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'Attn:Ricky Elgaricio ATO 3-344 '700 G Street SCANNED JUN 2 5 2015 Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. 1 1 I 1I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson 3 Chevron/KRU Rep 1 1 1 'Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4 IState of Alaska -AOGCC 1 1 2 I I Attn:Makana Bender 333 W.7th Ave,Suite 100 !Anchorage,Alaska 99501 5 jDNR-Division of Oil&Gas *** 1 Attn:Sean Clifton 1550 West 7th Avenue,Suite 802 ,Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 3 4 4 0 0 TOTALS FOR ALL PAGES: 0 3 4 4 0 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. 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Date: 3/51/ /s/ '/ '• Project Proofing BY: Date: & E. / /s/ 14413 Scanning Preparation x 30 = 3 0 + 1 e = TOTAL PAGES (Count does not include cover s eet) BY: Maria Date: / /s/ 11 Production Scanning Stage 1 Page Count from Scanned File: 1+7 (Count does include cover et) Page Count Matches Number in Scanning Preparation: YES I /NO BY: Date: 31S1 / /4 /s/t/�/ ID Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o II 1 rn m d 09 J J E 0 . N a) Z 1 0 m in ce 0 i M47) — 4: c CD CD O U U r.-'. y ' N y L o } m 0 0 2 a 2 Co °? 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INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2K-22A;2K-22AL1;2K-22AL1-01 RUN NUMBER (mandatory FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska _ PAGE OF (mandator/ LOG DATE: 3/11/2011 TODAYS DATE: 9/1/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatorv! 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 #OFPRINTS #UF-PHIN I5 #OF COPIES #OF COPIES 'CJ" 1 ConocoPhillips Alaska,Inc. I 1 I I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I 1 I 1 I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP I 1 1 I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 I 1 I I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 1 I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 ` '��� Letter of Transmittal ttalNt.,„FANt*S!, ceo Date: ���• BAKERNoventifit 11 11 HUGHES `v � To: From: Christine Mahnken Carl Ulrich/Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue rh An e coag , Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2K-22A ...V,- 0 -22AL1 2.1t—1 o?, 2K-22AL1-I 2-.►t.koei (3) total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes, Project Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich@BakerHughes.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Class: 20AAC 25.105 Q20AAC 25.110 Development EExploratory CI GINJ ❑ WINJ CI WAG CI WDSPL El No.of Completions: Nr' Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12-1/a Ilk 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: November,,2011 211-103/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 November 4,2011 50-103-20119-60 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 294'FNL,94'FEL,Sec. 11,T1ON,RO8E,UM November 8,2011 2K-22AL1 Top of Productive Horizon: 8. KB(ft above MSL): 154'RKB 15.Field/Pool(s): 985'FSL, 1559'FEL,Sec. 14,T1ON, R8E, UM GL(ft above MSL): 40'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 817'FSL, 1572'FEL,Sec. 14,T1ON,R8E,UM 10729'MD/6390'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-498310 y- 5938010 Zone-4 12605'MD/6382'ND ADL 25588,25605 TPI: x-496850 y- 5928730 Zone-4 11,SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-496837 y- 5928562 Zone-4 nipple @ 499'MD/499'ND 2674,2679 18.Directional Survey: Yes ENo❑ 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) 1400'MD/1380'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 9577'MD/6378'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 35' 115' 35' 115' 24" 170 sx ASI I 9.625" 36# J-55 35' 3760' 35' 2928' 12.25" 1300 sx ASIII,450 sx Class G 7" 26# J-55 30' 9796' 30' 6470' 8.5" 300 sx Class G 2.375" 4.7# L-80 10729'✓ 12605' ✓ 6390' 6382' 3" slotted liner 24.Open to production or injection? Yes a No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 9194' 9034'MD/6116'ND and 9199'MD/6211'ND alternating solid/slotted from 10741'-12604'MD 6390'-6382'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. W . .,. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Cosi'!PLL , i 27. . ., PI a$ TION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) November 24,2011 water jet lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 12/10/2011 16 hours Test Period--> 233 83 20 100 Bean 461 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 205 psi not available 24-Hour Rate-> 312 144 29 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No O Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RE.CEIVED RBDMS DEC 1.6 2011 DEG i7 11 giC� meotu Qit&Gas C ;iso COOfomission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE AncrioNgaibmit original only 28. GEOLOGIC MARKERS(List all formations and market Juntered): 29. FORMATION TESTS NAME MD TVD Well tested? 0 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 1400' 1380' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A5 sand 12435' 6403' N/A Formation at total depth: Kuparuk A5 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: James Ohlinger @ 265-1102 Printed Na ,\ L a Title: CTD Engineering Supervisor Signature 1.(1k Phone 265-6306 Date /2//8fr Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 No.' KUP 2K-22AL1 C011000P�li��i +�� Well Attributes Max Angle&MD TD • • AlaskaWellbore APINWI Field Name Well Status Incl(°) MD(RKB) Act Btm(RKB) 501032011960 KUPARUK RIVER UNIT PROD 97.87 12,350.36 12,605.0 Comment H2S(ppm) Date Annotation End Date KB-G d(ft) Rig Release Date 1 •— Welt Well Confip..-2K-22AL112/120118'.59'.20 AM 60 1/17/2010 Last WO: 4/30/2009 39.99 12/3/1989 Schematic-Actual Annotation Depth(MB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,654.0 9/10/2011 Rev Reason:ADD SIDETRACKS ninam 12/1/2011_ 41 Casing Casing Strings HANGER,31 4 alp Casing Description String 0... String ID...Top(SKS) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd �i LINER ALA 23/8 1.992 10,729.8 12,605.0 4.70 L-80 STL Liner Details Top Depth (TVD) Top Incl Nomi... MI Top(R1613) (RKB) (°) Item Description Comment ID(In) 10,729.8 6,390.5 93.21 BILLET LINER TOP BILLET/ANCHOR 1.992 CON DUCTO115 R, 10,986.2 6,386.3 90.52 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.992 35- NIPPLE.499 a Perforations&Slots Shot III. Top(TVD) Btm(TVD) Dens Top(RKB)Btm(RKB) (RKB) (RKB) Zone Dote (sh.,. Type Comment GAS LIFT, 10,741 10,971 6,389.8 6,386.5 A-4,2K-22 11/9/2011 32.0 SLOTS Alternating solid/slotted pipe- 2.880 0.125"x2.5"@ 4 circumferential _rl, adjacent rows,3"centers staggered (n� 18 deg,3'non-slotted ends !I 10,987' 12,605 6,386.3 6,382.0 11/9/2011 '32.0 SLOTS SURFACE, I l 35-3,760 rj GAS LIFT. 5,007 Ell GAS LIFT. _ e.- 6.684 _6.684 MI IIIII GASLIFT, 8,079 GAS LIFT, 8.904 SLEEVE-C. . , 8,965 SEAL ASSY. 9,017 PBR,9.020 [ PACKER,9,034 f�a...... NIPPLE.9,141 3 SEAL ASSY, 9,Y. 6J PBR,9,185 PACKER.9.199 -€..aaaaaa>� MI NIPPLE.9,242 TOG HOLES. 9.258 (PERF, = i 7 i 9,258-9,260 _g8g ___ WLEG,9.275- 8 APERFal, RRR ■ 6.348-9,358 APERF, II 111 9,430-9,450 APERF, 9,462-9,488 FISH,9,481 .111 WHIPSTOCK, Mandrel Details 9.500 Top Depth Top Port CEMENT, )TVD) Incl OD Valve Latch Size TRO Run 9'2N PRODUCTION. ^ Stn Top RKB (WI EN (°) Make Model (In) Sery Type Type (in) (psi) Run Date Com... 30-8.7 1 2,883.9 2,404.0 54.63 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,318.0 11/18/2011 12:30 SLOTS. 10,741-10,971 2 5,007.3 3,699.6 52.22 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,299.0 11/18/2011 3:00 LINER A. 9,575-11,694 3 6,684.1 4,709.7 53.75 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,281.0 11/18/2011 9:30 4 8,078.8 5,544.2 52.75 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,263.0 11/18/2011 5:00 5 8,904.0 6,039.3 53.18 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 11/18/2011 11:30 SLOTS. 10,987-12,605 LINER AL1, 10,730-12,605 TD(2K-22AL1), 12,605 2K-22 Proposed CTD Sidetrack Revised: 16-Nov-11 3-1/2"Camco DS nipple at 499'RKB ID=2.875" ■ 3-1/2"9 3#L-80 EUE 8rd Tubing to surface 16"62#H-40 shoe @115'RKB 3-1/2"Camco MMG gas lift mandrels at 2884',5007',6684', 8079',8904'RKB a 9-5/8"36#J-55 surface casing at 3760'RKB =_ Baker'CMU'Sliding Sleeve(2.813'ID)at 8965'RKB ME 80-40 seal assembly at 9017' IBaker 3-1/2"PBR at 9020'RKB(2.92"ID) Baker FHL packer at 9033'RKB(4.0"ID) - NNW- Camco D landing nipple at 9141'RKB -ID=2.75" -WII mill out to 2.80"pre-CTD �� 80-40 seal assembly at 9182'-9194' � Baker 3-1/2"PBR at 9185'RKB(3"ID) Baker FHL packer at 9199'RKB(2.992"ID) Camco D landing nipple at 9242'RKB Tubing Tail perfs at 9260'MD — -ID=2.75" �— 4{ r' 1 ;r. -Will mill out to 2.80"pre-CTD - �'„1, v ? 3-1/2"tubing tail at 9275'MD - G' C-sand perfs(sgz'd) _ a 9346'-9358'MD 11 �'�=+_; Top of Whipstock @ 9500'MD 2K-22AL1-01 TD=11,958' A-sand perfs(sgz'd) __ 2/ liner 9,245'-11,958' 9430'-9450'MD - 9462'-9466'MD . 9507'-9547'MD {�a4fi .- SS"�F ti', � : � , _ 2K-22A __ • 2 K-22AL 1 TD=11,694' :4,.,t,>,a .{ TD=12,605' 2'/."finer 9,577'-11,694' :::',,';'.7i� 2'R'liner 10,730'-12,605' 7"26#J-55 casing atmatrstP -f ' c :•'gX.TA 9796'MD k�5it F, t 0 • W al z `Wo mp Iz m CS C t C 0 0. 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ONO O oO. faO) ' ; my dZ N N N N N N N N 'Cl"to) ° o3m c� an33o U) 2K-22 Pre-Rig Operations DATE SUMMARY 8/23/11 PRE RWO--MITOA(PASSED) 8/31/11 DRIFT TBG TO 2.74"TO JET PUMP @ 8936' SLM. IN PROGRESS. 9/1/11 PULLED 2.812" CA LOCK AND JET PUMP (S#= PH-1022) @ 8964' RKB. PUMPED 235 BBLS DIESEL DOWN IA AND 25 BBLS DOWN TBG FOR FREEZE PROTECT. CLOSED CMU @ 8964' RKB, CONFIRMED CLOSED. COMPLETE. 9/8/11 MILL OUT D NIPPLES @ 9141 RKB/9242 RKB, RAN 2.78" CENTRALIZER ABOVE MOTOR, 1ST NIPPLE TOOK 2HRS, 2ND NIPPLE TOOK 5.5HRS WITH SAME MILL, IN PROGRESS 9/9/11 FCO TO 9625' CTMD, READY FOR SLICKLINE, IN PROGRESS 9/10/11 TAGGED @ 9654' SLM, EST. 9658' RKB. MEASURED BHP @ 9446' RKB: 3359 PSI. READY FOR E/L. 9/12/11 LOG MIT-24 ARM CALIPER FROM 9600'TO 9200'. PERFORATE TUBING TAIL FROM 9258'-9260' USING A 2" OD 2'6SPF GUN 60DEG PHASING 12 TOTAL SHOTS HMX BIG HOLE CHARGES. READY FOR COIL. 10/4/11 CTU-4 COIL HAS MILLION+ RUNNING FEET ON IT. DECIDED TO SWAP REELS PRIOR TO CEMENT SQ JOB. RU COIL TO BLOW DOWN COIL TO TANKS FOR REEL SWAP. 10/8/11 RAN BAKER NIPPLE LOCATOR TO TIE INTO D NIPPLES @ 9241' &9140' RKB, LOCATED BOTH NIPPLES FLAGED PIPE &CORRECTED TO RKB. TAG @ 9721' RKB, PAINT FLAG 5' OF BTM. OPENED CMU WITH NIPPLE LOCATOR WHILE POOH. RAN B SHIFTING TOOL&CLOSED CMU. BLED DOWN IA TO CONFIRM CLOSED, IN PROGRESS. 10/9/11 LOAD WELL WITH HEATED SEAWATER. LAY IN 25 BBLS OF 16.5 PPG CEMENT FROM TD OF 9716'TO 8700'. SQZ—3 TO 4 BBLS INTO THE PERFS. OBTAIN 1700 PSI SQZ PRESSURE. LAUNCH BALL AND CLEAN TO CEMENT TOP OF 9260' RKB. READY FOR SLICKLINE TAG AFTER 72 HOUR CURE TIME. JOB COMPLETE. 10/13/11 TESTED CEMENT PLUG TO 2000 PSI: LINEAR LOSS OF 300 PSI IN 30 MIN. TAGGED CEMENT @ 9200' SLM. GAUGED TBG TO 2.84"TO CMU @ 8965' RKB, 8942' SLM. RE-TESTED 10/16: INITIAL: 2000 PSI. AFTER 15 MIN, 1930 PSI;AFTER 30 MIN, 1870 PSI. ConocoPhiIIips Time Log & Summary We/Niew Web Reporting Report Well Name: 2K-22 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 10/25/2011 11:00:00 PM Rig Release: 11/15/2011 6:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10/25/2011 24 hr Summary Move Rig from 2L to 2K-22,Spot on well, Rig up. 06:00 16:00 10.00 0 0 MIRU MOVE MOB P Rig released from 2L-307 travel to 2K-22 16:00 23:00 7.00 0 0 MIRU MOVE MOB P Rig on 2K, Remove Jeeps,Spot on well,Start R/U 23:00 00:00 1.00 0 0 MIRU WHDBO NUND P ****RIG ACCEPT***** 23:00 Hrs PJSM, Nipple up stack 10/26/2011 Complete BOPE Test,Cut 597'of coil for fatigue Mgmt, Perform slack Mgmt, cut 43'rehead CTC/UQC 00:00 03:30 3.50 0 0 MIRU WHDBO NUND P Nipple up stack continued,Align stack and secure,M/U MP Line, transducers. Reconfigure riser 03:30 06:30 3.00 0 0 MIRU WHDBO BOPE P Start BOPE Test Completed up to test#8 06:30 11:30 5.00 0 0 MIRU WHDBO BOPE P Crew change PJSM-BOPE test, 250/4500 psi.Annular 250/2500psi. One failure R-3.greased&passed. 11:30 12:30 1.00 0 0 MIRU WELLPF MPSP P Clean up rig floor and do valve check list. Pressure test tiger tank line. 12:30 14:00 1.50 0 0 MIRU WELLPF MPSP P Rig up&pressure test lubricator and pull BPV est. 1000psi below. 1140 psi below plug. Rig down BPV lubricator. 14:00 15:00 1.00 0 0 MIRU WELLPF SFTY P Pre-spud meeting with Maddy's crew. 15:00 17:00 2.00 0 0 SURPRI WELLPF CTOP P Start cutting 600ft of Coil for fatigue mgmt 17:00 18:00 1.00 0 0 SURPRI WELLPF CTOP P M/U external coil connector in preperation for slack MGMT 18:00 21:00 3.00 0 0 SURPRI WELLPF CTOP P Crew change, reposition stack and secure to stab on injector,fill coil and test inner reel valve and pack off. Bleed off stack,get gas alarm from cellar and evacuate rig 21:00 21:30 0.50 0 0 SURPRI WELLPF CTOP P Evacuate rig to muster area,call pad operator to sniff cellar. Pad operator gives all clear, resume ops 21:30 00:00 2.50 0 0 SURPRI WELCTI CTOP P perform slack mgmt,cut 43'to find wire.cut total of 640',M/U and pull test CTC to 35K.Test wire and head up upper quick connect 10/27/2011 M/U BHA#1, Mill pilot hole to 9530 00:00 00:45 0.75 0 0 SURPRI WELLPF CTOP P Pressure test CTC to 4K 00:45 02:00 1.25 0 0 SURPRI WELLPF CTOP P Pressure test PDL's and TT line to 2.5K Page 1 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 02:30 0.50 0 0 SURPRI WELLPF SFTY P Pre Spud with night(Gary's)crew 02:30 03:15 0.75 0 0 SURPRI WELLPF CTOP P Install night cap and attempt to bleed well to Tiger tank, Initial WHP=1055 Bled immediatly to zero. Shut in and watch for pressure build, No build up 03:15 04:45 1.50 0 62 PROD1 WHPST PULD P PJSM, P/U BHA#1, .5 degree motor, D331 mill with slick gauge to mill pilot hole in cement 04:45 07:45 3.00 62 9,237 PROD1 WHPST TRIP P RIH, EDC Open, Pumping 1 BPM. 9175' Tie in+11 ft correction.Start pumping 2#Bio around taking gasy returns to tiger tank. Blled down IA from 900psi to 340psi. 07:45 09:45 2.00 9,237 9,281 PROD1 WHPST MILL P Tag Soft Cement @ 9237'-Start milling-1.50 bpm,2890psi, BHP 3500,WOB.02K, ROP 60 fpm. Harder Cement from 9253'-1.50 bpm,3200,BHP 3480,WOB 1.7K, ROP 30. 9266'Good cement returns to surface. 09:45 14:00 4.25 9,281 9,349 PROD1 WHPST MILL P Two light stalls on bottom-possible contact with the 7"casing @ 9281' Rolled the BHA to 340 ROHS for 6ft to get past transition area then back to 10 ROHS @ 9288'. ROP 20 fph. Good cement returns to surface. 14:00 16:00 2.00 9,349 9,382 PROD1 WHPST MILL P ROP dropped to 2fph. P/U and tried again,rolled TF to 335 ROHS. Making good ROP again 20 fph @ 9350'Roll back to 10 ROHS.Good cement returns to surface. 16:00 16:15 0.25 9,382 9,382 PROD1 WHPST WPRT P Annular pressure spiked up-pull a wiper to TOC to clean up tubing. P/U weight 37K. 16:15 19:21 3.10 9,382 9,462 PROD1 WHPST MILL P Milling ahead-1.50 bpm,3300, BHP 3560, ROP 25,WOB 1.8K. 19:21 19:57 0.60 9,462 9,426 PROD1 WHPST WPRT P Pull wiper trip, High annular pressure, Blow down choke, PUW=39K 19:57 21:57 2.00 9,426 9,509 PROD1 WHPST MILL P 9426',Mill Ahead, 1.51 BPM @ 2930 PSI FS, BHP=3580 21:57 22:27 0.50 9,509 9,509 PROD1 WHPST WPRT P Stall and pull heavy, PUW=48K, Pull Mini Wiper 22:27 23:21 0.90 9,509 9,530 PROD1 WHPST MILL P Mill Ahead, 1.51 BPM @ 2940 PSI FS, BHP=3590 23:21 23:51 0.50 9,530 9,212 PROD1 WHPST WPRT P 9530',TD,Wiper up to 9212, circulate Bottoms up, PUW=39K 23:51 00:00 0.15 9,212 9,460 PROD1 WHPST WPRT P RIH for dry drift, RIW=14.3K Midnight 9460' 10/28/2011 Complete dummy whipstock run,Set whipstock, RIH to mill window 00:00 00:42 0.70 9,460 9,530 PROD1 WHPST WPRT P Continue dry drift to TD, Looks good, no bobbles, PUH above set depth bring pumps online. Pump Lo-Hi vis sweeps 00:42 03:12 2.50 9,460 64 PROD1 WHPST TRIP P Trip out chasing sweeps, PUW=41K Page 2 of 15 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 03:12 04:27 1.25 64 71 PROD1 WHPST PULD P PJSM,Tag up and flow check well, No Flow, Pull BHA#1, Mill 2.81 Go, 2.80 No-Go, M/U BHA#2 Dummy whipstock 04:27 07:27 3.00 71 9,530 PROD1 WHPST TRIP P Trip in with Dummy Whipstock, BHA#2.Tie in+9 ft correction.Clean drift down to 9530' 07:27 09:27 2.00 9,530 70 PROD1 WHPST TRIP P POOH with dummy WS BHA 09:27 10:27 1.00 70 72 PROD1 WHPST PULD P Lay down BHA#2/P/U BHA#3 with a 3 1/2 Monobore WS 10:27 14:27 4.00 72 9,510 PROD1 WHPST TRIP P Rlh with EDC open pumping.3 bpm. Slow speed from 60 fpm to 20 fpm from 9100'to setting depth.Tie in +10, P/U weight 39K. 14:27 14:57 0.50 9,510 9,510 PROD1 WHPST OTHR P TOWS=9500', HS-Close EDC, WOB 0,CT weight 14K. Pressure up to 4500 psi,set WS.WOB 2.5K. _ Stop pumping.Set down 2K. 14:57 17:21 2.40 9,510 72 PROD1 WHPST TRIP P P/U weight-42K,Start pumping 15ft off bottom-POOH. 17:21 19:21 2.00 72 73 PROD1 WHPST PULD P PJSM, Flow check well. Pull BHA#3 Whipstock setting BHA,M/U window milling BHA#4 with.6 degree motor, dimond string and window mill, Surface test tool 19:21 21:45 2.40 73 9,180 PROD1 WHPST TRIP P Trip in well, EDC Open, .5BPM 21:45 21:57 0.20 9,180 9,210 PROD1 WHPST DLOG P Log tie in for+10',Close EDC,Wt Check PUW=39K, 21:57 22:15 0.30 9,210 9,501 PROD1 WHPST TRIP P Trip in to dry tag Whipstock,Set down @ 9500.5, PUH bring on pumps to 1.5 BPM @ 3500 PSI FS, BHP=3608, RBIH to start milling window 22:15 00:00 1.75 9,500 9,500 PROD1 WHPST MILL P 9499.7 Stall,stalled multiple time, Keep working, Reduce pump rate 10/29/2011 Milled window and rathole,Trip for build BHA 00:00 00:24 0.40 9,500 9,500 PROD1 WHPST MILL P Stalling,still working at getting started on tray.Try different pumpe rates and speeds,Add 776 lube. Consider swapping to Flo Pro 00:24 02:24 2.00 9,500 9,501 PROD1 WHPST MILL P Get started on tray, call pinch point 9499.7 start time milling per procedure 02:24 03:24 1.00 9,501 9,501 PROD1 WHPST MILL P Time milling,good metal on magnets 1.33 BPM @ 3000 PSI FS,Started taking 15 Minute straps we appear to have slight fluid loss BHP=3555 03:24 06:54 3.50 9,501 9,503 PROD1 WHPST MILL P Limiting ROP due to WOB—3.2K, No fluid losses in pits,Good metal on magnets Page 3 of 15 Time Logs . Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:54 07:06 0.20 9,503 9,503 PROD1 WHPST MILL P Hung at 9503.4,went to 3.5K WOB with no change in CT pressure. Back ream 1 fpm attemt to clear BHA, PUW=33K, 1.34 BPM @ 2910 PSI FS, RIW=14K 07:06 12:33 5.45 9,503 9,521 PROD1 WHPST MILL P 9503.4 Set down with little differential.saw motor work @ 9501. Continue milling. 1.35 bpm,2950, BHP 3530,WOB 2.5K 12:33 13:33 1.00 9,521 9,521 PROD1 WHPST REAM P 9521.TD Window. Begin back-reaming passes(33K P/U WGT).See a little motor work @ 9501 and 9504, pull up into WS face to 4'below window and make 3 up/down backreaming passes to clean up window per procedure. 13:33 13:39 0.10 9,494 9,515 PROD1 WHPST OTHR P Down on pump, PUH to 9494 and RIH to 9515 for dry drift.Clean drift. _ Current TOW 9499.7'BOW 9504.3' 13:39 17:09 3.50 9,515 71 PROD1 WHPST TRIP P Begin pulling OOH following MPD tripping schedule. 17:09 19:09 2.00 71 0 PROD1 WHPST PULD P No-flow test-had flow. Undeply BHA #4 19:09 21:24 2.25 0 62 PROD1 DRILL PULD P Deploy build section BHA#5,2.2 degree motor and Bi Center, M/U Coil track,surface test tool,set counters 21:24 23:54 2.50 62 9,170 PROD1 DRILL TRIP P Trip in well, EDC closed(2.2 degree motor)min rate on pump 23:54 00:00 0.10 9,170 9,194 PROD1 DRILL DLOG P Gamma tie in for+10'correction, PUW=31.5K 10/30/2011 Complete Build/Turn @ 9920'. Bump open sliding sleeve on trip out, RI and shut sleeve.M/U RSM 00:00 00:18 0.30 9,194 9,521 PROD1 DRILL TRIP P Trip in through window, Clean pass, Tag bottom @ 9521',PUW=34.5. Pull up above window,Open EDC swap well to 9.3 Flo Pro 00:18 01:12 0.90 9,521 9,223 PROD1 DRILL CIRC P Pull above TOC,Open EDC, Circulate well to Flow Pro 01:12 01:30 0.30 9,223 9,521 PROD1 DRILL TRIP P Shut down pump,Shut EDC,Trip in to Drill 01:30 03:45 2.25 9,521 9,670 PROD1 DRILL DRLG P 9521', Drill Ahead, 1.44 BPM @ 2950 PSI FS, BHP=3859 03:45 04:03 0.30 9,670 9,180 PROD1 DRILL WPRT P Wiper to window, Pull up above window to log gamma tie in and tie in RA marker on whipstock 04:03 04:15 0.20 9,180 9,207 PROD1 DRILL DLOG P Log Gamma tie in for no correction 04:15 04:27 0.20 9,207 9,525 PROD1 DRILL TRIP P trip in to log RA 04:27 04:33 0.10 9,525 9,535 PROD1 DRILL DLOG P Log RA Marker @ 9507',TOW=9500 04:33 04:39 0.10 9,535 9,670 PROD1 DRILL WPRT P Wipe back to bottom to drill 04:39 06:39 2.00 9,670 9,820 PROD1 DRILL DRLG P 9670', Drill Ahead, 1.45 BPM @ 2660PSI FS, BHP=3829, Increase WHP to 200 psi slight 4-5 bbls influx on last wiper trip. Page 4 of 15 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:39 07:09 0.50 9,820 9,820 PROD1 DRILL WPRT P Wiper trip-P/U weight 33K. Nice A-4 sands with heavy oil saturated cutting over shakers. 07:09 09:09 2.00 9,820 9,920 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3030, BHP 3870,WHP 220, ECD 12, ROP 120, WOB 1.6K,CT weight 14.5K. 1:1 returns while drilling.TD build section.Average 41.6. 09:09 12:09 3.00 9,920 8,970 PROD1 DRILL TRIP P Wiper&trip to surface.Open EDC- POOH. 8954'Weigth increased from 33 to 41K. Had an over pull at sliding sleeve. Rate out dropped IA jumped up from 400 to 1500 psi,. RIh slowly- try to close it,no luck. POOH holding MPD. IA stay steady at 1520 psi. Did not bleed it down. 12:09 15:09 3.00 72 61 PROD1 DRILL PULD P PJSM-undeploying BHA&P/U 3.5" BO shifting tool with Agitator#001 that has 45 hours on it.Tested it at surface with air.Good test. 15:09 17:27 2.30 61 8,865 PROD1 DRILL TRIP T RIH 150 test the agitator with fluid. Open EDC-IA 1473. RIH following MPD. 17:27 17:57 0.50 8,950 8,965 PROD1 DRILL DHEQ T Close EDC,WHP 600, IA 1500 psi. P/U weight 32K. RIH 10 fpm. No-pumps, Noticed WOB @ 8950.74'Travel down to 8951'.WOB 1.2K.Sheared stock. WHP 700, BHP 3750, IA bled down to 400 psi.Good indication of closure. No drop in Annular or WHP. IA did not go over 550 psi. RIH 20 ft past SS. 17:57 20:57 3.00 8,965 60 PROD1 DRILL TRIP T P/U 100ft above-Open EDC-POOH for Drilling assembly. 20:57 00:00 3.05 60 68 PROD1 DRILL PULD P PJSM,At surface,Trap 800 PSI, IA=700, Pressure up WH to 900 PSI and watch IA. IA remained constant. Go back to 800 PSI WH, Begin PUD BHA#7, Shifting tool not sheared, PD BHA#8 RSM and Bi Center,M/U to Coil and surface test 10/31/2011 Drill A Lateral from 9920 to 10670 00:00 02:24 2.40 68 9,180 PROD1 DRILL TRIP P Trip In Hole, EDC Open 02:24 02:30 0.10 9,180 9,209 PROD1 DRILL DLOG P Log tie in for a+10'correction, Close EDC, PUW=29.5 02:30 03:06 0.60 9,209 9,920 PROD1 DRILL TRIP P RIH to drill,set down in bottom of window twice. First time at 20 FPM, PUH and roll pumps to move bit. Second time @ 30 FPM @ 9204'. PUH and roll pumps.Shut down pumps and run through with no bobble @ 30 FPM Page 5 of 15 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 03:06 07:18 4.20 9,920 10,060 PROD1 DRILL DRLG P 9920', Drill Ahead, 1.4 BPM @ 3070 PSI FS, BHP=3900,WHP=160. Slow ROP from 10,030 ft.7-10 fph. 07:18 07:48 0.50 10,060 10,070 PROD1 DRILL DRLG P Quick BHA P/U-Drilling ahead- 1.40 bpm,3100,WOB 2.2K, ROP 17, ECD 12, BHP 3865 07:48 08:54 1.10 10,070 10,070 PROD1 DRILL DLOG P MADD pass&wiper trip-P/U weight 32K. 08:54 10:30 1.60 10,070 10,220 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3200, BHP 3890, ECD 12,WHP 130, ROP 115 10:30 12:00 1.50 10,220 10,220 PROD1 DRILL WPRT P Wiper trip-P/U weight 33k-need to re-MADD pass one section due to inaccurate readings.(tool).Media curve not clean. 12:00 13:30 1.50 10,220 10,370 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3365, BHP 3904, ECD 12.1,WHP 110,WOB 2.1,Ct weight 13K. 13:30 15:30 2.00 10,370 10,370 PROD1 DRILL WPRT P Wiper trip-33K P/U weight.Tie in with+1ft correction. 15:30 19:30 4.00 10,370 10,520 PROD1 DRILL DRLG P Drilling ahead-possible ankerite. 1.40 bpm,3150, BHP 3875, ECD 12, ROP 6,WOB 2.5K,CT weight 13K. 19:30 21:00 1.50 10,520 10,520 PROD1 DRILL WPRT P Wipe to window, PUW=31.5K, NHP=3900,WHP=110 21:00 23:00 2.00 10,520 10,670 PROD1 DRILL DRLG P 10670', Drill Ahead, 1.4 BPM @ 3120 PSI FS, BHP=3895,WHP=110 23:00 00:00 1.00 10,670 9,840 PROD1 DRILL WPRT P Wipe to window, PUW=32K, BHP=3910 11/01/2011 Continue drilling Lateral from 10670 to 11360 00:00 00:30 0.50 9,840 10,670 PROD1 DRILL WPRT P Continue wiper trip 00:30 02:00 1.50 10,670 10,820 PROD1 DRILL DRLG P 10670'Drill Ahead, 1.44 BPM @ 3000 PSI FS, BHP=3905,WHP=80 02:00 03:00 1.00 10,820 9,525 PROD1 DRILL WPRT P Wiper trip to window with tie in, PUW=32.5K, BHP=3940,WHP=75 03:00 03:12 0.20 9,525 9,571 PROD1 DRILL DLOG P Log RA Marker for+3'correction 03:12 03:57 0.75 9,571 10,820 PROD1 DRILL WPRT P Continue wiper back to bottom 03:57 05:27 1.50 10,820 10,970 PROD1 DRILL DRLG P 10820', Drill Ahead, 1.4 BPM @ 3100 PSI FS, BHP=3930,WHP=75, RIW=15K 05:27 07:27 2.00 10,970 10,970 PROD1 DRILL WPRT P Wiper trip-P/U weight 32K 07:27 10:27 3.00 10,970 11,120 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3300, BHP 3933, ROP 20,WOB 2.5K,Ct weight 13. 10:27 12:27 2.00 11,120 11,120 PROD1 DRILL WPRT P Wiper to window, PUW=33K 12:27 19:57 7.50 11,120 11,270 PROD1 DRILL DRLG P 11120', Drill Ahead, 1.4 BPM @ 3090 PSI FS, BHP=3960,WHP=105 19:57 21:12 1.25 11,270 9,530 PROD1 DRILL WPRT P Wiper to window,32K PUW. Start mud swap. 21:12 21:24 0.20 9,530 9,570 PROD1 DRILL DLOG P Tie-in, +3' 21:24 22:12 0.80 9,570 11,270 PROD1 DRILL WPRT P Wiper back in hole 22:12 00:00 1.80 11,270 11,360 PROD1 DRILL DRLG P Continue drilling. New mud. 1.4 BPM,3500 CTP, 130 WHP,3970 BHP Page 6 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11/02/2011 24 hr Summary Drilled to TD at 11694', long wiper to surface 00:00 02:06 2.10 11,360 11,420 PROD1 DRILL DRLG P Continue drilling. New mud. 1.4 BPM,3500 CTP, 130 WHP,3970 BHP 02:06 04:30 2.40 11,420 11,420 PROD1 DRILL WPRT P Wiper trip to window,31K PUW 04:30 05:36 1.10 11,420 11,461 PROD1 DRILL DRLG P 11420', Drill Ahead, 1.42 BPM @ 3225 PSI FS, BHP=3973,WHP=120 05:36 07:06 1.50 11,461 11,461 PROD1 DRILL SFTY P Pull off bottom for safety stand up 07:06 10:42 3.60 11,461 11,570 PROD1 DRILL DRLG P 11461, Drill Ahead, 1.4 BPM @ 3250 PSI FS, BHP=3965,WHP=80 10:42 13:12 2.50 11,570 11,570 PROD1 DRILL WPRT P 11570',Wiper to window, PUW=32K 13:12 15:12 2.00 11,570 11,670 PROD1 DRILL DRLG P 11570, Drill Ahead, 1.4 BPM @ 3380 PSI FS, BHP=3980,WHP=30, RIW=11.8K, DHWOB=2.2K 15:12 15:24 0.20 11,670 11,690 PROD1 DRILL DRLG P Pump sweeps,planned TD now is 11714'., 15:24 15:36 0.20 11,690 11,690 PROD1 DRILL CIRC P Call TD @ 11690', PUH waiting on sweeps, PUW=32K 15:36 19:48 4.20 11,690 0 PROD1 DRILL WPRT P Sweeps comeing out,Chase to swab following MP Schedule, PUW=32K 19:48 21:48 2.00 0 9,100 PROD1 DRILL WPRT P RBIH 21:48 22:06 0.30 9,100 9,150 PROD1 DRILL DLOG P Tie in, +11' 22:06 23:24 1.30 9,150 9,485 PROD1 DRILL CIRC P Holding 11.8 ECD circulate bottoms up,two times. 23:24 00:00 0.60 9,485 10,100 PROD1 DRILL WPRT P Continue wiper back to TD 11/03/2011 Condition hole, pump completion fluid,run liner to TD with billet at 9574'. Function Test BOP 00:00 00:54 0.90 10,100 11,694 PROD1 DRILL WPRT P Continue wiper to TD 00:54 04:12 3.30 11,694 0 PROD1 DRILL DISP P Tag TD at 11694', lay in liner running pill of 9.1 flo-pro and alpine beads followed by 12.0 brine and POOH, paint EOP flags 04:12 04:36 0.40 0 0 PROD1 DRILL SFTY P PJSM and watch well for no-flow 04:36 06:00 1.40 0 0 PROD1 DRILL PULD P Lay down drilling BHA 06:00 07:00 1.00 0 0 PROD1 DRILL BOPE P Function test BOP, R/U floor to run Liner 07:00 08:15 1.25 0 0 COMPZ CASING PUTB P PJSM, Run"A" Liner, Non ported bull nose,64 joints slotted liner, Aluminim billet 08:15 08:27 0.20 0 0 COMPZ CASING SFTY P Conduct BOP drill, Hold drill review, Great drill 08:27 10:15 1.80 0 0 COMPZ CASING PUTB P Continue picking up liner 10:15 11:15 1.00 0 2,163 COMPZ CASING PUTB P All liner in well, PJSM P/U coil track, M/U to liner,surface test tool,Strip on well 11:15 13:30 2.25 2,163 9,354 COMPZ CASING TRIP P RIH, EDC Closed 13:30 13:36 0.10 9,354 9,363 COMPZ CASING TRIP P Correct to flag+9.1 to 9363.35, PUW=36K 13:36 14:30 0.90 9,363 11,694 COMPZ CASING TRIP P Trip in Page 7 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:30 14:36 0.10 11,694 11,694 COMPZ CASING TRIP P Set down @ 11694, PUW=40K,Set back down, Pumps on 1.5 BPM, 1.3 Out, PUW=32K, Liner released 14:36 14:42 0.10 11,694 11,499 COMPZ CASING TRIP P Trip out of well on 12 PPG 14:42 18:00 3.30 11,499 0 COMPZ CASING TRIP P Stop and remove liner length left in hole from counters to 9379.81, continue out of well 18:00 18:30 0.50 0 0 COMPZ CASING SFTY P PJSM,check well for flow 18:30 19:30 1.00 0 0 COMPZ CASING PUTB P Lay down liner running BHA 19:30 20:30 1.00 0 0 PROD2 DRILL PULD P MU Drilling BHA 20:30 22:42 2.20 0 9,140 PROD2 DRILL TRIP P RIH 22:42 23:06 0.40 9,140 9,200 PROD2 DRILL DLOG P Tie-in,+11 23:06 00:00 0.90 9,200 9,485 PROD2 DRILL DISP P Displace well to 9.1 PPG flo-pro 11/04/2011 Milled off billet at 9577'and drilled tunr section,tripped for BHA and continued drilling lateral with rib steer motor 00:00 00:42 0.70 9,485 9,577 PROD2 STK DISP P Continue displacing well to flo-pro 00:42 03:12 2.50 9,577 9,590 PROD2 STK KOST P Dry tag billet at 9577',start pumping at 1.4 BPM,3490 CTP,3850 BHP, 16K RIW. Start time milling from 9576.8 03:12 05:42 2.50 9,590 9,770 PROD2 DRILL DRLG P Continue drilling ahead 05:42 06:00 0.30 9,770 9,770 PROD2 DRILL WPRT P 9770',Wiper to window, PUW=31K 06:00 07:00 1.00 9,770 9,865 PROD2 DRILL DRLG P 9770',drill ahead, 1.4 BPM @ 3410 PSI FS, BHP=3940 07:00 09:45 2.75 9,865 80 PROD2 DRILL TRIP P 9865, EOB/Turn, POOH for RSM following MP Schedule 09:45 13:30 3.75 80 80 PROD2 DRILL PULD P PUD BHA#9 Drill by BHA, PD BHA #10 AL1 Lateral RSM,Make up to injector,surface test tool 13:30 16:00 2.50 80 9,180 PROD2 DRILL TRIP P RIH, EDC Open 16:00 16:12 0.20 9,180 9,208 PROD2 DRILL DLOG P Log tie in for+10,Close EDC, PUW=31.5K 16:12 16:48 0.60 9,208 9,865 PROD2 DRILL TRIP P RIH to drill,Set down in bottom of window 9504,@ 20 FPM, PUH roll pumps set down again @ 30 FPM. PUH Roll pumps go through @ 30 FPM,Continue in 16:48 18:48 2.00 9,865 10,015 PROD2 DRILL DRLG P Drill Ahead, 1.46BPM @ 3588 PSI FS, BHP=3996,WHP=30 18:48 19:24 0.60 10,015 10,015 PROD2 DRILL WPRT P Wiper trip,32K PUW, 16K RIW 19:24 23:24 4.00 10,015 10,165 PROD2 DRILL DRLG P Continue drilling ahead, 1.45 BPM, 3500 CTP, 3920 BHP,70 WHP 23:24 00:00 0.60 10,165 10,165 PROD2 DRILL WPRT P Wiper to the window,32K PUW 11/05/2011 Drilled AU lateral 00:00 05:12 5.20 10,165 10,315 PROD2 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 3500 CTP,3900 BHP,30 WHP 05:12 06:27 1.25 10,315 10,315 PROD2 DRILL WPRT P Wiper to window,32K PUW, with tie in for 0'correction Page 8of15 Time Logs Date From To Dur S.Depth E. Depth-Phase< Code Subcode T Comment 06:27 09:42 3.25 10,315 10,465 PROD2 DRILL DRLG P 10315', Drill Ahead, 1.40 BPM @ 3235 PSI FS, BHP=3925 09:42 10:57 1.25 10,465 10,465 PROD2 DRILL WPRT P Wipe to window, PUW=32K 10:57 13:27 2.50 10,465 10,615 PROD2 DRILL DRLG P 10465', Drill Ahead 1.4 BPM @ 3380 PSI FS, BHP=3925,WHP=30 13:27 14:57 1.50 10,615 10,615 PROD2 DRILL WPRT P 10615',Wiper to window, PUW=32K 14:57 18:06 3.15 10,615 10,765 PROD2 DRILL DRLG P 10615', Drill Ahead, 1.4 BPM @ 3350 PSI FS, BHP=3980 18:06 19:54 1.80 10,765 10,765 PROD2 DRILL WPRT P Wiper to window,33K PUW,tie-in for +2' 19:54 22:00 2.10 10,765 10,915 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3450 CTP,4000 BHP 22:00 23:48 1.80 10,915 10,915 PROD2 DRILL WPRT P Wiper to the window,32K PUW 23:48 00:00 0.20 10,915 10,930 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 3450 CTP,3995 BHP 11/06/2011 00:00 02:18 2.30 10,930 11,065 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3450 CTP,3995 BHP 02:18 04:48 2.50 11,065 11,065 PROD2 DRILL WPRT P Wiper to the window,32K PUW, Swap mud. Reset choke. 04:48 06:30 1.70 11,065 11,215 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3450 CTP,4000 BHP,70 WHP 06:30 08:42 2.20 11,215 11,215 PROD2 DRILL WPRT P Wiper to window, BHP=4020, WHP=135, PUW=32K 08:42 10:42 2.00 11,215 11,365 PROD2 DRILL DRLG P 11215, Drill Ahead, 1.5 BPM @ 3550 PSI FS, BHP=4000,WHP=130 10:42 13:12 2.50 11,365 11,365 PROD2 DRILL WPRT P Wiper trip to window with tie in for+2' correction 13:12 15:42 2.50 11,365 11,515 PROD2 DRILL DRLG P 11365,drill Ahead 1.5 BPM @ 3700, BHP=4090,WHP=100 15:42 18:12 2.50 11,515 11,515 PROD2 DRILL WPRT P Wiper trip to window, PUW=33K 18:12 19:48 1.60 11,515 11,665 PROD2 DRILL DRLG P Continue drilling, 1.5 BPM,3650 CTP,4050 BHP 19:48 22:36 2.80 11,665 11,665 PROD2 DRILL WPRT P Wiper to the window,32K PUW 22:36 00:00 1.40 11,665 11,800 PROD2 DRILL DRLG P Continue drilling, 1.5 BPM, 3650 CTP,4040 BHP 11/07/2011 00:00 00:12 0.20 11,800 11,815 PROD2 DRILL DRLG P Continue drilling, 1.5 BPM,3650 CTP,4040 BHP 00:12 03:06 2.90 11,815 11,815 PROD2 DRILL WPRT P Wiper to the window,32 K PUW 03:06 05:00 1.90 11,815 11,965 PROD2 DRILL DRLG P Continue drilling, 1.5 BPM,3700 CTP,4060 BHP 05:00 08:15 3.25 11,965 11,965 PROD2 DRILL WPRT P Wiper to the window, 33K PUW 08:15 11:03 2.80 11,965 12,115 PROD2 DRILL DRLG P 11965, Drill Ahead, 1.5 BPM @ 3770 PSI FS, BHP=4093, ECD=12.4,WHP=20,Wide open choke, RIW=12.5K 11:03 14:21 3.30 12,115 12,115 PROD2 DRILL WPRT P Wiper trip to window, PUW=32.5K, BHP=4110 14:21 16:57 2.60 12,115 12,265 PROD2 DRILL DRLG P 12115, Drill Ahead, 1.45 BPM @ 3660 PSI FS, BHP=4110,Wide open choke Page 9 of 15 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 11/07/2011 24 hr Summary Drilled AL1 lateral 16:57 19:00 2.05 12,265 9,540 PROD2 DRILL WPRT P Wiper trip to window PUW=34K 19:00 19:12 0.20 9,523 9,550 .PROD2 DRILL DLOG P Tie in,+7' 19:12 20:30 1.30 9,550 12,265 PROD2 DRILL WPRT P Wiper back in hole 20:30 00:00 3.50 12,265 12,410 PROD2 DRILL DRLG P Continue drilling, 12K RIW, 1.4 BPM, 3750 CTP,4113 BHP 11/08/2011 Drilled AU lateral to TD 12605'. POOH to swab valves chasing low/hi sweeps. RBIH to TD. (12605')Lay in liner running pill to window,(9.1ppg FP). KWF from window to surface(12ppg). PU/MU AL1 lower segment liner. (49jnts) 00:00 00:24 0.40 12,410 12,430 PROD2 DRILL DRLG P Continue drilling, 12K RIW, 1.4 BPM, 3750 CTP,4113 BHP 00:24 02:30 2.10 12,430 9,520 PROD2 DRILL WPRT P Pump 5 Bbls of low vis and 5 Bbls. high vis sweeps. Wiper to the window,33K PUW 02:30 02:36 0.10 9,520 9,530 PROD2 DRILL DLOG P Tie-in,+1.5' 02:36 04:12 1.60 9,530 12,430 PROD2 DRILL WPRT P Wiper back in hole, 04:12 06:42 2.50 12,430 12,600 PROD2 DRILL DRLG P 12430, Drill Ahead, 1.4 BPM @ 3770 PSI FS, BHP=4170, ECD=12.7, RIW=10-12K 06:42 06:54 0.20 12,600 12,600 PROD2 DRILL WPRT P 12600', Pull BHA wiper, Drill 5 more feet to determine TD or wiper trip to window 06:54 07:00 0.10 12,600 12,605 PROD2 DRILL DRLG P 12600', Drill ahead, 1.4 BPM @ 3770 PSI FS, RIW=10-12K,Wide open choke, ECD=12.8, BHP=4200 07:00 07:45 0.75 12,605 12,605 PROD2 DRILL WPRT P Call TD, Pull mini wiper,start lo hi sweeps down coil 07:45 12:45 5.00 12,605 69 PROD2 DRILL WPRT P Trip out chasing sweeps to swab, PUW=32.5k, No additional cuttings noted as sweeps were coming across shaker 12:45 16:57 4.20 69 12,605 PROD2 DRILL WPRT P RBIH,Tie in for+9' 16:57 16:57 0.00 12,605 12,605 PROD2 DRILL WPRT P Called state for 24 hour notification for BOP test,est.time at 19:00 on 11/9. 16:57 21:27 4.50 12,605 0 PROD2 DRILL DISP P POOH, lay in 9.1 PPG liner running pill. Paint EOP flags and lay in 12.0 PPG from window to surface. 21:27 21:42 0.25 0 0 PROD2 DRILL SFTY P At surface, PJSM,Monitor well for flow 21:42 22:42 1.00 0 0 PROD2 DRILL PULD P Lay down BHA 22:42 23:12 0.50 0 0 COMPZ CASING SVRG P Prepare floor to PU liner 23:12 23:27 0.25 0 0 COMPZ CASING SFTY P PJSM, Discuss procedure on PU/MU liner 23:27 00:00 0.55 0 0 COMPZ CASING PUTB P PU/MU 49jnts 2 3/8"slotted liner 11/09/2011 RIH releasing AL1 lower liner on bottom 12605'.POOH, PU/MU/RIH upper AL1 liner.Set upper liner with OH anchor billet w/single slip 10 deg ROHS atop lower liner.Top of billet at 10729'. POOH, BOPE testing. (State Witness waived by Bob Noble) Page 10 of 15 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 00:00 00:06 0.10 0 0 COMPZ CASING PUTB P Continue PU/MU AU lower liner.49 jnts slotted 00:06 00:12 0.10 0 0 COMPZ CASING SFTY P On Jnt#6,Announce Drill."Kick While Tripping". Discuss drill afterwards.(2.5 minutes shut in time) 00:12 03:30 3.30 0 0 COMPZ CASING PUTB P Continue PU/MU AL1 lower liner.49 jnts slotted 03:30 04:00 0.50 0 0 COMPZ CASING SVRG P Service injector head 04:00 07:30 3.50 0 12,605 COMPZ CASING RUNL P RIH,Correct at flag+10',weight check 32.5K PUW,-4.5K WOB 07:30 11:00 3.50 12,605 0 COMPZ CASING RUNL P Release liner, POOH, Deployment sleeve at 10986' 11:00 11:30 0.50 0 0 COMPZ CASING SFTY P PJSM,check well for no flow 11:30 12:00 0.50 0 0 COMPZ CASING SVRG P Injector maint. 12:00 12:30 0.50 0 0 COMPZ CASING PUTB P Lay down liner running BHA 12:30 13:48 1.30 0 317 COMPZ CASING PUTB P MU upper liner,anchored billet and liner running BHA 13:48 17:18 3.50 317 9,400 COMPZ CASING RUNL P RIH 17:18 17:33 0.25 9,400 9,400 COMPZ CASING RUNL P Tie in depth with gamma+11' correction 17:33 18:18 0.75 9,400 10,986 COMPZ CASING RUNL P Record up 34K and down weights 18K, RIH to TOL 18:18 18:33 0.25 10,986 10,986 COMPZ CASING RUNL P Tag TOL#1, 10980'.set down 1K WOB.Set anchor 10 deg ROHS. 4058 CTP, PU 34K. Top of bilet at 10729.8' 18:33 21:33 3.00 10,986 0 COMPZ CASING RUNL P POOH 21:33 21:48 0.25 0 0 COMPZ CASING SFTY P At surface, PJSM monitor well for flow 21:48 22:48 1.00 0 0 COMPZ CASING PUTB P LD BHA 22:48 23:30 0.70 0 0 PROD3 CASING SVRG P Flush and grease stack. 23:30 00:00 0.50 0 0 PROD3 DRILL BOPE P Start BOPE testing(Waived by Bob Noble) 11/10/2011 Complete BOPE testing.State witness waived by Bob Noble. Perform maintenance on Injector Head 00:00 11:30 11.50 0 0 PROD3 DRILL BOPE P BOPE testing,250 low,4500 high. Two valves failed initial tests(R2, R3),total test time was 12 hours. 11:30 23:30 12.00 0 0 PROD3 DRILL RGRP T Start injector repairs ***Nabors on Rig Repair Rate*** 23:30 00:00 0.50 0 0 PROD3 DRILL RGRP T Cont. Injector repairs ***Nabors on Non-Billable Rig Repair Rate*** 11/11/2011 Complete Injector Maintenance, PU/MU/RIH BHA 13(.7 AKO, Hycalog bit). Displace KWF out of well with drilling mud.Sidetrack AL1-01 Lateral at 10731' 00:00 14:30 14.50 0 0 PROD3 DRILL RGRP T Cont. Injector Maintenance ***15 Hours of nabors non-billable rig repair time*** Page 11 of 15 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:30 14:54 0.40 0 0 PROD3 DRILL SFTY P PJSM for BHA 14:54 16:24 1.50 0 0 PROD3 STK PULD P MU drilling BHA for AL1-011ateral 16:24 19:39 3.25 0 9,180 PROD3 STK TRIP P RIH,stopping to check pipe and injector frequently 19:39 19:54 0.25 9,180 9,209 PROD3 STK DLOG P Tie in depth+11.5'correction 19:54 21:15 1.35 9,209 9,209 PROD3 STK CIRC P Displace KWF out of well to Flo-Pro drilling mud 21:15 21:24 0.15 9,209 9,507 PROD3 STK TRIP P Close EDC, RIH to TOB 21:24 21:30 0.10 9,507 9,507 PROD3 STK TRIP P Tag in window 18 FPM running speed,set down 8K, PU 33K CTW. RIH 30 FPM running speed. Run through window slick. Depths correlate to bottom of window 21:30 22:06 0.60 9,507 10,732 PROD3 STK TRIP P RIH to TOB 22:06 22:18 0.20 10,732 10,710 PROD3 STK TRIP P Offline with pumps, Dry tag TOB 7 FPM.Tag 1.8K WOB,at 10732'. PU 33K. 22:18 22:18 0.00 10,710 10,710 PROD3 STK TRIP P Online with pumps 1.4 BPM,3400 CTP,4020 BHP, 15K RIHW,400 diff psi off bottom. 22:18 22:30 0.20 10,732 10,732 PROD3 STK KOST P Start milling billet to sidetrack AL1-01 lateral. 22:30 23:30 1.00 10,732 10,732 PROD3 STK KOST P Weight Milled off on first set down. set auto driller to 1 FPH for 1' 23:30 00:00 0.50 10,732 10,733 PROD3 STK KOST P Set Auto driller to 2 FPH 11/12/2011 Drilled Ahead,AL1-01 lateral 00:00 00:15 0.25 10,733 10,734 PROD3 STK KOST P Cont milling 2 FPH for 1' 00:15 00:45 0.50 10,734 10,735 PROD3 STK KOST P Set auto driller to 3 FPH 1' 00:45 01:00 0.25 10,735 10,740 PROD3 STK KOST P set auto driller 10 FPH for 5' 01:00 01:15 0.25 10,740 10,743 PROD3 STK KOST P Set auto driller 20 FPH for 2' 01:15 01:36 0.35 10,743 10,755 PROD3 STK KOST P Increase ROP 40 FPH, 1.4 BPM, 3500 CTP, 150 WHP,3979 BHP, 14K CTW, 1K WOB 01:36 01:57 0.35 10,755 10,780 PROD3 STK KOST P Increase WOB 1.3K WOB,90 FPH, 3650 CTP, 150 WHP 01:57 02:09 0.20 10,780 10,780 PROD3 STK KOST P PU above sidetrack to drift w/o pumps.30K PUW, looks good, RIH 02:09 03:30 1.35 10,780 10,880 PROD3 DRILL DRLG P Drill Ahead, 1-2K WOB,3650 CTP, 1.4 BPM, 150 WHP 03:30 05:18 1.80 10,880 10,880 PROD3 DRILL WPRT P Wiper trip to window,33K PUW 05:18 07:30 2.20 10,880 11,030 PROD3 DRILL DRLG P Continue drilling, 1.4 BPM,3450 CTP,3930 BHP 07:30 09:24 1.90 11,030 11,030 PROD3 DRILL WPRT P Wiper to the window,33K PUW 09:24 11:24 2.00 11,030 11,180 PROD3 DRILL DRLG P Continue Drillig, 1.45 BPM,3450 CTP,3953 BHP 11:24 12:36 1.20 11,180 9,520 PROD3 DRILL WPRT P Wiper to the window,33K PUW 12:36 12:48 0.20 9,520 9,550 PROD3 DRILL DLOG P Tie in,+5' Page 12 of 15 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 12:48 13:48 1.00 9,550 11,180 PROD3 DRILL WPRT P Wiper back in hole 13:48 15:42 1.90 11,180 1• 1,330 PROD3 DRILL DRLG P Continue drilling, 13K RIW, 1.45 BPM,3500 CTP,3980 BHP 15:42 17:57 2.25 11,330 11,330 PROD3 DRILL WPRT P Wiper to the window, 33K PUW 17:57 20:12 2.25 11,330 11,480 PROD3 DRILL DRLG P Drill ahead, 13K, 1.5BPM,3540 CTP, 3990 BHP 20:12 22:42 2.50 11,480 11,480 PROD3 DRILL WPRT P Wiper trip to window,32K PUW 22:42 00:00 1.30 11,480 11,591 PROD3 DRILL DRLG P Drill Ahead 1.4 BPM,3600 CTP 13K CTW,4030 BHP 11/13/2011 TD AL1-01 lateral at 11958'. POOH to swab valves.(No increase in cuttings noted)Service injector head. RBIH to TD. Lay in liner running pill(9.1ppg FP with beads)in OH up to window. Lay in KWF(12ppg NaBr)to surface. 00:00 00:30 0.50 11,591 11,630 PROD3 DRILL DRLG P Continue drilling 00:30 02:15 1.75 11,630 11,630 PROD3 DRILL WPRT P Wiper trip to window,32K PUW 02:15 02:45 0.50 11,630 11,630 PROD3 DRILL SVRG P PU above TOC 9240'.Circulate minimum rate,replace goosneck roller on injector head 02:45 03:00 0.25 11,630 11,630 PROD3 DRILL WPRT P RIH,tie in depth to RA marker+5.5' correction 03:00 04:15 1.25 11,630 11,630 PROD3 DRILL WPRT P RIH to drill 04:15 06:00 1.75 11,630 11,780 PROD3 DRILL DRLG P Drill Ahead 1.5 BPM, 3750 CTP, 4023 BHP,open choke 06:00 08:42 2.70 11,780 11,780 PROD3 DRILL WPRT P Wiper to the window,33K PUW, 08:42 10:42 2.00 11,780 11,930 PROD3 DRILL DRLG P Continue drilling, 12K RIW,3550 CTP,4050 BHP, 930 pm. Field in Phase 2 weather condtions 10:42 11:18 0.60 11,930 11,930 PROD3 DRILL WPRT P 500'wiper,33K PUW, 12K RIW 11:18 12:00 0.70 11,930 11,955 PROD3 DRILL DRLG P Continue drilling, 1.5 BPM,3650 CTP,4050 BHP 12:00 16:18 4.30 11,955 0 PROD3 DRILL WPRT P TD,circulate low/high vis sweeps and start wiper to the swab. 16:18 16:36 0.30 0 0 PROD3 DRILL SVRG P Service injector and choke 16:36 20:36 4.00 0 11,958 PROD3 DRILL WPRT P Wiper back in hole,tie in depth 9180-9210'.+9'correction 20:36 00:00 3.40 11,958 0• PROD3 DRILL TRIP P Tag TD 11958'. POOH laying in liner running pill(Flo-pro with beads)to window,displace well to KWF (12ppg NaBr) 11/14/2011 PU/MU AL1-01 Liner(75jnts slotted with 8jnts solid 2 3/8"STL). Repair reel hub. RIH, release liner on bottom 11958'.TOL 9244'.Swap well to seawater and freeze protect well 2000'ND. Undeploy BHA, Set BPV.Flush reel&rig with inhibitor and blow down. 00:00 00:30 0.50 0 0 PROD3 DRILL OWFF P At surface, Monitor well for flow, PJSM 00:30 00:45 0.25 0 COMPZ DRILL SVRG P Unable to operate skate. Shut down. Hold PJSM, Found sensor to be covered with fluid.Clean sensors, test OK 00:45 01:45 1.00 0 0• PROD3 DRILL PULD P LD BHA Page 13 of 15 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 01:45 03:15 1.50 0 0 COMPZ CASING SVRG P Prep floor to PU liner,service injector head, inspect and service reel. Plates inside reel for hub bolts have cracks.Welder in route from Nabors 245. Continue moving forward to PU liner. Field back to phase 1 (except drill cites) 03:15 03:30 0.25 0 0 COMPZ CASING SFTY P PJSM,picking up liner 03:30 05:00 1.50 0 0 COMPZ CASING PUTB P PU AL1-01 liner 400am Field in Normal Driving conditions, Drillsites in Phase 1 05:00 06:00 1.00 0 0 COMPZ CASING RGRP T Welding on reel 06:00 06:36 0.60 0 0 COMPZ CASING SFTY P Crew change, PJSM 06:36 07:18 0.70 0 0 COMPZ CASING PUTB P Continue with liner operations. 07:18 07:42 0.40 0 0 COMPZ CASING SFTY P Safety joint drill,3 min.to well shut in,post drill safety talk. 07:42 09:42 2.00 0 2,750 COMPZ CASING PUTB P Continue liner operations, 75 Joints slotted and 8 joints solid. 09:42 10:42 1.00 2,750 2,750 COMPZ CASING PUTB P MU GS and Inteq tools. Strip on well with injector 10:42 12:24 1.70 2,750 9,357 COMPZ CASING RUNL P RIH with liner 12:24 13:18 0.90 9,357 10,958 COMPZ CASING RUNL P Correct at flag,+4.5'. 34K PUW,-7 WOB, 18K RIW,-5 WOB. Continue RIH 13:18 13:24 0.10 10,958 9,230 COMPZ CASING RUNL P Tag at 11958',8K WOB, pump at 1.3 BPM to release liner,2K WOB, change depth to reflect dropping off liner. Top of deployment sleeve is 9244.6' 13:24 14:12 0.80 9,230 9,230 DEMOB WELLPF DISP P Circulate KWF from well with SW 14:12 16:36 2.40 9,230 0 DEMOB WELLPF FRZP P FP well from 3000'while POOH 16:36 17:00 0.40 0 0 DEMOB WELLPF SFTY P PJSM for undeploy 17:00 18:00 1.00 0 0 DEMOB WELLPF PULD P Undeploy BHA 18:00 18:15 0.25 0 0 DEMOB WELLPF SFTY P Crew change. PJSM 18:15 19:30 1.25 0 0 DEMOB WELLPF PULD P Continue to undeploy BHA 19:30 19:45 0.25 0 0 DEMOB WHDBO SFTY P PJSM,setting BPV. (900 psi shut in tubing pressure) 19:45 23:15 3.50 0 0 DEMOB WHDBO SFTY P RU lubricator,Set BPV(first attempt failed,add additional rod)2nd attempt successful. PT good, RD lubricator 23:15 00:00 0.75 0 0 DEMOB WHDBO CIRC P Pre-Flush,circulate inhibitor throughCT and rig, Post-Flush 11/15/2011 ND BOP, RDMO. rig release at 06:00. 00:00 03:00 3.00 0 0 DEMOB WHDBO NUND P Cont. Flush with inhibitor,blow down CT and rig Page 14 of 15 Time Logs Date From To Dur S.Depth'E.Depth Phase Code Subcode T Comment 03:00 06:00 3.00 0 0 DEMOB WHDBO NUND P ND BOP'S prepare rig to move. **Rig release is 06:00** Page 15 of 15 2K-22A, 2K-22AL1 and 2K-22AL1-01 Post Rig Operations DATE SUMMARY 11/18/11 TAG DEPLOYMENT SLEEVE W, 2.72" CENT @ 9244' RKB.30 MIN SBHP, 9141' RKB 3484#AND 155 DEG.SET CATCHER @ 8965' RKB.PULLED 1.5" DV FROM 8904' RKB.IN PROGRESS 11/19/11 SET 1.5"X 1/4"ORFICE VLV @ 8904' RKB.REPLACED 1.5" DV'S WITH 1.5" GLV'S @ 2884' RKB (TRO=1318#) 5007' RKB (TRO=1299#)6684' RKB (TRO=1281#)AND 8079' RKB (TRO=1263#)ALL PORTS 3/16".PULLED CATCHER FROM 8965' RKB.JOB COMPLETE JTll1 DT Alta A\ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-22AL1 ConocoPhillips Alaska, Inc. Permit No: 211-103 Surface Location: 294' FNL, 94' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 880' FSL, 1466' FEL, SEC. 14, T1ON, R8E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 2K-22A, Permit No 211- 102, API 50-103-20116-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of August, 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) STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 6 2011 PERMIT TO DRILL 20 AAC 25.005 Albittalf&6n mr' si stiMS an 1 a.Type of Work: - lb.Proposed Well Class: Development-Oil 0 •Service-Winj ❑ Single Zone 0- 1c.Sped sed for: Drill ❑ Re-drill 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas Gas Hydrates❑ Re-entry ❑ Exploratory 0 Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 2K-22AL1 ' 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12600'• TVDSS: 6274' - Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:294'FNL,94'FEL,Sec. 11,T1ON,R8E,UM ADL 25588,25605 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2138'FNL, 1385'FEL,Sec. 14,T1ON,R8E,UM 2674,2679 10/5/2011 Total Depth: 9.Acres in Property: 14.Distance to o 880'FSL, 1466'FEL,Sec. 14,T1ON, R8E,UM 2560 lcq,�,,Nearest�P jperty: 3760 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: et 15.Distance to Nearest Well Open Surface:x- 498310 • y- 5938010- Zone- 4 GL Elevation above MSL: 40 feet to Same Pool: 2K-21 ,8890 16.Deviated wells: Kickoff depth: 9600 - ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 97° deg Downhole:4678 psig - Surface:4060 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.325" 4.7# L-80 ST-L 2335' 10265' 6231' 12600' 6274' slotted/solid liner a 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 9811 6476 9717' 6441' 9481 Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 170 sx AS II 115' 115' Surface 3725' 9.625" 1300 sx AS III,450 sx Class G 3760' 2928' Intermediate Production 9766' 7" 300 sx Class G 9796' 6470' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 9346-9358',9430'-9450',9462'-9466',9507'-9547' 6288'-6294',6327'-6337',6343'-6345',6363'-6379' 20.Attachments: Property Plat❑ BOP Sketch 0 Drilling Program 0 Time v.Depth Plot Li Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263-4172 Ik ` Printed Name L. Gantt Title CTD Engineering Supervisor Signature b() Phon 263-4021 Date tZ4\\\. 4nak cistuu, Commission Use Only Permit to Drill API Number: Permit A ro( c ( al See cover letter Number: /l 5(�� 50-/O R-avr)J Date: D I f for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: U ,r yr p3L 50 P 7s t l Samples req'd: Yes ❑ No EY Mud log req'd: Yes ❑ No [1 Other: a4 � r_I` Ahn 4 ,/ 4- S H2S measures: Yes [r No ❑ Directional svy req'd: Yes 0 No ❑ J OA ---- , APPROVED BY THE COMMISSION //:3‘,/// / DAT ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid or 24.rr�►orhN Boit eidfitkyofa ikal(20 AAC 25.005(g)) it in Duplicate /1 8•LH Argelp/if 9. �( KRU 2K-22A, AL1, AL1-01 - Coiled Tubing Drilling Summary of Operations: Well 2K-22 is a Kuparuk A-sand production well equipped with 31/2"tubing and 7"production casing. Three proposed A-sand CTD laterals will increase reservoir exposure and offset the planned 2K-28 CTD injection laterals. Prior to drilling,the existing A-Sand perfs in 2K-22 will be squeezed with cement to provide a means to kick out of the 7"casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the perfs in this manner. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 9540' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2K-22A sidetrack will exit the 7"casing at 9500' MD and will target the A4 sand north of the existing well with a 2150' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,650' MD with an aluminum billet at 9600' MD. The 2K-22AL1 lateral will kick off from the aluminum billet at 9600' MD and will target the A4 sand south of the existing well with a 3000' lateral. The hole will be completed with a 2%" slotted liner to the TD of 12,600' MD with an aluminum billet at 10,265' MD. The 2K-22AL1-01 lateral will kick off from the aluminum billet at 10,265' MD and will target the A5 sand south of the existing well with an 1585' lateral. The hole will be completed with a 23/8" slotted liner to the TD of 11,850' MD with the final liner top located just inside the 3'/2"tubing at 9260' MD. CTD Drill and Complete 2K-22 Laterals: October 2011 Pre-CTD Work 1. Positive pressure and drawdown tests on master valve& swab valve 2. RU slickline. Pull jet pump and close CMU sliding sleeve. Pressure test IA to confirm CMU is closed. 3. RU coil. Mill out D-nipples at 9141' & 9242' to 2.80"ID. Perform fill cleanout to 9600' MD. 4. RU slickline. Tag fill. Get updated static BHP survey. 5. RU e-line. Run caliper survey in 7"casing from 9600' to 9280'. Perf holes in 31/2'tubing tail at 9260' MD. RD e-line. 6. RU coil. Plug all perfs with cement up to tubing tail perfs at 9260' MD. RD coil. 7. RU slickline. Tag top of cement. RD slickline. 8. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2K-22A Sidetrack(A4 sand,north) (4( a. Drill2.80"high-side pilot hole through cement to 9540' MD'. b. Drift pilot hole with whipstock dummy c. Set whipstock at 9500' MD with high-side orientation. d Mill 2 80"window at 95510' MD. e. Drill 2.70"x 3"bi-center lateral to TD of 11,650' MD f. Run 2%" slotted liner with an aluminum billet from TD up to 9600' 3. 2K-22AL 1 Lateral (A4 sand, south) a. Kick off of the aluminum billet at 9600' MD b. Drill 2.70"x 3"bi-center lateral to TD of 12,600' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 10,265' P Page 2 of 4 ORIGIN ,1\ August 23, 2011, FINAL KRU 2K-22A, AL1, AL1-01 — Coiled Tubing Drilling 4. 2K-22AL1-01 Lateral (A5 sand, south) a. Kick off of the aluminum billet at 10,265' MD b. Drill 2.70"x 3"bi-center lateral to TD of 11,850' MD c. Run 2%" slotted liner from TD up to 9260' MD, up inside the 31/2"tubing tail 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production Mud Program: • Will use chloride-based Biozan brine or used drilling mud(9.0 ppg)for milling operations, and chloride- based Flo-Pro mud(9.0 ppg)for drilling operations. We will have to kill the well with weighted brine in order to deploy 2%" slotted liner in the three laterals. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind&Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 2K-22A: 2%", 4.7#,L-80, ST-L slotted/solid liner from 9600' MD to 11,650' MD • 2K-22AL1: 2%", 4.7#,L-80, ST-L slotted/solid liner from 10,265' MD to 12,600' MD • 2K-22AL1-01: 2%", 4.7#, L-80, ST-L slotted/solid liner from 9260' MD to 11,850' MD Existing Casing/Liner Information Surface: 9%",J-55, 36 ppf Burst 3520 psi Collapse 2020 psi Production: 7", J-55, 26 ppf Burst 4980 psi Collapse 4320 psi Reservoir Pressure • The most recent static BHP survey in well 2K-22 was taken March 2011. The A-sand reservoir pressure was measured at 3391 psi at 8960' MD, 6073' TVD, corresponding to 10.8 ppg EMW. We generally expect to encounter increasing pressure as laterals are drilled away from the mother well. Well Control: • Two well bore volumes(-200 bbl)of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2"coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4700 psi. Maximum potential surface pressure in 2K-22 is 4060 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on a pressure measurement of 4678 psi at 6347' TVD taken in offset injection well 2K-24 in August 2011, corresponding to 14.2 ppg formation pressure. • The annular preventer will be tested to 250 psi and 2500 psi. • Since there is no S SSV,the 2K-22 CTD laterals will have to be displaced to an overbalancing fluid prior . to deploying 23/8" slotted liner. bl<- Page 3 of 4 ORIGIN L August 23,2011, FINAL KRU 2K-22A, AL1, AL1-01 — Coiled Tubing Drilling Logging • MWD directional,resistivity,and gamma ray will be run over the entire open hole section. Directional: • See attached directional plans: 1. 2K-22APlan#3 2. 2K-22AL1,plan#3 • 3. 2K-22AL1-01,plan#1 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 2K-22A,northern lateral: 6440' to property line, 1440' to well 2K-16 • 2K-22AL1 & 2K-22AL1-01, southern laterals: —3760' to property line,—8890' to well 2K-21 . Hazards • Low weight-on-bit is expected to be the most significant drilling problem expect due to length of the • laterals and wellbore tortuosity. We will mitigate by minimizing dogleg severity when possible,keeping the borehole clean, and using lubricants in the mud. • There has been no MI gas injection in the vicinity of 2K-22 for 15+years, so it is unlikely that an influx , will yield significant quantities of gas. • Well 2K-22 has 60 ppm measured H2S as of January 2010. Well 2K-21A is located 25' to the right side and 2K-23 is 25' to the left side of the 2K-22 surface location. Well 2K-21A has 90 ppm H2S as of January 2010. Well 2K-23 is an injection well so there is no H25 measurement. The maximum H2S level on the pad is 400 ppm from well 2K-27(1/13/09). All H2S monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by • using 9.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%"BHA will be accomplished utilizing the 2%"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. Well 2K-22 will have to be killed prior to deploying slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 3566 psi at 9500' MD(6360' TVD), or 10.8 ppg EMW. v' • Expected annular friction losses while circulating: 950 psi (assuming annular friction of 100 psi/1000 ft due to the 3'/2"tubing) • Planned mud density of 9.0 ppg equates to 2976 psi hydrostatic bottom hole pressure at 6360' TVD. Mud hydrostatic pressure alone will not be sufficient to overbalance formation pressure. • While circulating 9.0 ppg mud,bottom hole circulating pressure is estimated to be 3926 psi or 11.9 ppg - EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 2K-22. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability,but not necessarily for well control. • When circulation is stopped,—950 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. Page 4 of 4Q ! N i L August 23,2011, FINAL 2K-22 Proposed CTD Sidetrack Revised:23-Aug-11 ' 3-1/2"Camco DS nipple at 499'RKB -ID=2.875" I 3-1/2"9.3#L-80 EUE 8rd Tubing to surface i 16"62#H-40 shoe 115'RKB X3-1/2"Camco MMG gas lift mandrels at 2884',500T,6684', @8079',8904'RKB 9-5/8"36#J-55 surface casing at 3760'RKB MIMI_ 1111ft....._ 80-40 seal assembly at 9017' Baker 3-1/2"PBR at 9020'RKB(2.92 ID) 11::::=1 �_ Baker FHL packer at 9033'RKB(4.0"ID) -1 Camco D landing nipple at 9141'RKB -I D=2.75" -Will mill out to 2.80"pre-CTD 80-40 seal assembly at 9182'-9194' ,..,_.--,==,-,„...-_,..,_-...–_,..--.. Baker 3-1/2"PBR at 9185 RKB(3"ID) Baker FHL packer at 9199'RKB(2.992"ID) Tubing pelts at 9260'MD Camco D landing nipple at 9242'RKB -ID=2.75" Planned top of cement at 9260'< —1' Will mill out to 2.80"pre-CTD 3-1/2"tubing tail at 9275 MD CBL shows 7"joints @ 9407,9424',9447,9484', C-sand perfs(sgz'd) 9523'(CBL appears to be 1'deep to OFM log) 9346'-9358'MD KOP @ 9500'MD 2K=22AL1 01,TD=11,850 • 23/4"liner 9260'-11,850' A-sand perfs(sgz'd) , 9430'-9450'MD 9462'-9466'MD 9507'-954T MD Ar // ✓ 2K-22A,TD=11,650' /02G� 2K-22AL1,TD=12,600' 2 2%"liner 9600'-11,650' '/e"liner 10265-12,600' l 7"26#J-55 casing at 9796'MD ORIGINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N I Lubricator Riser 7 71 Annular Blind Blind/Shear 2" Pipe/Slip (CT) _ Pump into Lubricator / �J L><� above BHA rams 1 r 7 17 Choke 1 2-3/8" Pipe/Slip (BHA) Choke Equalize Manifold 2-3/8" Pipe/Slip (BHA) J L Kill ►><>\ ><DQCJ L ► i 1 r Blind/Shear 2" Pipe/Slip(CT) 'ir Choke 2 I Swab Valves ANIL Wing Valves bi®Vi•4 Tree Flow Cross 0 Surface Safety Valve BOPE: 7-1/16", 5M psi,TOT I Choke Line: 2-1/16", 5M psi 01 Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union ORIGINIL ConocoPhilli Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-22 2K-22AL1 Plan: 2K-22AL1_wp03 Standard Planning Report 23 August, 2011 In. BAKER HUGHES ORIGINAL Iv" ConocoPhillips or its affiliates /1'111 ConocoPhillips Planning Report B/JCER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-22 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-22 @ 154.00ft(2K-22) ' Site: Kuparuk 2K Pad North Reference: True Well: 2K-22 Survey Calculation Method: Minimum Curvature - Wellbore: 2K-22AL1 Design: 2K-22AL1_wp03 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 2K Pad Site Position: Northing: 5,938,600.18ft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17ft Longitude: 150°0'49.133 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 2K-22 Well Position +N/-S 0.00 ft Northing: 5,938,010.40 ft Latitude: 70° 14'30.718 N +EI-W 0.00 ft Easting: 498,310.19 ft - Longitude: 150°0'49.129 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 2K-22AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 10/20/2011 16.39 79.80 57,351 Design 2K-22AL1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,600.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (') 0.00 0.00 0.00 188.27 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) 0100ft) (°/100ft) (°) Target 9,600.00 89.96 214.75 6,227.35 -6,492.07 -1,117.08 0.00 0.00 0.00 0.00 9,670.00 97.23 210.53 6,222.96 -6,550.84 -1,154.74 12.00 10.38 -6.03 330.00 9,745.00 89.42 206.04 6,218.61 -6,616.71 -1,190.17 12.00 -10.41 -5.98 210.00 9,815.00 89.43 197.64 6,219.32 -6,681.62 -1,216.19 12.00 0.01 -12.00 270.00 10,065.00 89.44 187.64 6,221.80 -6,925.23 -1,270.84 4.00 0.00 -4.00 270.00 10,265.00 85.33 180.77 6,230.94 -7,124.32 -1,285.50 4.00 -2.05 -3.44 239.00 10,465.00 85.38 172.74 6,247.17 -7,323.18 -1,274.23 4.00 0.02 -4.01 270.00 10,665.00 90.10 166.28 6,255.07 -7,519.52 -1,237.86 4.00 2.36 -3.23 306.00 10,865.00 90.76 158.31 6,253.56 -7,709.89 -1,177.08 4.00 0.33 -3.99 274.80 11,365.00 90.72 178.31 6,247.03 -8,196.98 -1,076.26 4.00 -0.01 4.00 90.00 11,565.00 90.02 186.28 6,245.75 -8,396.66 -1,084.25 4.00 -0.35 3.98 95.00 12,065.00 87.90 206.17 6,254.94 -8,874.24 -1,223.18 4.00 -0.42 3.98 96.20 12,600.00 88.04 184.76 6,274.11 -9,386.56 -1,364.88 4.00 0.03 -4.00 270.00 8'232011 10:49:57AM Page 2 COMPASS 2003.16 Build 69 ORIGINJ\ L I.- ConocoPhillips or its affiliates VP`' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-22 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-22 @ 154.00ft(2K-22) Site: Kuparuk 2K Pad North Reference: True Well: 2K-22 Survey Calculation Method: Minimum Curvature Wellbore: 2K-22AL1 Design: 2 K-22AL 1_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 9,600.00 ' 89.96 214.75 6,227.35 -6,492.07 -1,117.08 6,585.23 0.00 0.00 5,931,519.23 497,191.77 TIP/KOP 9,670.00 97.23 210.53 6,222.96 -6,550.84 -1,154.74 6,648.81 12.00 -30.00 5,931,460.48 497,154.10 2 9,700.00 94.11 208.73 6,220.00 -6,576.78 -1,169.49 6,676.61 12.00 -150.00 5,931,434.54 497,139.34 9,745.00 89.42 206.04 6,218.61 -6,616.71 -1,190.17 6,719.09 12.00 -150.18 5,931,394.62 497,118.65 3 9,800.00 89.43 199.44 6,219.17 -6,667.40 -1,211.42 6,772.31 12.00 -90.00 5,931,343.94 497,097.39 9,815.00 89.43 197.64 6,219.32 -6,681.62 -1,216.19 6,787.07 12.00 -89.93 5,931,329.72 497,092.62 4 9,900.00 89.43 194.24 6,220.17 -6,763.33 -1,239.54 6,871.29 4.00 -90.00 5,931,248.02 497,069.26 10,000.00 89.43 190.24 6,221.16 -6,861.03 -1,260.74 6,971.03 4.00 -89.97 5,931,150.34 497,048.04 10,065.00 89.44 187.64 6,221.80 -6,925.23 -1,270.84 7,036.02 4.00 -89.93 5,931,086.14 497,037.92 Ribsteer 10,100.00 88.72 186.44 6,222.36 -6,959.96 -1,275.13 7,071.00 4.00 -121.00 5,931,051.42 497,033.62 10,200.00 86.66 183.01 6,226.40 -7,059.52 -1,283.37 7,170.71 4.00 -120.98 5,930,951.87 497,025.37 10,265.00 85.33 180.77 6,230.94 -7,124.32 -1,285.50 7,235.14 4.00 -120.84 5,930,887.08 497,023.22 6 1 10,300.00 85.33 179.36 6,233.79 -7,159.21 -1,285.54 7,269.67 4.00 -90.00 5,930,852.20 497,023.17 10,400.00 85.35 175.35 6,241.91 -7,258.75 -1,280.95 7,367.52 4.00 -89.89 5,930,752.66 497,027.74 10.465.00 85.38 172.74 6,247.17 -7,323.18 -1,274.23 7,430.31 4.00 -89.56 5,930,688.24 497,034.44 7 10,500.00 86.20 171.61 6,249.74 -7,357.76 -1,269.48 7,463.85 4.00 -54.00 5,930,653.66 497,039.19 10,600.00 88.56 168.37 6,254.31 -7,456.12 -1,252.12 7,558.68 4.00 -53.92 5,930,555.31 497,056.521 10,665.00 90.10 166.28 6,255.07 -7,519.52 -1,237.86 7,619.38 4.00 -53.77 5,930,491.91 497,070.771 8 10,700.00 90.21 164.88 6,254.97 -7,553.42 -1,229.15 7,651.67 4.00 -85.20 5,930,458.01 497,079.47, 10,800.00 90.55 160.90 6,254.31 -7,648.97 -1,199.73 7,742.00 4.00 -85.20 5,930,362.46 497,108.861 10,865.00 90.76 158.31 6,253.56 -7,709.89 -1,177.08 7,799.02 4.00 -85.23 5,930,301.55 497,131.50 9 10,900.00 90.76 159.71 6,253.10 -7,742.56 -1,164.54 7,829.55 4.00 90.00 5,930,268.88 497,144.03 11,000.00 90.76 163.71 6,251.77 -7,837.48 -1,133.16 7,918.97 4.00 90.02 5,930,173.96 497,175.39 11,100.00 90.75 167.71 6,250.44 -7,934.35 -1,108.48 8,011.29 4.00 90.07 5,930,077.09 497,200.04 11,200.00 90.74 171.71 6,249.14 -8,032.72 -1,090.61 8,106.06 4.00 90.12 5,929,978.73 497,217.88 11,300.00 90.73 175.71 6,247.85 -8,132.08 -1,079.66 8,202.82 4.00 90.18 5,929,879.37 497,228.82 11,365.00 90.72 178.31 6,247.03 -8,196.98 -1,076.26 8,266.55 4.00 90.23 5,929,814.48 497,232.20 10 11,400.00 90.60 179.70 6,246.63 -8,231.98 -1,075.65 8,301.09 4.00 95.00 5,929,779.49 497,232.80 11,500.00 90.24 183.69 6,245.89 -8,331.91 -1,078.61 8,400.41 4.00 95.02 5,929,679.57 497,229.82 11,565.00 90.02 186.28 6,245.75 -8,396.66 -1,084.25 8,465.30 4.00 95.05 5,929,614.82 497,224.16 11 11,600.00 89.86 187.67 6,245.78 -8,431.40 -1,088.50 8,500.29 4.00 96.20 5,929,580.09 497,219.91 11,700.00 89.43 191.65 6,246.40 -8,529.96 -1,105.27 8,600.24 4.00 96.20 5,929,481.54 497,203.12 11,800.00 89.01 195.62 6,247.76 -8,627.11 -1,128.84 8,699.77 4.00 96.17 5,929,384.40 497,179.53 11,900.00 88.58 199.60 6,249.87 -8,722.39 -1,159.08 8,798.40 4.00 96.12 5,929,289.15 497,149.27 12,000.00 88.16 203.58 6,252.71 -8,815.31 -1,195.86 8,895.65 4.00 96.04 5,929,196.24 497,112.48 12,065.00 87.90 206.17 6,254.94 -8,874.24 -1,223.18 8,957.90 4.00 95.92 5,929,137.32 497,085.14 12 12,100.00 87.90 204.77 6,256.22 -8,905.82 -1,238.22 8,991.31 4.00 -90.00 5,929,105.75 497,070.10 12,200.00 87.91 200.76 6,259.88 -8,997.95 -1,276.88 9,088.05 4.00 -89.95 5,929,013.64 497,031.42 12,300.00 87.93 196.76 6,263.52 -9,092.55 -1,309.02 9,186.29 4.00 -89.80 5,928,919.05 496,999.26 12,400.00 , 87.96 192.76 6,267.11 -9,189.17 -1,334.48 9,285.56 4.00 -89.66 5,928,822.45 496,973.79 8/23/2011 10:49:57AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips or its affiliates • ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-22 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: KuparukRiver Unit MD Reference: 2K-22 @ 154.00ft(2K-22) Site: Kupanak 2K Pad North Reference: True Well: 2K-22 Survey Calculation Method: Minimum Curvature Wellbore: 2K-22AL1 Design: 2K-22AL1_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (0) (ft) (ft) 12,500.00 87.99 188.76 6,270.65 -9,287.33 -1,353.13 9,385.39 4.00 -89.51 5,928,724.30 496,955.11 12,600.00 88.04 184.76 6,274.11 . -9,386.56 -1,364.88 9,485.27 4.00 -89.37 5,928,625.09 496,943.34 TD Targets - Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2K-22AL1 T2 0.00 0.00 6,254.00 -7,456.27 -1,252.54 5,930,555.16 497,056.11 70°13'17.385 N 150° 1'25.505 W -plan hits target center -Point 2K-22AL1_T4 0.00 0.00 6,274.00 -9,386.44 -1,365.14 5,928,625.21 496,943.09 70°12'58.401 N 150°1'28.765 W -plan hits target center -Point 2K-22AL1T1 0.00 0.00 6,222.00 -6,959.24 -1,275.65 5,931,052.14 497,033.11 70°13'22.273 N 150°1'26.179 W -plan hits target center -Point 2K-22AL1_T3 0.00 0.00 6,246.00 -8,480.32 -1,097.30 5,929,531.18 497,211.10 70°13'7.313 N 150°1'20.992 W -plan misses target center by 1.33ft at 11649.71ft MD(6245.99 TVD,-8480.54 N,-1095.98 E) -Point 2K-22AL1,AL1-01 Po 0.00 0.00 0.00 -6,307.23 -1,450.81 5,931,704.13 496,858.11 70°13'28.685 N 150°1'31.270 W -plan misses target center by 6231.76ft at 9745.00ft MD(6218.61 TVD,-6616.71 N,-1190.17 E) -Polygon Point 1 0.00 -6,307.23 -1,450.81 5,931,704.13 496,858.11 Point2 0.00 -6,638.04 -657.64 5,931,373.18 497,651.13 Point 3 0.00 -9,612.46 -1,085.86 5,928,399.15 497,222.28 Point 4 0.00 -9,348.69 -2,028.03 5,928,663.10 496,280.27 Point 5 0.00 -6,307.23 -1,450.81 5,931,704.13 496,858.11 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name W . . ,M'tx,;y: ': ( ( ) 12,600.00 6,274.11 2-3/8" 2-3/8 3 8/23/2011 10:49:57AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips or its affiliates ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-22 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-22 @ 154.00ft(2K-22) Site: Kuparuk 2K Pad North Reference: True Well: 2K-22 Survey Calculation Method: Minimum Curvature Wellbore: 2K-22AL1 Design: 2K-22AL1_wp03 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (ft) (ft) (ft) (ft) Comment 9,600.00 6,227.35 -6,492.07 -1,117.08 TIP/KOP 9,670.00 6,222.96 -6,550.84 -1,154.74 2 9,745.00 6,218.61 -6,616.71 -1,190.17 3 9,815.00 6,219.32 -6,681.62 -1,216.19 4 10,065.00 6,221.80 -6,925.23 -1,270.84 Ribsteer 10,265.00 6,230.94 -7,124.32 -1,285.50 6 10,465.00 6,247.17 -7,323.18 -1,274.23 7 10,665.00 6,255.07 -7,519.52 -1,237.86 8 10,865.00 6,253.56 -7,709.89 -1,177.08 9 11,365.00 6,247.03 -8,196.98 -1,076.26 10 11,565.00 6,245.75 -8,396.66 -1,084.25 11 12,065.00 6,254.94 -8,874.24 -1,223.18 12 12,600.00 6,274.11 -9,386.56 -1,364.88 TD • 8121%2011 10:49:57AM Page 5 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad 2K-22 2K-22AL1 2K-22AL1_wp03 Travelling Cylinder Report 23 August, 2011 BAKER HUGHES ORIGINAL ConocoPhillips or its affiliates rT/1" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-22 Project: Kuparuk River Unit TVD Reference: 2K-22 @ 154.00ft(2K-22) Reference Site: Kuparuk 2K Pad MD Reference: 2K-22 @ 154.00ft(2K-22) Site Error: 0.00ft North Reference: True Reference Well: 2K-22 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-22AL1 Database: EDM Alaska Prod v16 Reference Design: 2K-22AL1_wp03 Offset TVD Reference: Offset Datum Reference 2K-22AL1_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,600.00 to 12,600.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,444.60ft Error Surface: Elliptical Conic Survey Tool Program Date 8/2212011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 200.00 9,500.00 2K-22(2K-22) GCT-MS Schlumberger GCT multishot 9,500.00 9,600.00 2K-22A_wp03(2K-22A) MWD MWD-Standard 9,600.00 12,600.00 2K-22AL1_wp03(2K-22AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name n (") 12,600.00 6,428.11 2-3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2K Pad 2K-13-2K-13AL1 -2K-13AL1 Out of range 2K-19-2K-19-2K-19 Out of range 2K-19-2K-19A-2K-19A Out of range 2K-19-2K-19AL1 -2K-19AL1 Out of range 2K-20-2K-20-2K-20 Out of range 2K 21 2K 21 2K 21 Out of range 2K-21-2K-21A-2K-21A Out of range 2K-22-2K-22-2K-22 9,614.03 9,625.00 32.66 152.95 -68.99 FAIL-Major Risk 2K-22-2K-22A-2K-22Awp03 9,600.00 9,600.00 0.00 0.32 -0.22 FAIL-Major Risk 2K-22-2K-22AL1-01 -2K-22AL1-01_wp01 10,275.00 10,275.00 0.11 0.40 -0.16 FAIL-Minor 1/10 2K 27 2K 27 2K 27 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/23/2011 10:11:03AM Page 2 of 7 COMPASS 2003.16 Build 69 ORIGINAL 0 2 Y h I 111 8 I C...;g .• a h } 0,g gi . a • I • r+ I a ._.__ ________\. ........ ,..., 1 1 a O _e I N .h chi /: ' 1 i _._/L 1 _ I / l h W .... .-_._..4 ..�._� _._ _�._ __�_—_' -m H '<c.,',,,,0,1 ...1 ! 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V..jGOOm b= ' 8 ck 2OppN N 4 MMN2 8VV,' �NrYmrn� m� a � �8rnmw 0 �/ 88 - d _ d ' 8d <t d •' 68" � a' 6 O22b . b O '0 b 20 0p�pQSO ,ene,en weepy v 0 ?d .-N M V)CO CO o V- (11iA/ 00I) uldaCI 1E3910A anis, ORIGINAL OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL/LETTER CHECKLIST WELL NAME ` ( �K' 2Zi/ t ( - PTD# 2y-- ( 003 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: f ( / s X POOL: / 1 Gt t, ,'L i / Circle Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segmenfvf existing well e'f //( 241'� 2 I/ (If last two digits in Permit No. 2— //OZ- ,API No. 50-/O-i -2L)// - /I. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce I inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 8 m a CT Ga Ta - 0 r7 S o m o D p o 7 D a ' -. r 0 3 G) .< co rn _ r 3,0 0o 0o au y m cn(o rn v co v CO C) 0 O 0 X O O O CCD NO CCD O cD 4. m - -I w w w w w CO w w w w N N NJ NJ N N N N N N CO CO V C) C)) A W NJ 0 n CO CO -.I C) CO A w N - O CO CO -.I O) C)1 A w N -, O CO 00 0) Cl> A w N -, O ---1 m Ocncnom Cc * 0Oo000a Dn D0000C -11 Dg 0) mmoo = w * ggcCDmz ,. 0 o ° CD (D (c CD (0 7• 7 0_ Q N Q O) c 0 = 0) CO CD b a Q c 7 (D CD 0 X ED ° v ° ° ° o .(i3 = m CD CA4, 7 m m ° m 0 CD m m m v CD v (T v 3 7• m < 0 o < .o 0, ,0 7 -I -{ -i 0 Q -o
