' RKB (FULL OF METAL SHAVINGS). COMPLETE. =m. Time Log & Summary ConocoPhillips Wel!view Web Reporting Report Well Name: 3H-34 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 1/13/2012 12:00:00 PM Rig Release: 2/4/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01/12/2012 24 hr Summary RDMO from 2K-08 06:00 00:00 18.00 MIRU MOVE MOB P MIRU 01/13/2012 MIRU,continue conversion to 2"CT 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Arrive on location 02:00 08:00 6.00 0 0 MIRU MOVE MOB P Spot rig 08:00 12:00 4.00 0 0 MIRU MOVE MOB P Rig up,erect scaffolding in cellar Rig accept at 12:00 12:00 18:00 6.00 0 0 MIRU WHDBO NUND P NU BOP, 18:00 00:00 6.00 0 SURPRI WELLPF CTOP P Convert to 2"CT 01/14/2012 Continue conversion to 2"CT, install inner reel iron and pressure bulkhead in new reel 00:00 06:00 6.00 0 0 SURPRI WELLPF CTOP P Continue with conversion to 2", change gooseneck rollers, install gripper blocks 06:00 06:30 0.50 0 0 SURPRI WELLPF SFTY P Crew Change, Entire field phase 2 conditions 06:30 09:30 3.00 0 0 SURPRI WELLPF CTOP P Cont.converting injector head to 2", 09:30 12:30 3.00 0 0 SURPRI WELLPF CTOP P Stab CT 12:30 15:30 3.00 0 0 SURPRI WELLPF CTOP P MU inner reel iron 15:30 18:30 3.00 0 0 SURPRI WELLPF CTOP P MU Pressure bulk head 18:30 21:00 2.50 0 0 SURPRI WELLPF CTOP P Install tubing depth counters, prepare to pump slack in CT, MU riser QC and pump-in sub 21:00 00:00 3.00 0 0 SURPRI WELLPF RGRP T Continue trouble shooting e-line, change out whip from pressure bulkhead to j-box,tests good,with new whip eline tested good,may have been crossed wires coming through the pressure bulkhead "**Three hours of Nabors down time*** 01/15/2012 Completed conversion to 2"CT, Pump slack management and cut 500'of coil,test BOP, install CTC and e-line head, pull BPV 00:00 02:30 2.50 0 SURPRI WELLPF SLPC P Fluid pack reel and pump slack 02:30 03:30 1.00 SURPRI WELLPF BOPE P Test inner reel valve and shell test surface equipment. Page 1 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 06:00 2.50 SURPRI WELLPF SLPC P RU to cut CT, Reverse circulate thru CT pumping slack. cut 500'. Found cable at 6'cut. ****Send last 120'of CT cut back to Quality Coil Tubing in Houston,Tx for corrosion test at QC lab.**** 06:00 08:30 2.50 MIRU WHDBO BOPE P Start BOPE testing Inspect Injector motor shafts. Looked good 08:30 15:30 7.00 MIRU WHDBO BOPE P Complete BOPE Testing.0 failures Waived by: Bob Noble 15:30 19:30 4.00 MIRU WHDBO CTOP P MU CTC, BHI drilling head, PT PDL's, Inspect ODS PDL, PT CTC 19:30 22:30 3.00 MIRU WHDBO BOPE P Pull BPV. 22:30 00:00 1.50 MIRU WHDBO BOPE P Test line to TT, PT C13 and bleed well down to TT. 01/16/2012 PU window milling BHA,mill window at 7063'plus 16'of rathole to 6087'. Start managed pressure after exiting liner, maintaining 12.0 ECD at window. Get 30 min.static BHP:5953'TVD,3670 BHP. Swap well over to 9.7 ppg flo-pro 00:00 01:18 1.30 0 0 PROD1 WHPST PULD P PU window milling BHA with 2.80" mill and new 2.80"string reamer 01:18 03:42 2.40 0 6,830 PROD1 WHPST TRIP P RIH, checking pipe and surface equipment 03:42 04:00 0.30 6,830 7,063 PROD1 WHPST DLOG P Tie in to K-1, +14' 04:00 04:03 0.05 7,063 7,063 PROD1 WHPST MILL P Close EDC,tag WS at 7063'. 04:03 12:30 8.45 7,063 7,071 PROD1 WHPST MILL P Start milling, 1.57 BPM,3750 CTP, 3450 BHP, 11.1 ECD with WOC 12:30 15:30 3.00 7,071 7,087 PROD1 WHPST MILL P Start milling rat hole 5.5 FPH, 1.3 WOB,3800 CTP, , Start holding MP, 12ppg at window. 15:30 18:24 2.90 7,087 7,087 PROD1 WHPST MILL P Back ream window making a total of 5 passes. Seeing motor work @ TOW 7063.7'.After 5 passes drift with pumps on and off looked good. 18:24 19:00 0.60 7,087 7,050 PROD1 WHPST SIPB P SBHP:MD=7050,TVD of DPS= 5953.73,8.6 PPG biozan Time BHP 18:25 3672 18:35 3682 18:45 3677 18:55 3672 19:00 19:42 0.70 7,050 7,050 PROD1 WHPST CIRC P Displace well to 9.7ppg Flo-Pro SF 19:42 21:30 1.80 7,050 0 PROD1 WHPST TRIP P POOH 21:30 21:48 0.30 0 0 PROD1 WHPST SFTY P PJSM for undeployment 21:48 00:00 2.20 0 0 PROD1 WHPST PULD P Undeploy BHA. DSM 2.79"no-go, String Mill 2.80" no-go 01/17/2012 Drill L1 Lateral to 7655 Page 2 of 16 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 02:24 2.40 0 0 PROD1 DRILL PULD P Deploy drilling BHA with 2.55 Deg motor and 2.80"X 3.25"bicenter bit 02:24 04:18 1.90 0 6,825 PROD1 DRILL TRIP P RIH 04:18 04:36 0.30 6,825 6,875 PROD1 DRILL DLOG P Tie-in,-2. Shut EDC 04:36 07:06 2.50 7,087 7,182 PROD1 DRILL DRLG P Run through window and start drilling at 7087'. 1.4 BPM, 17K RIW,3600 CTP, 3730 BHP 07:06 08:36 1.50 7,182 0 PROD1 DRILL TRIP P Land build section 7182'.5'low of plan. POOH 08:36 08:51 0.25 0 0 PROD1 DRILL SFTY P At surface, PJSM 08:51 12:21 3.50 0 72 PROD1 DRILL PULD P Undeploy/Deploy BHA#3 with 2.80" X 3.25"Bi-center. Service injector. 12:21 14:39 2.30 72 7,182 PROD1 DRILL TRIP P RIH with EDC open following MPD.- 2ft correction tie in. P/U weight 32K. RIH HS through window-log RA marker. TOW=7059' RA marker=7067' BOW=7068' 14:39 16:57 2.30 7,182 7,330 PROD1 DRILL DRLG P Drilling ahead-1.50 bpm, 3890, BHP 3800, ROP 70,WOB 2.2K, Ct weight 16K,WHP 140, ECD 12.1. 16:57 17:27 0.50 7,330 7,330 PROD1 DRILL WPRT P Wipe to window, PUW=32K, MADD Pass 7215 to 7090 17:27 19:27 2.00 7,330 7,480 PROD1 DRILL DRLG P 7330', Drill Ahead, 1.46 BPM @ 3550 PSI FS, RIW=16K, WOB=1.6K, BHP=3735 19:27 20:03 0.60 7,480 7,480 PROD1 DRILL WPRT P 7480 Wiper to window, PUW=31 K 20:03 22:21 2.30 7,480 7,630 PROD1 DRILL DRLG P 7480', Drill Ahead, 1.45 BPM @ 3600 PSI FS, BHP=3790 22:21 23:15 0.90 7,630 7,630 PROD1 DRILL WPRT P 7630,Wiper to window with tie in for -8'correction, PUW=34K 23:15 00:00 0.75 7,630 7,655 PROD1 DRILL DRLG P 7626', Drill ahead, 1.45 BPM @ 3700 PSI FS, BHP=3833 01/18/2012 Drill ahead to 7751',Out of target, POOH, run anchored Billet to 7610, 00:00 03:24 3.40 7,655 7,720 PROD1 DRILL DRLG P 7655', Drill ahead, 1.45 BPM @ 3700 PSI FS, BHP=3830 03:24 03:36 0.20 7,720 7,720 PROD1 DRILL WPRT P Low ROP<20 FPH, Pull BHA Wiper PUW=34k 03:36 05:36 2.00 7,720 7,751 PROD1 DRILL DRLG P 7720 drill ahead, 1.47 BPM @ 3700 PSI FS, BHP=3820, ECD=12.22 05:36 06:36 1.00 7,751 7,000 PROD1 DRILL WPRT P P/U Weight 32K,Wipe up to cased hole. . 06:36 08:06 1.50 7,000 7,000 PROD1 DRILL CIRC T Open EDC&Circ.Wait on road conditions to improve from deadhorse. No Mud trucks&service trucks allowed to transport from Deadhorse. 08:06 10:06 2.00 7,000 72 PROD1 DRILL TRIP T Start POOH following MPD for Billet BHA. 10:06 11:36 1.50 72 0 PROD1 DRILL PULD T PJSM-undeploy BHA#3. lay down BHA. Page 3 of 16 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 11:36 12:36 1.00 0 0 PROD1 DRILL RGRP P Pre-spud meeting,service injector& Injector counter. 12:36 14:06 1.50 0 73 PROD1 STK WPST T P/u&deploy BHA#4-OH anchored Billet with bull nose. 14:06 17:06 3.00 73 7,621 PROD1 STK WPST T Rlh with EDC open pumping .3 bpm. Tie in-3ft. P/U weight 28K. EDC closed. RIH to 7621.15'Orient single slip 170 ROHS. 17:06 17:18 0.20 7,621 7,610 PROD1 STK WPST T Ct weight 19K-Bring pumps up to 4300 psi,WOB zero to 2k,set down additional 3K-P/U weight 33K. POOH HS through window.TOB- 7610' 17:18 19:48 2.50 7,610 80 PROD1 STK WPST T POOH following MPD. 19:48 23:36 3.80 80 72 PROD1 DRILL PULD T PJSM,At surface, Lay down Billet running tools, BHA#4/P/U BHA#5 1.2 degree motor, Hycalog 2.8 X 3.25 Bi Center with reamer jet braized shut,Make up to Coil track and surface test tool 23:36 00:00 0.40 72 490 PROD1 DRILL TRIP T Trip in with BHA#5, Lateral L1 Drilling, EDC Open 01/19/2012 Kick Off Billet @ 7609, Drill ahead to 8210 00:00 01:36 1.60 490 6,850 PROD1 DRILL TRIP T Continue running in hole, EDC Open 01:36 01:48 0.20 6,850 6,880 PROD1 DRILL DLOG T 6850,Tie in for 0 correction,Close EDC, PUW=31K 01:48 02:36 0.80 6,880 7,609 PROD1 DRILL TRIP T Trip in to kick off billet,clean pass through window„S/D pumps for dry tag,tag TOB @ 7609, PUW=32K 02:36 02:54 0.30 7,609 7,609 PROD1 STK KOST T PUH and bring pumps online 1.4 BPM @ 3620 PSI FS,Tag TOB @ 7609.0,start time milling 02:54 05:54 3.00 7,609 7,612 PROD1 STK KOST T 7609.24,Stall, S/D pumps, PUW=32K,Clean pick up, Stall @ 7609.16 drilled off, Stall @ 7609.54. All clean pick ups with no grabbing. 05:54 07:54 2.00 7,612 7,660 PROD1 STK KOST T Crew change-Time milling 1.5 fph, 3fph, 10 fph&20+fph for 50'.Clean dry drift. 07:54 08:54 1.00 7,660 7,760 PROD1 DRILL DRLG P Drilling ahead-1.50 bpm,4000, BHP 3780, ECD 12, ROP 96,WOB 1.1, Ct weight 16.5K. 08:54 09:24 0.50 7,760 7,760 PROD1 DRILL WPRT P Wiper trip-P/U weight 32K 09:24 12:24 3.00 7,760 7,910 PROD1 DRILL DRLG P Drilling ahead-1.50 bpm,4060, BHP 3800, ROP 80,WOB 1.2K,Ct weight 15.5K 12:24 13:24 1.00 7,910 7,910 PROD1 DRILL TRIP P Wiper trip-P/U weight 32K, During top of wiper the depth counter stopped.try to reboot computer, no luck. 13:24 14:24 1.00 7,910 7,910 PROD1 DRILL TRIP P Pull into cased hole,open EDC&fix counter.Close EDC RIH-tie in +11ft. RIH to TD. Page 4of16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:24 19:24 5.00 7,910 8,060 PROD1 DRILL DRLG P Two stalls on bottom-Drilling ahead -1.48 bpm,4050, BHP 3820, ECD 12.2, ROP 85,WOB 1.4K, Ct weight 13K. DH temp 122.Stall @ 7977'- Clean P/U 31K. Drill ahead 19:24 20:54 1.50 8,060 8,070 PROD1 DRILL WPRT P Wiper trip#1 to window, PUW=32K, Clean trip up and down did not see billet. Found bottom 10'late.Will tie in next wiper and inspect counter 20:54 23:24 2.50 8,070 8,210 PROD1 DRILL DRLG P 8070', Drill ahead, 1.47 BPM @3820 PSI FS, BHP=3850, Low ROP -30-60 FPH 23:24 00:00 0.60 8,210 7,463 PROD1 DRILL WPRT P 8210 wiper to window with tie in, PUW=34K ECD=12.4, BHP=3870 01/20/2012 Drill 8210 to 8960,Change out gooseneck counter,Swap Mud 00:00 00:21 0.35 7,463 7,080 PROD1 DRILL WPRT P Continue wiper trip from 8210 00:21 00:33 0.20 7,080 7,126 PROD1 DRILL DLOG P Gamma tie into RA marker for-18.5 00:33 00:45 0.20 7,126 7,126 PROD1 DRILL WPRT P Wipe up through window, Open EDC to circulate while changing out counter assembly 00:45 01:39 0.90 7,126 7,126 PROD1 DRILL RGRP T Replace BHI counter assembly 01:39 02:21 0.70 7,126 8,197 PROD1 DRILL WPRT P Close EDC,Trip in,tie in on way in for 0 correction,continue to bottom to drill 02:21 06:21 4.00 8,197 8,360 PROD1 DRILL DRLG P Tag bottom early and stall. 1.46 @ 3800 PSI FS, BHP=3892, 8195' WOB and differential, Pull off bottom to straighten out logs/depths before continuing to drill.Two motor stalls @ 8350'P/U weight 33K-Drill ahead broke through with better ROP. 06:21 08:21 2.00 8,350 8,350 PROD1 DRILL TRIP P Wiper trip-31K P/U-tie in+1 ft correction. Prep for mud swap. 08:21 10:45 2.40 8,350 8,510 PROD1 DRILL DRLG P Mud swap(1500'on system)- Drilling ahead-1.45 bpm,4023, BHP 3850, ECD 12.2,WOB 1.8K, ROP 60, CT weight 15K. 10:45 12:30 1.75 8,510 8,510 PROD1 DRILL WPRT P Wiper trip 12:30 15:00 2.50 8,510 8,660 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3940, BHP 3890, ECD 12.3, ROP 20,WOB 1.9K,Ct weight 14K,Temp 130. ROP increased with good Al sand 130 ROP 15:00 17:00 2.00 8,660 8,660 PROD1 DRILL WPRT P Wiper trip-P/U weight 32K 17:00 19:06 2.10 8,660 8,810 PROD1 DRILL DRLG P Drilling ahead- 1.45 BPM @ 3700 PSI FS, BHP=3966 19:06 21:24 2.30 8,810 8,810 PROD1 DRILL WPRT P Wiper to window with tie in, PUW=33K,Observed slight over pulls and motor work at 8180, 8330, and 8390. Clean back in. Correction at tie in+3 _ 21:24 23:54 2.50 8,810 8,960 PROD1 DRILL DRLG P 8812', Drill ahead, 1.44 BPM @ 3720 PSI FS, BHP=3980, RIW=11K, WOB=1.7K Page 5 of 16 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 23:54 00:00 0.10 8,960 8,927 PROD1 DRILL WPRT P Wiper trip to window, PUW=32K, BHP=3950 Midnight 8927 01/21/2012 Drill to 9200'TD,Wipe to swab,test SSSV, RBIH to lay in liner pill 00:00 02:30 2.50 8,927 8,960 PROD1 DRILL WPRT P Continue wiper trip from 8960',Clean trip up set down @ 8675, Picked up and adjusted TF to as drilled.We were off 30 degrees.Went right through 02:30 04:00 1.50 8,960 8,970 PROD1 DRILL DRLG P 8960', Drill ahead, 1.4 BPM @ 3720 PSI FS, RIW=12.2K,WOB=2.9K Very low ROP<10 FPH,Consult/ Inform Geo GEO,drilling like Ankorite 04:00 04:30 0.50 8,970 8,970 PROD1 DRILL DRLG P Samples not showing Ankorite. Clays in samples, prep for Drill Zone sweep. Pull BHA wiper and increase pump rate to 1.6. Off bottom differential 100PSI higher then expected. 04:30 05:00 0.50 8,970 8,977 PROD1 DRILL DRLG P Drill Zone heading down coil, 1.45 BPM, BHP=3940, 05:00 06:00 1.00 8,977 8,981 PROD1 DRILL DRLG P Saw a little improvement with drill zone, P/U off bottom to clear bit.- drill ahead. 06:00 06:45 0.75 8,981 8,981 PROD1 DRILL WPRT P Pump 7/7 bbl sweeps. P/U weight 32K.Open choke.Wiper up 400' past 8675'while pumping sweeps. Sweep at bit 100'off bottom.Clean to TD. Drill from 8980.55' 06:45 09:45 3.00 8,981 9,110 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3990, BHP 3890, ECD 12.2,WHP 0, ROP 30, WOB 1.6K, CT weight 12K.Slight increase in cutting when sweep came around. Cuttings less than yesterday while drilling. ROP increased to 80 fph @ 9090'. Pumped sweeps prior to Wiper trip. 09:45 12:15 2.50 9,110 9,110 PROD1 DRILL WPRT P Wiper trip P/U weight-35K Tie in correction+2.5'RIH with small weight bobble @ 8675'. RIH. 12:15 14:15 2.00 9,110 9,163 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,4080, BHP 3920, ECD12.4,WHP 60,WOB 1.8K, ROP 60, Ct weight 11K. Stacking weight @ 9055'-Slow ROP -Wiper BHA-clean weights. Pump low/high sweeps. Stall @ 9163'P/U weight 35K. 14:15 15:15 1.00 9,163 9,200 PROD1 DRILL DRLG P Drilling ahead ROP increase @ 9163' 1.45 bpm,4040, BHP 3920, ECD 12.3,WOB 1.2K, Ct weight 14K, ROP 50,Temp 136. 15:15 17:30 2.25 9,200 6,750 PROD1 DRILL WPRT P TD-P/U weight 33K-Wipe to swab valves-pump another sweep in cased hole. Page 6of16 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:30 19:36 2.10 6,750 72 PROD1 DRILL WPRT P 6750.Stop and open EDC,Continue trip out, Recip accross SSSV then continue to surface. No additional cuttings observed at shakers when sweeps arrived or coming to surface. 19:36 21:00 1.40 72 72 PROD1 DRILL PRTS P At surface, reset counters, PJSM to test SSSV, Dump Pressure,Start No Flo test. Dump CT pressure, Calling test good. Line back up to pump, pump well up to 700. Pump up SSSV to open 5500PS1 21:00 22:54 1.90 72 6,849 PROD1 DRILL WPRT P Continue wiper to TD with tie inti lay in beaded liner pill 22:54 23:24 0.50 6,849 6,891 PROD1 DRILL DLOG P Log Tie in for+17',Close EDC, Hold pre spud 23:24 00:00 0.60 6,891 7,559 PROD1 DRILL WPRT P RIH, Log RA marker for zero correction,Continue in hole, 01/22/2012 Condition Hole run L1 lower liner section, P/U upper section and RIH 00:00 01:00 1.00 7,559 9,200 PROD1 DRILL WPRT P Continue wiper to TD, Clean trip in 01:00 04:00 3.00 9,200 102 PROD1 DRILL TRIP P Trip out of hole laying in beaded liner running pill, Paint EOP Flags @ 7700,&5600 04:00 06:00 2.00 102 0 PROD1 DRILL PULD P At surface, PJSM, Bleed off SSSV and coil pressure to zero,Observe for flow.Good test, break off injector and lay down BHA 06:00 07:00 1.00 0 0 COMPZ CASING SFTY P Crew change&PJSM for Picking up liner. Lower Top drive and let it warm up. Weekly function test of BOP's. 07:00 09:30 2.50 0 1,300 COMPZ CASING PUTB P Service top drive and start P/U 40 joints of liner with bullnose&shorty _deployment sleeve. 09:30 10:30 1.00 1,300 1,350 COMPZ CASING PULD P P/U coiltrak BHA&strip over injector. 10:30 11:00 0.50 1,350 1,350 COMPZ CASING SFTY P Hold Post PJSM to review Pipe handling procedure 11:00 13:00 2.00 1,440 6,949 COMPZ CASING RUNL P RIH 100'to equalize above SSSV- WHP 720 psi,CT press 1000psi. No pumps.Open SSSV-Dropped 15 psi to 700psi. RIH following MPD pumping .3 bpm through GS.-3.3K WOB. 13:00 14:00 1.00 6,949 9,200 COMPZ CASING RUNL P Tie into flag+12.5 ft correction. P/U weight 32K, -6k WOB. RIH pumping 3bpm,clean through the window. Good string weight through OH section 15K CT weight. Lower flag +1ft. Light bobble @ 9140'Tag TD @ 9203'set down 2K-P/U weight 36K -3.2K WOB. RIH Tag TD 9203'Set down 3K-bring pumps up 1.3 bpm, Open choke, P/U weight 31K,WOB zero. Liner=9200-7895' Page 7 of 16 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 14:00 15:00 1.00 9,200 7,050 COMPZ CASING TRIP P Stop reset counters-line up to pump down backside&CT string. POOH following MPD. Hard time holding BHP due to choke fluctuating. Set back up down CT string. POOH to Tie in depth. +2.5 ft. 15:00 17:00 2.00 7,050 60 COMPZ CASING TRIP P POOH to EOP flag @ 6600'. POOH following MPD.CT bumped up trap 720 psi on WHP.Shut SSSV-then bleed choke&CT pressure off. 15 minute no-flow test. 17:00 18:45 1.75 60 60 COMPZ CASING PULD P PJSM for laying down BHA-Still small trickle at surface. Cycle SSSV again. 18:45 19:15 0.50 60 0 COMPZ CASING PULD P Crew change, No Flo looks good, Break off injector, Lay down down Liner running tools 19:15 21:30 2.25 0 325 COMPZ CASING PUTB P R/U floor to run liner, Run ported guide shoe, 10 Jts 2 3/8 slotted, Anchored billet 21:30 22:45 1.25 325 396 COMPZ CASING PULD P P/U coil track,make up to liner, make up coil to tools,surface test, set counters 22:45 00:00 1.25 396 3,200 COMPZ CASING RUNL P RIH with L1 Upper liner section. 01/23/2012 Run L1 Upper liner with Anchored Billet TOL 7566,Mill By and drill ahead 00:00 01:18 1.30 3,200 6,982 COMPZ CASING TRIP P Continue in well with L1 liner upper section 01:18 01:36 0.30 6,982 6,996 COMPZ CASING TRIP P Correct to flag, +14 to 6996, PUW=30.5K, Close EDC,Continue in hole 01:36 02:24 0.80 7,180 7,900 COMPZ CASING DLOG P Log tie into K1 for no correction, continue in 02:24 02:30 0.10 7,900 7,900 COMPZ CASING RUNL P Set down @ 7900, Pick up @ 32.5. Set back down TF @ 160R, Pumps on see tool shift @ 4700 PSI, PUW=30.5, POOH, Estimate TOB @ 7566 02:30 05:00 2.50 7,900 COMPZ CASING TRIP P Trip out of well,Stop @ 7338, remove liner length left in hole 334.57'Continue out of well 05:00 06:00 1.00 77 77 COMPZ CASING PULD P PJSM UD BHA#7 Linner running tools. Problems with bravo 4 holding. 06:00 09:00 3.00 77 0 COMPZ CASING PULD P Crew change.Continue with undeploying BHA#7. Slow moving equipment due to cold temperatures top of PDL's. 09:00 11:00 2.00 0 0 COMPZ CASING CIRC P Stab back on with injector and circulate reel volume to ensure warm fluid in reel prior to deploying BHA. Flush stack&choke valves to ensure beads are washed out of system. 11:00 12:30 1.50 0 72 PROD2 DRILL PULD P PJSM for deploying BHA#8 with 1.1 AKO and re-run 3.25"Bi-center. Page 8 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 15:00 2.50 72 7,566 PROD2 DRILL TRIP P RIH with EDC open-flush by SSSV 3 times. Continue RIH+12ft correction.Smooth through window &build. Dry tag TOB 7566' 15:00 17:30 2.50 7,566 7,569 PROD2 STK KOST P P/U weight 32K.TF 180-pumping 1.45 bpm, 3970, BHP 3850,WHP 0, WOB.7,CT weight 15K, ROP.8 fph. Light Stall @ 7566.31'getting started. Mill as per procedure. 17:30 18:42 1.20 7,569 7,600 PROD2 STK KOST P 7569,Goto 10 FPH, 1.45 BPM @ 3825 PSI FS 18:42 18:54 0.20 7,600 7,600 PROD2 STK WPRT P P/U to dry drift Billet, PUW=31 K, BHP=3810 Clean trip past billet 18:54 21:06 2.20 7,600 7,760 PROD2 DRILL DRLG P 7600', Drill Ahead, 1.48 BPM @ 3900 PSI FS, , BHP=3840 21:06 22:12 1.10 7,760 7,760 PROD2 DRILL WPRT P 7760,Wiper to window, PUW=31 K, BHP=3840 22:12 00:00 1.80 7,760 7,896 PROD2 DRILL DRLG P 7760, Drill Ahead, 1.45 BPM @ 3950 PSI FS, BHP=3880 01/24/2012 Drilled L1-01 lateral 00:00 00:06 0.10 7,896 7,910 PROD2 DRILL DRLG P Continue drilling ahead 00:06 01:12 1.10 7,910 7,910 PROD2 DRILL WPRT P 7910,Wiper to window, PUW=31K, Clean trip in and out. Nothing in Billet area 01:12 02:48 1.60 7,910 8,060 PROD2 DRILL DRLG P 7910', Drill Ahead 1.48 BPM @ 3980 PSI FS, RIW=15K,WOB=1.2, BHP=3875, ECD=12.27,Choke full open 02:48 04:48 2.00 8,060 8,060 PROD2 DRILL WPRT P Wiper trip to window with tie in, BHP=3895, ECD=12.35, PUW=30.5K 04:48 06:00 1.20 8,060 8,210 PROD2 DRILL DRLG P Drilling ahead- 1.45 bpm,circ 4280, BHP 3880, ECD 12.3, ROP 98, WOB 1.9K,Ct weight 14K. 10 bbls loss in 12 hours. 06:00 07:30 1.50 8,210 8,210 PROD2 DRILL WPRT P Wiper trip-P/U weight 33K. Clean wiper trip. Call dispatch for mud swap trucks. 07:30 09:12 1.70 8,210 8,360 PROD2 DRILL DRLG P Drilling ahead-1.44 bpm,4210, BHP 3890, ECD 12.3, ROP 60,WOB.7K, CT weight 17K. 09:12 10:54 1.70 8,360 8,360 PROD2 DRILL WPRT P Wiper trip-P/U weight 33K 10:54 13:24 2.50 8,360 8,510 PROD2 DRILL DRLG P 8360', Drill Ahead, 1.45 BPM @ 3850 PSI FS, BHP=3920 Swap Mud 13:24 15:42 2.30 8,510 8,510 PROD2 DRILL WPRT P Wiper to window with tie in,+1 foot correction 15:42 19:12 3.50 8,510 8,660 PROD2 DRILL DRLG P 8510', Drill Ahead, 1.49 BPM @ 3850 PSI FS, BHP=3884 ECD=12.33 19:12 21:18 2.10 8,660 8,660 PROD2 DRILL WPRT P Wiper to the window, 31K PUW Page 9 of 16 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:18 00:00 2.70 8,660 8,727 PROD2 DRILL DRLG P Continue drilling, 1.47 BPM, 3900 CTP,3875 BHP with 100 WHP. Differential pressure increased from 550 to 700 PSI, Pump low/high sweeps, pressure came back to normal as low-vis went through the bit. 01/25/2012 00:00 02:18 2.30 8,727 8,810 PROD2 DRILL DRLG P Continue drilling, 1.47 BPM,3900 CTP, 3875 BHP with 100 WHP. 02:18 04:36 2.30 8,810 8,810 PROD2 DRILL WPRT P Wiper to window, 31K PUW, 15K RIW 04:36 04:57 0.35 8,810 8,832 PROD2 DRILL DRLG P 8810', Drill ahead, 1.47 BPM @ 3870 PSI FS, BHP=3950 04:57 10:21 5.40 8,832 8,832 PROD2 DRILL WPRT P 8832 Wiper trip to sort out plan forward 10:21 13:09 2.80 8,832 8,980 PROD2 DRILL DRLG P 1.46 BPM @ 3850 PSI FS, BHP=3960 13:09 15:33 2.40 8,980 8,980 PROD2 DRILL WPRT P Wiper trip to window with tie in, +2' correction, PUW=34K 15:33 18:24 2.85 8,980 9,130 PROD2 DRILL DRLG P Drill Ahead, 1.44 BPM @ 3900 PSI FS, RIW=17K, EDC=12.5 18:24 21:00 2.60 9,130 9,130 PROD2 DRILL WPRT P Wiper to the window 21:00 00:00 3.00 9,130 9,267 PROD2 DRILL DRLG P Continue drilling, 1.47 BPM,3900 CTP, 3975 BHP with 60 WHP. 01/26/2012 TD L1-01 PB1. Set anchored billet at 8300',oriented 180 deg. Started testing BOPE,AOGCC witness waived by Matt Herrera 00:00 00:42 0.70 9,267 9,275 PROD2 DRILL DRLG P Continue drilling, 1.47 BPM, 3900 CTP,3975 BHP with 60 WHP. 00:42 05:57 5.25 9,275 75 PROD2 DRILL TRIP T POOH,Jet 4 1/2 tubing and make a couple of passes across SSSV 05:57 06:57 1.00 75 75 PROD2 DRILL CIRC T At surface,Circulate while doing crew change out waiting on billet 06:57 08:27 1.50 75 0 PROD2 DRILL PULD T PJSM,Trap Pressure, Dump SSSV, Flo check well, PJSM Lay down mill and motor 08:27 09:27 1.00 0 82 PROD2 STK WPST T M/U anchored billet, M/U to coil track,stab on coil and surface test 09:27 11:51 2.40 82 6,855 PROD2 STK WPST T Trip in hole with billet EDC open, Stop and pressure up well bore to 750PSI,Apply 5500 PSI to SCSSV, Continue in well @ min rate 11:51 12:09 0.30 6,855 7,090 PROD2 STK WPST T Log K1 marker for+8'correction,Trip in close to window and shut EDC, PUW=31K 12:09 12:57 0.80 7,090 8,313 PROD2 STK WPST T Trip into set depth @ 8313.3. Orientation at 180 degrees, Pumps on see setting tool shift @ 4300 PSI, Get 2K DHWOB 12:57 15:57 3.00 8,313 100 PROD2 STK WPST T Trip out of hole 15:57 18:00 2.05 100 0 PROD2 STK WPST T At surface,trap pressure, bleed of SSSV,bleed off WH Pressure, Perform no flo test 15 min, PJSM pull tools from dead well. Page 10 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 0 0 PROD2 DRILL CTOP P Crew change,Valve check list, remove checks from UQC, Flush stack and surface lines 20:00 00:00 4.00 0 0 PROD2 DRILL BOPE P Test ROPE,AOGCC Witness waived by Matt Herrera,AOGCC 01/27/2012 Completed testing BOP,WOW,PU drilling BHA, mill off billet at 8300'and drill L1-01 lateral. 00:00 06:00 6.00 0 0 PROD2 DRILL BOPE P Continue testing BOPE, BOPE Test complete, Had to change out C-3 06:00 09:45 3.75 0 0 PROD2 DRILL OTHR T Wait on weather, need vac trucks to off load fluid 09:45 11:00 1.25 0 72 PROD2 DRILL PULD T PJSM, Shut down managed pressure pumping, S/I SSSV, bleed off WHP and observe for flow,Good test, Install Checks in UQC, M/U BHA#9 Drill By BHA, 1.2 degree AKO with Re run Hycalog 3.25 Bi Center, Make up to coil and surface test 11:00 13:15 2.25 72 6,840 PROD2 DRILL TRIP T Open EDC, Pressure up well, Pressure up SSSV,Trip in 13:15 13:27 0.20 6,840 6,874 PROD2 DRILL DLOG T Log Tie in for+7.5, Close EDC, PUW=31.5K 13:27 14:12 0.75 6,874 8,301 PROD2 DRILL TRIP T Trip in to top of billet 14:12 18:54 4.70 8,301 8,335 PROD2 STK KOST T Dry tag TOB @ 8301, PUH, PUW=31.5K, Bring on pumps 1.44 BPM @3725 PSI, 155 ROHS,Get Positive WOB @ 8300.4,Start time milling. Stall @ 8301.7 18:54 19:06 0.20 8,335 8,335 PROD2 STK KOST T Drift billet, clean 19:06 21:06 2.00 8,335 8,480 PROD2 DRILL DRLG T Drilling ahead, 1.47 BPM,3840 CTP, 3900 BHP 21:06 23:00 1.90 8,480 8,480 PROD2 DRILL WPRT T Wiper to the window,32K PUW 23:00 00:00 1.00 8,480 8,548 PROD2 DRILL DRLG T Drilling ahead, 1.4 BPM, 3840 CTP, 3920 BHP 01/28/2012 Drilled L1-01 lateral to TD at 9215',Wiper trip to surface 00:00 00:48 0.80 8,548 8,630 PROD2 DRILL DRLG T Drilling ahead, 1.4 BPM,3840 CTP, 3920 BHP 00:48 02:48 2.00 8,630 8,630 PROD2 DRILL WPRT T Wiper to the window, 32K PUW 02:48 04:24 1.60 8,630 8,780 PROD2 DRILL DRLG T Drilling ahead, 1.4 BPM,3840 CTP, 3920 BHP 04:24 07:12 2.80 8,780 8,780 PROD2 DRILL WPRT T Wiper to the window, 32K PUW, With Tie in for+2'Correction 07:12 08:48 1.60 8,780 8,930 PROD2 DRILL DRLG T 8780', Drill Ahead, 1.43 BPM @ 3850 PSI FS, BHP=3960 08:48 11:24 2.60 8,930 8,930 PROD2 DRILL WPRT T 8930,Wiper to window, PUW=32K ECD=12.67, BHP=3990 11:24 12:12 0.80 8,930 9,015 PROD2 DRILL DRLG T 8930', Drill Ahead, 1.43 BPM @ 3950 PSI PSI FS, RIW=13K 12:12 13:24 1.20 9,015 9,030 PROD2 DRILL DRLG T Stalled, Slight drop in returns, Ratty drilling, Mud @ 1%solids,trucks here, line up pits for swap 13:24 14:00 0.60 9,030 9,080 PROD2 DRILL DRLG T New mud going down coil, Drilling Ahead 14:00 16:45 2.75 9,080 9,080 PROD2 DRILL WPRT T Wiper to window, PUW=30K Page 11 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 18:00 1.25 9,080 9,215 PROD2 DRILL DRLG T 9080', Drill ahead, 1.45 BPM @ 3810 PSI FS, BHP=3955, ECD=12.57 18:00 23:00 5.00 9,215 72 PROD2 DRILL WPRT P TD, pump low/high vis sweeps,wiper to the swab 23:00 23:54 0.90 72 72 PROD2 DRILL SVRG P Service injector 23:54 00:00 0.10 72 500 PROD2 DRILL WPRT P Wiper back in hole 01/29/2012 Completed long wiper trip. Lay in liner running pill and trip. MU lower liner string and RIH to TD @ 9219'. 00:00 03:18 3.30 500 9,219 PROD2 DRILL WPRT P Wiper back in hole. Tie-in to K1 for -12.5'correction.Tag TD at 9219' 03:18 04:18 1.00 9,219 7,000 PROD2 DRILL DISP P Lay in liner pill with beads in open hole, Paint EOP flag at 7300' 04:18 07:36 3.30 7,000 73 PROD2 DRILL TRIP P POOH, Paint EOP flag at 5200',Jet SSSV 07:36 08:54 1.30 73 0 PROD2 DRILL PULD P At surface, Close SSSV and monitor for flow, PJSM Lay down drilling BHA #10 08:54 11:24 2.50 0 0 COMPZ CASING SVRG P Service&inspect Injector head, Rig up floor to run liner,Warm up top drive and service. Install splitter valve in hydraulic bale circut 11:24 14:42 3.30 0 1,745 COMPZ CASING PUTB P P/U 53 Jts 2 3/8"liner, L1-01 lower section with non ported bullnose and shorty deployment sleeve. Perform BOP Drill 14:42 15:30 0.80 1,745 1,790 COMPZ CASING PUTB P M/U coil track to liner-Coil to BHA, Surface test 15:30 17:18 1.80 1,790 6,998 COMPZ CASING RUNL P Pressure up well to equalize SSSV, Open SSSV with 5500 PSI hydraulic • pressure,Trip in 17:18 18:42 1.40 6,998 9,219 COMPZ CASING RUNL P 6698, correct to flag,-8'to 6990.29, Continue in hole, PUW=33.5K,tie in to RA for-3'correction. Tag TD at 9219', PUW off bottom was 34K with -4K WOB. Pump at 1.4 BPM, 4000 CTP and release from liner,31K PUW with 0 WOB. 18:42 20:36 1.90 9,219 0 COMPZ CASING RUNL P POOH, 20:36 20:54 0.30 0 0 COMPZ CASING SFTY P Close SSSV and monitor well for flow. PJSM 20:54 22:42 1.80 0 268 COMPZ CASING PUTB P Lay down liner running BHA,MU upper liner section and anchored billet and BHA 22:42 23:12 0.50 268 268 COMPZ CASING SVRG P Service injector 23:12 00:00 0.80 268 3,000 COMPZ CASING RUNL P Open SSSV and RIH with EDC open 01/30/2012 Ran upper section of L1-01 liner with anchored billet at 7266'. Milled off billet and drilled L1-02 lateral 00:00 01:12 1.20 3,000 7,077 COMPZ CASING RUNL P RIH,tie in to K1 for a-8.5'correction, close EDC and continue RIH 01:12 01:30 0.30 7,077 7,473 COMPZ CASING RUNL P Continue RIH,Tag lower liner top at 7473', orient single slip to 210 deg. Pump to 4100 CTP to set anchor. 01:30 03:06 1.60 7,473 0 COMPZ CASING RUNL P POOH Page 12 of 16 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 03:06 03:24 0.30 0 0 COMPZ CASING SFTY P Close SSSV and monitor well for flow. PJSM 03:24 04:00 0.60 0 0 COMPZ CASING PUTB P Lay down liner running BHA 04:00 04:48 0.80 0 0 PROD3 DRILL PULD P MU drilling BHA for L1-02 lateral 04:48 05:18 0.50 0 0 PROD3 DRILL SVRG P Service injector 05:18 07:06 1.80 0 6,855 PROD3 DRILL TRIP P RIH 07:06 07:18 0.20 6,855 6,880 PROD3 DRILL DLOG P Tie into K-1 For-9', PUW=31K. 07:18 07:45 0.45 6,880 7,268 PROD3 DRILL TRIP P Trip into top of billet 07:45 10:30 2.75 7,268 7,269 PROD3 STK KOST P Dry tag TOB @ 7268, PUW=31 K, Pumps online 14 BPM @ 3825PS1 FS Tag TOB @ 7267.3 and start time milling.Stall @ 7268.5 10:30 11:12 0.70 7,269 7,270 PROD3 STK KOST P Go to 2 FPH 11:12 11:30 0.30 7,270 7,273 PROD3 STK KOST P Go to 15 FPH, 1.41 BPM @ 3800 PSI FS, BHP=3795 11:30 12:15 0.75 7,273 7,305 PROD3 DRILL DRLG P 7273', Drill Ahead, ROP=39 FPH 12:15 12:27 0.20 7,305 7,305 PROD3 DRILL WPRT P Drift Billet, PUW=29.5K,Slight DHWOB coming up.Clean running in 12:27 14:45 2.30 7,305 7,420 PROD3 DRILL DRLG P 7305', Drill Ahead, 1.4 BPM @ 3800 PSI FS, RIW=18K, BHP=3860 14:45 15:15 0.50 7,420 7,420 PROD3 DRILL DRLG P BHA Wiper, PUW=30.0K,goback to bottom and drill ahead 15:15 16:00 0.75 7,440 7,440 PROD3 DRILL WPRT P 7440',Wipe to window, PUW-31K 16:00 18:54 2.90 7,440 7,590 PROD3 DRILL DRLG P 7440', Drill Ahead, 1.40 BPM @ 3810 PSI FS, BHP=3830, ECD 12.2 18:54 19:30 0.60 7,590 7,590 PROD3 DRILL WPRT P Wiper to the window, 31K PUW, 16K RIW 19:30 00:00 4.50 7,590 7,740 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3800 CTP, 3815 BHP 01/31/2012 Drill L 1-02 lateral.7740'-8640' 00:00 00:24 0.40 7,740 7,090 PROD3 DRILL WPRT P Wiper to the window, 31K PUW 00:24 00:36 0.20 7,090 7,110 PROD3 DRILL DLOG P Tie-in, No Correction 00:36 00:54 0.30 7,110 7,740 PROD3 DRILL WPRT P Wiper back in hole, 16K RIW 00:54 03:00 2.10 7,740 7,890 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3820 CTP, 3860 BHP, 03:00 04:06 1.10 7,890 7,890 PROD3 DRILL WPRT P Wiper to window, PUW=30K 04:06 07:48 3.70 7,890 8,040 PROD3 DRILL DRLG P 7890', Drill Ahead 1.4 BPM @ 3840, BHP=3840, ECD=12.1, 8000' Pumped lo hi vis sweeps to clear suspected bit balling and increased circulating pressure, Cured problem 07:48 09:06 1.30 8,040 8,040 PROD3 DRILL WPRT P Wiper to window, PUW=31K 09:06 11:42 2.60 8,040 8,190 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3820 CTP, 3850 BHP 11:42 12:36 0.90 8,190 7,090 PROD3 DRILL WPRT P Wiper to the window, 31K PUW, 12:36 12:48 0.20 7,090 7,115 PROD3 DRILL DLOG P Tie-in, no correction Page 13 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:48 13:24 0.60 7,115 8,190 PROD3 DRILL WPRT P Wiper back in hole, 16K RIW 13:24 15:24 2.00 8,190 8,350 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3860 CTP,3910 BHP 15:24 16:54 1.50 8,350 8,350 PROD3 DRILL WPRT P Wiper to the window,32K PUW, 16K RIW 16:54 19:30 2.60 8,350 8,470 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3900 CTP, 3900 BHP 19:30 19:36 0.10 8,470 9,470 PROD3 DRILL WPRT P Stall, PU,34K PUW, 19:36 19:45 0.15 8,470 8,490 PROD3 DRILL DRLG P Drill Ahead, 1.4 BPM,4150 CTP, 3909 BHP. Pump pressure increased 150-250psi after stall. 19:45 21:45 2.00 8,490 8,490 PROD3 DRILL WPRT P Wiper trip to window,33.5K PUW, Lower pump rate to 1.3 BPM during wiper trip.pump pressures getting to high. Discuss possible plugged nozzle, bit balling,or rubber from motor causing increased pressure. Pump low/high 5brls each sweep on RBIH close to bottom. 21:45 23:30 1.75 8,490 8,640 PROD3 DRILL DRLG P Drill Ahead 1.3 BPM,4290 CTP, 3927 BHP, 100 MP choke,while sweeps circ.to surface..Wide open choke 4190 CTP, 3913 BHP.Sweep did not seem to help. Cont drilling. 23:30 00:00 0.50 8,640 8,640 PROD3 DRILL WPRT P Wiper trip to window. 33K PUW.Tie in depth-3'correction 02/01/2012 TD L1-02 lateral at 8940'. POOH to swab valves. Park at surface manage pressure pumping waiting on weather.Ambient temps.-50 00:00 01:45 1.75 8,640 8,640 PROD3 DRILL WPRT P Wiper trip to window 01:45 04:06 2.35 8,640 8,790 PROD3 DRILL DRLG P Drill Ahead 1.3 BPM,4180 CTP, 13K CTW,3930 BHP 04:06 06:18 2.20 8,790 8,790 PROD3 DRILL WPRT P Wiper trip to window 33K PUW 06:18 10:18 4.00 8,790 8,940 PROD3 DRILL DRLG P Continue drilling, 1.4 BPM,4100 CTP,3940 BHP 10:18 14:06 3.80 8,940 0 PROD3 DRILL WPRT P TD, pump sweeps and wiper to the swab. 14:06 21:24 7.30 0 0 PROD3 DRILL OTHR T -51 ambient temp. Park at surface, manage pressure pumping, 21:24 00:00 2.60 0 0 PROD3 DRILL OTHR T -56 ambient temp.At surface, manage pressure pumping. 02/02/2012 Wait on weather(lam). RBIH to TD 8938' POOH lay in liner pill in OH. PU/MU/RIH lower L1-02 liner, release on bottom 8942'TOL 7518'. POOH PU/MU L1-02 lower liner. 00:00 01:45 1.75 0 0 PROD3 DRILL OTHR T Wait on weather manage pressure pumping 01:45 03:45 2.00 0 6,835 PROD3 DRILL WPRT P PJSM, RIH Temps: Pioneer-32 ambient 30 pad-38 ambient 3S pad-40 ambient 03:45 03:57 0.20 6,835 6,835 PROD3 DRILL WPRT P Tie in depth-13'correction 03:57 04:42 0.75 6,835 8,940 PROD3 DRILL WPRT P Cont RIH to TD Page 14 of 16 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:42 06:30 1.80 8,940 7,000 PROD3 DRILL DISP P Lay in liner pill while POOH 06:30 09:12 2.70 7,000 0 PROD3 DRILL TRIP P Continue POOH,jet across SSSV 09:12 09:42 0.50 0 0 PROD3 DRILL SFTY P Shut SSSV and monitor well for no-flow. PJSM 09:42 10:42 1.00 0 0 PROD3 DRILL PULD P Lay down drilling BHA 10:42 15:54 5.20 0 1,467 COMPZ CASING PUTB P RU for liner operations and run lower liner string,43 joints slotted liner. 15:54 17:24 1.50 1,466 6,966 COMPZ CASING RUNL P RIH first liner section BHA#14. 17:24 18:24 1.00 6,966 6,966 COMPZ CASING RUNL P Tie in to EOP flag-10.5'. Record up in down weights.33K up, 16K down, close EDC. RIH 18:24 18:36 0.20 6,966 8,942 COMPZ CASING RUNL P Tag TD 8942'. PU with liner 35K,-4K DHWOB. RBIH tag.online with pumps 1.2 BPM 3800 psi. PU 30K PUW,-1K DHWOB. Liner released. 18:36 18:54 0.30 7,249 6,848 COMPZ CASING RUNL P POOH pumping manage pressure. choke closed maintain MP.24 BPM. Remove liner length from bit depth. 1421.91' 18:54 19:00 0.10 6,848 6,848 COMPZ CASING RUNL P Tie in depth with gamma-2' correction. 19:00 20:00 1.00 6,848 1,898 COMPZ CASING RUNL P POOH 20:00 20:30 0.50 1,898 1,898 COMPZ CASING RUNL P Open EDC Jet SSSV 20:30 21:00 0.50 1,898 0 COMPZ CASING RUNL P POOH 21:00 21:15 0.25 0 0 COMPZ CASING SFTY P At surface, Close SSSV,flow check, PJSM 21:15 21:45 0.50 0 0 COMPZ CASING PUTB P LD BHA 14 21:45 22:15 0.50 0 0 COMPZ CASING PUTB P Prep floor to PU liner 22:15 00:00 1.75 0 0 COMPZ CASING PUTB P PU upper L1-02 liner(17jnts 2 3/8" slotted liner) 02/03/2012 RIH with upper L1-02 liner. Release liner on depth. Final liner depths,TOL-7053', Break in liner 7516', BOL-8938' 00:00 01:18 1.30 507 6,500 COMPZ CASING RUNL P RIH 01:18 01:30 0.20 6,500 7,040 COMPZ CASING RUNL P Tie in depth to EOP flag-8' 01:30 01:51 0.35 7,040 7,517 COMPZ CASING RUNL P Record up and down weights 29K up, 16K down. RIH to TOL 01:51 01:57 0.10 7,517 7,500 COMPZ CASING RUNL P Tag TOL#1 7516.57'. PU wt. check. with liner.32K, -1.68K DHWOB. RBIH tag TOL#1 7516.93'with 5.4K down on DHWOB.Online with pumps 1.2 BPM,4000 CTP, PU 29K CTW, 0 DHWOB. Liner released. Remove liner length from BHA 462.9'. TOL 7053' 01:57 02:09 0.20 7,500 6,830 COMPZ CASING RUNL P Open EDC, PUH to tie in depth. 02:09 02:39 0.50 6,830 6,830 COMPZ CASING RUNL P Tie in depth-.5'correction 02:39 04:09 1.50 6,830 7,022 COMPZ CASING DISP P RIH to TOWS. Displace well to Seawater, POOH Page 15 of 16 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04:09 05:03 0.90 7,022 2,500 COMPZ CASING FRZP P Wait on LRS to arrive with diesel. 05:03 06:03 1.00 2,500 0 COMPZ CASING FRZP P LRS on location. Rig up LRS and POOH pumping freeze protect. 06:03 09:03 3.00 0 0 COMPZ CASING PULD P Undeploy liner running BHA. FMC on location for BPV install. 09:03 15:03 6.00 0 0 DEMOB WELLPF NUND P Rig up FMC BPV lubricator. Troubleshoot lubricator. Lubricator fixed; set BPV. 15:03 18:03 3.00 0 0 DEMOB WELLPF DISP P Flush CT and rig iron then pump inhibitor. 18:03 00:00 5.95 0 0 DEMOB WELLPF DMOB P Flush/Purge CT and Rig. Nipple down,flange up tree cap. ***Rig Release*** Page 16 of 16 • • Letter of Transmittal FARO BAKER Date: February 6, 2012 HUGHES To: From: Christine Mahnken Carl Ulrich/Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3H-34L1 3H-34L1PB1 3H-34L1-01 2_11-\(,3 3H-34L1-01PB1 3H-34L1-02 211-16, (5) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files %WED MAR l 2 2018 r tri Note: Please feel free to send us an email in place of return mail. 0 s Am Sachin Gandra, Baker Hughes, Project Engineer `II 5,0 �.a Sachin.Gandra@BakerHughes.com 3ems, 171 CJCarl.Ulrich, Baker Hughes, Survey Manager e Carl.Ulrich@BakerHughes.com . I ,111 ` g W' 1 d C ♦, ca 0 a RS W ce . 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CD m Co r- r co N co N 0 N m N N M O Cn 4 N 0 0 0 ; N C.-;i M U "' m m co m m co m co m R 0 N co— — -. C O M CD:', 000 0 M W N N a CO CO O cM 'Q 0 0) •A t d w 0_ cy c M co V V sr co co co co �Ci > . "-E E M Mai 022 C O_ d (`i M 1 n V 1CN] M O NCO `- ,- 0C O 7 = mix _ Ni N O 0 h 00 0 0 ,� ,,O 0 Y Y CO CO M ‘- g° 0 0 0 0 m m m m m CO 0 0 CO m o m o i N N R 7 co Co r- Co O /� C .. N m N 0 co0O O N- OO OC) Y� ca VO C T m m m ro cocoa) m VQ a o .. a a) 2 m m CO m m m m CO CO c 0 aiva ) 33c co a Mwr i £ 1 `}16 r2, I - tAl v ; SEAN PARNELL,GOVERNOR t 3 f P ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt Alaska CTD Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H-34L1-02 ConocoPhillips Alaska, Inc. Permit No: 211-164 Surface Location: 932' FNL, 282' FWL, SEC. 12, T12N, R8E, UM Bottomhole Location: 1969' FSL, 1660' FEL, SEC. 1, T12N, R8E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 3H-34, Permit No 211- 128, API 50-103-20643-00. 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, Al Daniel T. Seamount, Jr. Chair DATED this2-'day of December, 2011. cc: Department of Fish 86 Game, Habitat Section w/o end. (via e-mail) Department of Environmental Conservation w/o end. (via e-mail) sConocoPhillip Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 13, 2011 RiEr‘it" DEC 5 ,90 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission Nada Oil&Gas333 West Anchorage,th Alaskaue 99501 e 100 ilei Or g. C�31amisson Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete three laterals from Kuparuk well 3H-34 (PTD# 211-128). Coiled tubing drilling (CTD) operations are scheduled to begin as early as January 10, 2012, using the rig, Nabors CDR2-AC. The objective of the CTD project is to improve A-Sand sweep efficiency and oil recovery within the target pattern by drilling lateral sidetracks. Each lateral will be drilled from a single window exit from the 4.5" liner in parent wellbore 3H-34. The parent wellbore will have no producing sections; it will be considered "suspended". For that reason, the laterals will then be named: 3H-34L1, 3H-34L1-01, and 3H-34L1-02. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 3H-34L1, 3H-34L1-01, and 3H-34L1-02 — Directional Plans for 3H-34L1, 3H-34L1-01, and 3H-34L1-02 — Current Wellbore Schematic — Proposed Wellbore Schematic If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, Jill ong ConocoPhillips Alaska Coiled Tubing Drilling Engineer RECEIVED1 STATE OF ALASKA NEC 1 5 ?fl1' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Aka Oil & Gas Cans.Cernnission 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil a• Service-Winj ❑ Single Zone a- lc.Specify if well is proposed for: Drill o Re-drill❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: LJ Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 3H-34L1-02 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:9285' - TVDSS: 6034' - Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:932'FNL,282'FWL,Sec. 12,T12N,R8E,UM ADL 25531 Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2161'FSL,2240'FWL,Sec. 1,T12N, RO8E,UM 2657 1/10/2012 Total Depth: 9.Acres in Property: 14.Distance to 1969'FSL, 1660'FEL,Sec. 1,T12N,RO8E, UM 2560 Nearest Property: 9500' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 64 feet 15.Distance to Nearest Well Open Surface:x- 498655 . y- 6000725 - Zone- 4 GL Elevation above MSL: _ 36 feet to Same Pool: 3H-14B,600' 16.Deviated wells: Kickoff depth:• 7380 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 101° deg Downhole:3990 psig • Surface:3387 psig 18.Casing Prov ram: 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 2432' 6583' 5680' 9285' 6034' 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) 7300' 6206' none none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 170 sx cement 114' 114' Surface 3943' 10.75" 1578 sx LiteCRETE 3977' 3518' Intermediate 380 sx DeepCRETE Production 6857' 7.625" 532 sx Class G 6891' 5947' Liner 717' 4.5" 28 bbls Class G 7300' 5393' Perforation Depth MD(ft): Perforation Depth TVD(ft): none none 20.Attachments: Property Plat❑ BOP Sketch a Drilling Programa Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Programa 20 AAC 25.050 requirements E 21.Verbal Approval: Commission Representative: Date:iQS d Pr t 7 J It 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263-4093 Printed Name L. GanttTitle Alaska CTD Manager Signature Phon zs Date / g . ivellittok /2 is/�/ (v7�1 Commission Use Only " Permit to Drill API Number: Permit Approval See cover letter Number: / (/ 50-/t `-;_(21(% ( 3'62-Cr-Date: l L\v i 11 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m hane,gas hydrates,or gas contained in shales: a/ 7V-- u�OD S y ao O f Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No d Other: —1 P / H2S measures: Yes [j No ❑ Directional svy req'd: Yes [✓] No ❑ 0 ,e APPROVED BY THE COMMISSION /2/ /// DATE: II"v. y°-- 1 3� ' ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid fdr 24()Ninths'frojn;the date of p oval(20 AAC 25.005(g)) Sub it in Duplicate ) .t( art p I L• Lz. /1/x,4 /L�' Kuparuk CTD Laterals NABORS ALASKA Drilling 3H-34L1, 3H-34L1-01 , and 3H-34L1-02 Application for Permit to Drill Document 2RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)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 3 (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information and Reservoir Pressure 3 (Requirements of 20 AAC 25.005(c)(4)) 3 5. Procedure for Conducting Formation Integrity tests 3 (Requirements of 20 AAC 25.005(c)(5)) 3 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 4 (Requirements of 20 AAC 25.005(c)(7)) 4 8. Drilling Fluids Program 4 (Requirements of 20 AAC 25.005(c)(8)) 4 9. Abnormally Pressured Formation Information 5 (Requirements of 20 AAC 25.005(c)(9)) 5 10. Seismic Analysis 5 (Requirements of 20 AAC 25.005(c)(10)) 5 11. Seabed Condition Analysis 5 (Requirements of 20 AAC 25.005(c)(11)) 5 12. Evidence of Bonding 5 (Requirements of 20 AAC 25.005(c)(12)) 5 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 3H-34L1,3H-34L1-01,and 3H-34L1-02 7 Attachment 2: Current Well Schematic for 3H-34 7 Attachment 3: Proposed Well Schematic for 3H-34L1, 3H-34L1-01,and 3H-34L1-02 7 Page 1 of 7 12/13/2011 PTD Application: 3H-34L 3H-34L1-01, and 3H-34L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3H-34L1, 3H-34L1-01 and 3H-34L1-02. All three of these laterals will be classified as"Development- Oif'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 932' FNL, 282' FWL, Sec 12, T12N, RO8E, UM NAD 1927 RKB Elevation 64 AMSL Northings: 6000725 Eastings: 498655 9 9 Pad Elevation 36 AMSL 3H-34L1 Location at Top of Productive Horizon 2272' FSL, 2286' FWL, Sec 1, T12N, RO8E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7500' Northings: 6003928 Eastings: 500658 Total Vertical Depth, SS: 6016' Location at Total Depth 1961' FSL, 1675' FEL, Sec 1, T12N, RO8E, UM NAD 1927 Measured Depth, RKB: 9150' Northings: 6003617 Eastings: 501977 Total Vertical Depth, SS: 6052' 3H-34L1-01 Location at Top of Productive Horizon 2162' FSL, 2240' FWL, Sec 1, T12N, RO8E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7380' Northings: 6003819 Eastings: 500612 Total Vertical Depth, SS: 6019' Location at Total Depth 2001' FSL, 1639' FEL, Sec 1, T12N, RO8E, UM NAD 1927 Measured Depth, RKB: 9220' Northings: 6003657 Eastings: 502013 Total Vertical Depth, SS: 6076' 3H-34L1-02 Location at Top of Productive Horizon 2161' FSL, 2240' FWL, Sec 1, T12N, RO8E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 7380' Northings: 6003819 Eastings: 500612 Total Vertical Depth, SS: 6019' Location at Total Depth 1969' FSL, 1660' FEL, Sec 1, T12N, RO8E, UM NAD 1927 Measured Depth, RKB: 9285' Northings: 6003626 Eastings: 501992 Total Vertical Depth, SS: 6034' OR i ,., Page 2 of 7 i t , t 't .. 12/13/2011 PTD Application: 3H-34L1, 3H-34L1-01, and 3H-34L1-02 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 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 to 4000 psi. (Using the maximum pressure in the area of 3990 psi, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3387 psi. 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 (Requirements of 20 AAC 25.005(c)(4)(a)) When the Doyon 141 was drilling 3H-34, the fluid weight at TD (7300'MD/6142'TVDSS) at which the reservoir (both A and C sands combined) remained static was 12.0 ppg. Based up on this static data, the anticipated bottomhole pressure at the kickoff point(KOP) is 3833 psi, a 12.0 ppg equivalent mud weight(EMW). The maximum downhole pressure in the 3H-34 pattern is near injector 3H-17. 3H-17 has been shut-in since August 2010. An updated static bottomhole pressure (BHP) reading was obtained on December. 10, 2011, indicating a pressure of 3990 psi at 8290' MD/6027' TVDSS. This would be the equivalent of 12.7ppg fluid. Using this pressure as the maximum possible in 3H-34, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3387 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; however, 3H pad does have some wells on miscible gas injection (MI) so encountering MI gas is a possibility. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 3H-34 laterals will be at fault crossings. The primary fault crossing is expected to have a 30' throw. This risk has been taken into account by drilling the A2 sand lateral first. This is the middle sand package and, once it is drilled, the other two laterals (above and below) can be adjusted accordingly. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity tests. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 3H-34L1 7500' 9150' 6016' 6052' 2%" 4.7#, L-80, ST-L slotted liner; anchored aluminum billet on top. 3H-34L1-01 7380' 9220' 6019' 6076' 2'/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. 3H-34L1-02 6583' 9285' 5744' 6034' 23/" 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. OR ! ' _ Page 3 of 7 12/13/2011 PTD Application: 3H-34L., 3H-34L1-01, and 3H-34L1-02 Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.55 H-40 Welded 0' 107' 0' 107' 1640 630 Surface 10-3/4" 45.5 L-80 BTC 0' 3977' 0' 3187' 5210 2470 Casing 7-5/8" 29.7 L-80 BTCM 0' 6891' 0' 5111' 6890 4790 Liner 4-1/2" 12.6 L-80 EUE 8rd-mod 6582' 7300' 4907' 5393' 7700 7500 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 0' 6582' 0' 4907' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not 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(8.6 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.7 ppg). While this mud weight does not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 3H-34 contains a subsurface safety valve (SSSV). The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg Sodium Bromide completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes (-165 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. 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 an overbalance on the reservoir. /Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the i minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP target of 12.0 ppg, targeted at the window, is available based on data from the recently drilled 3H-34 parent wellbore. . The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 4 of 7 12/13/2011 • PTD Application: 3H-34L-i, 3H-34L1-01, and 3H-34L1-02 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 Kuparuk well 3H-34 was drilled and completed in November 2011 as a set-up for the three CTD laterals that this application covers. The liner across the reservoir was cemented in place and has not been perforated. The plan for the parent wellbore is to leave it as "suspended" ; i.e. not open the parent up to production. At this time, the only production from 3H-34 will come from the CTD laterals. The CTD sidetracks at 3H-34 are intended to improve areal sweep efficiency and oil recovery from the 3H- 34 pattern. The 3H-34 CTD project is the third well in a four well program at 3H pad in the years 2011 and 2012. Previously, 3H-10 and 3H-12 have had CTD laterals drilled. After 3H-34, CTD sidetracking from 3H-11 is planned for mid-2012. Pre-Rig Work 1. Perform drift and tag. Perform a dummy whipstock drift as well. 2. Perform GR/CCL log for tie-in purposes to confirm KOP is spaced between collars. 3. Set whipstock pre-rig at 7062' MD (+/- 10' to adjust for actual collar locations). 4. Set BPV and prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. If the whipstock was not set pre-rig, set whipstock at 7062' MD (+/- 10' to adjust for actual collar locations). 3. Mill a 2.80", single string window exit with high-side orientation. 4. Drill 3H-34L1 Lateral a. Drill 2.70" x 3" bi-center lateral in the A2 sand to a TD of 9150' MD b. Run 2%" slotted liner from TD to —7500', utilizing the SSSV for deploying the liner Rig Work Continued on next page.... 1r1 L. Page 5 of 7 12/13/2011 PTD Application: 3H-34L-1, 3H-34L1-01, and 3H-34L1-02 Rig Work Continued 5. Drill 3H-34L1-01 Lateral a. Drill 2.70"x 3" bi-center lateral in the Al sand to a TD of 9220' MD b. Run 2%" slotted liner from TD to—7380', utilizing the SSSV for deploying the liner 6. Drill 3H-34L1-02 Lateral a. Drill 2.70" x 3" bi-center lateral in the A3 sand to a TD of 9285' MD 1/ 71;5 5 b. Run 2%" slotted liner from TD up into the 3.5"tubing (to—6580' MD). Leave the top of liner below the X nipple at 6573'to allow for use of the X nipple. 7. POOH swapping well over to brine. Freeze protect. 8. Set BPV. ND BOPE. RDMO Nabors CRD2-AC. 9. Handover to Production group. Post-Rig Work 1. Pull BPV and install gas lift design. 2. Put 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 listed 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 observed, only in reverse. Liner Running — Since 3H-34 is equipped with a SSSV, the 3H-34 CTD laterals will not need to be displaced to an overbalancing fluid prior to running 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%" rams will provide secondary well control while running 2%" liner. 0 I) Page 6 of 7 12/13/2011 PTD Application: 3H-34L_, 3H-34L1-01, and 3H-34L1-02 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)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — 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 (measured to Tarn PA boundary at closest point) Lateral Name Distance 3H-34L1 9500' 3H-34L1-01 9500' 3H-34L1-02 9500' — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 3H-34L1 600' 3H-14B 3H-34L1-01 800' 3H-14B 3H-34L1-02 600' • 3H-14B 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for this well because it will be put on production service. 17. Attachments Attachment 1: Directional Plans for 3H-34L1, 3H-34L1-01, and 3H-34L1-02 Attachment 2: Current Well Schematic for 3H-34 Attachment 3: Proposed Well Schematic for 3H-34L1, 3H-34L1-01, and 3H-34L1-02 Page 7 of 7 12/13/2011 / § o / ) / / _ \ Ja � - \ E ° #\ a\ ( G §2 #aH k § R r00 \ /\ s %§ p • / • •L'' / { / \ §\ 0 \ / \ \ 0 / E , 5 �- / \ a LO Cs1 c \ \ • \ ± » \ \ , • e 4 ) - a r ( { E ( E o7 x j - ) ) _ / § / / \ \ \ \ 2222 § Co \ \ \ w \ 3 \\ // / G / CO 2G )) . / i i / 2 � _ ^ �k z «4 f _ \ 0 - . . . . I- 0 _ \ 0 1c,I § $ \ 2 ! ± / ƒ )§ Ica ? 2 am 2a a \ Q § \ 2 7 .- « 0 $ ok / / 0) - (N IN }\ \ \\ \/ \ \ \ \\ . \ ORIGINAL KUP 3H-34 T:DAL ConocoPhillips awe is Well Attributes Max Angle&MD TD ` Alaska,he.. Wellbore API/VW] Field Name Well Statue Incl(°) MD(ftKB) Act Btm(MB) CorndPhafips, 501032064300 KUPARUK RIVER UNIT PROD Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date °°° Well Con99:-3H-31.12120119:31:St AM SSSV:TRDP Last WO: 11/25/2011 Schematic-Actual - Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Rev Reason:NEW WELL ninam 12/1/2011 Casing Strings HANGER,23 IP 'di. Casing Description String 0... String ID...Top(ftKB) Set Depth(/...Set Depth(TVD)...String Wt...String.„String Top Thrd CONDUCTOR 16 15.062 28.0 107.0 107.0 62.60 H-40 WELDED _ - _ Coning Description String 0... String ID„.Top(ftKB) Set Depth(f...Set Depth(TVD)--String Wt...String...String Top Thrd C 7SURFACE 103/4 9.950 28.7 3,977.4 3,545.6 45.50 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE 75/8 6.875 25.3 6,890.9 5,974.7 29.70 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER 41/2 3.958 6,582.5 7,300.0 6,233.2 12.60 L-80 IBT-mod _--_-- _-- -Liner Details Top Depth (TVD) Top Incl Mond... Top(ftKB) (ftic6) CI Item Description Comment ID(in) 6,5825 5,771.0 44.34 PACKER BAKER HRD ZXP LINER TOP PACKER 4.960 6,601.5 5,784.7 45.01 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 6,606.4 5,788.2 45.18 HANGER BAKER DOUBLE GRIP FLEX-LOCK LINER HANGER 4.900 6,616.3 5,795.1 45.53 XO Reducing CROSSOVER,5-1/2"x 5" 4.490 6,617.3 5,795.8 45.56 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 GOND 28-1007 6,635.8 5,808.6 46.22 XO Reducing CROSSOVER 5"x 4-1/2" 3.970 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING 4.5x3.5 31/2 2.992 23.1 6,639.3 5,811.0 9.30 L-80 EUE8RDMOD SAFETY VIv. Completion Details ten 11. Depth (ND) Top Incl Noml... Top(ftKB) (ftKB) (°) item Description Comment ID(in) 23.1 23.1 -0.02 HANGER FMC TUBING HANGER 4.500 88.4 88.4 0.25 XO Reducing CROSSOVER,4W IBT-m box x 3-1/2"EUE pin 3.500 Gas 2 738 - 1,898.8 1,843.8 33.39 SAFETY VLV CAMCO TRMAXX-CMT-5SR SAFETY VLV w/2.812"X PROFILE 2.812 6,572.8 5,763.9 43.99 NIPPLE HESXNIPPLE 2.813 6,620.3 5,798.0 45.67 LOCATOR BAKER 80-40 GBH-22 LOCATOR SUB' 3.000 I6,621.2 5,798.5 45.70 SEAL ASSY BAKER SEAL ASSEMBLY w/10'STROKE 81/2 MULE SHOE 2.990 6,639.2 5,810.9 46.34 MULE MULE SHOE 2.990 SURFACE, 29-3,977 I. GAS LIFT, 1.208 GAS LIFT, ,1]1 GASL.982IFT,______./ .. : GAS LIFT. 8,514 NIPPLE,6,573 lii LOCATOR, 8,820 SEAL ASSY. , 8,821 - ) ( Mandrel Details MULE,6,839 Top Depth Top Port (ND) Ind OD Valve Latch Size TRO Run Sm Top(ftKB) (ftKB) P) Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 2,738.4 2,531.7 37.30 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/23/2011 2 4,206.2 3,732.6 33.56 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/23/2011 3 5,170.6 4,573.2 27.34 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1123/2011 NTERM2 _891 A 4 5,981.6 5,282.3 26.33 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11232011 5 6,514.3 5,721.5 42.08 CAMCO MMG 1 12 GAS LIFT SOV REK 0.000 0.0 11232011 I RoiGht,„pr • LINER,6.583-7.300 1 • �' yTD,],300 -. 3H-34 Wellbore Design (final 11-29-11) ConOCOPhillips :: 30"x 16" 62.6# insulated conductor i% @ 79'MD 10-%" Stage Collar @ 975.83'MD/ 963.9'TVD •J • Schlumberger TRMAXX • - r CMT SCSSV @ 1,898.77' , MD/ 1,816.6'TVD G - h 1 ) .•. „ ,5 �. 10-3/4"45.5#L-80 BTC 3,977.40'MD/3,517.5' TVD 3 r 5 3-1/2"9.3#L-80 EUE tubing GLM# TVD ft MD ft Valve Type 1 2,502.5 2,738.41 Dummy TOC @+/-5,100'MDI 2 3,705.0 4,206.24 Dummy 3 4,545.8 5,170.62 Dummy . 4 5,256.4 5,981.58 Dummy 5 5,693.9 6,514.32 SOV(annulus to tubing shear) s • Baker Liner top HES 2.813"x 3.5""X"Nipple with ZXP packer k2@ 6,572.78'MD/5.736.8' @ 6,582.51'MD/5,743.0'TVD :: • ;. ,. : TVD, 43°inclination i 7-5/8"29.7#L-80 BTCM r@689090 'MD/5,946.7'TVD Production Liner 4-1/2" 12.6#L-80 IBTM R2 7,300.00'MD/6,205.7'TVD ORIGINAL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H-34 3H-34L1-02 Plan: 3H-34L1-02_wp04 Standard Planning Report 12 December, 2011 r' I BAKER HUGHES ConocoPhillips or its affiliates V&I" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-34 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 0141 @ 63.91ft(D141(36.4+27.51)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-34 Survey Calculation Method: Minimum Curvature Wellbore: 3H-34L1-02 Design: 3H-34L1-02_wp04 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3H Pad Site Position: Northing: 6,000,110.73ft Latitude: 70°24'41.531 N I From: Map Easting: 498,655.44 ft Longitude: 150°0'39.416 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 3H-34 Well Position +N/-S 0.00 ft Northing: 6,000,725.46 ft Latitude: 70°24'47.578 N +El-W 0.00 ft Easting: 498,655.48 ft Longitude: 150°0'39.418 W I Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 36.40 ft Wellbore 3H-34L1-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 1/11/2012 16.29 79.93 57,373 Design 31-1-34L1-02_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,380.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -36.40 0.00 0.00 75.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +El-W Rate Rate Rate TFO (ft) (°l (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,380.00 91.63 27.68 6,019.32 3,093.61 1,956.42 0.00 0.00 0.00 0.00 7,460.00 101.23 27.68 6,010.37 3,163.93 1,993.30 12.00 12.00 0.00 0.00 7,540.00 97.06 18.91 5,997.64 3,236.40 2,024.47 12.00 -5.21 -10.95 245.00 7,620.00 90.60 26.03 5,992.30 3,310.06 2,054.96 12.00 -8.08 8.90 132.00 7,820.00 89.73 50.02 5,991.72 3,466.46 2,177.27 12.00 -0.43 11.99 92.00 8,120.00 88.90 86.01 5,995.43 3,576.92 2,450.88 12.00 -0.28 12.00 91.50 8,320.00 89.81 110.00 5,997.72 3,549.27 2,647.47 12.00 0.45 11.99 88.00 8,460.00 87.51 126.65 6,001.01 3,483.12 2,770.24 12.00 -1.64 11.89 98.00 8,685.00 89.60 153.57 6,006.80 3,312.12 2,913.14 12.00 0.93 11.97 86.00 8,885.00 89.63 129.57 6,008.17 3,156.58 3,036.53 12.00 0.02 -12.00 270.00 9,010.00 85.43 143.99 6,013.58 3,065.85 3,121.82 12.00 -3.36 11.53 106.50 9,285.00 86.17 110.91 6,034.32 2,901.45 3,336.53 12.00 0.27 -12.03 270.00 12/12/2011 1:48:53PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates FAQ ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-34 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: D141 c 63.91ft(D141(36.4+27.51)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-34 Survey Calculation Method: Minimum Curvature Wellbore: 3H-34L1-02 Design: 3H-34L1-02_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +EI-W Section Rate Azimuth Northing Easting (ft) (°) l°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 7,380.00 91.63 27.68 6,019.32 3,093.61 1,956.42 2,690.45 0.00 0.00 6,003,818.41 500,612.27 TIP/KOP 7,400.00 94.03 27.68 6,018.33 3,111.30 1,965.70 2,703.99 12.00 0.00 6,003,836.09 500,621.55 7,460.00 101.23 27.68 6,010.37 3,163.93 1,993.30 2,744.27 12.00 0.00 6,003,888.71 500,649.15 2 7,500.00 99.17 23.27 6,003.29 3,199.46 2,010.23 2,769.81 12.00 -115.00 6,003,924.24 500,666.08 7,540.00 97.06 18.91 5,997.64 3,236.40 2,024.47 2,793.13 12.00 -115.78 6,003,961.17 500,680.33 3 7,600.00 92.22 24.26 5,992.79 3,291.97 2,046.47 2,828.76 12.00 132.00 6,004,016.73 500,702.34 7,620.00 90.60 26.03 5,992.30 3,310.06 2,054.96 2,841.65 12.00 132.43 6,004,034.82 500,710.83 4 7,700.00 90.25 35.63 5,991.70 3,378.68 2,095.92 2,898.97 12.00 92.00 6,004,103.42 500,751.79 7,800.00 89.82 47.62 5,991.64 3,453.29 2,162.22 2,982.32 12.00 92.07 6,004,178.01 500,818.10 7,820.00 89.73 50.02 5,991.72 3,466.46 2,177.27 3,000.27 12.00 92.08 6,004,191.18 500,833.16 5 7,900.00 89.48 59.62 5,992.27 3,512.50 2,242.58 3,075.27 12.00 91.50 6,004,237.20 500,898.47 8,000.00 89.20 71.61 5,993.43 3,553.71 2,333.49 3,173.74 12.00 91.43 6,004,278.39 500,989.37 8,100.00 88.95 83.61 5,995.05 3,575.11 2,430.97 3,273.44 12.00 91.30 6,004,299.78 501,086.85 8,120.00 88.90 86.01 5,995.43 3,576.92 2,450.88 3,293.14 12.00 91.10 6,004,301.58 501,106.76 6 8,200.00 89.25 95.61 5,996.72 3,575.79 2,530.77 3,370.02 12.00 88.00 6,004,300.44 501,186.64 8,300.00 89.71 107.60 5,997.63 3,555.72 2,628.54 3,459.26 12.00 87.84 6,004,280.35 501,284.40 8,320.00 89.81 110.00 5,997.72 3,549.27 2,647.47 3,475.88 12.00 87.74 6,004,273.90 501,303.33 7 8,400.00 88.48 119.51 5,998.91 3,515.82 2,720.03 3,537.31 12.00 98.00 6,004,240.44 501,375.87 8,460.00 87.51 126.65 6,001.01 3,483.12 2,770.24 3,577.35 12.00 97.86 6,004,207.73 501,426.07 8 8,500.00 87.85 131.44 6,002.63 3,457.95 2,801.28 3,600.81 12.00 86.00 6,004,182.56 501,457.10 8,600.00 88.77 143.41 6,005.58 3,384.48 2,868.78 3,647.00 12.00 85.81 6,004,109.09 501,524.58 8,685.00 89.60 153.57 6,006.80 3,312.12 2,913.14 3,671.12 12.00 85.45 6,004,036.72 501,568.93 9 8,700.00 89.60 151.77 6,006.90 3,298.79 2,920.03 3,674.32 12.00 -90.00 6,004,023.39 501,575.81 8,800.00 89.61 139.77 6,007.60 3,216.26 2,976.17 3,707.19 12.00 -89.99 6,003,940.86 501,631.93 8,885.00 89.63 129.57 6,008.17 3,156.58 3,036.53 3,750.05 12.00 -89.90 6,003,881.18 501,692.28 10 8,900.00 89.12 131.30 6,008.33 3,146.85 3,047.95 3,758.56 12.00 106.50 6,003,871.45 501,703.69 9,000.00 85.76 142.83 6,012.82 3,073.85 3,115.88 3,805.28 12.00 106.48 6,003,798.44 501,771.60 9,010.00 85.43 143.99 6,013.58 3,065,85 3,121.82 3,808.95 12.00 105.96 6,003,790.44 501,777.54 11 9,100.00 85.51 133.16 6,020.72 2,998.68 3,181.10 3,848.82 12.00 -90.00 6,003,723.27 501,836.80 9,200.00 85.79 121.12 6,028.34 2,938.59 3,260.44 3,909.90 12.00 -89.14 6,003,663.17 501,916.12 9,285.00 86.17 110.91 6,034.32 , 2,901.45 3,336.53 3,973.79 12.00 -88.22 6,003,626.02 501,992.20 TD 12/12/2011 1:48:53PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates Ird' ConocoPhillips Planning Report BAKaska E ES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-34 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: D141 @ 63.91ft(D141(36.4+27.51)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-34 Survey Calculation Method: Minimum Curvature Wellbore: 3H-34L1-02 Design: 3H-34L1-02_wp04 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +El-W Northing Easting -Shape (°) (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3H-34AL2_A3_T5(copy 0.00 0.00 6,008.00 3,157.04 3,008.49 6,003,881.64 501,664.24 70°25'18.621 N 149°59'11.188 W -plan misses target center by 18.02ft at 8864.71ft MD(6008.04 TVD,3169.83 N,3021.17 E) -Point 3H-34AL2_A3_T3(copy 0.00 0.00 5,997.00 3,544.99 2,562.39 6,004,269.64 501,218.25 70°25'22.438 N 149°59'24.267 W -plan misses target center by 26.25ft at 8237.24ft MD(5997.16 TVD,3570.71 N,2567.65 E) -Point 3H-34AL2_A3_T4(copy0.00 0.00 6 003.00 3 452.02 2 764.42 6 004 176.64 501 420.25 70°25'21.523 N 149°59'18.342 W , -plan misses target center by 28.25ft at 8475.14ft MD(6001.65 TVD,3473.90 N,2782.24 E) -Point 3H-34 CTD Polygon(col 0.00 0.00 0.00 3,796.95 2,179.32 6,004,521.64 500,835.26 70°25'24.917 N 149°59'35.500 W -plan misses target center by 5999.35ft at 7900.00ft MD(5992.27 TVD,3512.50 N,2242.58 E) -Polygon Point 1 0.00 3,796.95 2,179.32 6,004,521.64 500,835.26 Point2 0.00 3,852.01 2,404.33 6,004,576.65 501,060.26 Point 3 0.00 3,048.19 3,547.63 6,003,772.71 502,203.30 Point 4 0.00 2,510.11 3,411.74 6,003,234.71 502,067.33 / Points 0.00 3,449.98 2,451.43 6,004,174.66 501,107.28 `✓ Point6 0.00 2,897.85 2,131.52 6,003,622.64 500,787.31 Point7 0.00 3,143.80 1,804.43 6,003,868.62 500,460.29 3H-34AL2_A3_T1(copy 0.00 0.00 6,005.00 3,162.86 1,975.40 6,003,887.65 500,631.25 70°25'18.681 N 149°59'41.485 W -plan misses target center by 16.89ft at 7451.53ft MD(6011.95 TVD,3156.56 N,1989.44 E) -Point 3H-34AL2_A3_T6(copy 0.00 0.00 6,011.00 3,071.04 3,055.51 6,003,795.64 501,711.24 70°25'17.775 N 149°59'9.810 W -plan misses target center by 48.51ft at 8960.82ft MD(6010.36 TVD,3104.05 N,3091.05 E) -Point 3H-34AL2_A3_T7(copy 0.00 0.00 6,034.00 2,886.07 3,321.56 6,003,610.64 501,977.23 70°25'15.954 N 149°59'2.010 W -plan misses target center by 19.84ft at 9278.28ft MD(6033.87 TVD,2903.89 N,3330.29 E) -Point 3H-34AL2_A3_T2(copy 0.00 0.00 5,992.00 3,500.94 2,248.37 6,004,225.64 500,904.26 70°25'22.005 N 149°59'33.477 W -plan misses target center by 12.94ft at 7898.07ft MD(5992.25 TVD,3511.52 N,2240.92 E) -Point 3H-34 CTD Faultl(copy 0.00 0.00 6,015.00 2,931.92 2,458.48 6,003,656.65 501,114.24 70°25'16.409 N 149°59'27.320 W -plan misses target center by 519.84ft at 7460.00ft MD(6010.37 TVD,3163.93 N,1993.30 E) -Polygon Point 1 6,015.00 2,931.92 2,458.48 6,003,656.65 501,114.24 Point2 6,015.00 3,453.04 2,762.39 6,004,177.66 501,418.21 Point 3 6,015.00 3,706.11 2,928.35 6,004,430.68 501,584.20 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") P.) 3,977.40 3,454.11 10 3/4" 10-3/4 13-1/2 6,890.90 5,882.95 7 5/8" 7-5/8 9-7/8 7,062.00 5,988.36 4-1/2" 4-1/2 5-3/4 9,285.00 6,034.32 2-3/8" 2-3/8 3 12/12/2011 1:48:53PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates Irri' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3H-34 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: D141 @ 63.91ft(D141(36.4+27.51)) Site: Kuparuk 3H Pad North Reference: True Well: 3H-34 Survey Calculation Method: Minimum Curvature Wellbore: 3H-34L1-02 Design: 3 H-34 L 1-02_w p 04 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,380.00 6,019.32 3,093.61 1,956.42 TIP/KOP 7,460.00 6,010.37 3,163.93 1,993.30 2 7,540.00 5,997.64 3,236.40 2,024.47 3 7,620.00 5,992.30 3,310.06 2,054.96 4 7,820.00 5,991.72 3,466.46 2,177.27 5 8,120.00 5,995.43 3,576.92 2,450.88 6 8,320.00 5,997.72 3,549.27 2,647.47 7 8,460.00 6,001.01 3,483.12 2,770.24 8 8,685.00 6,006.80 3,312.12 2,913.14 9 8,885.00 6,008.17 3,156.58 3,036.53 10 9,010.00 6,013.58 3,065.85 3,121.82 11 9,285.00 6,034.32 2,901.45 3,336.53 TD 11 12/12/2011 1:48:53PM Page 5 COMPASS 2003.16 Build 69 I I I I I • d I I I IR I 111 0 . 4 0 o e M 8 8 O N .6. 0 '7; z o= Atv .+.� Y_ ei I Fob 8 cJ�]] --- - = ,, s N C V O Z O `_/,-.1 x m Mil cr, x MA o 21,r s‘ , e i \ N / O to O O . 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ConocoPhillips Travelling Cylinder Report BAKERHi GHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3H-34 Project: Kuparuk River Unit TVD Reference: D141 @ 63.91ft(D141(36.4+27.51)) Reference Site: Kuparuk 3H Pad MD Reference: D141 @ 63.91ft(D141(36.4+27.51)) Site Error: 0.00ft North Reference: True Reference Well: 3H-34 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3H-34L1-02 Database: EDM Alaska Prod v16 Reference Design: 3H-34L1-02_wp04 Offset TVD Reference: Offset Datum Reference 3H-34L1-02_wp04 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,380.00 to 9,285.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,125.75ft Error Surface: Elliptical Conic Survey Tool Program Date 12/9/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 109.00 632.00 3H-34 Gyro(3H-34) CB-GYRO-SS Camera based gyro single shot 684.06 3,944.95 3H-34 MWD R200(3H-34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,019.06 6,856.36 3H-34 MWD R400(3H-34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,923.04 7,018.38 3H-34 MWD R500(3H-34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,018.38 7,380.00 3H-34L1_wp08(3H-34L1) MWD MWD-Standard 7,380.00 9,285.00 3H-34L1-02_wp04(3H-34L1-02) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,977.40 3,518.02 10 3/4" 10-3/4 13-1/2 6,890.90 5,946.86 7 5/8" 7-5/8 9-7/8 7,062.00 6,052.27 4-1/2" 4-1/2 5-3/4 9,285.00 6,098.23 2-3/8" 2-3/8 3 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/9/2011 4:38:49PM Page 2 of 18 COMPASS 2003.16 Build 69 1,, ConocoPhillips or its affiliates It1P.- COIIOCOPhIIhIpS Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3H-34 Project: Kuparuk River Unit TVD Reference: D141 @ 63.91ft(D141(36.4+27.51)) Reference Site: Kuparuk 3H Pad MD Reference: D141 @ 63.91ft(D141(36.4+27.51)) Site Error: 0.00ft North Reference: True Reference Well: 3H-34 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3H-34L1-02 Database: EDM Alaska Prod v16 Reference Design: 3H-34L1-02_wp04 Offset TVD Reference: Offset Datum 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 3H Pad . 3H-14-3H-14-3H-14 9,285.00 7,800.00 291.75 :9.58 103.81 Pass-Major Risk 3H-14-3H-14A-3H-14A 9,268.15 7,709.00 369.63 207.48 190.37 Pass-Major Risk 3H-14-3H-14APB1-3H-14APB1 9,281.53 7,775.00 :.0 209.63 129.73 Pass-Major Risk 3H-14-3H-14B-31-I-14B 9,285.00 7,025.00 1,121.64 191.96 968.80 Pass-Major Risk 3H-14-3H-14BL1-3H-14BL1 9,285.00 7,025.00 1,121.64 191.96 968.80 Pass-Major Risk 3H-14-3H-14BL2-3H-14BL2 9,285.00 7,025.00 1,121.64 191.96 968.80 Pass-Major Risk 3H-14-3H-14BL3-3H-14BL3 9,285.00 7,025.00 1,121.64 191.96 968.80 Pass-Major Risk 3H-14-3H-14BL4-3H-14BL4 9,285.00 7,025.00 1,121.64 191.96 968.80 Pass-Major Risk 3H-17-3H-17-3H-17 Out of range 3H-19-3H-19-3H-19 Out of range 3H-20-3H-20-3H-20 8,236.67 7,725.00 898.69 183.44 719.83 Pass-Major Risk 3H-21-3H-21-3H-21 Out of range 3H-22-3H-22-3H-22 Out of range 3H-24-3H-24-3H-24 Out of range 3H-31-3H-31-3H-31 Out of range 3H-33-3H-33-3H-33 Out of range 3H-33-3H-33A-3H-33A Out of range 3H-33-3H-33AL1-3H-33AL1 Out of range 3H-33-3H-33AL1PB1-3H-33AL1 PB1 Out of range 3H-33-3H-33AL2-3H-33AL2 Out of range 3H-33-3H-33AL2-01-3H-33AL2-01 Out of range 3H-34-3H-34L1-3H-34L1_wp08 7,399.98 7,400.00 0.59 0.81 -0.06 FAIL-Minor 1/10 3H-34-3H-34L1-01-3H-34L1-01_wp06 7,399.98 7,400.00 0.59 0.81 -0.06 FAIL-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/9/2011 4:38:49PM Page 3 of 18 COMPASS 2003.16 Build 69 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTKO( A WELL NAME PTD# 21 I /6 17 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 1et -- '« L' ���POOL: / /C%`e 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 wellllbiare segm/cnt of existing well ( / (If last two digits in Permit No. 24/C'Z ,API No. 50-/L) 3- �k , / CL , . API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to 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 o r a CO 3I0 m o Cn 3 O - *t I- 0 3 G) m 0 _ N 3 N w m N O N CC N CA O O 0 N v O 0 0 O /7J N p Fir O CD 0:, N CO w O.) w w CO w w w w N N N N N.) N N N fes) N.) CO 0D V 0) 01 A CO N O n CO CO V 0) 01 A w N - 0 CO 0D V 0) 01 A w N - 0 CO OD 0) 01 A w N - 0 V 17 m CD C) 0) Cn O m K N * O CO W o 4 D =. 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