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Home My WebLink About214-115 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. C% 1-- I Lv Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RE CAN: OVERSIZED: NOTES: olor Items: ❑ Maps: Grayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: Ti Other: BY: Maria Date: /v /s/ WI 9 Project Proofing BY: OCO Date: DI 9 /S /s/ 01P Scanning Preparation x 30 = 1,0 + ay- = TOTAL PAGES' ail . (Count does not include cover sheet) fil BY: Maria Date: a i /s/ Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES !VIP BY: Maria Date: al 1 `'5' /s/ 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 "' 0 . + , C o a o Q E LL (v ,N • • O 0 . • �. ao r� O r " LL •lL a > X + co o Z _� m a C9 0 a a o o X aaai • 0 0 ct J J M 0_ NI 2 Z J j, J O O O O O r j• O O Oo 5 >- (0 N f'� 0) 0)7 M J J c J J c c°. 00 O O J J Lc. 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DATA LOGGED February 1, 2015 M K.BENDER HUGHES -- - To: From: State of Alaska, AOGCC Jesse Salyer 333 West 7th Ave, Suite 100 Baker Hughes INTEQ Anchorage, Alaska 99501 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the final well data for the following well(s): Well: 2K-34L1 Enclosed for each well(s): 1 hardcopy print of final logs • 2MD, 5MD & TVDSS 1 compact disk containing final field data • CGM • PDF • SURVEY • TIFF • LAS I j RECEIVED • STATE OF ALASKA SEP 19 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANE4MCC la Well Status Oil ❑ . Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb Well Class 20AAC 25 105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2 Operator Name 5 Date Comp,Susp, 12 Permit to Drill Number. ConocoPhillips Alaska, Inc orAband.: August 19,2014• 214-115/ 3 Address. 6 Date Spudded 13 API Number P.O.Box 100360,Anchorage,AK 99510-0360 August 15,2014• 50-103-20688-60 4a Location of Well(Governmental Section) 7.Date TD Reached 14 Well Name and Number Surface: 116'FSL,94'FEL,Sec.2,T1ON, R8E, UM August 17,2014 , w',lti, 2K-34L1 - Top of Productive Horizon 8. KB(ft above MSL). . 143'RKB 15 Field/Pool(s) 346'FSL, 1915'FEL,Sec.3,T1ON, R8E, UM GL(ft above MSL): 115.8'AMSL Kuparuk River Field . Total Depth: 9.Plug Back Depth(MD+TVD)- 576'FSL,997'FWL, Sec. 3,T1 ON,R8E, UM 12330'MD/6207'TVD Kuparuk Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27) 10.Total Depth(MD+TVD) 16 Property Designation Surface: x-498310 y- 5938420 Zone-4 •12397'MD/6201'TVD ADL 25588,25589 , TPI: x-491210 y- 5938655 Zone-4 11.SSSV Depth(MD+TVD) 17 Land Use Permit. Total Depth: x-488842 y- 5938888 Zone-4 nipple @ 643'MD/642'TVD 2674,2675 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) 1600'MD/1440'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 9955'MD/6170'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 164.8# A-106 28' 104' 28' 104' 42" driven 10.75" 45.5# L-80 28' 3543' 28' 2876' 13.5" 1338 sx ArcticLiteCRETE, 198 sx Class G 7" 26# L-80 26' 9248' 26' 5978' 8 5" 289 sx Class G 4.5" 12.# L-80 8979' 10117' 5906' 6215' 6.125" 195 sx Class G 2.375" 4.6# ST-L 9952' 12330' 6170' 6207' 3" slotted liner 24 Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom,Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MDITVD) F.__ 3.5" 9025' 8979'MD/5906'TVD slotted liner 9953'-12330'MD 6170'-6207'TVD ` AMP,pl Iat—i t 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC ( Was hydraulic fracturing used during completion? Yes❑ No Q DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 3460'-3575' 91 sx Class G 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) waiting on facility tie-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 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q ., Sidewall Cores Acquired? Yes ❑ No O ' 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 ABC MS OCT - 1 2014A\ Form 10-407 Revised 10/2012 CONTINUED ON REVERSE 7)/4h II36I1C- Submit original only VTC- I/21`' S //. /%, G • 29 GEOLOGIC MARKERS(List all formations and mai. ,;ncountered) 30 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1600' 1440' needed,and submit detailed test information per 20 AAC 25.071 Kuparuk A4 9955' 6170' Kuparuk A5 10492' 6170' Kuparuk A4 10561' 6171' Kuparuk A5 12359' 6201' N/A Formation at total depth: Kuparuk A5 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: James Ohlinger @ 265-1102 Email: James J.Ohlinqerconocophillips corn Printed Name D Venhaus Title CTD Supevising Engineer 947-10 Signature 0; �� Phone 263-4372 Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28 Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • II b 11 co co p ,-L i EN 11 CD 11 F-- c.. 11 o rn `m I1 co I I m N o � Y in o J E 4_ 11 _ co r- 2 M g O 0 11 N p ma. Y p O O II m 0 a u) E co Y NI— CO I— H Yo p N M II aoo � @) 0 II J r CZ 00 E CO (N N- 0 a) c3) II o 0 O m co g II N ,— O °' Yco (J II t3U ol —, Y >-SS • os 0`0 Y `-) II N a) o -3 v -- m a) `n mm � H v n (13 C o 9 E co co aYm ;+_ © I- _ © co n_ `w Y I I rn TD_ CO 0) Q coo ,_ m II o Z D 0 c aa) = a) J C) cis f) cn W 2 m u) u' CL a x LLJ m p o Y p 3 N .0-L N m p 11 o °, o � o Z _ � W II U J U � U O r- (/) N- 0 I1 � CO (B co a3 U Qx � X0 OCL II U o Ooo U o 0inTx) inm co II N N N (O N -64- L- 0 C _ Y Y Y * v O i i i � i i43 co a3 0 coa) a) M M MI- co Co J co co co co (V O 03 1— c CO \l H r11•i t i Ili, \I. cnp 0 w ► . . m coo :Ex o Mitt' Lt ,..4„), z-,1O CD -4-< 0) a a Y a) Y m O U 0 U 21Q 4t Co N c`oog v v m g a) CO 0 co O U) O L ti • KUP PROD 2K-34L1 COnOCOPhillips a • Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(^) MD(ftKB) Act She(ftKB) a.rxcn.Ilp, 501032068860 KUPARUK RIVER UNIT PROD 95.72 12,324.97 12,330.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) –Rig Release Date 2K-34L1,9/16/2014 8:3859 AM Last WO: 27.33 6/23/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason ADD LATERAL haggea 9/16/2014 HANGER;23.5 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ..........................................................._.. l LINER L1 23/8 1.990 9,951.9 12,330.0 6,206.6 4.60 STL 2.375 1 IL Liner Details Nominal ID .... ... Top(ftKB) Top(TVD)(ftKB) Top Inc'r) Item Des Com (in) 9,951.9 6,169.5 74.10 DEPLOY SHORTY DEPLOYMENT SLEEVE 1 000 1 Perforations&Slots � Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 9,952.7 12,329.6 6.169.7 6,206.6 A-4,2K-34L1 8/18/2014 SLOTS Slotted Liner CONDUCTOR;28.040404 • Notes: 8.01040- Notes:General&Safety End Date Annotation NIPPLE;643.3 i 8/18/2014 NOTE:ADD LATERAL L1 as GAS LIFT;3,021.1 SURFACE;28.3-3,5430 GAS LIFT;5,097.1 c_ a GAS LIFT;6.58.9.8 t� GAS LIFT;7.705.63 GAS LIFT;8,875.5 C1 NIPPLE;8,935.7 LOCATOR;8.983.6 • SEAL ASSY;8,984.9 $ s INTERMEDIATE;25.8-9,247.7 A a !PERF;9,9550-9.960.0— LINER; ,955.0-9,960.0 LINER;8.9792-10.117.0 SLOTS;9.962.7-12.329.6 LINER Lt;9,951.9-12,330.0 ConocoPhilli s Time Log & Summary p We/Mew Web Reporting Report Well Name: 2K-34 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 5/25/2014 10:00:00 AM Rig Release: 6/24/2014 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/24/2014 24 hr Summary Released from rig maintenance @ 12:00 hrs. Rig down,separate modules and begin moving from 2B pad to 2K-34. Made notification to AOGCC of upcoming diverter test. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Release from rig maintenance @ 12:00 hrs,disconnect electrical and steam lines. Trucks arrived at 15:00 hrs. Pull apart rig mods. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Begin moving rig mods to 2K pad, pipe sheds and rock washer. Sub departed 2B pad @ 20:30 hrs. X5/25/2014 Move rig from 2B pad to 2K-34, rig up and accept rig @ 10:00 hrs. R/U diverter, load pipe shed and P/U 5" DP. 00:00 03:30 3.50 0 0 MIRU MOVE MOB P Spot sub base and pit complex over well 2K-34. 03:30 04:30 1.00 0 0 MIRU MOVE MOB P Mobilize pump room, motor room and boiler complex for 2B pad to 2K pad. 04:30 07:30 3.00 0 0 MIRU MOVE MOB P Spot power pack, rock washer and pipe shed. 07:30 08:30 1.00 0 0 MIRU MOVE RURD P Plug in electrical lines, hook up steam, air fuel and water. 08:30 10:00 1.50 0 0 MIRU MOVE RURD P PJSM,Work on rig accetance check list and test gas alarms. Rig Accepted at 10:00 hours. 10:00 12:00 2.00 0 0 MIRU DRILL NUND P PJSM, Nipple up diverter and install 4"valves on conductor. 12:00 14:00 2.00 0 0 MIRU DRILL NUND P PJSM, continue N/U diverter. 109' from well to end of diverter, 90'from cellar wall to end of diverter. 14:00 18:00 4.00 0 0 MIRU DRILL RURD P Take on Drilplex mud, load pipe shed with 103 jts 5"DP, 17 jts HWDP, R/U envirovac, instqall mouse hole, install elevators. 18:00 20:00 2.00 0 0 MIRU DRILL RURD P Strap DP, HWDP and DC in pipe shed, continue on-loading mud, R/U to P/U DP. 20:00 00:00 4.00 0 0 MIRU DRILL PULD P PJSM, P/U 30 stands 5"drill pipe via mouse hole. 35/26/2014 Complete P/U pipe. Perform diverter and accumulator test,witness waived by AOGCC Bob Noble. M/U BHA #1 and clean out to 130' MD. M/U drilling BHA, adjust motor to 1.5°, directional drill to 746' MD taking Gyro surveys. 00:00 01:00 1.00 0 0 MIRU DRILL PULD P PJSM, P/U 4 stands of 5"DP and 6 stands of 5"HWDP. Page 1 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:30 0.50 0 0 MIRU DRILL BOPE P Perform diverter test: system pressure=2900 psi, pressure after closing= 1800 psi,200 psi recharge= 42 sec, full pressure after 168 sec. Time to knife valve open= 10 sec, time for annular to close= 18 sec. Witness of test waived by AOGCC rep Bob Noble. 01:30 03:30 2.00 0 0 MIRU DRILL RURD P Load pipe shed with SLB tools and pick up tools from ground via beaver slide. 03:30 05:00 1.50 0 0 SURFA( DRILL PULD P PJSM, M/U BHA#1 as per SLB rep. 05:00 05:45 0.75 0 0 SURFA( DRILL RURD P Flood conductor, R/U and pressure test surface equipment to 5000 psi, good. 05:45 08:15 2.50 0 130 SURFA( DRILL DRLG P Drill out conductor with 0°bent in motor. Drill f/30'MD to 130' MD pump @ 450 gpm,400 psi, 86% flow, 20-30 rpm's. 08:15 09:00 0.75 130 30 SURFA( DRILL TRIP P PJSM, POOH f/130'MD to 30'MD. 09:00 09:45 0.75 30 30 SURFA( DRILL PULD P Adjust motor bend to 1.5°as per SLB rep. 09:45 11:15 1.50 30 30 SURFA( DRILL PULD T Trouble shoot Gyrodata tools- SIMOPS, P/U 3 joints of drill collars. 11:15 12:15 1.00 30 60 SURFA( DRILL PULD P PJSM, P/U BHA#2 as per SLB rep. 12:15 14:00 1.75 60 130 SURFA( DRILL PULD P PJSM, Continue P/U BHA#2 14:00 14:30 0.50 130 130 SURFA( DRILL SRVY P RIH tag bottom, Take Gyro survey, shallow pulse test @ 450 gpm, 500 psi. 14:30 16:00 1.50 130 243 SURFA( DRILL DRLG P Drill from 130'MD to 243' MD @ 40 rpm, 1k TQ,450 gpm @ 500 psi, 86%Flow out. (SIMOPS on L/D single and rack back stand.) 16:00 16:30 0.50 243 243 SURFA( DRILL PULD P POOH with single, rack back 1 stand. P/U flex collars and saver sub, P/U stand HWDP. Establish parameters. 16:30 00:00 7.50 243 746 SURFA( DRILL DDRL P Directional drill from 243'MD to 746' MD, 746'TVD.ART=2.77, AST=2.76,ADT=5.53,Jar Hrs=29.23, Bit Hrs=5.53, P/U=74k, S/O=74k, ROT=74k,Tq on/off=4/1k ft lbs,WOB=5-25k, ECD=10.76, 56%Flow out, 60 rpm,493 gpm @ 900 psi. Reduced rpm to 60 per Gyrodata for tool. No recordable losses. 05/27/2014 Continued directional drilling 13 1/2" surface hole section from 746-2159'MD,2013'TVD. Page 2 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 746 1,141 SURFA( DRILL DDRL P Directional drill from 746' MD to 1141' MD, 1131'ND.ART=1.87, AST=2.08,ADT=3.95, Jar Hrs=33.18, Bit Hrs=9.48, P/U=87k, S/O=82k, ROT=85k,Tq on/off=6/3k ft lbs,WOB=15-20k, ECD=10.32, 64% Flow out, 60 rpm, 500 gpm @ 1000 psi. No recordable losses. 06:00 12:00 6.00 1,141 1,419 SURFA( DRILL DDRL P Directional drill from 1141' MD to 1419'MD, 1398'TVD.ART=.72, AST=2.97,ADT=3.69,Jar Hrs=36.87, Bit Hrs=13.17, P/U=93k, S/O=83k, ROT=88k,Tq on/off=7/3k ft lbs,WOB=20-25k, ECD=10.65, 84%Flow out,60 rpm, 500 gpm @ 1100 psi. Observing loss—8 bph,total for tour 55 bbls. 12:00 18:00 6.00 1,419 1,753 SURFA( DRILL DDRL P Directional drill from 1419'MD to 1753'MD, 1714'TVD.ART=.95, AST=3.4,ADT=4.35,Jar Hrs=41.22, Bit Hrs=17.52, P/U=97k, S/O=88k, ROT=92k,Tq on/off=4/2k ft lbs, WOB=5-15k, ECD=10.41, 71% Flow out, 60 rpm,607 gpm @ 1300 psi. 18:00 00:00 6.00 1,753 2,159 SURFA( DRILL DCSG P Directional drill from 1753' MD to 2159' MD,2013'TVD.ART=1.71, AST=2.15,ADT=3.86, Jar Hrs=45.08, Bit Hrs=21.38, P/U=104k, S/0=90k, ROT=95k,Tq on/off=4/2k ft lbs,WOB=5-25k, ECD=10.52, 87% Flow out,60 rpm, 604 gpm @ 1400 psi. 35/28/2014 Directional drilled from 2159'-3590'MD, 2909 TVD.Circulate surface to surface 2X. OWFF&backream out of hole to 3090'MD. 00:00 06:00 6.00 2,159 2,530 SURFA( DRILL DDRL P Directional drill from 2159' MD to 2530'MD, 2285'ND.ART=1.42, AST=2.10,ADT=3.52,Jar Hrs=48.60, Bit Hrs=24.90, P/U=106k, S/0=91k, ROT=98k,Tq on/off=6/3k ft lbs,WOB=15-20k, ECD=10.32, 59%Flow out, 60 rpm, 608 gpm @ 1710 psi. 06:00 12:00 6.00 2,530 2,994 SURFA( DRILL DDRL P Directional drill from 2530'MD to 2994' MD, 2562'TVD.ART=2.98, AST=1.13,ADT=4.11, Jar Hrs=52.71, Bit H rs=29.01, P/U=109k, S/O=88k, ROT=96k,Tq on/off=6/5k ft lbs,WOB=20-25k, ECD=10.72, 66%Flow out,60 rpm, 650 gpm @ 1850 psi. Page 3 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 2,994 3,455 SURFA( DRILL DDRL P Directional drill from 2994' MD to 3455'MD,2830'TVD.ART=3.35, AST=.32,ADT=3.67, Jar Hrs=56.38, Bit Hrs=32.68, P/U=115k, S/O=91k, ROT=100k,Tq on/off=8/4k ft lbs, WOB=5-25k, ECD=10.85, 84% Flow out, 80 rpm,750 gpm @ 2475 psi. 18:00 21:00 3.00 3,455 3,590 SURFA( DRILL DDRL P Directional drill from 3455'MD to 3590'MD,2908'TVD.ART=1.60, AST=0,ADT=1.6,Jar Hrs=57.98, Bit Hrs=34.28, P/U=120k, S/O=93k, ROT=101 k,Tq on/off=7/4k ft lbs, WOB=5-20k, ECD=10.46, 80% Flow out, 80 rpm, 755 gpm @ 2475 psi. 21:00 22:30 1.50 3,590 3,590 SURFA( CASING CIRC P Circulate surface to surface 2X @ 650 gpm, 1850 psi,60 rpm, 5k tq, FO 60%. 22:30 23:00 0.50 3,590 3,590 SURFA( CASING OWFF P Monitor well, losses observed, calculated 18 BPH. 23:00 00:00 1.00 3,590 3,090 SURFA( CASING REAM P BROOH from 3590'-3090' MD, 650 gpm, 1750 psi, 60 rpm, 6k tq, FO 60 %, calcualted 3.75, actual 33 bbls, 30 bbls loss 05/29/2014 BROOH from 3090'-1698' MD. Hole unloaded&exceed surface equipment capacity. Clean up&stage up pumps.Whlie staging up pumps tagged up at 1647'MD. Made several attempts to get back in the hole.Tried to slide back into the original hole with gyro&MWD surveys confirming, not in original wellbore. Decision made to sidetrack and obtain wellbore seperation. Directional drill from 1882'-2380'MD, 2161'TVD. 00:00 01:45 1.75 3,090 1,698 SURFA( CASING REAM P BROOH f/3090'MD to 1698'MD. Began BROOH @ 650 gpm, hole taking 30 bbls for 5 stands pulled. Slowed pumps to 450 gpm= 1430 psi, hole still taking 16 bbls for 5 stands pulled. Rotate @ 60 rpm's with 5K Tq. 01:45 03:45 2.00 1,698 1,698 SURFA( CASING OTHR T Observed hole unloading cuttings at a high rate, unable to process the large amount of cutting on surface equipment. Shut down, unpack and clean flow line, possum belly. Stage pumps back up to 450 gpm. 03:45 05:00 1.25 1,698 1,647 SURFAC CASING REAM T Pick up f/1698'MD to 1607'MD, work string down.Tagged up @ 1647'MD. Set down 15K two times. P/U and line up tool face high side, pump @ 2 bpm and attempt to slack-off.Attempt to slack-off w/5 rpm's and no pump, no success. Attempt to rotate @ 5 rpm's, pump @ 2 bpm, no success. Increase rotary to 60 rpm's and pump @ 2 bpm, no success. Unable to work past 1647'MD. Page 4 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:45 0.75 1,647 1,662 SURFA( CASING DDRL T Attempt to re-enter wellbore by pumping @ 300 gpm=950 psi,60 rpm's,Tq=4K, 10K WOB.All inductions point that new hole was drilled to 1662'MD. P/U to 1640'MD, had to set down 20K to get past 1647'MD. 05:45 06:45 1.00 1,662 1,662 SURFA( CASING CIRC T P/U and work pipe, pump©2 bpm=200 psi, P/U=96K, S/O=90K. Discuss options with town. 06:45 09:30 2.75 1,662 1,793 SURFA( CASING DDRL T Slide 10L f/1662'MD to 1698'MD, pump @ 450 gpm=850 psi,63% flow. Perform Gyro survey, Gyro tool 8'into sidetrack. Data showed we are 1/2° low and 1° R of original wellbore. Slide @ 40L f/1698' MD to 1750'MD to attempt to intersect original wellbore. Shoot Gyro survey @ 1750'MD, Drill ahead f/1750'MD to 1793' MD, pump @ 500 gpm, 1000 psi,63%flow,60 rpm's,6K Tq. 09:30 11:15 1.75 1,793 1,515 SURFA( CASING REAM T BROOH @ 510 gpm=850=1050 psi, 60 rpm's f/1793'MD to 1603'MD, observed high and erratic torque @ 1647'MD. Shut down rotary and pumps,worked though trouble zone @ 1647' MD multiple times, good. POOH to 1515' MD on elevators. 11:15 11:30 0.25 1,515 1,790 SURFA( CASING TRIP T Trip in to hole f/1515' MD to 1790' MD. No tight hole observed. 11:30 12:00 0.50 1,790 1,790 SURFA( CASING SRVY T Survey hole, Discuss plan forward to re-drill surface hole f/1647'MD to TD 12:00 13:30 1.50 1,790 1,882 SURFA( CASING DDRL T Directional drill from 1790'MD to 1882' MD, 1802'TVD. P/U=100k, 5/0=89k, ROT=95k, Tq on/off=6/4k ft lbs,WOB=10-25k, ECD=10.18, 62%Flow out, 60 rpm, 500 gpm @ 1150 psi. 13:30 15:00 1.50 1,882 1,882 SURFA( CASING SRVY T POOH from 1882'- 1697' MD,taking MWD surveys at 1759', 1744', 1697' MD.Wash back to 1882'MD& consult with town to drill ahead to obttain wellbore seperation. 15:00 18:00 3.00 1,882 2,160 SURFA( CASING DDRL T Directional drill from 1882'MD to 2160'MD,2025'TVD.ART=1.58, AST=2.11,ADT=3.69,Jar Hrs=61.67, Bit Hrs=37.97, P/U=103k, S/O=89k, ROT=95k, Tq on/off=6/3k ft lbs,WOB=5-30k, ECD=10.35, 71%Flow out, 60 rpm, 648 gpm @ 1600 psi. Page 5 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:45 3.75 2,160 2,344 SURFA( CASING DDRL T Directional drill from 2160' MD to 2344'MD,2161'TVD.ART=.38, AST=1.41,ADT=1.79,Jar Hrs=63.46, Bit Hrs=39.76, P/U=106k, S/0=90k, ROT=97k, Tq on/off=5/2k ft lbs,WOB=5-30k, ECD=10.21, 71% Flow out,60 rpm, 651 gpm @ 1650 psi. 21:45 23:00 1.25 2,344 2,344 SURFA( CASING SFTY T Remove ice build up from derrick. 23:00 00:00 1.00 2,344 2,380 SURFA( CASING DDRL T Directional drill from 2344' MD to 2380'MD, 2161'TVD.ART=0, AST=1,ADT=1, Jar Hrs=64.45, Bit Hrs=40.75, P/U=106k, S/0=90k, ROT=97k,Tq on/off=8/4k ft lbs, WOB=5-25k, ECD=10.28, 71% Flow out, 70 rpm,650 gpm @ 1650 psi. 05/30/2014 While drilling at 2380' MD,encounter a hard spot.While trying varying parameters to make it drill, noticed indications that we might be hanging up on a stabilizer up the string. Racked back a stand and reamed 2349'-2257' MD. Tagged up at 2305'on second full ream. Made several attempts to re-enter hole without pumps. Lined up tool face directionally and stacked 35k on string,with pumps and slid ahead with no differential psi into well bore. Reamed clean and confirmed position with survey. Drilled to TD,from 2383-3555' MD,2882 TVD. CBU 3X&OWFF 30 min. 00:00 00:30 0.50 2,380 2,383 SURFA( CASING DDRL T Directional drill from 2380'MD to 2383'MD,2161'TVD.ART=.5, AST=0,ADT=.5,Jar Hrs=66.10, Bit Hrs=42.40, P/U=106k, S/0=90k, ROT=97k,Tq on/off=5/4k ft lbs, WOB=5-30k, ECD=10.21, 71% Flow out, 60 rpm,650 gpm© 1650 psi. 00:30 02:30 2.00 2,383 2,383 SURFA( CASING DDRL T No progress making hole.Try varying parameters 40-70 rpm, 5-35k WOB, 650 gpm, 1650 psi,with no success. Conditions indicated stab was hanging up a stand up the hole. 02:30 03:30 1.00 2,383 2,305 SURFA( CASING REAM T Rack one stand back and ream from 2349'-2257'MD. On second ream down tagged up at 2305'MD. Made several attempts to get back into hole with no pumps on(stacking weight&lining up tool face). Pick up away from tag point and shoot survey to confirm location. 03:30 05:45 2.25 2,305 2,383 SURFA( CASING REAM T Line up tool face for directional and slide from 2305'-2349'MD,stacking 30k WOB,650 gpm, 1500 psi. Observed no differential psi while sliding. Shot survey to confirm correct position. Reamed from 2300'-2383'MD(650 gpm, 1500 psi, 60 rpm, 3-9k tq.)&shot survey to confirm correct position. Page 6of34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 12:00 6.25 2,383 2,665 SURFA( CASING DDRL T Directional drill from 2383'MD to 2665'MD,2368'TVD.ART=1.60, AST=2.52,ADT=4.12, Jar Hrs=72.15, Bit Hrs=48.45, P/U=111 k, S/0=86k, ROT=96k, Tq on/off=7/4k ft lbs,WOB=15-20k, ECD=10.42, 60%Flow out, 60 rpm, 650 gpm @ 1680 psi. 12:00 18:00 6.00 2,665 3,238 SURFA( CASING DDRL T Directional drill from 2665' MD to 3238' MD, 2696'TVD.ART=2.94, AST=1.33,ADT=4.27, Jar Hrs=76.42, Bit Hrs=52.72, P/U=115k, S/0=91k, ROT=99k,Tq on/off=8/4k ft lbs,WOB=25-30k, ECD=10.64, 69% Flow out, 80 rpm, 670 gpm @ 1900 psi. 18:00 21:30 3.50 3,238 3,555 SURFA( CASING DDRL T Directional drill from 3238' MD to 3555'MD, 2883'TVD.ART=1.98, AST=0,ADT=1.98,Jar Hrs=78.40, Bit Hrs=54.70, P/U=120k, 5/0=94k, ROT=100k, Tq on/off=8/5k ft lbs, WOB=15-20k, ECD=10.50,70% Flow out, 80 rpm,700 gpm @ 2200 psi. 21:30 23:30 2.00 3,555 3,555 SURFA( CASING CIRC T CBU 3X with rotation and recipication. 720 gpm, 2200 psi, 80 rpm, 5-6k Tq, PU 120K, SO 91K, & ROT 101K. 23:30 00:00 0.50 3,555 3,555 SURFAC CASING OWFF T Monitor well, static 35/31/2014 BROOH from 3555'-1886'MD.At 2534'MD a large amount of clay exceeded the capacity of our surface equipment. Shut down to clear. POOH on elevators from 1886-1515 MD. RIH from 1515-3460' MD. CBU 3X& OWFF. POOH to surface laying down BHA. Flushed stack of clay and made a dummy run with the hanger. Rigged up Tesco casing equipment. Made up shoe and float equipment. 00:00 00:30 0.50 3,555 3,365 SURFA( CASING TRIP T PJSM,Attempt to POOH on elevators, pull 2 stands, pulling tight w/30K OP @ 3365' MD. Decision made to BROOH. 00:30 02:15 1.75 3,365 2,534 SURFAC CASING REAM T BROOH f/3365'MD to 2534'MD. Pump @ 650 gpm= 1800 psi, rotate @ 60 rpm's w/5-6K Tq, 1200 fph string speed. 02:15 05:45 3.50 2,534 2,534 SURFAt CASING OTHR T Cuttings over loaded the flow line and riser, large clay/gravel balls packed off the flow line. Unpack flow line and riser. 05:45 07:30 1.75 2,534 r 1,886 SURFA( CASING REAM T BROOH f/2534'MD to 2164'MD. Pump @ 650 gpm= 1800 psi, rotate @ 60 rpm's w/5-6K Tq, 1200 fph string speed. Slow back reaming speed to 4.5 fpm @ 2164', CBU x 2 to 1886' MD.Actual displacement= 17 bbls, Calculated displacement= 11.7 bbls. Page 7 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 1,886 1,515 SURFA( CASING WPRT T POOH on elevators f/1886' MD to 1515 MD. No overpull observed. Actual displacement=7.14 bbls, _ _ Calculated displacement=3.9 bbls. 08:00 0815 0.25 1,515 1,880 SURFA( CASING WPRT P RIH from 1515'-1880'MD. 08:15 09:15 1.00 1,880 1,880 SURFA( CASING SFTY P Remove ice from derrick. 09:15 10:00 0.75 1,880 3,460 SURFA( CASING WPRT P RIH from 1880'-3460'MD. Smooth trip no problems. Calculated displacement 19.5,actual displacement 20.86. 10:00 10:15 0.25 3,460 3,555 SURFA( CASING REAM P Wash and ream from 3460'-3555' MD,450 gpm, 1250 psi,60 rpm,Tq 5-6K, PU 105K, SO 80K. 10:15 12:15 2.00 3,555 3,450 SURFA( CASING CIRC P CBU 3X @ 650 gpm, 1650 psi, FO 74%, 60 rpm, Tq 5-6K. Lay down single and rack back a stand at each BU. 12:15 12:45 0.50 3,450 3,450 SURFA( CASING OWFF P Monitor well, static. 12:45 15:00 2.25 3,450 790 SURFA( CASING TRIP P POOH on elevators from 3450'-790' MD, PU 117K, SO 90K. Calculated displacement 40.86, actual 65.11 bbls. 15:00 16:00 1.00 790 219 SURFA( CASING TRIP P Stand back HWDP. 16:00 18:30 2.50 219 0 SURFA( CASING PULD P Lay down BHA as per SLB DD. 18:30 20:00 1.50 0 0 SURFA( CASING RURD P Clear BHA from floor and clean up. 20:00 21:15 1.25 0 0 SURFA( CASING RURD P Flush&drain stack. Make dummy run with hanger. 21:15 23:00 1.75 0 0 SURFA( CASING RURD P Rig up Tesco casing equipment. 23:00 00:00 1.00 0 123 SURFA( CASING RNCS P PJSM, make up shoe joint and float equipment. 06/01/2014 RIH with 10 3/4"casing from 123'-720' MD. Started losing returns&could not establish circulation. Decision made to lay down casing till circulation could be established. Bowspring centralizers packed with clay. Stage up pumps and RIH washing each joint down from 123'-3505'MD,stopping several time to CBU&de-ice derrick. Make up hanger&landing joint. Land casing @ 3542'MD.After laying down Tesco CRT&making up cement head could not pick up string. Circulate&condition for cement job. 00:00 00:15 0.25 123 123 SURFA( CASING RNCS P Test float equipment,good. 00:15 02:00 1.75 123 720 SURFA( CASING RNCS P RIH with 10.75"casing from 123'-720' MD. Returns lost to hole and could not establish circulation. Decision made to POOH and establish circulation. 02:00 04:15 2.25 720 123 SURFA( CASING RNCS T POOH from 720'-123'MD. Bowspring centralizers packed with clay. 04:15 04:45 0.50 123 123 SURFA( CASING CIRC T Establish circulation staging the pumps up to 4.5 bpm, 100 psi, FO 45%. 04:45 07:00 2.25 123 720 SURFA( CASING RNCS T RIH from 123'-720' MD,4 bpm, 100psi,45%FO. 07:00 08:30 1.50 720 1,040 SURFA( CASING RNCS P RIH from 720'-1040' MD. Reduce pump rate and running speed to 3 bpm, 75 psi, FO 35%, 180 fph. Page 8 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:00 0.50 1,040 1,040 SURFA( CASING CIRC P CBU staging up pump rate 3-5 bpm, 75-150 psi, FO 35-54%. 09:00 11:00 2.00 1,040 1,802 SURFA( CASING RNCS P RIH from 1040'-1802'MD, 5 bpm, 150 psi, FO 54%. 11:00 12:00 1.00 1,802 1,802 SURFA( CASING CIRC P CBU @ 5 bpm, 210 psi, 54% FO, PU 100K, SO 72K. Losses for tour 295 bbls. 12:00 14:45 2.75 1,802 2,685 SURFA( CASING RNCS P RIH from 1802'-2685'MD, 5 bpm,200 psi. 14:45 15:45 1.00 2,685 2,685 SURFA( CASING SFTY P Remove ice from derrick. Circulate @ 5 bpm =200 psi. 15:45 16:00 0.25 2,685 2,740 SURFA( CASING RNCS P RIH from 2685'-2740'MD, 5 bpm, 200 psi. 16:00 16:45 0.75 2,740 2,740 SURFA( CASING SFTY P Remove ice from derrick, circulate 5 bpm, 250 psi. 16:45 19:15 2.50 2,740 3,505 SURFA( CASING RNCS P RIH form 2740'-3505'MD, 5 bpm, 300 psi. 19:15 21:15 2.00 3,505 3,505 SURFA( CASING CIRC P CBU @ 5 bpm, 300 psi, PU 160K, SO 103K. Pick up cement head& long bales. 21:15 22:45 1.50 3,505 3,542 SURFA( CASING RNCS P Make up hanger&landing joint. Land hanger @ 3542'MD. Lay down Tesco CRT&make up cement head. Calculated displacement 33.05, actual 79.52 bbls. 22:45 00:00 1.25 3,542 3,542 SURFA( CEMEN'CIRC P Circulate&condition mud for cement. Stage up pumps 2-5 bpm, 150-300 psi.Attempt to ricpicate string. Pull 100k over, decision made to leave landed. Losses for tour 127 bbls 36/02/2014 Circulated&conditioned mud for cement job. Cemented 10.75"surface casing as per program, CIP @ 05:00 hrs. Flush stack with retarder pill. Nipple down surface&diverter equipment. Nipple up, orient&test wellhead to 1000 psi for 10 min. Nipple up casing spool&BOPE. Rig up&test BOPE 250/3500 psi, for 5 minutes each. Completed 6 out of 10 tests at 24:00 hrs. Test waived by AOGCC Rep.Jeff Jones. 00:00 01:15 1.25 3,542 3,542 SURFA( CEMEN-CIRC P Circulate&condition mud for cement staging pumps up 6-7 bpm, 300-400 psi, FO 49-54%. Slight losses at 7 bpm. 01:15 01:30 0.25 3,542 3,542 SURFA( CEMEN SFTY P PJSM with all involved parties for cement job. 01:30 05:15 3.75 3,542 3,542 SURFA( CEMEN-CMNT P Pump 5 bbl of water to flood lines. Test cement lines 550&3000 psi. Rig pumps 100 bbls of 10.5 ppg MudPush @ 5 bpm=200 psi. Drop bottom plug. SLB pumped 460 bbls 11.02 ppg of ALC @ 6 bpm=250 psi. SLB pumped 57 bbls of 12 ppg tail cement @ 5 bpm =330 psi. Drop top plug&SLB pumped 10 bbls of water to flush lines. Swap to rig&pump 316 bbls of mud @ 7 bpm=600 psi, to bump top plug. Pressure up to 1100 psi for 5 min, bled off to check floats(good). CIP @ 05:00 hrs. 178 bbls of cement to surface. Page 9 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 06:15 1.00 3,542 3,542 SURFA( CEMEN-RURD P Flush out stack with cement retarder pill. Rig down cement head&landing joint. 06:15 07:15 1.00 3,542 3,542 SURFA( CEMEN'SFTY P Remove ice from derrick. 07:15 12:00 4.75 3,542 3,542 SURFA(WHDBO NUND P Function and wash out surface annular. Nipple down diverter equipment. Sim-op clear floor of casing running tools. 12:00 13:00 1.00 3,542 3,542 SURFA(WHDBO NUND P Prep&install wellhead as per FMC rep. 13:00 14:30 1.50 3,542 3,542 SURFA( WHDBO NUND P Orient&verify wellhead with pad operator.Torque&test well head to 1000 psi for 10 min. 14:30 17:00 2.50 3,542 3,542 SURFA( WHDBO NUND P Nipple up casing spool&BOPE. 17:00 18:00 1.00 3,542 3,542 SURFA( WHDBO NUND P Change out lines on annular&install riser. 18:00 18:45 0.75 3,542 3,542 SURFA( WHDBO NUND P Clear and clean rig floor&cellar. 18:45 20:00 1.25 3,542 3,542 SURFA(WHDBO RURD P Rig up BOPE test equipment. 20:00 00:00 4.00 3,542 3,542 SURFA(WHDBO BOPE P Test BOPE with 5"joint 250/3500 psi,for 5 min each.#1 top VBR's; CV's 1,12,13,14; Manual Kill Line Valve.#2 Upper IBOP; CV's 9, 11; HCR Kill.#3 Lower IBOP; CV's 5,8,10.#4 Dart valve; CV's 4,6,7.#5 FSV; CV 2.#6 HCR Choke&4"Kill Line Demo Valve. AOGCC Jeff Jones waived on 6-1-14 @ 19:10 hrs. 36/03/2014 Finish testing BOPE&rig down. Pick up and stand back 111 joints of 5"DP. Pick up and make up BHA 3. Single in the hole with BHA 3 to 3404'. CBU&test casing to 3000 psi for 30 min. Drill out float equipment, shoe&20'of new hole to 3575'MD. CBU&rack back one stand. Rig up&perform LOT to a 14.0 ppg EMW. Shut in pressure, bled down to 190 psi. Confer with town and decide to perform second test. LOT to 13.4 ppg EMW. Shut in pressure bled down to 115 psi. Confer with town,decide to POOH to RIH&squeeze cement. Monitor well&POOH from 3401'-1100'MD. 00:00 01:45 1.75 3,542 3,542 SURFA( WHDBO BOPE P Test BOPE with 5"joint 250/3500 psi,for 5 min each.#7 Manual Choke Vavle&HCR Kill.#8 Annular Preventer.#9 Lower VBR's.#10 Blind Rams&CV 3.Accumulator Test: Initial System Psi=2900 psi; After Closure= 1650 psi;200 psi Attained=40 sec; Full psi Attained = 188 sec. 5 Nitrogen bottles averaged 2150 psi.Test waived by AOGCC Jeff Jones waived on 6-1-14 @ 19:10 hrs. 01:45 02:45 1.00 3,542 3,542 SURFA( WHDBO RURD P Rig down test equipment, blow down TD&all lines. Install wear ring 10.125". 02:45 03:15 0.50 0 0 SURFA( CEMEN-RURD P Mobilize tools to rig floor&install mouse hole. 03:15 06:30 3.25 0 0 SURFA( CEMEN PULD P Pick up 111 joints(37 stands)&rack back in the derrick. Page 10 of 34 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:30 07:00 0.50 0 0 SURFA( CEMEN"RURD P Clear&clean rig floor. Mobilize BHA to rig floor. 07:00 09:00 2.00 0 724 SURFA( CEMEN-PULD P Pick up&make up BHA 3, as per SLB DD. 09:00 09:45 0.75 724 724 SURFA( CEMEN-DHEQ P Shallow pulse test MWD&Power Drive @ 470 gpm,975 psi, FO 53%. 09:45 10:15 0.50 724 724 SURFA( CEMEN-SVRG P Service Rig 10:15 12:45 2.50 724 3,404 SURFA( CEMEN-PULD P Single in the hole from 724'-3404', calculated displacement 28.2; actual 22.4 bbls. 12:45 13:45 1.00 3,404 3,404 SURFA( CEMEN CIRC P CBU @ 500 gpm = 1300 psi. 13:45 14:15 0.50 3,404 3,404 SURFA( CEMEN"RURD P Rig up to test casing. 14:15 14:45 0.50 3,404 3,404 SURFA( CEMEN-PRTS P Test 10 3/4"surface casing to 3000 psi for 30 min. 14:45 15:15 0.50 3,404 3,455 SURFA( CEMEN-COCF P Wash&ream from 3404'-3455'MD, 475 gpm, 1200 psi, 30 rpm,6-10K Tq, PU 112K, SO 82K, ROT 92K. 15:15 18:00 2.75 3,455 3,462 SURFA( CEMEN-DRLG P Drill out float equipment from 3455'-3462' MD,475 gpm, 1200 psi, 20-50 rpm,6-10k Tq,WOB 10-20K. 18:00 19:30 1.50 3,462 3,575 SURFA( CEMEN-DRLG P Drill cement,shoe, &20'of new hole from 3462'-3575'MD, 550 gpm, 1700 psi, 50-60 rpm, Tq 5-8K,WOB 5-12 K. 19:30 20:00 0.50 3,575 3,501 SURFA( CEMEN-CIRCP CBU 550 gpm, 1600 psi, PU 120K, SO 82K, ROT 82K, 80 rpm, 5-8k Tq. Rack a stand back. SPR @ 3501'MD 2869'TVD, MW 9.8 ppg, 22:15 hrs. #1 @ 30= 130; @ 40=220 #2 @ 30= 140; @ 40=220 20:00 20:15 0.25 3,501 3,501 SURFA( CEMEN RURD P Rig up test equipment for LOT. 20:15 22:00 1.75 3,501 3,501 SURFA( CEMEN'LOT P Perform LOT to 14.0 ppg EMW. Shut in pressure bled down to 190 psi. Confer with town and decide to perform second test. LOT to 13.4 ppg EMW. Shut in pressure bled down to 115 psi. Confer with town, decide to POOH to RIH&squeeze cement. 22:00 22:30 0.50 3,501 3,501 SURFA( CEMEN-OWFF T Monitor well, static. 22:30 00:00 1.50 3,501 1,100 SURFA( CEMEN-TRIPT POOH from 3501'-1100'MD, PU 60K, SO 59K. Calculated displacement 15, actual 17.68 bbls. 06/04/2014 Finish POOH to surface. Rig up and test with 3.5"test joint. Rig up&pick up-900'of 3.5"tubing. RIH with tubing on 5"DP to 3575'MD. Lay 200'cement plug around casing shoe, POOH to 3000'MD&squeeze. POOH from 3000'-970'MD. Lay down tubing from 970'-538'MD. 00:00 00:15 0.25 1,100 724 SURFA( CEMEN-TRIP T POOH from 1100'-724'MD. Monitor well,static 00:15 01:00 0.75 724 0 SURFA( CEMEN-PULD T Rack back HWDP, DC, BHA 3. Lay down stab&bit. Calculated displacement 23.67, actual 23.46 bbls. Page 11 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:15 0.25 0 0 SURFA( CEMEN-RURD T Clear&clean rig floor. 01:15 01:30 0.25 0 0 SURFA( CEMEN-BOPE T Drain stack, pull wear bushing, & R/U to test 3.5"tubing. 01:30 03:30 2.00 0 0 SURFA( CEMEN-BOPE T Test 3.5"joint to 250/3500 psi for 5 min each test.Annular, upper& lower VBR's were tested. 03:30 04:00 0.50 0 0 SURFA( CEMEN BOPE T Rig down test equipment,drain stack, install 10.125"wear bushing. 04:00 05:00 1.00 0 0 SURFA( CEMEN RURD T Rig up tubing handling equipment. 05:00 06:30 1.50 0 939 SURFA( CEMEN-PULD T Pick up&RIH 3.5"8rd EUE tubing from surface to 939'MD. 06:30 06:45 0.25 939 939 SURFA( CEMEN RURD T Change out handling equipment to 5". 06:45 08:15 1.50 939 3,531 SURFA( CEMEN-TRIP T RIH from 939'-3531'MD, rig up cement lines. Calculated displacement 25.02, actual 21.7 bbls. 08:15 09:15 1.00 3,531 3,575 SURFA( CEMEN CIRC T Wash down from 3531'-3575'MD& condition mud for cement @ 7 bpm, 525 psi, FO 40%. 09:15 12:45 3.50 3,575 3,575 SURFA( CEMEN-OTHR T Wait on SLB cementers. 12:45 15:30 2.75 3,575 3,575 SURFA( CEMEN'RURD T Rig up cementer&condition mud 300 gpm,400 psi. 15:30 15:45 0.25 3,575 3,575 SURFA( CEMEN-RURD T SLB pump 3 bbls H2O, psi test cement lines 400&2500 psi. 15:45 16:30 0.75 3,575 3,575 SURFA( CEMEN CMNT T SLB Batch up&pump 13.4 bbls of 10.5 ppg MudPush, 18.7 bbls of 15.8 cement, &3 bbls of 10.5 MudPush to clear lines. Swap to Rig pumps and chase with 47 bbls of 9.7 ppg mud. 16:30 17:15 0.75 3,575 3,000 SURFA( CEMEN-TRIP T POOH from 3575'-3000'MD, running speed 3 min per stand. 17:15 17:30 0.25 3,000 3,000 SURFA( CEMEN-CIRC T Circulate pipe volume at 250 gpm, 130 psi. 17:30 17:45 0.25 3,000 3,000 SURFA( CEMEN'RURD T Rig up head pin, valves, &cement line for squeeze job. 17:45 19:30 1.75 3,000 3,000 SURFA( CEMEN SQEZ T Pressure up well bore to 500 psi& shut in. Bring psi back up from 250 to 500 psi&shut in several times. Confer with town and decide to psi up to 600 psi and shut in for 10 min, pressuring back up every 10 min. This was repeated till cement thickening time reached a 70 Bc.6 bbls of cement squeezed away, 1/2 barrel bled back after pressure release. 19:30 20:30 1.00 3,000 3,000 SURFA( CEMEN CIRC T CBU @ 500gpm, 500 psi, PU 80K, SO 68K 20:30 20:45 0.25 3,000 3,000 SURFA( CEMEN'OWFF T Monitor well, static. 20:45 22:15 1.50 3,000 970 SURFA( CEMEN-TRIP T POOH from 3000'-970'MD. 22:15 22:45 0.50 970 970 SURFA( CEMEN-RURD T Change out handling equipment from 5"to 3.5". Page 12 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 970 538 SURFA( CEMEN-PULD T Lay down 3.5"tubing from 970'-538' MD 06/05/2014 RIH with BHA 4.Tag TOC @ 3457'MD&cleaned out cement to 3575' MD. Perform FITto EMW 14.7 ppg. Drill 20'of new hole and perform LOT to EMW 14.3 ppg. Drill ahead from 3595'-4517'MD. 00:00 00:30 0.50 538 0 SURFA( CEMEN-PULD T Lay down 3.5"tubing from 538'- surface. 00:30 01:30 1.00 0 0 SURFA( CEMEN-RURD T Rig down tubing handling equipment, clear&clean rig floor. 01:30 02:00 0.50 0 0 SURFA( CEMEN'EQRP T Change out SLB psi sensor on gooseneck of standpipe. 02:00 03:00 1.00 0 724 SURFA( CEMEN'PULD T Make up bit&down load MWD. Pick up stab&RIH with remaining BHA, as per SLB Rep. 03:00 03:15 0.25 724 724 SURFA( CEMEN-DHEQ T Shallow pluse test MWD,450 gpm, 925 psi, FO 55%, as per SLB Rep. 03:15 04:00 0.75 724 3,127 SURFA( CEMEN-TRIPT RIH from 724'-3127'MD,fill pipe evey 20 stands. Calculated displacement 37.71,actual 33.6 bbls. 04:00 04:30 0.50 3,127 3,127 SURFA( CEMEN'WOC T Wait on cement to reach 500 psi compressive strength. 04:30 05:15 0.75 3,127 3,457 SURFA( CEMEN-WASHT Wash down from 3127'-3457'MD, 2 bpm, 250 psi, FO 36%.Tagged TOC @ 3457', set 10k down weight. 05:15 06:30 1.25 3,457 3,457 SURFA( CEMEN-CIRC T CBU,450 gpm, 1350 psi 40 rpm,Tq 6k. Slow pumps to 278 gpm, 550 psi to handle thick cement contaminated mud coming back. 06:30 07:45 1.25 3,457 3,575 SURFA( CEMEN-DRLG T Drill out cement plug from 3457'-3575' MD, 350-400 gpm, 775-975 psi, FO 80-85%,40 rpm,Tq 6K. 07:45 08:15 0.50 3,575 3,501 SURFA( CEMEN-CIRC T Circulate&condition @ 464 gpm, 1200 psi, FO 72%,40 rpm,Tq 6K. Rack back one stand. 08:15 08:30 0.25 3,501 3,501 SURFA( CEMEN-RURD T Rig up test equipment for FIT. 08:30 09:30 1.00 3,501 3,501 SURFA( CEMEN-FIT T Preform FIT to a EMW of 14.7 ppg. R/D test equipment. 09:30 10:00 0.50 3,501 3,595 SURFA( CEMEN-DDRL T Make up stand&drill from 3575-3595'MD, 550 gpm, 1650 psi, FO 77%,60 rpm,Tq 7K, PU 117K, SO 83K, ROT 90K. 10:00 10:30 0.50 3,595 3,595 SURFA( CEMEN-CIRCT CBU @ 550 gpm, 1600 psi,40 rpm, Tq 6K. 10:30 11:30 1.00 3,595 3,595 SURFA( CEMEN LOT T Perform LOT to a EMW of 14.3 ppg. 11:30 12:00 0.50 3,595 3,595 INTRMI DRILL RURD T Rig down test equipment, blow down lines, &clear rig floor. 12:00 12:45 0.75 3,595 3,595 INTRM1 DRILL CIRC P Displace wellbore to a 9.6 ppg LSND mud system 500 gpm, 1000 psi. 12:45 18:00 5.25 3,595 4,051 INTRM1 DRILL DDRL P Directional drilling from 3595-4051' MD,3175'TVD,ART=3.49,ADT 3.49,Jars 35.76, Bit 3.49, PU 115K, SO 91K, ROT 105K, Tq on 6-10K, off 4-5K, ECD no info, FO 69%,WOB 10-12K, 130 rpm, 550 gpm, 129 spm, 1525 psi. Page 13 of 34 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 00:00 6.00 4,051 4,517 INTRM1 DRILL DDRL P Directional drilling from 4051'-4517' MD, 3441'TVD,ART=4.53,ADT 4.53, Jars 40.29, Bit 8.02, PU 117K, SO 93K, ROT 105K,Tq on 6-7K, off 4-5K, ECD 11.2, FO 70%,WOB 10-12K, 130 rpm, 575 gpm, 135 spm, 1700 psi. 06/06/2014 Directional drilled from 4517'-6431' MD,4546'TVD. Observed a drilling break @ 6277' MD,4457'TVD,with 35 bbls loss. Shut down to monitor well. Observe well flowing, perform wellbore breathing test. 30 bbls returns with flow decreasing to nothing. Observe wellbore breathing on connections,verify flow steadily decreases. 00:00 06:00 6.00 4,517 5,165 INTRM1 DRILL DDRL P Directional drilling from 4517'MD to 5165'MD, 3815'TVD,ART=4.03, ADT 4.03, Jars 44.32, Bit Hrs 12.05, PU 122K, SO 104K, ROT 113K, Tq on 7-8 K, off 2-3 K, ECD 11.73, FO 72%,WOB 10-15K, 140 rpm, 590 gpm, 138 spm,2020 psi. 06:00 12:00 6.00 5,165 5,592 INTRM1 DRILL DDRL P Directional drilling from 5165'MD to 5592'MD,4061'TVD,ART=3.42, ADT 3.42, Jars 47.74, Bit Hrs 15.47, PU 134K, SO 115K, ROT 118K, Tq on 5-6 K, off 2-3 K, ECD 11.78, FO 70%,WOB 10-15K, 140 rpm, 594 gpm, 138 spm,2125 psi. SPR's 5535' MD,4028'TVD, MW=10.0 ppg, 11:15hrs #1 @ 30=300, @40=370 psi #2 @ 30=300, @40=390 psi 12:00 20:00 8.00 5,592 6,279 INTRM1 DRILL DDRL P Directional drilling from 5592'MD to 6279'MD,4351'TVD,ART=5.54, ADT 5.54, Jars 51.68, Bit Hrs 19.41, PU 135K, SO 114K, ROT 122K, Tq on 5-9 K, off 2-4 K, ECD 11.99, FO 70%,WOB 10-15K, 130 rpm, 595 gpm, 139 spm,2250 psi. SPR's 5999'MD,4296'TVD, MW 10.0ppg, 17:00hrs #1@ 30=280, @ 40=370 psi #2@ 30=290, @ 40=350 psi 20:00 21:15 1.25 6,279 6,279 INTRM1 DRILL OWFF T Observed a drilling break @ 6277' MD,4457'TVD,35 bbl loss, &pump psi decrease. Shut down to monitor well. Observe well flowing, perform wellbore breathing test. 30 bbls returns with flow decreasing to nothing. Decision made to drill ahead and monitor gains&losses very closely. 21:15 00:00 2.75 6,279 6,431 INTRM1 DRILL DDRL P Directional drilling from 6279' MD to 6431' MD,4546'TVD,ART=4.8,ADT 4.8,Jars 54.89, Bit Hrs 22.62, PU 131K, SO 112K, ROT 121K,Tq on 6-9 K,off 3-4 K, ECD 11.71, FO 70%,WOB 10-15K, 130 rpm, 590 gpm, 138 spm,2300 psi. Observe wellbore breathing on connections, verify flow steadily decreases. Page 14 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/07/2014 24 hr Summary Directional drilled ahead from 6431'-6833'. Observed increasing trend with losses. Pump LCM pill&continue to drill ahead with reduced pump rate to manage losses from 6833'-7800' MD, 5328'TVD. 00:00 04:45 4.75 6,431 6,833 INTRM1 DRILL DDRL P Directional drilling from 6431' MD, 4546'TVD to 6833'MD,4692 TVD., ART=3.4,ADT 3.4, Jars 58.3, Bit Hrs 26.03, PU 140K, SO 115K, ROT 125K,Tq on 6-8 K,off 5K, ECD 12.01, FO 60%,WOB 10-15K, 130 rpm, 590 gpm, 138 spm, 2400 psi. 04:45 06:30 1.75 6,833 6,833 INTRM1 DRILL CIRC T Circ. Obtain loss rate.550GPM, 2100PSI, Losses=80 bbl/hr. Mix LCM Pill 06:30 07:45 1.25 6,833 6,833 INTRM1 DRILL CIRC T Pump and spot 67.5 bbl. LCM pill. 5 bpm @ 500 psi. for 1400 stks. Stage up pump to 590 gpm/2500 psi. Loss rate @80 bbl/hr, reduce pump rate to 500gpm/1850 psi. Circ. out LCM pill. 07:45 12:00 4.25 6,833 7,083 INTRM1 DRILL DDRL P Directional drilling from 6833'MD, 4692 TVD to 7083 MD,4923'TVD., ART=3,ADT 3,Jars 61.3, Bit Hrs 29.03, PU 141K, SO 116K, ROT 130K, Tq on 9 K, off 5K, ECD 11.42, FO 49%,WOB 5-10K, 120 rpm, 525 gpm, 122 spm, 2000 psi. Average loss rate 14 bbls/hr after LCM pill. SPR@6923' MD,4831'TVD. MW=10.1, 0900 hrs. #1 @ 30 spm=290 psi.40 spm+360 psi #2 @ 30 spm=290 psi.40 spm=390 psi Mud losses for tour=294 bbls 12:00 18:00 6.00 7,083 7,482 INTRM1 DRILL DDRL P Directional drilling from 7083' MD to 7482 MD, 5153'TVD.,ART=4.29, ADT 4.29,Jars 65.59, Bit Hrs 33.32, PU 151K, SO 124K, ROT 134K, Tq on 7-9 K, off 5-6K, ECD 11.16, FO 65%,WOB 4-9K, 120 rpm, 525 gpm, 122 spm, 2025 psi. Monitor breathing every 200'on trip tank for 15 min. Strap every 5 min to ensure flow back is decreasing, measured loss rate in 5 min increments 10 bph to 3 bph in 15 minutes. Page 15 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 7,482 7,800 INTRM1 DRILL DDRL P Directional drilling from 7482'MD to 7800' MD, 5328'TVD.,ADT 3.25, Jars 68.84, Bit Hrs 36.57, PU 153K, SO 127K, ROT 139K, Tq on 9-10 K, off 5-6K, ECD 11.23, FO 65%,WOB 4-7K, 120 rpm, 525 gpm, 122 spm, 2000 psi. Monitor breathing every 200'on trip tank for 15 min. Strap every 5 min to ensure flow back is decreasing, measured loss rate in 5 min increments 14 bph to 2 bph in 15 minutes. SPR's @ 7760'MD, 5313'ND, MW 10 ppg,23:00hrs #1 @30=310@40=390 psi #2 @ 30=300 @ 40=390 psi 06/08/2014 Directionally drilled from 7800'to the casing drilling point at 9151'MD,5951'ND. Observed a increase in connection gas,decision made to increase MW to 10.4 ppg for trip margin. Pumped a sweep&CBU 3X. Sweep returned to surface at calculated strokes indicating gauged hole. 00:00 06:00 6.00 7,800 8,224 INTRM1 DRILL DDRL P Directional drilling from 7800'MD to 8224'md, 5581'TVD.,ADT 4.93,Jars 73.57, Bit Hrs 41.3, PU 161K, SO 129K, ROT 144K,Tq on 9-10 K, off 5-6K, ECD 11.35, FO 50%,WOB 5-15K, 120 rpm, 525 gpm, 123 spm, 2130 psi. Max gas 102 units 06:00 12:00 6.00 8,224 8,543 INTRM1 DRILL DDRL P Directional drilling from 8224'md to 8543',5756'TVD.,ADT 3.70,Jars 77.27, Bit Hrs 45.0, PU 161K, SO 131K, ROT 145K, Tq on 10-11 K, off 6K, ECD 11.49, FO 52%,WOB 5-10K, 120 rpm, 550 gpm, 129 spm, 2300 psi. Max gas 162 units SPR's @ 8406'MD, 5686'ND, MW 10.1 ppg, 09:30 hrs #1 @ 30=320 @ 40=400 psi #2 @ 30=320 @ 40=390 psi Kick w/Drilling drill @08:00 hrs. CRT=120 sec. 12:00 18:00 6.00 8,543 8,965 INTRM1 DRILL DDRL P Directional drilling from 8543'-8965' MD, 5902'ND.,ADT 4.6, Jars 81.87, Bit Hrs 49.6, PU 163K, SO 134K, ROT 147K,Tq on 10-11 K, off 6-7K, ECD 11.63, FO 61%,WOB 6-10K, 120 rpm, 550 gpm, 129 spm, 2200 psi. Max gas 199 units SPR's©8962'MD, 5901'ND, MW 10.1 ppg, 18:00 hrs #1 @ 30=370 @ 40=470 psi #2 @ 30=370 @ 40=470 psi Page 16 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:15 3.25 8,965 9,151 INTRM1 DRILL DDRL P Directional drilling from 8965'md to 9151', 5951'TVD.,ADT 2.15,Jars 84.02, Bit Hrs 51.75, PU 164K, SO 134K, ROT 147K,Tq on 10-13 K,off 6-7K, ECD 11.75, FO 64%,WOB 5-10K, 120 rpm, 550 gpm, 129 spm, 2300 psi. Max gas 276 units 21:15 00:00 2.75 9,151 9,151 INTRM1 DRILL CIRC P Weight up mud from 10.1 - 10.4 ppg. Pump high vis weighted sweep w/nut plug. Sweep returned on calculated strokes to show hole in guage. CBU 3X @ 550 gpm,2250 psi, 120 rpm, Tq 7k, FO 51%, PU 164K, SO 135K, ROT 148K. Rack back 1 stand when 10.4 ppg went surface to surface. SPR's @ 9151'MD, 5951'TVD, MW 10.4 ppg,23:00 hrs #1 @ 30=370 @ 40=480 psi #2@30=380@40=480 psi 06/09/2014 BROOH to shoe. Circulate hole clean at the shoe. Slip&cut drill line. POOH on elevators&lay down BHA. Pull wear bushing&function test BOPE. Flush stack, recover large portion of 10.75"top plug. Perform dummy run with 7"hanger. 00:00 01:15 1.25 8,966 8,966 INTRM1 CSGDRI OWFF P Observe well @8966' MD.Well static after total of 3 bbls.flowed back 01:15 01:45 0.50 8,966 8,966 INTRM1 CSGDRI OWFF P Observe well. Static 01:45 04:30 2.75 8,966 8,227 INTRM1 CSGDRI REAM P PJSM-BROOH 8,966'MD to 8227' MD. 525 gpm,2150 psi, 120 rpm, 8K TQ. PU 165K, SO 130K, Rot 147K 04:30 05:30 1.00 8,227 8,227 INTRM1 CSGDRI CIRC P CBU @ 8,227 MD to lower ECD's and background gas. Rotate and reciprocate. 525 gpm, 2100psi, 120 rpm,TQ 7K 05:30 10:00 4.50 8,227 5,262 INTRM1 CSGDRI REAM P BROOH 8227'MD to 5262'MD. 525 gpm,2150 psi, 120 rpm, 7K TQ. ECD @ 5262' MD=11.90 ppg. 10:00 10:45 0.75 5,262 5,262 INTRM1 CSGDRICIRC P CBU @ 5,262 MD.to lower ECD's.. Rotate and reciprocate. 500 gpm, 1700psi, 100 rpm,TQ 4K. Reduced ECD to 11.66 ppg. 10:45 12:00 1.25 5,262 4,891 INTRM1 CSGDRI REAM P BROOH 5262'MD to 4891 MD. 525 gpm,1700 psi, 120 rpm,4K TQ. ECD =11.65 ppg.Actual disp=74 bbls. Cal. disp=30 bbl's 12:00 14:15 2.25 4,891 3,500 INTRM1 CSGDRI REAM P PJSM. BROOH 4891 MD to 3500' MD. 525 gpm,1700 psi, 120 rpm,4K TQ. . 14:15 15:45 1.50 3,500 3,500 INTRM1 CSGDRI CIRC P Circulate hole clean @ 525 gpm, 1600 psi. Condition mud from 10.7 ppg to 10.4+ppg at shoe. 15:45 16:45 1.00 3,500 3,500 INTRM1 CSGDRI SLPC P Slip&cut 84'drill line. (Monitor well on trip tank, 1.75 bbl increase in 5 min, .25 bbl increase in 45 minutes. Well static after 1 hr. 16:45 17:15 0.50 3,500 3,500 INTRM1 CSGDRISVRG P Service top drive. Page 17 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 19:30 2.25 3,500 724 INTRM1 CSGDRI TRIP P POOH on elevators from 3500'-724' MD, calculated displacement 38.19, actual 56 bbls. Kick w/Tripping CRT=67sec @ 19:00 hrs 19:30 19:45 0.25 724 724 INTRM1 CSGDRI OWFF P Monitor well,flowed back.25 bbls, static after 5 min. 19:45 20:15 0.50 724 170 INTRM1 CSGDRI TRIP P Rack back HWDP. 20:15 22:00 1.75 170 0 INTRM1 CSGDRI PULD P Lay down BHA 4, as per SLB DD. 22:00 22:15 0.25 0 0 INTRM1 CSGDRI RURD P Clean and clear rig floor. 22:15 22:30 0.25 0 0 INTRM1 CSGDRI BOPE P Function test rams&annular. Pull wear bushing. 22:30 23:30 1.00 0 0 INTRMI CSGDRI RURD P Rig up,flush stack, &rig down. 23:30 00:00 0.50 0 0 INTRM1 CSGDRI RURD P Rig up landing joint and hanger. Perform dummy run with 7" intermediate hanger. 06/10/2014 Change upper rams to 7",test upper rams and annular. R/U Tesco CDS and calibrate. P/U Bit,float equipment and 7"26#L-80 TN Blue casing drilling string, RIH to 5091' MD. 00:00 02:00 2.00 0 0 INTRM1 CASING NUND P PJSM-Change upper pipe rams to 7" 02:00 04:45 2.75 0 0 INTRMI CASING BOPE P PJSM-R/U and test upper pipe rams, 250/3500 psi. Test annular to 250/2500 psi.. Chart test. Sim-ops Tesco Rep rig up torque turn equip. Rig down test equip. 04:45 08:30 3.75 0 0 INTRM1 CASING RURD P PJSM-Rig up Tesco CDS. 08:30 09:00 0.50 0 0 INTRM1 CASING PUTB P Calibrate torque turn, M/U bit and wearsox centralizer joint. 09:00 10:30 1.50 0 48 INTRM1 CASING RNCS T Torque turn graph showed indication of improper makeup.Recalibrate torque turn. Galled collar on bit jt. and pin on wearsox jt. 10:30 12:00 1.50 48 90 INTRM1 CASING RNCS T Lay dn.wearsox jt. Change out collar on bit joint. Used the good box from joint#2 to replace the bad box on joint#1. Picked up a new single wearsox joint#2 and made it up to the original 3 wearsox joint#1. 12:00 14:00 2.00 90 1,718 INTRM1 CASING RNCS P PJSM, M/U shoe track joints, RIH with 7"26#L-80 TN Blue casing to jt 40 @1718'MD. 14:00 16:45 2.75 1,718 1,718 INTRM1 CASING CIRC P Circulate surface to surface volume 150 bbl @ 200 gpm,300 psi. P/U=69k, S/O=68k,flow out 40%no losses. 16:45 20:30 3.75 1,718 3,500 INTRM1 CASING RNCS P Continue RIH with 26#TN Blue casing from 1718'MD to 3500'MD. Ran total 48 Hydroform centralizers on joints#3-50. 20:30 22:30 2.00 3,500 3,500 INTRM1 CASING CIRC P Circulate surface to surface volume 300 bbl, ICP @ 3 bpm=200 psi, staged up to 300 gpm, 550 psi Flow out=41%. P/U=91k, 5/0=84k.. Page 18 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 3,500 5,091 INTRM1 CASING RNCS P Continue RIH from 3500'MD to 5091' MD. P/U=120k, S/O=100k. Fill pipe every joint,top off every 10 joints. Calc Disp=47.76 bbl,Actual Disp=46.44 bbl. 06/11/2014 RIH with 7"26#TN Blue/Hydril 563 string to 9151'MD. Displace to new 11.0 ppg mud and perform LOT to 12.0 ppg(Well breathing). Begin casing drilling from 9151' MD to 9187'MD, losses @ 20 bph. 00:00 01:15 1.25 5,091 5,175 INTRM1 CASING CIRC P Continue RIH from 5091'MD to 5175'.MD Brk. circ. Stage pump up to 300 gpm. Circ. surface to surface.Lost 20 bbl's w/circ. Gain back 20 bbl.s after shutting down pump. 01:15 04:45 3.50 5,175 6,839 INTRM1 CASING RNCS P Continue RIH w/7"csg.from 5175' MD to 6839'MD. 04:45 07:15 2.50 6,839 6,839 INTRM1 CASING CIRC P Brk. circ. Stage pump up to 300 gpm. Circ.surface to surface.Lost 38 bbl's w/circ. Gain back 10 bbl.s after shutting down pump. 07:15 10:45 3.50 6,839 8,358 INTRM1 CASING RNCS P Continue RIH w/7"csg. from 6839' MD to 8358' MD.200 jt's in hole. P/U=185K, 5/0=120K.Actual Disp.=66 bbls. Calculated Disp=79 bbls. 10:45 13:30 2.75 8,358 8,358 INTRM1 CASING CIRC P Establish circulation,stage pump up to 300 gpm. 1000 psi. Circ. surface to surface. P/U=170K. S/0=120K. Total losses for tour=25 bbls. 13:30 13:45 0.25 8,358 8,490 INTRM1 CASING RNCS P Continue to RIH with 7"casing from 8358'MD to 8490' MD. Hit tight spot. 13:45 14:45 1.00 8,490 8,520 INTRM1 CASING REAM T Work thru tight spot @ 8490'MD, took 15k down wt.Worked pipe several times, Rotate 15 rpm, pump 2 bpm, stage up to 3.5 bpm,work pipe down to 8520", regained good circulation. 14:45 17:30 2.75 8,520 9,151 INTRM1 CASING RNCS P Continue RIH from 8520'MD,wash down last jt to 9151' MD pumping 2 bpm,tagged bottom and set down 5k. P/U=195k, S/O=129k. 17:30 18:45 1.25 9,151 9,151 INTRM1 CSGDRICIRC P Establish circulation @ 2 bpm,425 psi. Stage up to 7 bpm, 300 gpm=1250 psi. Circulate 1 bottoms up, initial condition for mud displacement. 18:45 20:45 2.00 9,151 9,151 INTRM1 CSGDRI CIRC P PJSM,displace well to 11.0 ppg P-vis mud with Torque seal additive for casing drilling. Displace @ 300 gpm, 1250 psi ICP, FCP=1000 psi. Rotate 20 rpm, reciprocate 20'after new mud reached 6200'MD in annulus. Optain SPR's @ 20:40, 11.0 ppg, 9148' MD, 5951'TVD. #1-10 spm=140 psi, 20 spm=220 psi #2-10 spm=160 psi, 20 spm=260 psi Page 19 of 34 Time Logs Date From _To Dur S. Depth E.Depth.Phase Code Subcode T Comment 20:45 22:00 1.25 9,151 9,151 INTRM1 CSGDRI LOT P PJSM, lay down jt 219, R/U and perform LOT. Pumped total 15 bbl, pressured up to 175 psi and flatlined. Monitored SIP, bled down to 120 psi and flatlined. Bled back 8.7 bbl. Calculated 12.0 ppg EMW LOT. Discuss results with drilling engineer. 22:00 22:15 0.25 9,151 9,151 INTRM1 CSGDRI RURD P R/D test equipment. 22:15 00:00 1.75 9,151 9,187 INTRM1 CSGDRI DCSG P Casing drill from 9151'MD to 9187' MD, 5960'TVD. Bit hrs=1.75, P/U=185k, 5/O=127k, ROT=152k, Tq on/off=15/13k, 37%Flow out, 5-20 WOB,80 rpm, 300 gpm @ 700 psi, Max gas=27. Losses stable at 20 bph,total losses for tour 32.5 bbl. 06/12/2014 Casing drill to 9257'MD, 5980'TVD. Stop drilling due to complete lost circulation while weighting up to 12.5 ppg.Wait on mud,build LCM pills and pump 120 bbl LCM pill,followed by active with 15 ppb. Losses temporarily improved. Re-building pills. 00:00 03:30 3.50 9,187 9,257 INTRM1 CSGDRI DCSG P Casing drill from 9187'MD, 5960' TVD to 9257' MD, 5980'TVD.. Bit hrs=2.86, P/U=185k, S/0=130k, ROT=185k,Tq on/off=12-15/14k, 34%Flow out, 8-18 WOB, 80 rpm, 300 gpm @ 500 psi, Max gas=78 units. 03:30 12:00 8.50 9,257 9,241 INTRM1 CSGDRI COND T Stop drilling due to total loss of returns to surface while weighting up mud to 12.5 ppg. Pull off bottom and reduce pump rate to.5 bpm, 100 psi. Stop rotating. P/U=185K S/O=125K. Loss rate at 50-60 bph. Shut down mud pump and fill hole with trip tank. Losses at 40 bph. LID 1 jt. 7"casing to 9,241 MD.Work string at 100 FPH w/5 RPM, TQ=13K Ordered mud from mud plant while building mud in pits. ROT P/U 156K, ROT S/O 150K. Losses decreasing to 20bph with no pump.Total losses for tour=940 bbls. 12:00 16:00 4.00 9,241 9,241 INTRM1 CSGDRI COND T PJSM, Building 100 bbl mud volume in pit 6, Mixing LCM, monitor losses via trip tank to keep annulus full. Reciprocate pipe @ 100 fph, rotate @ 10 rpm.Tq=12-13k, P/U=156k, 5/O=149k, ROT=154k. Static losses @ 18 bph. 16:00 19:15 3.25 9,241 9,241 INTRM1 CSGDRI COND T Offload 12.5 ppg mud into pits, dilute back to 11.5 ppg.Top off pits, build 20 ppb Torque seal pill in pill pit. Build 100 ppb Mixed LCM(100 ppb total)pill in pit 5.Add treatment of 5 ppb Torque Seal, 5 ppb G-Seal and 3 ppb SafeCarb to pit 6 for chase fluid. Page 20 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 22:00 2.75 9,241 9,241 INTRM1 CSGDRI CIRC T Pump 20 bbl LCM pill from pill pit, followed by 100 bbl 100 ppb pill from pit 5, chase with pit 6 11.5 ppg mud. Pump pills down at 1 bpm, 125 psi 65%loss, stage up to 2.5 bpm 70% loss, 3 bpm 95%loss, reduce rate to 2.5 bpm to place pills. 22:00 23:00 1.00 9,241 9,241 INTRM1 CSGDRI CIRC T Pump pills to bit and up to 4000 stks at 2.5 bpm,65%losses while pumping.At 4000 stks, increase rotation to 80 rpm, flow rate to 200 gpm. Initially 95%losses, pumped to 5700 strokes then backed off rate to 3 bpm. Losses at 65%or 120 bph at 3 bpm, slightly improved from 95% losses pre LCM and reducing mud weight to 11.5 ppg. Mud weight in/out 11.5 ppg. Could not notice any remarkable increase in flow out while pumping. 23:00 23:30 0.50 9,241 9,198 INTRM1 CSGDRI CIRC T Confer with enginner, Shut down pumps and lay down joint#221 to move circulation point. 23:30 00:00 0.50 9,198 9,198 INTRM1 CSGDRICIRC T Continue circulation @ 1 bpm-100 psi while mixing more LCM.Total losses for today=1233 bbl 06/13/2014 Keep casing moving while building high concentration 120 ppb LCM pill, adding 40 ppb LCM to all surface volume. Cut mud weight on surface volume from 11.5 ppg to 10.5 ppg. Begin pumping LCM down hole @ 1 bpm. 00:00 02:00 2.00 9,198 9,198 INTRM1 CSGDRICIRC T Continue circulation @ 1 bpm-100 psi w/no returns at surface. Mixing 50 ppb LCM into active pits. Losses a 02:00 06:00 4.00 9,198 9,198 INTRM1 CSGDRI COND T Shut down pump, reduce rotary to 5 RPM,work string. Fill hole with trip tank, losses at 24 bph. Reduce mud weight in active pit to 11.2 ppg. 06:00 07:30 1.50 9,198 9,198 INTRM1 CSGDRICIRC T Continue to reduce mud weight to 11.0 ppg. Reciprocate pipe at 9,198 MD. P/U=165K, S/0=150K.Attempt to regain circulation twice pumping at 2 bpm, 150 psi. No returns to surface, Keep hole full with trip tank. 20 bph losses. 07:30 10:30 3.00 9,198 9,198 INTRM1 CSGDRICIRC T Attempt to break circulation @ 1bpm.No returns to surface. Pumped total of 30bbls. P/U=160K, S/O=145K. Shut down pump. 10:30 12:00 1.50 9,198 9,198 INTRM1 CASING COND T Decision made to reduce mud weight to 10.5 ppg and establish circulation for cement job. Page 21 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 22:00 10.00 9,198 9,198 INTRM1 CASING COND T PJSM, continue to reduce all mud in pits and vacuum trucks to 10.4-10.5 ppg.Adjust additives in Mega 'Pill-120 ppb, 100 bbl in pit 5. Pit 6 has 400 bbl at 45 ppb total LCM and 10.4+ppg.(SIMOPS unload pipeshed of 7"casing, bring cement head to rig floor) 22:00 00:00 2.00 9,198 9,198 INTRM1 CASING CIRC T Pump 110 bbl Mega Pill 100 ppb LCM from pit 5 @ 1 bpm, 110 psi ICP. FCP @ midnite 210 psi, 5 rpm 14k Tq, 80%losses @ 1 bpm. (SIMOPS load pipe shed with 4"drill pipe) Total losses for the day 540 bbl 06/14/2014 Circulate 10.4 ppg LCM laden mud to regain circulation. Reduce mud weight to 10.4 ppg and regain circulation. Cement 7"casing @ 9247.72' MD. Set and test 7"packoff. Rig down casing equip, R/U to lay down drill pipe. 00:00 07:00 7.00 9,198 9,198 INTRM1 CASING CIRC T PJSM-Chase Mega Pill w/10.5 ppg, mud. Remove trip tank from active system and take returns to pit#5. Monitor returns and increase pump rate to 1.5 bpm, 290 psi, 15 rpm, 13-14K tq. Slight returns observed at surface. 90%losses @ 1.5 bpm. Stage pump rate to 2 bpm,490 psi. Losses at 76%. Increase pump rate to 2.5 bpm. 300 psi. Losses steadily reduced to<10%as 10.4 ppg mud made it around. LCM had little effect. 07:00 08:30 1.50 9,198 9,198 INTRM1 CASING CIRC T Continue to circ. and cond. mud @9,198 MD.2.5 bpm, 300 psi, 15 rpm, 12-14K tq. Could not heal losses,decision to cement 7"casing @ 9274'MD. 08:30 09:15 0.75 9,198 9,247 INTRM1 CEMEN-CIRC P PJSM-M/U 20'pup jt„ hanger and landing jt. Break circ.Wash down to 9,247 MD. Monitor well while making up hanger. Gained 1 bbl. 09:15 10:30 1.25 9,247 9,247 INTRM1 CEMEN'CIRC P Continue to circulate @ 2.5 bbls, 300 psi. Stage up to 4.5 bpm w/full returns., 375 psi. Rig down Tesco bails. 10:30 12:15 1.75 9,247 9,247 INTRM1 CEMEN-RURD P PJSM-Rig down Tesco CDS. R/U long bails,350T elevators. Ran total of 171 jts. Tenaris Blue,49 jts Hydril 563., lx 20'Hydril 563 pup jt., and hanger. 12:15 14:30 2.25 9,247 9,247 INTRM1 CEMEN-CIRCP Establish circulation @ 1 bpm, stage up to 4.5 bpm 200-450 psi, 36% Flow out @ 4.5 bpm. Obtain SPR's, SIMOPS PJSM on cementing 7" casing. Page 22 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:45 2.25 9,247 0 INTRM1 CEMEN-CMNT P Pump cement job per program, SLB pumped 60 bbl 12.5 ppg MudPushll, 60 bbl 15.8 ppg Class G Tail Cement,followed by 10 bbl water, displace with 342 bbl 10.4 ppg mud with rig. Bump plugs @ 3378 stks, CIP @ 16:28 hrs. FCP=850 psi, held 1350 psi on floats for 5 min and released,floats held. Minimal flow from annulus after shut down, monitor with trip tank until stopped. Lost 22 bbl mud during cement job. Float shoe @ 9247.72'MD, 5976.97' TVD. Double valve float collar @ 9154.8' MD. 16:45 18:15 1.50 0 0 INTRM1 CEMEN-RURD P Rig down cementing equipment, rig down long bails and elevators, remove from floor. 18:15 19:00 0.75 0 0 INTRM1 CEMEN-WWSP P R/U packoff running tool, set packoff, RILDS,torque and remove running tools. 19:00 19:30 0.50 0 0 INTRM1 CEMEN-PRTS P Test packoff to 250/5000 psi, 10 minutes each witnessed by Co Rep. 19:30 21:45 2.25 0 0 INTRM1 CEMEN RURD P PJSM, C/O 4%IF"saver sub to 4" XT39,space out grabbers, C/O grabber dies and bell guide. 21:45 23:15 1.50 0 0 INTRM1 CEMEN RURD P PJSM, change out upper 7"rams to 3%"X 6"VBR's. 23:15 00:00 0.75 0 0 INTRM1 CEMEN RURD P R/U Short bails and 5"elevators, get tools and equipment ready to L/D 5" DP. SIMOPS-R/U OA for annular flush and FP. 06/15/2014 Perform annular flush and Isotherm freeze protection on 10%'x 7"annulus. Lay down 5" DP. Test BOPE with 3%",4"and 4%"test jts to 250/3500 psi.Annular to 250/2500. P/U 4"drill pipe and stand back 15 stands. 00:00 00:45 0.75 0 0 INTRM1 CEMEN-PULD P PJSM-L/D 5" DP,6 stands of 5" HWDP 00:45 03:00 2.25 0 0 INTRM1 CEMEN-FRZP P PJSM-R/U and flush 10 3/4'x7"annulus w/190 bbls H2O. Initial injection rate 1/2 bpm=100 psi. Stage pump up to 4 bpm. Final injection pressure=830 psi. Shut in pressure=600 psi. R/D lines. 03:00 06:00 3.00 0 0 INTRM1 CEMEN-PULD P L/D 5' DP 06:00 06:45 0.75 0 0 INTRM1 CEMEN-PULD P Unload pipeshed 06:45 10:30 3.75 0 0 INTRM1 CEMEN-PULD P Continue to L/D drill pipe. Sim-Ops, PJSM. Spot Little Red,test lines to 2500 psi. Pump 121 bbls of Isotherm NT down OA. Initial rate-1 bpm=500 psi. Final injection rate= 1.5 bpm @ 905 psi. SIP=690 psi. L/D mouse hole, Clear rig floor. 10:30 12:00 1.50 0 0 INTRM1 CEMEN-OTHR P Level rig due to pad settling. 12:00 13:45 1.75 0 0 INTRM1 WHDBO RURD P PJSM-Bring tools to rig floor and rig up to test BOPE Page 23 of 34 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 13:45 17:45 4.00 0 0 INTRM1 WHDBO BOPE P PJSM-Test BOPE w/4"test jt.Test #1 Upper VBR's, valves 1,12,13,14, manual kill valve,Test#2 upper IBOP, HCR kill,valves 9,11. Test#3 Lower IBOP,valves 5,8,10.Test#4 Dart valve,valves 4,6,7.Test#5 Floor valve,and valve#2.Test#6 HCR choke,4"Demco kill line valve.Test #7 Manual choke, HCR kill. Test#8 annular preventer.Test#9 Lower VBR's. 17:45 19:45 2.00 0 0 INTRM1 WHDBO BOPE P Change test jt. out to 4 1/2". Test #10 Upper VBR's,Test#11 Lower VBR's. Test#12 Annular preventer. Change test jt.to 3 1/2". Test#13 Upper VBR'sa. Test#14 Lower VBR's.Test#16 Annular preventer. Test#16 Blind rams.All tests 250 psi low, 3500 psi high, test annular to 2500 psi high for 5 min's each 19:45 20:15 0.50 0 0 INTRM1 WHDBO BOPE P Accumulator test. System Pressure=2900 psi. Pressure after closed=1600 psi. 200 psi attained=48 sec. Full Pressure attained=209 sec. Nitrogen bottles avg=2025 psi.Test witness waived by Johnnie Hill w/AOGCC on 6/15/14 @ 07:44 hrs. 20:15 21:00 0.75 0 0 INTRM1 WHDBO BOPE P Rig down test equipment, blow down choke, kill and choke lines. set 6.938"wear bushing. 21:00 00:00 3.00 0 0 INTRM1 WHDBO RURD P PJSM, load 8 jts HWDP and jars in pipe shed, strap and process same. P/U BHA components from beaverslide. P/U and rack back 15 stds 4"DP. L/D mouse hole. Prep for P/U BHA. 06/16/2014 P/U BHA#6, P/U 4"DP and single in hole, perform casing test to 3000 psi 30 min. Drill out float equipment, cement, EZ case bit, rathole and 10'formation to 9267'MD. 00:00 01:15 1.25 0 106 INTRM1 CEMEN-PULD P PJSM-M/U BHA to 106'MD 01:15 02:15 1.00 106 106 INTRM1 CEMEN-PULD P PJSM-Load nuclear sources 02:15 02:45 0.50 106 200 INTRM1 CEMEN'PULD P PJSM-Continue to make up BHA to 200'MD 02:45 03:45 1.00 200 200 INTRM1 CEMEN'SVRG P Service drawworks,top drive and iron _roughneck. 03:45 04:30 0.75 200 478 INTRMI CEMEN-PULD P Continue to make up BHA to 478' MD 04:30 05:30 1.00 478 1,543 INTRM1 CEMEN-PULD P TIH. Picking up singles from pipe shed to 1543'MD 05:30 06:30 1.00 1,543 1,543 INTRM1 CEMEN-DHEQ P Perform shallow pulse test. @ 1543' _MD. 250 gpm, 60 spm, 1500 psi. 06:30 12:00 5.50 1,543 7,288 INTRMI CEMEN'PULD P Continue TIH, picking up singles from pipe shed to 7288'MD. Fill pipe every 20 stands. OA pressure=250 psi Page 24 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 7,288 9,087 INTRM1 CEMEN-PULD P PJSM, Continue single in hole from 7822'MD to 9087'MD. Calc Disp=58.74 bbl,Actual Disp=60.95 _ bbl. P/U=140k, S/O=88k. 13:30 14:00 0.50 9,087 9,150 INTRM1 CEMEN WASH P Wash and ream from 9087' MD to 9150'MD©200 gpm, 1800 psi,40 rpm, 5K Tq, 34% Flow out. Cement at shakers. 14:00 16:00 2.00 9,150 9,150 INTRM1 CEMEN-CIRC P Circulate and condition mud to even mud weight 10.4 ppg,200 gpm, 1450 psi, 50 rpm, 7k Tq, 36%Flow out. 16:00 17:30 1.50 9,150 9,150 INTRM1 CEMEN-PRTS P R/U and test casing to 3000 psi for 30 minutes charted,good test. Rig down test equipment. SPR's @ 19:00 hrs, 10.4 ppg 9146' MD/5950'TVD #1-20 spm=480 psi, 30 spm=670 psi #2-20 spm=500 psi, 30 spm=730 psi 17:30 00:00 6.50 9,150 9,267 INTRM1 CEMEN DRLG P Drill cement and float equipment from 9150'MD to 9257'MD,formation to 9267'MD/5950'TVD.ART=.52, P/U=137k, 5/0=87k, ROT=114k,Tq on/off=9/7k, Flow out=33%, WOB=10k 60 rpm, 207 gpm © 1700 psi. 06/17/2014 Drill to 9277'MD, 5986'TVD and perform 16.0 ppg FIT. Displace to 12.5 ppg LSND Mud, condition and commence drilling 6-1/8"tangent to 9662'MD @ 20-30 fph. Pyrite and siderite streaks. SIMOPS-Pull rig boilers for replacement and prep boiler room for new install. 00:00 01:00 1.00 9,267 9,277 INTRM1 CEMEN-DRLG P Continue drilling 20' new formation to 9277' MD, 5986'TVD, 230 gpm, 1900 psi, P/U=148k, 5/0=90k, ROT=112k, Tq on/off=10/7k, ADT=.89, Bit Hrs=1.41, Jar Hrs=146.82. Noted slow ROP 10-20 fph when drilling formation. 01:00 02:00 1.00 9,277 9,274 INTRM1 CEMEN-CIRCP CBU @ 9274'MD to clean hole and get even mud weight 10.4 ppg in/out. 230 gpm 1900 psi, Rotate 30 rpm, Tq=9k. 02:00 03:30 1.50 9,274 9,240 INTRM1 CEMEN-FIT P PJSM, R/U test equipment and circulate additional pipe volume @ 230 gpm 1900 psi. Perform FIT to 16.0 ppg, 15 sec SIP 1625 psi. Held flat at 1600 psi after five minutes. 03:30 05:15 1.75 9,240 9,277 PROD1 DRILL CIRC P PJSM,displace well over to 12.5 ppg treated LSND @ 5 bpm, ICP 1900 psi, FCP 2600 psi. 05:15 09:00 3.75 9,277 9,277 PROD1 DRILL CIRC T Circulate and condition mud. Shakers screening out LCM and weight material after displacement. Changed shaker screens to 1 ea-84 mesh on each shaker to keep Barite in the system. Circulate @ 4 bpm, 1700 psi, adding barite to obtain 12.5 ppg in/out prior to drilling ahead. Page 25 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 9,277 9,374 PROD1 DRILL DDRL P Drill from 9277'MD to 9347'MD, 6004'TVD.ADT=2.54, Bit Hrs=3.95, Jar Hrs=149.36, P/U=148k, S/O=90k, ROT=112k, Tq on/off=7/6k, ECD=14.55 ppg EMW, Flow out=38%,WOB=6-8, RPM=100,230 gpm @ 2700 psi. SPR's @ 9272'MD, 5984'TVD, 12.5 ppg, 08:45 hrs. #1-20 spm=830 psi, 30 spm=1200 psi #2-20 spm=750 psi, 30 spm= 1110 psi 12:00 18:00 6.00 9,374 9,556 PROD1 DRILL DDRL P Directional drill from 9347' MD to 9556' MD,6042'TVD.ART=5.04, Bit Hrs=8.99, Jar Hrs=154.4, P/U=127k, S/O=94k, ROT=105k, Tq on/off=7/5k, ECD=14.34 ppg EMW, Flow out=36%,WOB=8-15k, RPM=100,222 gpm @2650 psi, Max Gas=90 units. Intermittant hard streaks of pyrite and siderite slowing ROP. 18:00 00:00 6.00 9,556 9,662 PROD1 DRILL DDRL P Directional drill from 9347'MD to 9662'MD, 6092'TVD.ART=3.54, Bit Hrs=12.53,Jar Hrs=157.54, P/U=130k, S/O=94k, ROT=108k,Tq on/off=7/5k, ECD=14.43 ppg EMW, Flow out=37%,WOB=10-12k, RPM=100,225 gpm @2675 psi, Max Gas=452 units at botoms up after connection. Noted increased flow and gas at BU strokes. Flow check on connection-slight but steady flow. Begin slow weight up to 12.7 ppg. SPR's @ 9613'MD,6076'TVD, 12.5 ppg,21:00 hrs. #1-20 spm=640 psi, 30 spm=970 psi #2-20 spm=630 psi, 30 spm=980 psi. 36/18/2014 Drill from 9662'MD to TD @ 10127'MD, 6217'TVD.Weight up to 13.1 ppg trip margin. CBU x 2, OWFF. Pump out to shoe @ 2 bpm,2500 fpm. CBU @ shoe. Continue pump out of hole @ 2 bpm,2500 fph. Page 26 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 9,662 9,910 PROD1 DRILL DDRL P Directional drill from 9662'MD to 9910'MD,6159'TVD.ART=10.59, Bit Hrs=23.12, Jar Hrs=168.53, P/U=128k, S/O=80k, ROT=106k,Tq on/off=8/6k, ECD=14.96 ppg EMW, Flow out=36%,WOB=6-13k, RPM=100-120, 225 gpm @2900 psi, Max Gas=281 units at bottoms up after connection. SPR's @ 9727'MD, 6110'ND, 12.7 ppg,02:30 hrs. #1-20 spm=780 psi, 30 spm=1040 psi #2-20 spm=740 psi, 30 spm=1070 psi. SPR's @ 9830'MD,6137'ND, 12.8 ppg,08:45 hrs. #1-20 spm=780 psi, 30 spm=1080 psi #2-20 spm=740 psi, 30 spm=1110 psi. 12:00 17:30 5.50 9,910 10,127 PROD1 DRILL DDRL P Directional drill from 9910'MD to 10127' MD,6217'ND.ART=4.59, Bit Hrs=27.71,Jar Hrs=173.12, P/U=152k, 5/0=93k, ROT=110k,Tq on/off=8/6k, ECD=15.37 ppg EMW, Flow out=37%,WOB=8-12k, RPM=100,225 gpm @ 2800 psi, Max Gas=380 units at bottoms up after connection. SIMOPS-Weight up mud sytem to 13.1 ppg for trip margin. 17:30 17:45 0.25 10,127 10,127 PROD1 CASING SRVY P Obtain SPR's, Survey on bottom. SPR's @ 10127'MD,6217'TVD, 17:30hrs, 13.1 ppg. #1-20 spm=710 psi, 30 spm=1090 psi #2-20 spm=780 psi, 30 spm=1100 psi. 17:45 19:00 1.25 10,127 10,127 PROD1 CASING CIRC P Circulate hole clean @ drilling rate. 19:00 19:45 0.75 10,127 10,127 PROD1 CASING OWFF P Motitor well for flow. Slight trickle to static after 7 min, 30 min static. (SIMOPS-PJSM on pumping out of hole.) 19:45 21:30 1.75 10,127 9,182 PROD1 CASING TRIP P Pump out @ 2 bpm 700 psi, pulling 2500 fph to 9182'MD. Ream x 2 on stand#95, 9467'-9372'due 15k overpull and slight pressure increase. No problems after reaming 3.5 bpm 50 rpm. Calc Fill=5.6 bbl,Actual Fill=11.16 bbl. 21:30 22:15 0.75 9,182 9,182 PROD1 CASING CIRC P CBU @ 9182'MD,225 gpm 2850 psi, 100 rpm,6k Tq, 37%Flow out. 157 units gas on bottom up strokes. Page 27 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:45 0.50 9,182 9,182 PROD1 CASING OWFF P Monitor well @ shoe, static. 22:45 00:00 1.25 9,182 8,519 PROD1 CASING TRIP P Continue pumping out of hole from 9182'MD to 8519'MD @ 2500 fph,2 bpm 650 psi. Drop 2.25"hollow rabbit with 100'wire on stand#90. (8514' DP length). P/U=130k, 5/0=93k, Calc Fill=2.8 bbl,Actual Fill=4.54 bbl. 06/19/2014 Pump out to 2500'MD, POOH with BHA#6 and L/D. Pick up 4'/i'liner sting and RIH to 9300'MD.Circulating as needed to even out mud weight due to barite sag. 13.1 ppg in/12.6 ppg out. 00:00 09:00 9.00 8,519 2,560 PROD1 CASING TRIP P Continue pumping out of the hole f/ 8519'MD to 2560' MD. Increased pump rate f/2 bpm=600 psi to 4 bpm= 1300 psi due to dynamic barite sag.Actual displacement= 46.3 bbls, Calculated displacement= 39.2 bbls. 09:00 09:15 0.25 2,560 2,560 PROD1 CASING OWFF P OWFF, static. 09:15 11:15 2.00 2,560 478 PROD1 CASING TRIP P POOH on elevators @ 2500 fph to 478'MD.Actual displacement= 11.9 bbls, Calculated displacement= 11.8 bbls. 11:15 12:00 0.75 478 478 PROD1 CASING PULD P OWFF, P/U SLB tools to rig floor, prep to L/D Nuke tools. 12:00 13:45 1.75 478 0 PROD1 CASING PULD P PJSM, rack back 3 stds HWDP, L/D 3 jts flex collars, unload nuclear sources. Break bit, L/D remaining BHA. 13:45 14:45 1.00 0 0 PROD1 CASING RURD P Clean and clear rig floor, L/D tools, P/U casing equipment. 14:45 15:30 0.75 0 0 COMPZ CASING RURD P PJSM, Rig up casing equipment. SIMOPS-install hydroform centralizers with bottom stop collar per running detail in the pipe shed. 15:30 16:00 0.50 0 0 COMPZ CASING SVRG P Lubricate top drive and rig. 16:00 20:00 4.00 0 1,135 COMPZ CASING RNCS P Pick up liner string per detail. M/U EZ Ream liner shoe, double float collar, landing collar, SBE. Flex lock liner hanger, RS Nipple,ZXP packer w/HRDE. Mix Pal Mix, pour and let set for 30 minutes. P/U=44k, 5/0=43k. Calc Disp=4.97 bbl,Actual Disp=5.02 bbl. 20:00 21:30 1.50 1,135 3,041 COMPZ CASING RUNL P Break circulation on first stand, continue RIH,filling pipe every 10 stands to 3000' MD. 21:30 22:00 0.50 3,041 3,041 COMPZ CASING CIRC P Establish circulation©4 bpm, circulate surface to surface to break gels and even mud weight. P/U=64k, 5/0=61k. 22:00 23:30 1.50 3,041 5,873 COMPZ CASING RUNL P Continue RIH from 3041'MD to 5873' MD filling pipe every 10 stands. Calc Disp=31.85 bbl,Actual Disp=35.7 bbl. P/U=89k, S/O=73k. Page 28 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 5,873 5,873 COMPZ CASING CIRC P Cirulate and condition mud @ 5873' MD, 5 bpm 900 psi,40% Flow out. Noted barite sag, 12.6 ppg mud weight coming out. Circulate until even @ 12.9 ppg. 06/20/2014 Run liner to bottom,washing down from 9740'MD to tag @ 10127'no fill. C&C then pump 30 bbl cement per program. Set liner hanger and ZXP packer but saw no verification.Test ZXP to 1500 psi 10 minutes-good. _ POOH, rotating dog sub not sheared out. 00:00 01:00 1.00 5,873 5,873 COMPZ CASING CIRC P PJSM, continue circulate and condition mud @ 5873' MD, 5 bpm 900 psi. P/U=95k, S/0=75k. 01:00 02:45 1.75 5,873 9,187 COMPZ CASING RUNL P Continue RIH t/9187'MD filling pipe every 10 stands. Calc Disp=51.4 bbl, Actual Disp=85.5 bbl. 02:45 05:45 3.00 9,187 9,187 COMPZ CASING CIRC P Circulate and condition mud @ 9187' MD. 3.5 bpm 900 psi. Pumped 3 BU to even out mud weight due barite sag, 12.5 ppg out, 12.9 ppg in. Obtain P/U=130k, S/0=90k and rotating torque 5k @ 10 rpm values. 05:45 06:15 0.50 9,187 9,740 COMPZ CASING RUNL P Continue RIH from 9187'MD to 9740' MD, lost 15k slack off weight. 06:15 08:00 1.75 9,740 9,740 COMPZ CASING CIRC P M/U top drive, establish circulation, reciprocate pipe 30'. Stage pump up to 3 bpm, 975 psi. Mud weight on BU 13.7 ppg. 08:00 09:00 1.00 9,740 10,117 COMPZ CASING RUNL P Wash down from 9740'MD to 10127' MD @ 2.7 bpm 800 psi,tag bottom no fill. 09:00 10:15 1.25 10,117 10,117 COMPZ CEMEN-RURD P Make up cement head and XO's with pup joint to space out liner string. M/U to top drive. 10:15 12:45 2.50 10,117 10,117 COMPZ CEMEN CIRC P Circulate and condition mud for cement job, reduce mud weight to 12.8 ppg. 2.5 bpm, 1200 psi, P/U=135k, 5/0=85k. Noted some minor packing off while circulating, decide to pump cement. 12:45 14:30 1.75 10,117 10,117 COMPZ CEMEN'CMNT P Cement liner per program, pump 5 bbl H2O,test lines to 4000 psi. Batch up and pump 30 bbl 13.3 ppg MudPush II, 30 bbl 15.8 pptg Tail cement, kick out plug with 10 bbl H2O,displace with rig pump. Dart latched wiper plug©915 stks, bumped plug @ 1065 stks, CIP @ 14:20. 14:30 15:30 1.00 10,117 8,979 COMPZ CEMEN-PACK P Set hanger and ZXP pack assy per Baker rep.Pressure up to 3500 with rig pumps to set liner hanger, no set. Line up SLB to pump up to 4200 psi to set liner hanger and HRDE. P/U 7' and set down 40k to set ZXP packer. No indication of shear, repeat with rotation, no indication of shear out. Page 29 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 8,979 8,959 COMPZ CEMEN'RURD P Rig down cement head pup jts and XO's, L/D single while picking up to clear the RS packoff. 16:00 18:30 2.50 8,959 8,959 COMPZ CEMEN-CIRC P Circulate excess cement out from liner top, condition mud per Mud rep. 6 bpm, 1750 psi, 39%Flow out. 18:30 18:45 0.25 8,959 8,959 COMPZ CEMEN-PRTS P Test ZXP packer to 1500 psi 10 minutes(Good) 18:45 19:15 0.50 8,959 8,959 COMPZ CEMEN'CIRC P Pump and spot 40 bbl High Vis 12.8 ppg pill on top of packer. 19:15 20:00 0.75 8,959 8,959 COMPZ CEMEN-SFTY P Conduct Safety Stand down with rig crew concerning Ladder Safety and ladder inspection. Review recent incident,discuss equipment inspection. Inspect all ladders on rig, take 2 out of service. SIMOPS- Observe well for flow-Static. 20:00 20:15 0.25 8,959 8,956 COMPZ CEMEN-RURD P PJSM, rack back stand, blow down top drive, P/U instring single. 20:15 23:45 3.50 8,956 0 COMPZ CEMEN-TRIP P Continue POOH on elevators to surface, lay down running tool. Calc Fill=52.63 bbl,Actual Fill=56.95 bbl. L/D running tools, inspect rotating dog sub, not sheared out. 23:45 00:00 0.25 0 0 COMPZ CEMEN-RURD T Clean and clear rig floor, prepare new packoff and rotating dog sub for RIH to verify ZXP packer is set fully. SIMOPS-Held Safety Stand down with oncoming crew-Ladder Safety and ladder inspection. 06/21/2014 M/U Baker rotating dog sub assy. RIH on 4"DP to verify packer set. Set down X 3 @ 40k observed shear out,. POOH. Test ZXP to 3500 psi-Good. M/U and RIH with 3'%2'upper GL completion, locate and space out. Begin displacement from 12.8 ppg mud to 8.5 seawater. 00:00 00:30 0.50 0 0 COMPZ CEMEN"SFTY P Conduct Safety Stand down with rig crew concerning Ladder Safety and ladder inspection. Review recent incident,discuss equipment inspection. Inspect all ladders on rig 00:30 01:00 0.50 0 0 COMPZ CEMEN-PULD T PJSM, break XO and pups off cement head, lay down. 01:00 01:45 0.75 0 0 COMPZ CEMEN-PULD T PJSM P/U Baker Pack-off dog sub and M/U as per Baker rep. 01:45 02:00 0.25 0 1,140 COMPZ CEMEN'TRIP T PJSM, RIH w/7 stands of 4"DP f/ derrick, P/U 6 joints of 4"HWDP and RIH w/2 stands of 4"HWDP f/ derrick. 02:00 05:15 3.25 1,140 8,979 COMPZ CEMEN'TRIP T RIH w/4"DP f/derrick f/1140'MD to 8979'MD.Actual displacement= 56.44 bbls, Calculated displacement=52.60 bbls. Page 30 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 05:45 0.50 8,979 8,979 COMPZ CEMEN-PACK T Set down on ZXP liner top packer, observed a bobble on weight inductor @ 26K, cont. to S/O to 40K. P/U and set down 45K on ZXP. P/U, rotate @ 15 rpm's,4-6K tq. S/O setting 40K down on ZXP. P/U to neutral. P/U= 142K, S/O=85K. Baker rep confirmed w/town ZXP is set. 05:45 08:45 3.00 8,979 0 COMPZ CEMEN-TRIP T OWFF, POOH f/8974'MD to surface. Dog sub was sheared on Baker tool. Actual displacement= 57.4, Calculated displacement= 52.60 bbls. 08:45 09:00 0.25 0 0 COMPZ CEMEN-PULD P Clean and clear rig floor. 09:00 10:00 1.00 0 0 COMPZ CEMEN-PRTS P PJSM, R/U and test ZXP packer to 3500 psi f/30 minutes on chart,good _test. 10:00 11:15 1.25 0 0 COMPZ RPCOM RURD P Wash stack and pull wear bushing. _Blow down kill line and top drive. 11:15 12:00 0.75 0 0 COMPZ RPCOM RURD P PJSM, mobilize casing equipment to rig floor and R/U cazsing handling tools. 12:00 19:30 7.50 0 8,970 COMPZ RPCOM RCST P P/U and RIH with 31/2'GL completion string. P/U locator seal assembly, DS Nipple 2.813", 1 GLM w/SOV,4 GLM w/DMY, DS nipple 2.875"and _233 jts 3'/"tubing. 19:30 21:15 1.75 8,970 9,008 COMPZ RPCOM HOSO P P/U jt 234 and M/U circulating hose, establish circulation and RIH to locate top of seal bore @ 9011'MD .5 bpm,400 psi. Continue in and fully locate @ 9029'MD. Lay down 3 jts, P/U 4.21', 10.11'and 10.20'pup, jt 232, hanger and landing joint. R/U circulating hoses for brine _displacement. 21:15 00:00 2.75 9,008 9,008 COMPZ RPCOM DISP P PJSM,displace well from 12.8 ppg Mud to 8.5 ppg Seawater. Pump 200 bbl Seawater @ 3 bpm, ICP=800 psi, 37%Flow out, max pressure 1650 psi @ 3 bpm. Pump 100 bbl HV spacer,followed by 35 bbl Soap spacer,followed by seawater©3 bpm, 750 psi. 06/22/2014 Complete brine displacement. Land hanger and RILDS.Attempt to test tubng string with IA open, bled down with flow out IA. R/U SLB slickline, set CAT-SV plug in DS @ 8934'.Test tubing fail. Pull SOV from GLM @ 8875, appeared good. R/D SLB and R/U HES slickline. 00:00 02:00 2.00 9,008 9,008 COMPZ RPCOM DISP P Cont to displace well to 8.5 ppg sea water,staging pumps up f/3 bpm=600 psi to 7.5 bpm=1290 psi, 36%flow. Pumped 690 bbls of seawater. 02:00 02:15 0.25 9,008 9,008 COMPZ RPCOM THGR P FMC rep inspect tbg hanger to confirm TWC will fit in hanger profile. Page 31 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 02:45 0.50 9,008 9,008 COMPZ RPCOM CRIH P Pump 20 bbls of inhibited sea water @ 3 bpm=225 psi,chase w/73 bbls of sea water to spot inhibited sea water from seal assy to SOV on GLM. 02:45 03:15 0.50 9,008 0 COMPZ RPCOM THGR P Drain stack, land hanger and run in lock downs on tbg hanger. 03:15 03:30 0.25 0 0 COMPZ RPCOM PRTS T Attempt to pressure test 3-1/2"tbg to 3500 psi,observed pressure bleeding off via IA at a fast rate. 03:30 03:45 0.25 0 0 COMPZ RPCOM OTHR T Discuss options with town engineer. Decision made to R/U Slickline to replace SOV in GLM#5, run leak detection tools. 03:45 04:00 0.25 0 0 COMPZ RPCOM CIRC T Pump down IA to determine if leak is two-way., observed fluid coming out 3-1/2"tbg. 04:00 07:00 3.00 0 0 COMPZ RPCOM SLKL T Mobilize SLB digital slickline to rig. SIMOPS-Clean rig pits, clean and paint boiler room, prep for hopper installation it pits. 07:00 08:30 1.50 0 0 COMPZ RPCOM SLKL T Load digital slickline tools in pipe shed,spot trucks. SIMOPS, pull landing joint, replace with 3-pups in order to get stump closer to rig floor to rig up slickline pressure control and lubricator. 08:30 10:30 2.00 0 0 COMPZ RPCOM SLKL T PSJM-P/U and R/U SLB Slickline tools. 10:30 11:15 0.75 0 0 COMPZ RPCOM SLKL T Test lubricator and grease head to 500 psi. 11:15 13:00 1.75 0 8,925 COMPZ RPCOM SLKL T RIH with D-CAT SV standing valve and catcher on Slickline, set in 2.812"DS nipple @ 8935.73'. Pick up 10'with line. 13:00 13:15 0.25 8,925 8,935 COMPZ RPCOM PRTS T R/U circulating lines, pressure test to 1500 psi, presure bleeding off. Pressure up to 3500 psi, bled off fast and flowing out the IA. 13:15 14:00 0.75 8,935 0 COMPZ RPCOM SLKL T POOH w/Slickline, C/O plug running tool to kick over tool. 14:00 18:30 4.50 0 0 COMPZ RPCOM SLKL T RIH w/Kickover tool attempt to pull SOV GLM#5, un-successful. Re-dress tool and re-attempt, un-successful.. 18:30 20:00 1.50 0 0 COMPZ RPCOM SLKL T Attempt pressure test on tubing again due D-CAT SV setting uncertainty.Again tubing failed. Re-dress kickover tool with roller stem, RIH and pull SOV. Successfull, no sign of shear on SOV. 20:00 21:00 1.00 0 0 COMPZ RPCOM SLKL T PJSM, R/D SLB digital slickline due crew timed out. Clear SLB tools from rig floor. 21:00 00:00 3.00 0 0 COMPZ RPCOM SLKL T PJSM-R/U HES slickline. MOB tools to rig floor,spot trucks, load lubricator in the pipe shed. Page 32 of 34 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/23/2014 24 hr Summary R/U HES Slickline and set SOV in GLM#5. Test tubing to 3500, annulus to 3000 psi 30 min ea charted. Shear out SOV, set TWC and test to 3200 psi. N/D BOPE, install tubing adapter and test 5k good. Install tree test 5k good. Pump inhibited brine and diesel FP. Lay down drill pipe. Secure well and release rig @ 00:00. 00:00 00:45 0.75 0 0 COMPZ RPCOM SLKL T Cont to R/U HES Slick line unit. 00:45 02:15 1.50 0 8,875 COMPZ RPCOM SLKL T RIH w/new SOV on HES slick line. Attempt to set SOV in GLM#5@ 8875'MD 02:15 02:30 0.25 8,875 0 COMPZ RPCOM SLKL T Inspect slick line running tool on surface. SOV did not set in GLM#5. 02:30 04:00 1.50 0 0 COMPZ RPCOM SLKL T RIH w/new SOV on slick line. Set SOV in GLM#5 @ 8875'MD. 04:00 04:15 0.25 0 0 COMPZ RPCOM PRTS T Pressure test 3-1/2"tbg to 3500 psi for 5 minutes, good test. 04:15 05:00 0.75 0 0 COMPZ RPCOM SLKL T Rig down HES slick line unit. 05:00 06:30 1.50 0 0 COMPZ RPCOM PRTS P Pressure test 3-1/2"tbg to 3500 psi f/30 minutes good test. Bleed down tbg to 2000 psi, pressure up IA to 3000 psi and test for 30 minutes, good test. Bleed off IA and tbg. Ramp up on IA, SOV sheared @ 2700 psi.All tests recorded on chart recorder. 06:30 06:45 0.25 0 0 COMPZ WHDBO RURD P R/D testing equipment and L/D landing joint. 06:45 07:15 0.50 0 0 COMPZ WHDBO MPSP P Set TWC as per FMC rep,test TWC to 3200 psi f/5 minutes in the direction of flow. 07:15 07:30 0.25 0 0 COMPZ WHDBO RURD P Blow down choke line, kill line and cellar lines. 07:30 08:30 1.00 0 0 COMPZ WHDBO NUND P PJSM, Nipple down BOPE. 08:30 10:15 1.75 0 0 COMPZ WHDBO NUND P Install SBMS seals and adapter flange,test void to 5000 psi f/10 minutes.Test witnessed by CPAI rig supervisor,good test. 10:15 11:30 1.25 0 0 COMPZ WHDBO NUND P N/U tree as per FMC.Test to to 5000 psi,good. 11:30 12:15 0.75 0 0 COMPZ WHDBO MPSP P PJSM, Pull TWC, SIMOPS-R/U freeze protect&U-tube hoses and equipment. 12:15 14:30 2.25 0 0 COMPZ WHDBO FRZP P PJSM, Pressure test lines to 2500 psi. Pump 190 bbl inhibited brine, followed by 65 bbl diesel freeze protection @ 2.25 bpm 900 psi with Litte Red. Shut down pump,static pressure 160 psi. Line up to U-tube well. SIMOPS-Cut and slip drilling line. 14:30 16:00 1.50 0 0 COMPZ WHDBO FRZP P U-Tube well. SIMOPS R/U to lay down 4"drill pipe and HWDP from derrick. 16:00 17:00 1.00 0 0 COMPZ WHDBO MPSP P PJSM, R/U Lubricator and set 3" Type H BPV. 17:00 17:45 0.75 0 0 COMPZ MOVE RURD P Rig down hoses, secure wellhead, clean cellar area for rig move. Page 33 of 34 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 17:45 00:00 6.25 0 0 COMPZ MOVE PULD P Lay down 4"drill pipe. Page 34 of 34 ConocoPhillips Time Log & Summary Weliview Web Reporting Report Well Name: 2K-34 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 8/12/2014 6:00:00 AM Rig Release: 8/19/2014 9:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/11/2014 24 hr Summary Move CDR2 from 3Q pad to 2K-34, Begin spotting subs 08:00 10:30 2.50 0 0 MIRU MOVE MOB P PJSM with Peak trucking, seperate Rig, move off of 3Q-14, install jeeps, secure BOPE, hook up to jeeps. 10:30 16:00 5.50 0 0 MIRU MOVE MOB P Start 24 mile move towards 2K-pad. 16:00 20:30 4.50 0 0 MIRU MOVE MOB T Shut down move at 2B pad, need to shuffle rented mats around rig,wait on mats/plywood laid on road 2B to 2K pad. 20:30 21:45 1.25 0 0 MIRU MOVE MOB P Move rig from 2B pad to 2K-pad. 21:45 23:15 1.50 0 0 MIRU MOVE SFTY P Arrive on location, remove jeeps, prep cellar, DSO on site, PJSM 23:15 00:00 0.75 0 0 MIRU MOVE MOB P Begin spotting up rig over 2K-34, MIRU 08/12/2014 Spot subs over 2K-34. 00:00 02:15 2.25 0 0 MIRU MOVE MOB P Continue spot up, place mats, set down both subs over 2K-34. 02:15 06:00 3.75 0 0 MIRU MOVE RURD P PJSM- Continue with rig up ops, Pre spud checklist, landings,stairs and walkways, MP line, sensors. 06:00 10:00 4.00 0 0 MIRU WHDBO NUND P Start nipple up, prep for BOPE test, grease manifold and BOPE stack, check all flange bolts for tightness. Rig accept at 06:00 10:00 13:30 3.50 0 0 MIRU WHDBO CTOP P Trim 700'of coiled tubing for pipe management. Note:****Test waived by Chuck Sheve,AOGCC 13:30 15:30 2.00 0 0 MIRU WHDBO CTOP P Fluid pack surface lines fora shell test. Preping to perform slackmanagement.Trim 72'of coil to find wire 15:30 17:30 2.00 0 0 MIRU WHDBO CTOP P Prep Coil, install CTC, Pull test to 35k, P/T to 4000psi, 17:30 18:00 0.50 0 0 MIRU WHDBO BOPE P Start BOPE testing 18:00 00:00 6.00 0 0 MIRU WHDBO BOPE P Crew change, perform valve checklist,continue with BOPE test. Test witness waived by Chuck Sheve,AOGCC 08/13/2014 Spot up, MIRU, Perform CT Fatigue mgmt. Install CTC and head up E-line 00:00 06:00 6.00 0 0 MIRU WHDBO BOPE P Continue BOPE Test,Witness waived by Chuck Sheve,AOGCC Page 1 of 6 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:00 07:00 1.00 0 0 MIRU WHDBO BOPE P Continue testing BOPE 07:00 08:00 1.00 0 0 MIRU WHDBO CTOP P Test PDL, kill tank line,to 1500psi, 08:00 09:30 1.50 0 0 MIRU WHDBO CTOP P PJSM, M/U FMC lubricator and tools, P/T 2000psi,pull BPV, """Note: 1150psi on well 09:30 10:00 0.50 0 0 MIRU WHDBO CTOP P Pump forward 1 coil volume. 10:00 10:45 0.75 0 0 PROD1 RPEQP1SFTY P PJSM-deploying whipstock BHA. 10:45 12:30 1.75 0 0 PROD1 RPEQP1PULD P M/U and deploy WS setting BHA#1 12:30 17:30 5.00 0 0 PROD1 RPEQP1CTOP T Unable to pressure up PDL, troubleshooted pulled and inspected R1, R2, and R3. In the process of troubleshooting R valves,found B5 not operational. 17:30 23:00 5.50 0 0 PROD1 RPEQP1 CTOP T Crew change, complete change out of B5, Pressure test B5, Normal up rig 23:00 00:00 1.00 0 75 PROD1 RPEQP1WPST P PJSM, Continue PD BHA#1 with G-II whipstock,J Hydraulic setting tool, M/U to coil and surface test. RIH, EDC open, 1700'at Midnight 08/14/2014 Complete BOPE test, Troubleshoot to find and repair B5, PD BHA#1 and RIH 00:00 02:30 2.50 1,700 9,635 PROD1 RPEQP1WPST P RIH to set whipstock 02:30 03:48 1.30 9,635 9,967 PROD1 RPEQP1 DLOG P Log K1 tie in for-9.5', Set up and run CCL to 9980 bit 9916 locator. See joint©9910'corrected should be 9911.Will exit above jt @ 9968 by 5' 03:48 04:06 0.30 9,967 9,947 PROD1 RPEQP1WPST P At set depth @ 9967.97, oriented to HS,close EDC, See tool shift @ 3600PSI, Set down 3.5K,TOWS @ 9955, PUH to 9947 04:06 06:06 2.00 9,947 75 PROD1 RPEQP1WPST P Start rolling hole to 9.2 used flow pro for window milling fluid,while POOH 06:06 06:36 0.50 75 75 PROD1 RPEQP1 SFTY P Try and bleed wellhead pressure, unsuccessful, PJSM-for undeploying WS setting tools. 06:36 08:06 1.50 75 0 PROD1 RPEQP1PULD P PUD, BHA#1 08:06 08:36 0.50 0 0 PROD1 WHPST PULD P M/U milling assy. """"Note: Notified State of Alaska on HCR Valve(B5)replacement, retest and sent form to Jim Regg as per slope based AOGCC recommendation. 08:36 09:15 0.65 0 74 PROD1 WHPST PULD P PD, Milling BHA#2 09:15 11:15 2.00 74 9,670 PROD1 WHPST TRIP P RIH,with milling assy. 11:15 11:30 0.25 9,670 9,670 PROD1 WHPST DLOG P 9670',Tie into the K1 Marker correction of minus 11'. 11:30 11:45 0.25 9,670 9,958 PROD1 WHPST TRIP P Continue RIH to dry tag WS 11:45 14:45 3.00 9,958 9,961 PROD1 WHPST WPST P Time milling 1.5bpm at 3602psi, BHP 3835, IA 699, OA 260 Page 2 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 18:21 3.60 9,961 9,967 PROD1 WHPST WPST P 9961' looks like we are the the midway point of milling casing exit. 1.5bpm at 3765psi, BHP 3845, IA 258, OA 263 18:21 19:57 1.60 9,967 9,980 PROD1 WHPST WPST P 9967', Drilling rathole, 1.5 BPM @ 3602 PSI FS, BHP=3844 19:57 21:57 2.00 9,980 9,980 PROD1 WHPST REAM P Make window reaming passes, HS, 30L, 30R, HS,with dry drift.Window looks good, PUW=36K, BHP=3600 21:57 00:00 2.05 9,980 60 PROD1 WHPST TRIP P Trip out of hole, Stop and open EDC, PUW=36K 08/15/2014 Set Whipstock 9955'. Mill window, Rathole to 9980, Trip out for Build BHA 00:00 01:30 1.50 60 0 PROD1 WHPST PULD P PJSM, PUD BHA#2 window milling BHA,Window mill out at 2.79 No Go. String reamer out©2.79 no go. 01:30 02:30 1.00 0 0 PROD1 DRILL PULD P Lay down BHA#2, Reconfig for Build section drilling BHA#3, Swap out R6 valve stem 02:30 04:30 2.00 0 72 PROD1 DRILL PULD P PJSM M/U BHA#3, Build section BHA 1.5°AKO Motor 3.25 Bi Center with USR, M/U to coil and surface test 04:30 06:30 2.00 72 9,640 PROD1 DRILL TRIP P Trip in hole BHA#3, EDC open 06:30 06:45 0.25 9,640 9,640 PROD1 DRILL DLOG P 9640',Tie into the K1 marker minus 11'. 06:45 07:00 0.25 9,640 9,980 PROD1 DRILL TRIP P Continue RIH to bottom. 07:00 08:45 1.75 9,980 10,115 PROD1 DRILL DRLG P 9980', OBD 1.43bpm at 3550psi, BHP 3899,WHP 105, IA 303, OA 274 08:45 09:00 0.25 10,115 9,640 PROD1 DRILL TRIP P 10115',TD build section, PUW 30k, PUH to tie into the K1 marker. 09:00 09:15 0.25 9,640 9,640 PROD1 DRILL DLOG P 9640', Tie into the K1 marker no correction 09:15 09:30 0.25 9,640 9,970 PROD1 DRILL TRIP P RIH to log the RA marker 09:30 09:45 0.25 9,970 9,970 PROD1 DRILL DLOG P 9970', Log RA marker 9962.5'. 09:45 10:45 1.00 9,970 72 PROD1 DRILL TRIP P POOH,for lateral BHA. 10:45 13:00 2.25 72 0 PROD1 DRILL PULD P PJSM-PUD build BHA#3, L/D tools 13:00 14:00 1.00 0 72 PROD1 DRILL PULD P PJSM-M/U, PD, lateral BHA#4 w/ .65°motor bend, 3.25"bi-center bit. 14:00 16:00 2.00 72 9,620 PROD1 DRILL TRIP P RIH,with 0.65°ako motor and rerun hughes bi-center bit 16:00 16:15 0.25 9,620 9,620 PROD1 DRILL DLOG P 9620',Tie into the K1 Marker correction of minus 11'. 16:15 16:45 0.50 9,620 10,115 PROD1 DRILL TRIP P Continue RIH to bottom, 16:45 18:51 2.10 10,115 10,320 PROD1 DRILL DRLG P 10115', OBD 1.5bpm at 3550psi. BHP 3865,WHP 60, IA 326, OA 274 18:51 19:27 0.60 10,320 10,320 PROD1 DRILL WPRT P Wiper to 10010', PUW=30.5K 19:27 22:15 2.80 10,320 10,520 PROD1 DRILL DRLG P 10320', Drill ahead, 1.5 BPM @ 3630 PSI FS, BHP=3895, Out of zone @ 10450 22:15 22:45 0.50 10,520 10,520 PROD1 DRILL WPRT P 10520',Wiper trip to 10020, PUW=32K Page 3 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 10,520 10,552 PROD1 DRILL DRLG P 10520', Drill ahead, 1.48 BPM @ 3685 PSI FS, BHP=3917 Midnight depth 10552 08/16/2014 TD Build section @ 10115, Drill L1 to 10552 00:00 02:54 2.90 10,552 10,720 PROD1 DRILL DRLG P 10552', Drill ahead, 1.48 BPM @ 3685 PSI FS, Back in zone-10610' 02:54 04:36 1.70 10,720 10,721 PROD1 DRILL WPRT P Wiper trip to 3 1/2 tubing @ 9000' with sweeps, PUW=29K,Tie into RA for+2.5'. Swap Mud 04:36 07:21 2.75 10,721 10,920 PROD1 DRILL DRLG P 10,721', Drill Ahead, 1.5 BPM @ 3766 PSI FS, BHP=3887, new mud coming out of bit. Did observe additonal out density on bottoms uo from window through 4 1/2 tubing. 07:21 08:36 1.25 10,920 10,920 PROD1 DRILL WPRT P 10920',Wiper up hole to10075', PUW 31k 08:36 10:36 2.00 10,920 11,120 PROD1 DRILL DRLG P 10920', BOBD 1.5bpm at 3720psi, BHP 3962,WHP 111, IA 805, OA 301, 80-100 fph ****Note: Bleed down IA from 804psi to 235psi. 10:36 11:36 1.00 11,120 11,120 PROD1 DRILL WPRT P 11120',Wiper up hole to 10200', PUW31k, RIW 11k 11:36 14:06 2.50 11,120 11,320 PROD1 DRILL DRLG P 11120', BOBD 1.5bpm at 3730psi, BHP 3960,WHP 111, IA 233, OA 300 14:06 15:06 1.00 11,320 9,963 PROD1 DRILL WPRT P 11320',Wiper up hole to 9963', PUW 31k, 15:06 15:21 0.25 9,963 9,000 PROD1 DRILL WPRT P PU through window to 9000'to clean 4 1/2"section, 15:21 15:36 0.25 9,000 9,640 PROD1 DRILL WPRT P 9000',Wiper back in hole to tie into the RA marker. 15:36 15:51 0.25 9,640 9,640 PROD1 DRILL DLOG P 9640',Tie into the K1 marker correction of plus 4ft. 15:51 16:21 0.50 9,640 11,320 PROD1 DRILL WPRT P Continue wiper in hole, RIW 11k 16:21 19:09 2.80 11,320 11,520 PROD1 DRILL DRLG P 11320', BOBD 1.5bpm at 3770psi, BHP 3976,WHP 70, IA 161, OA 298 19:09 20:09 1.00 11,520 11,520 PROD1 DRILL WPST P 11520 wiper to 10510', PUW=32K 20:09 21:57 1.80 11,520 11,721 PROD1 DRILL DRLG P 11520', Drill ahead, 1.45 BPM @ 3660 PSI FS, BHP=3965 21:57 23:03 1.10 11,721 11,721 PROD1 DRILL WPRT P 11721',Wiper to 10530', PUW=32.5K 23:03 00:00 0.95 11,721 11,816 PROD1 DRILL DRLG P 11721', Drill, 1.45 BPM @ 3677 PSI FS, BHP=3966, RIW=7.8K DHWOB=I.6K 08/17/2014 Drill L1 10552 to 11861 00:00 03:18 3.30 11,816 11,904 PROD1 DRILL DRLG P 11816', Drill Ahead, 1.4 BPM @ 3766 PSI FS 03:18 04:33 1.25 11,904 8,945 PROD1 DRILL WPRT P 11904, Tough spot with poor weight transfer, Pull wiper trip with sweeps up through 4 1/2"Clean through 10,500'Area 04:33 04:48 0.25 8,945 9,985 PROD1 DRILL WPRT P 8945',Wiper back in hole. RIW 12k Page 4 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:48 05:03 0.25 9,985 9,985 PROD1 DRILL DLOG P 9985,Tie into the RA marker correction plus 3.5'. 05:03 06:03 1.00 9,985 11,904 PROD1 DRILL WPRT P 9985',Wiper back in hole, 06:03 13:33 7.50 11,904 12,105 PROD1 DRILL DRLG P 11904', BOBD 1.48bpm at 3828psi, BHP 4043,WHP 61, IA 331, OA 299 13:33 14:33 1.00 12,105 12,105 PROD1 DRILL WPRT P 12105',Wiper up hole to 11000', PUW31k 14:33 18:33 4.00 12,105 12,305 PROD1 DRILL DRLG P 12105', BOBD 1.5bpm at 3738psi, BHP 4059,WHP 51, IA 363, OA 302 18:33 19:39 1.10 12,305 12,305 PROD1 DRILL WPRT P Wiper to 12,200', PUW=32K 19:39 22:33 2.90 12,305 12,397 PROD1 DRILL DRLG P 12305', Drill, 1.47 BPM @ 3755 PSI FS, BHP=4097 22:33 23:03 0.50 12,397 12,397 PROD1 DRILL WPRT P Call TD Early @ 12397, Start 10 X 10 sweeps downhole recip waiting for sweeps, PUW=29K @ TD 23:03 00:00 0.95 12,397 10,515 PROD1 DRILL WPRT P Sweeps out,Wiper to swab 38/18/2014 Drill well to early TD @ 12397, Start wiper trip to swab 00:00 00:18 0.30 10,515 9,928 PROD1 DRILL WPRT P Cointinue wiper trip to swab, Circulate sweeps to surface 00:18 00:54 0.60 9,928 9,928 PROD1 DRILL PRTS P 9928, Obtain 30 min static pressure test @ window, DH pressure start at 4016 with 792 WHP,After 30 min 3901 PSI with 800 PSI WHP 12.44 PPG at window 00:54 02:48 1.90 9,928 53 PROD1 DRILL WPRT P Continue swab wiper trip 02:48 04:36 1.80 53 9,640 PROD1 DRILL WPRT P At surface, reset depth, RBIH 04:36 04:54 0.30 9,640 9,672 PROD1 DRILL DLOG P Log K1 for-12'correction 04:54 06:54 2.00 9,672 12,330 PROD1 DRILL WPRT P Continue wiper to bottom to confirm TD and pump liner running pill 06:54 07:54 1.00 12,330 9,950 PROD1 DRILL DISP P 12330', POOH laying in 12.6ppg completion fluid with alpine beads above window 07:54 09:54 2.00 9,950 72 PROD1 DRILL TRIP P 9950', POOH displacing well to 12.6ppg completion fluid ****Note: Paint EOP flags at 6500' (Yellow)and 9800'(White) 09:54 10:24 0.50 72 72 PROD1 DRILL SFTY P PJSM for laying tools down on dead well-While checking well for flow. 10:24 11:54 1.50 72 0 PROD1 DRILL PULD P L/D lateral drilling tools. 11:54 12:24 0.50 0 0 COMPZ CASING SFTY P PJSM-For M/U L1 liner completion. Prep rig floor 12:24 16:24 4.00 0 0 COMPZ CASING PUTB P M/U L1 liner assy. 16:24 17:54 1.50 0 2,422 COMPZ CASING PULD P PJSM-M/U BHI tools w/BOT GS M/U to coil and surface test tools, tag stripper and set depth. Check saddle clamp bolts 17:54 19:48 1.90 2,422 8,939 COMPZ CASING RUNL P RIH BHA#5,75 Jts slotted liner, non ported bullnose,and shorty deployment sleevr 19:48 19:54 0.10 8,939 8,921 COMPZ CASING DLOG P Correct to 6500'EOP flag for-17.3, PUW=33.1 K Page 5 of 6 r Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:54 21:06 1.20 8,921 11,985 COMPZ CASING RUNL P Continue in well, clean pass through window 21:06 21:12 0.10 11,985 12,005 COMPZ CASING DLOG P Log K1 marker for+5'correction 21:12 21:24 0.20 12,005 12,330 COMPZ CASING RUNL P Continue in hole 21:24 21:36 0.20 12,330 9,941 COMPZ CASING RUNL P Smooth trip to 12,300, PUW=36K, RBIH to 12300', pumps on 1.3 BPM @ 4189, PUW=28K., PUH to 12319, reset depth to GS @ 9941 21:36 00:00 2.40 9,941 9,941 COMPZ CASING CIRC P Pump 15 BBI Viscosified spacer followed by seawater recover 12.6 PPG completion fluid. Open EDC when water gets around BHA. Recovered 250 bbls 12.6 formate. 08/19/2014 Condition hole, Run L1 liner 12330 to 9951, roll hole to seawater 00:00 02:18 2.30 9,941 29 COMPZ CASING TRIP P POOH, F/P from 2500'to surface with LRS 02:18 04:18 2.00 29 0 COMPZ CASING PULD P PJSM, PUD BHA#5 04:18 07:00 2.70 0 0 DEMOB WHDBO CTOP P Pull checks from UQC, stab on well, flush with fresh water, circulate inhibitor through rig. Flush with freshwater 07:00 09:00 2.00 0 0 DEMOB WHDBO MPSP P Rig up lubricator. Install BPV. Detach from shore power. Rig down lubricator. Empty pits, begin blowing down. ND stack. Note:freeze protected tree with 5 gals methanol. *******Rig Release @ 0900******** Page 6 of 6 2K-34 WELL WORK SUMMARY ;Z 34-1- 1 DATE SUMMARY A-00 / /0101.-a101•1 R P T 7/17/2014 SLB CTU #5: PERFORM BOP SHELL TEST AND PUSH/PULL AFTER MONTHLY REBUILD AND BOPE TEST. CIRCULATE OUT DRILLING MUD WITH JET SWIRL NOZZLE, SLICK DIESEL, AND FLO-VIS GEL TO HARD TAG AT 9988' CTMD (10,003' RKB). DISPLACE WELL TO SLICK SEA WATER WITH CRW-132 CORROSION INHIBITOR AND LAY IN DIESEL FREEZE PROTECT FROM 2000'. READY FOR ELINE. 7/19/2014 DRIFTED TO TD @ 9953' SLM....JOB IN PROGRESS. 7/20/2014 PERFORATE FROM 9,955' - 9,960' RKB W/2-1/2" POWER JET GUNS, WAIT 1 HOUR AND LOG SBHPS: 30 MINS PRESSURE STOP @ 9,955' RKB: 3803 PSI & 161 DEGF. 15 MINS GRADIENT STOP @ 9,590' RKB 3758 PSI & 157 DEGF. PRESSURES WERE STILL RISING WHILE LOGGING , LOG GR &CCL FROM SHOT DEPTH TO SBR @ 8,994' RKB, LOG CCL TO SURFACE @ 120 FPM JOB DONE. 7/25/2014 DRIFT TBG W/2.68" CENT&TAG TD @ 10021' SLM; MEASURE BHP @ 9955' RKB: 3832 PSI. JOB COMPLETE 7/26/2014 (PRE-CTD)T POT PASSED, T PPPOT PASSED, IC POT PASSED, IC PPPOT PASSED, SV NEG PASSED, SV POS PASSED, SSV NEG PASSED, SSV POS PASSED, MV NEG PASSED, MV POS PASSED. W 1i�_ `M2 Q= Ca N O. I C i CC 0 U) 0 w WCe a H ,, Q U Z > .— a, i ._ — ....... _ .— J - co Pe5 . E Q. 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N O) m N O •C 8 0 40 N m N N CO 0) n m CO CO m CO N m CO 0 0) r n n O V CO N (O N 0) 1 C a N 0) N (V M R O N P. N (() O U 00 N N W h N N 4 W 3 m 2228 V O N V N (0 Q .°... CO CO N N N N N N N N N N N N N N N CO N N N N N N CO CO CO N N N (mV a a � a VI L iX N fa Y • O( N C n O O4 O N a ^0 60 a M - OO ° M 2 M V N 8 N O N ° V no 0O " N C QM MM (O ' '- ' S 0 0 NNN 0 ".. mm m 0) moCON CO N02 000mm 822E2 00202 00Nm 0 CL.O @ � V i Te 3 8TO OV m C'8 `4..' CO N O MM M M M N mO VNN- mmV N t N O .. In h6 (() V (n Y) 6 (() 6 IA 6 Nn ((I (f) (() L() ui NA N (() (() N (n N (() Y) O N O O CO CD CO N N CO N. 0 CO CO 0) N m CO N. 0 M CD 0) N (0 m 7 N. O C ` y 7 7 7 V 0 (O m CO (0 CO N. n N. N. CO m CO 0) 0) O) O O 0 0N N N CO_ V, O G N E V O O O O O O O O O O O O O O O O O O O C .- .- .- .- s- s- s- s- s- .- .- ^O Vo O r O 0 N7 CO,..CV O O. 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V V 2,30s--0 ( CO CO CO CO 0 aD 0 U) 0 00 00 a0 0 0 COCO 0 00 0i 0) 0i 0) 0i 0) 0) 0) 0i 0 0) _ x N_ CO M N ,OO M M 7 -O M 0 n O V 0 (O N M u) V N N M V M V O du V 822 ,73 &'M O0 0 M C (0 N 0 n N O O .-- N u) N M O M u) M n n N V V V 0 (O N N O 0 u) (O N N N /0 N J O (V I� ui 0) O CO C) V CO 0i r CO V 0) V CD M CO r O N O .- O Ci CO CO O CO CO j.. + + C m 0 M 0 `( 0 m E m N V 41' 7 Q M QNpp n pp pp MU� n (0 O (0 N N (0 O) o o N V (0 O) N n n (0 CO U) V — M M N E n (O N (O (O (0 0 0 N N U) V V O O (!) O S ; N N M M (O O O n u) (0 N O Na) O 0 O O O O O O ((yy V N f0 f0 (O (�7 (0 (,.(1-;-; O I� dD Oi O O ci Y . C 0 C n N. N O) (0 a0 (06' N ,82 M O n OD (O N (O O n 01 co_ a, 00 n n n co_ 0) (O M O u) (O V V V V CO CO.. 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O z (n (O N (A (0 N N (A (0 V] (O (b (0 ((] (O (f] N ((1 (n ((1 N (O ((I (O (n (O N (i UI (O (0 a) N U a) C A C 'OL C U a) C '' N U ` C Q. c _ O w w ) 0 U UO D OO 0 V N L- 7 CO n u 0 N CO M L- n N •- n 0 N 0 N V V .- CO n 0 N N4_ U NW Te1 ..- .= _ VO N' M U) (0 (O O (OO O O O O U) n 0 ) O (N V O V V 4 V N N NO 0 A• o i 0 JO > 2 o to O w 2 co 4 aQ m aQ m 4 m 4 m m aD m m m 4- 4 4 o? 4 of of m of of m of m o) m aS F I' V UD N- (O M 2 (MO (00 (00 V 00) N (D 0V UO N- N 8 (O v v N On (n0 M 003 O - (NO V O 11 _ Ci V U7 f� (V (O O) Oi Ci (V ) M I: cV 4) h r N O V O 0) C U) N 0 O O N N N N 0 m n n (O n n 0 0 0 0 �'' M c'';', M co V V V V V V V V V V V M M M CO CO (`7 (h CO CO CO M CO CO CO V Z N } .7. M U) 0 V N' UO 0 n n 0 M 0 N 0 N CO N 0 N Up CO u) 0 n 10 M 0 N V n aM (0 N n (Op ((N (np u) M V N- 0 OD (O (0 (((N (()O M OD (O 0 a0 N 0 U) , C 0 0 0 0 0 0 N N 0 0 0 0 0O 0 0 0 O O O 0 O O O O O O O O O O = O co O co O co O O O co O O O O O O 7.- c0 co" O co- (0 co' as (O co co" O (O co- co- co- co- (0 (0 (0 (0 (0 (0 (0 (0 (0 (0 (0 (0 6co- co. .j CV f 1 (O 0) N n n0 0 N u)(O 0 NCOV M 0 UD V(0 M co N (n N 00 V 0 N V CO C) (O O m 0 COM,- N . n(0 0 0 ((0p V N coV (O O n 0 M V N 0 7 0 V 888 ,c-,-.., ,c-i, Ih O W W 0 0 O (V (() u) n ND 0 O (V V O N- 0) 00 I� u) Y q 0 C) 0) 0 0 0 0 0 0) 0 0 0 0 0 `0 0 0 0 0 N N N N N N N N N N N N N N ',SDI N N N U x 0 (0 co' (O (O N co' (D O O (0 (0 (O 0 M O (0 O N (0 f0 (O (O (O (O (O (O (D (D (O (C1‘31 t0 C to Y N M u) M M 0 0 n V 0 0 n O N N V W 0 07 V M M 0 O 0 O N '. (O M O M u) E. a0 O V 0 (O U7 O n 0 N 0) 0 O n O n n M n V 0 Q 7 a J ^ 0) 82228 Onnn Nn O (0 O O (O O 23222 uO n Vn nm OU)D N N 2 N' . 4) d Q Z-. N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N I 2 tA E k N O YM M O MO N M N0 M N M V n A 0 O V c'.,-3 0 CO N O O n V O 0 M M C d M M 0 7 7 U aW pp pp mf W 000 oad m a 0 Ni d Ia�D 0,-; 0N7 2 2 IW� i 0 0 0 0 0 0 ad a0S U Y Y N N N Z CL i M O V 1 N p N m O V O n t-3 ,7. 4 UV O VD M NVD M N V N O O (O w O 0 ND 0 0 c4 O_ a N O ui ui ui ui ui ui u) u) u) u) u) ui Ui ui ui Ui u) u) u) u) u) ui ui ui ui ui ui ui ui ui ui M (0 0 N u) 0 n 0 M M 0 N u) 0 ((pp 0 N u) 0 V n O M C .. i O y M (`') M V V (O uI u) 0 M 0 n n n z-0- 2S-388 0 0 0 0 0 N N ;7-- 0 0co O L >. 2 C - . .- .- .- .- . r .- .- , . . . . . . .. . . ,- .- ' N N N N N N N (V O U co O U E• O y d d N N CO O Q. (.i) 0 CO -4 CO CO 1.1 0 P. I o ics ‹C c O YQ 0 E 0 to 1- Z o v- s o as 0 UJ 00 > � > > � U) 2 M M M a 7 7 (O co O r O O O CO CO N ai CD M M (1 CO V V COV U) x co co d) 2 CO M « •C N 1Q r V O N- r V O O +N N al CD+ 2 U) J O co O t` N O ] 00 CO = al ❑ i ✓ vi vi O Y M E CO ti Q E N CO CO CO CO i N• M M G1 E CO. O V N 1� >6) 2 •S ❑ c CD co rn 0 ro m N N F- W N V C6 06 O 0) a0 2 Wrj 'OV V V OV V O - 5 € U -O 6& '000 (00 f cc ` 0 m 0) N OJ • ) T w 0) co 6 6 co C CO CO CO CO CO S j 2.‘44- 2/-rt k 44-2/-rtk Letter of Transmittal BAKER Date. DATA LOGGED August 19 2014 2.0/2o144HUGHES g ' M.K.BENDER To: From: Meredith Guhl Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage,Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2K-34L1 44( o & 4 4' 0 (1) Total print 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. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager MAILa,frui.d17) 6,„zet Yosha.Ragbirsingh • BakerHughes.com 2.1) r � ■ W W; ` gXN O. On m , � e2e9 C; t$e o 0. co C3 a) — w Zi i— ,, Q. z a� ._ 0 C s — .c c VO w °. co = >_ Y ao o 0 v c•, o L :1-• c O0 r. _Ne _Ne (14 1mm V `1 `Cl� qtr CD• y- = 0 a . "? 1- CO C a 0 Y Cl 00 0 NI Z co a 1r co7 S ll r, v ao m of co V u') ) CO O S p c co 0 b N u) 12. C N ,r)r` a co V) m LL Z 0 0 C o 0 O o 0 F.', a N- Q N T1 V V O J a 0 c 0 7 .0 0 0 'p « c O 0 is O 2d J J 0 C co o oW .. 7 7 Q 2. 0 M M 0. CO co (h 0 .▪ .. - ,-- @) @ O coco co co N .O V (N 1,- C NI CO CO C7 W V CO ri U Y (h 1 P , _ 0_ Oy £ a w WoN V V a + ? — M co a) 0 > C NNH2W CUNO ITi)• wO O Q' N 7 7 7 J ,- 0 0 m Tv, o °� o 0_ d U) > O) C) m N C a C O) O) V COC 0 p7 C C O O M Q W c >0 �... V ,- r C y co 7 d (I) R U N ja c (°i ` 7 o) o 17) ; A co CO w a) a) 0 y C d LL' .. a) d IP O O 7 R > y O a co c m o O r c .c L N E a) Z w N > i to d w @ aS U 0 v -O a) o N 0. 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Y cir— 00 � ` 0 CO 10 stC'') st C° M O O n U L 0 Y Y N N N 2-- m m rn m 0 01 Z L=QC d` 0 o() rn 0 yN0) MM N NOi O 0 V0. ° 0 C Ta ` N N N N N 7 V E m NN 'N C O « N0 ca o a m 3 3 o co co OF 7,--(--, �\\I%%iY.� k E SAE .`` ._ a 1`.(: � C � ' A' +_v 333 Wesl Se\enlh Aenue �'" r t� GOVERNOR Si- AN PARNI:1 I Anchorage, Alaska 99571-3572 Mc P 9C7 279 1L33 r.Ac...:-.-- D. Venhaus CTD Supervising Engineer ConocoPhillips Alaska, LLC P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-34L1 ConocoPhillips Alaska, Inc. Permit No: 214-115 Surface Location: 4983' FNL, 94' FEL, SEC. 2, T10N, R8E, UM Bottomhole Location: 346' FSL, 1921' FEL, SEC. 3, T10N, R8E, UM Dear Mr. Venhaus: 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 Permit No. 214-026, API No. 50-103- 20688-00-00. 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 AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Y ,,2-,,7____ David J. Mayber Commissioner DATED this Lt 'day of August, 2014. RECEIVE' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,jUL 2 9 2014 PERMIT TO DRILL a � 20 AAC 25.005 902 1 a Type of Work k 1 b Proposed Well Class: Development-Oil 2. Service-Winj ❑ Single Zone 0• 1 c Specify if well is proposed for Drill L 1 Lateral Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redd! ❑ Reentry Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name 5. Bond , U Blanket Li Single Well 11 Well Name and Number ConocoPhillips Alaska, Inc. Bond No. 59-52-1801 2K-34L1 3 Address 6 Proposed Depth. 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 i� MD: 12450' • TVD: 6208' ' Kuparuk River Field 4a Location of Well(Governmental Section) 7.Property Designation(Lease Number) Surface:4983'FNL,94'FEL,Sec.2,TiON,, E, UM ' ADL 25588,25589 • Kuparuk Oil Pool • Top of Productive Horizon 8 Land Use Permit 13 Approximate Spud Date. 569'FSL,911'FWL,Sec.3,T1ON, R8E,UM 2674,2675 9/1/2014 Total Depth 9 Acres in Property 14.Distance to 346'FSL, 1921'FEL,Sec.3,T1ON, R8E,UM ' 5120 • Nearest Property 16496 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10 KB Elevation above MSL• 143 feet 15 Distance to Nearest Well Open Surface:x- 498310 y- 5938600 Zone- 4 - GL Elevation above MSL• 27 feet to Same Pool 2K-13AL1 ,2683 16.Deviated wells Kickoff depth . 9955 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle. • 93° deg Downhole:4328 psig • Surface:3711 psig • 18 Casing Program Specifications Top - Setting Depth -Bottom Cement Quantity,c f or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 2500' 9950' 6169' 12450' 6208' slotted liner 1 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) 10127 6217 none 10117 6215 none Casing Length Size Cement Volume MD TVD Conductor/Structural 76' 16" pre-installed 104' 104' Surface 3515' 10.75" 1338 sx CI G, 198 sx CI G 3543' 2876' Intermediate 9222' 7" 289 sx Class G 9248' 5978' Production Liner 1138' 4.5" 195 sx Class G 10117' 6215' Perforation Depth MD(ft): Perforation Depth TVD(ft): none none 20 Attachments Property Plat ❑ BOP Sketch ❑ Drilling Prograrr ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21 Verbal Approval Commission Representative Date. 7/cW/Ir 04 22. I hereby certify that the foregoing is true and correct Contact James Ohlinger @ 265-1102 Email James.J.Ohlinger@conocophillips.corr Printed Name 7 D. Venh S Title CTD Supevising Engineer Signatur . / Phone:263-4372 Date 7-2Y':`V Commission Use Only Permit to Drill i API Number Permit Approval See cover letter Number Q 3)4 3 50- 3 03-0113 G?--GT-i_D Date -k 1-2 p\8.( for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed me ane,gas hydrates,or gas contained in shales. Er/ Other:Ou P t e S f-- /-c ¢G G C 1, 5 / Samples req'd: Yes No [j Mud log req'd: Yes❑ No g H2S measures: Yes No LnJ r❑ Directional svy req'd: Yes No❑: Spacing exception req'd: Yes ❑ No E J Inclination-only svy req'd: Yes❑ No[v r n` ft S INP O Y THE 8'I,1/,y Approved by C M I E M ISS10N Date: Form 10-401(Revised 10/2012) Ri�pegmu rs li f 4 n f t of approval(20 AAC 25.005(g)) '�l6 713)`�/LI e 70 RECEIVED ConocoPhillips JUL 2 9 2014 Alaska A OG C C P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 24, 2014 Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for a permit to drill a lateral out of the Kuparuk Well 2K-34 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in September 2014. The CTD objective will be to lateral 2K-34L1 targeting the A4 sand interval. d Attached to this application are the following documents: - Permit to Drill Application Form for 2K-34 - Detailed Summary of Operations - Directional Plans - Proposed Schematic If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, James Ohlinger Coiled Tubing Drilling Engineer 1117, Ns Kuparuk CTD Laterals NABpASALASKA 0' 2K-34L1 C� CCnxxuet 4i, Application for Permit to Drill Document 2tit 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 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 6 (Requirements of 20 AAC 25.005(c)(14)) 6 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 Plan for 2K-34L1 7 Attachment 2: Current Well Schematic for 2K-34 7 Attachment 3: Proposed Well Schematic for 2K-34L1 7 Page 1 of 7 7/24/2014 ORIGINAL • PTD Application: 2K-34L1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed lateral described in this document is 2K-34L1. The lateral will be classified as "Development- Oif'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The lateral will target the A sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 2K-34L1. 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 formation pressure in the area of 4328 psi in the 2M-14, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3711 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)) A static bottom hole pressure of 2K-34 on July 20, '14 indicated a reservoir pressure of 3803 psi or 11.85 ppg equivalent mud weight. During the recent drilling of the motherbore a 13.1 ppg LSND fluid was used to overbalance the well. The maximum down hole pressure in the 2K-34 pattern is at 2M-14 with 4328 psi. It is not expected that reservoir pressure as high as 2M-14 will be encountered while drilling the 2K-34 lateral because of offset distance and faulting. Using the 2M-14 pressure as the maximum possible in 2K-34, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3711 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection is not in the area, so there is a low probability of encountering gas Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 2K-34 laterals will be if pressure exceeds 12.8 ppg, well will have to be delayed and pre-production needed to reduce pressure prior to CTD. 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. Page 2 of 77/24/2014 CRIGINAL PTD Application: 2K-34L1 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 2K-34L1 9950' 12,450' 6026' 6065' 2%", 4.7#, L-80, ST-L slotted liner Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 165 A-106 Welded 28' 104' 0' 104' -Surface 10-3/4" 45.5 L-80 H563 28' 3543' 0' 2876' 5210 2480 Casing 7" 26.0 L-80 TN Blue 26' 9248' 0' 5978' 7240 5410 Tubing 3 1/2" 9.2 L-80 EUE-MOD 24' 9025' 0' 5918' 10160 10540 Tubing 4 W 12.6 L-80 IBTM 8979' 10117' 6215' 8430 7500 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 Flo-Pro FloVis mud (9.2 ppg) - Drilling operations: Chloride-based Flo-Pro FloVis mud (9.2 ppg). While this mud weight hydrostatically underbalances the reservoir pressure, a higher overbalanced condition will be maintained using MPD practices described below. - Completion operations: 2K-34 does not contain a subsurface safety valve (SSSV). The well will be loaded with 12.0 ppg NaBr completion fluid in order to provide formation over-balance while running completions. - Emergency Kill Weight fluid: Two well bore volumes (-220 bbl)of at least 12.0 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. Page 3 of 7 ORIGINAL 7/24/2014 PTD Application: 2K-34L1 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 minimum EMW to ensure stability of shale sections. For 2K-34 CTD operations will begin with holding a 12.0 ppg EMW at the window. 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. Pressure at the 2K-34 Window (9,955' MD, 6,170' TVD) Using MPD � Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.85 ppg) 3803 psi 3803 psi Mud Hydrostatic(9.2 ppg) 2952 psi 2952 psi Annular friction (i.e. ECD, 0.090 psi/ft) 896 psi 0 psi Mud + ECD Combined 3848 psi 2952 psi (no choke pressure) (overbalanced (underbalanced —45 psi) —851 psi) Target ,. at Window(12.0 ppg) 3850 psi 3850 psi Choke Pressure Required to Maintain Target BHP 0 psi 898 psi 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. Page 4 of 7 ci R I G I N A L 7/24/2014 PTD Application: 2K-34L1 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well 2K-34 will be a Kuparuk A-sand Producer(development)well equipped with 3'h"tubing,7"casing, and a 4-1/2' liner. The well was recently drilled to replace 2K-08. The original well plan was adjusted from rotary grass-root horizontal to a slant completion with a CTD set-up due to severe lost circulation in a shallower zone(7,250 ft MD). A 6-1/8"hole was drilled at a tangent to the current angle and landed into the base of the A4 sand. The well currently has 4-1/2"liner cemented in-place to set-up for a CTD sidetrack. A mechanical whipstock will be placed in the 4-1/2"liner at the planned kickoff point. The 2K-34L1 lateral will exit through the 4-1/2"liner at 9,955' MD and will target the A4 sand west of the existing well. The lateral will be completed with 2-%" slotted liner from TD with the liner top located 5' above the whipstock, inside the 4-1/2"liner focr C dri SC-19G 6 M L) Pre-CTD Work 1. RU slickline:pull sheared SOV, set dummy valve 2. MIT-IA 3. RU slickline: drifted tubing with 29'-3" x 2.125" STEM(tractor)&6'-8"x 2.74"dummy perf 4. RU CTU:Fill clean-out down to 9988' CTMD(10,003' RKB) 5. RU Digital Slickline:drift tubing,perforate from 9955' -9960' RKB, SBHP(3803 psi) 6. 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-34L1 Lateral(A4 sand) a. Set whipstock at 9,955' MD b. Mill 2.80"window at 9,955' MD. c. Drill lateral to TD of 12,450' MD d. Run 2%"slotted liner from TD up to 9,950' MD,inside the 4-%2"liner 3. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Install GLV 3. Return well to production Page 5 of 7 7/24/2014 ORIGINAL PTD Application: 2K-34L1 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 — The 2K-34 CTD lateral will be displaced to an overbalancing fluid (12.0 ppg NaBr) 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. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 ORIGINAL 7/24/2014 PTD Application: 2K-34L1 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 KPA boundary at closest point) Lateral Name Distance 2K-34L1 16,496' — Distance to Nearest Well within Pool (heel measured to offset well) Lateral Name Distance Well 2K-34L1 1683 2K-13AL1 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 17. 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C!) 1.N.N.N-CC)IA CO CO c....CO CO CO CO C) NCV 00 0000 CV 0000 CV N NCV CV CV E.� U._000 CO CV Fs CO ts .72,- n O V CV V iliiffii� C O---C V C D C C] a CO V T = 0 Is:CO CV.,-�OS^F.:n Is:F.: O ��Fs O C)CD C)O CD OD CO CO COLO g ',a 'I0 ci n 8888888888888 o e quiN-to o o o o o o o o o CDLO0 h co 0,SS OCO CO 0D OOS�CV 01-Li r Iana1 eas maw O O C -C ,_CV Md'...r)CO N-CO C)0f-CV cour o (u!f jsn S6)gidaQ 1sotuan an.i1, ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-34 2K-34L1 Plan: 2K-34L1_wp04 Standard Planning Report 24 July, 2014 BAKER HUGHES ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2K-34 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-34:115.8+27.33 @ 143.13usft(Doyon 141) Project: Kuparuk River Unit MD Reference: 2K-34:115.8+27.33 @ 143.13usft(Doyon 141) Site: Kuparuk 2K Pad North Reference: True Well: 2K-34 Survey Calculation Method: Minimum Curvature Wellbore: 2K-34L1 Design: 2K-34L1_wp04 Project Kuparuk River Unit,North Slope Alaska,United States 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: 5,938,600.18 usft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17 usft Longitude: 150°0'49.133 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.01 ° Well 2K-34,Replaces 2K-08C Well Position +NI-5 0.00 usft Northing: 5,938,419.98 usft Latitude: 70°14'34.747 N +EI-W 0.00 usft Easting: 498,309.81 usft Longitude: 150°0'49.143 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 115.80 usft Wellbore 2K-34L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 11/1/2014 19.01 80.83 57,563 Design 2K-34L1_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,875.71 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 27.33 0.00 0.00 270.00 Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 9,875.71 74.01 270.98 6,148.53 232.27 -7,025.33 0.00 0.00 0.00 0.00 9,955.00 74.10 271.38 6,170.32 233.84 -7,101.56 0.50 0.11 0.50 76.88 9,980.00 77.10 271.38 6,176.53 234.42 -7,125.76 12.00 12.00 0.00 0.00 10,060.00 93.10 271.38 6,183.34 236.33 -7,205.19 20.00 20.00 0.00 0.00 10,130.00 92.28 257.39 6,180.04 229.51 -7,274.60 20.00 -1.17 -19.99 267.00 10,200.00 91.92 252.50 6,177.48 211.34 -7,342.13 7.00 -0.52 -6.99 265.80 10,700.00 91.57 287.51 6,161.78 211.41 -7,834.14 7.00 -0.07 7.00 90.00 10,970.00 91.48 268.61 6,154.52 249.08 -8,100.17 7.00 -0.03 -7.00 -90.00 11,120.00 89.47 278.91 6,153.27 258.90 -8,249.63 7.00 -1.34 6.87 101.00 11,220.00 87.31 285.58 6,156.08 280.09 -8,347.26 7.00 -2.15 6.66 108.00 11,470.00 87.44 268.06 6,167.62 309.61 -8,594.26 7.00 0.05 -7.01 -90.00 11,770.00 87.54 289.08 6,180.92 354.01 -8,888.96 7.00 0.03 7.01 90.20 12,085.00 87.72 267.01 6,194.13 397.78 -9,198.67 7.00 0.06 -7.01 -90.00 12,450.00 87.94 292.58 6,208.19 459.31 -9,555.10 7.00 0.06 7.00 90.00 7/24/2014 3:27:53PM Page 2 COMPASS 5000.1 Build 61 O ! G1NAL v IS" ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2K-34 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-34:115.8+27.33 @ 143.13usft(Doyon 141) Project: Kuparuk River Unit MD Reference: 2K-34:115.8+27.33 @ 143.13usft(Doyon 141) Site: Kuparuk 2K Pad North Reference: True Well: 2K-34 Survey Calculation Method: Minimum Curvature Wellbore: 2K-34L1 Design: 2K-34L1_wp04 Planned Survey Measured Vertical Vertical Dogleg Toolface Map Map Depth Inclination Azimuth Depth +Nl-S +El-W Section Rate Azimuth Northing Easting (usft) (0) (0) (usft) (usft) (usft) (usft) (1100usft) (°),_ (usft) (usft) 9,875.71 74.01 270.98 6,148.53 232.27 -7,025.33 7,025.33 0.00 0.00 5,938,653.80 491,285.23 TIP 9,900.00 74.04 271.10 6,155.22 232.69 -7,048.68 7,048.68 0.50 76.88 5,938,654.23 491,261.89 9,955.00 74.10 271.38 6,170.32 233.84 -7,101.56 7,101.56 0.50 76.85 5,938,655.39 491,209.02 KOP 9,980.00 77.10 271.38 6,176.53 234.42 -7,125.76 7,125.76 12.00 0.00 5,938,655.97 491,184.81 End 12 dls,Start 20 dls 10,000.00 81.10 271.38 6,180.31 234.89 -7,145.39 7,145.39 20.00 0.00 5,938,656.45 491,165.19 10,060.00 93.10 271.38 6,183.34 236.33 -7,205.19 7,205.19 20.00 0.00 5,938,657.91 491,105.40 4 10,100.00 92.65 263.38 6,181.33 234.51 -7,245.06 7,245.06 20.00 -93.00 5,938,656.09 491,065.52 10,130.00 92.28 257.39 6,180.04 229.51 -7,274.60 7,274.60 20.00 -93.40 5,938,651.09 491,035.99 End 20 dls,Start 7 dls 10,200.00 91.92 252.50 6,177.48 211.34 -7,342.13 7,342.13 7.00 -94.20 5,938,632.94 490,968.46 6 10,300.00 91.90 259.50 6,174.14 187.18 -7,439.05 7,439.05 7.00 90.00 5,938,608.81 490,871.55 10,400.00 91.86 266.51 6,170.85 175.01 -7,538.19 7,538.19 7.00 90.23 5,938,596.66 490,772.42 10,500.00 91.79 273.51 6,167.67 175.03 -7,638.07 7,638.07 7.00 90.46 5,938,596.70 490,672.54 10,600.00 91.69 280.51 6,164.63 187.22 -7,737.22 7,737.22 7.00 90.69 5,938,608.91 490,573.41 10,700.00 91.57 287.51 6,161.78 211.41 -7,834.14 7,834.14 7.00 90.90 5,938,633.12 490,476.50 7 10,800.00 91.56 280.51 6,159.05 235.60 -7,931.07 7,931.07 7.00 -90.00 5,938,657.33 490,379.59 10,900.00 91.52 273.51 6,156.36 247.79 -8,030.23 8,030.23 7.00 -90.19 5,938,669.54 490,280.44 10,970.00 91.48 268.61 6,154.52 249.08 -8,100.17 8,100.17 7.00 -90.38 5,938,670.85 490,210.51 8 11,000.00 91.08 270.67 6,153.85 248.89 -8,130.16 8,130.16 7.00 101.00 5,938,670.67 490,180.52 11,100.00 89.74 277.54 6,153.13 256.04 -8,229.84 8,229.84 7.00 101.05 5,938,677.84 490,080.85 11,120.00 89.47 278.91 6,153.27 258.90 -8,249.63 8,249.63 7.00 101.10 5,938,680.71 490,061.06 9 11,200.00 87.74 284.24 6,155.22 274.95 -8,327.95 8,327.95 7.00 108.00 5,938,696.77 489,982.76 11,220.00 87.31 285.58 6,156.08 280.09 -8,347.26 8,347.26 7.00 107.87 5,938,701.91 489,963.45 10 11,300.00 87.33 279.97 6,159.82 297.75 -8,425.16 8,425.16 7.00 -90.00 5,938,719.59 489,885.56 11,400.00 87.38 272.96 6,164.45 308.99 -8,524.36 8,524.36 7.00 -89.74 5,938,730.85 489,786.38 11,470.00 87.44 268.06 6,167.62 309.61 -8,594.26 8,594.26 7.00 -89.41 5,938,731.49 489,716.48 11 11,500.00 87.43 270.16 6,168.96 309.15 -8,624.23 8,624.23 7.00 90.20 5,938,731.03 489,686.52 11,600.00 87.44 277.17 6,173.44 315.52 -8,723.86 8,723.86 7.00 90.11 5,938,737.43 489,586.89 11,700.00 87.48 284.17 6,177.87 334.01 -8,821.97 8,821.97 7.00 89.79 5,938,755.93 489,488.80 11,770.00 87.54 289.08 6,180.92 354.01 -8,888.96 8,888.96 7.00 89.48 5,938,775.95 489,421.82 12 11,800.00 87.54 286.98 6,182.21 363.29 -8,917.46 8,917.46 7.00 -90.00 5,938,785.23 489,393.32 11,900.00 87.57 279.97 6,186.48 386.55 -9,014.56 9,014.56 7.00 -89.91 5,938,808.51 489,296.24 12,000.00 87.63 272.96 6,190.67 397.80 -9,113.77 9,113.77 7.00 -89.61 5,938,819.78 489,197.04 12,085.00 87.72 267.01 6,194.13 397.78 -9,198.67 9,198.67 7.00 -89.32 5,938,819.78 489,112.15 13 12,100.00 87.72 268.06 6,194.72 397.13 -9,213.64 9,213.64 7.00 90.00 5,938,819.14 489,097.18 12,200.00 87.74 275.07 6,198.69 399.86 -9,313.46 9,313.46 7.00 89.96 5,938,821.88 488,997.37 12,300.00 87.80 282.07 6,202.59 414.73 -9,412.21 9,412.21 7.00 89.68 5,938,836.78 488,898.64 12,400.00 87.88 289.08 6,206.37 441.54 -9,508.41 9,508.41 7.00 89.41 5,938,863.61 488,802.45 12,450.00 87.94 292.58 6,208.19 459.31 -9,555.10 9,555.10 7.00 89.14 5,938,881.38 488,755.77 Planned TD at 12450.00 7/24/2014 3:27:53PM Page 3 COMPASS 5000.1 Build 61 ORIGINAL A ' I ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2K-34 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-34:115.8+27.33 @ 143.13usft(Doyon 141) Project: Kuparuk River Unit MD Reference: 2K-34:115.8+27.33 @ 143.13usft(Doyon 141) Site: Kuparuk 2K Pad North Reference: True Well: 2K-34 Survey Calculation Method: Minimum Curvature Wellbore: 2K-34L1 Design: 2K-34L1_wp04 Planned Survey Measured Vertical Vertical Dogleg Toolface Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (1 (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2K-34L1_T2 0.00 0.00 6,153.13 252.831,131,934.35 5,938,419.00 1,630,131.00 70°0'47.064 N 140°56'39.575 W -plan misses target center by 1138959.69usft at 9875.71 usft MD(6148.53 TVD,232.27 N,-7025.33 E) -Point 2K-34L1_Fault 2 0.00 0.00 143.13 318.751,131,515.29 5,938,485.00 1,629,712.00 70°0'48.315 N 140°56'51.192 W -plan misses target center by 1138556.47usft at 9875.71 usft MD(6148.53 TVD,232.27 N,-7025.33 E) -Rectangle(sides W625.00 H1.00 D0.00) 2K-34L1_T1 0.00 0.00 6,179.13 242.061,132,951.46 5,938,408.00 1,631,148.00 70°0'45.477 N 140°56'10.743 W -plan misses target center by 1139976.79usft at 9875.71 usft MD(6148.53 TVD,232.27 N,-7025.33 E) -Point 2K-34 CTD Polygon 0.00 0.00 143.13 1,156.401,129,615.92 5,939,323.00 1,627,813.00 70°0'59.215 N 140°57'41.562 W -plan misses target center by 1136657.49usft at 9875.71 usft MD(6148.53 TVD,232.27 N,-7025.33 E) -Polygon Point 1 143.13 0.00 0.00 5,939,323.00 1,627,813.00 Point2 143.13 -737.12 3,470.55 5,938,585.18 1,631,283.04 Point 3 143.13 -1,144.17 3,427.66 5,938,178.18 1,631,240.06 Point 4 143.13 -946.86 856.35 5,938,376.04 1,628,669.05 Points 143.13 0.00 0.00 5,939,323.00 1,627,813.00 2K-34L1_T4 0.00 0.00 6,208.13 469.551,130,585.17 5,938,636.00 1,628,782.00 70°0'51.134 N 140°57'16.960 W -plan misses target center by 1137610.53usft at 9875.71 usft MD(6148.53 TVD,232.27 N,-7025.33 E) -Point 2K-34L1_T3 0.00 0.00 6,169.13 318.751,131,516.29 5,938,485.00 1,629,713.00 70°0'48.314 N 140°56'51.164 W -plan misses target center by 1138541.63usft at 9875.71 usft MD(6148.53 TVD,232.27 N,-7025.33 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 3,542.99 2,875.71 10-3/4"x 13-1/2" 10.750 13.500 9,257.00 5,980.18 7"x 8-1/2" 7.000 8.500 12,450.00 6,208.19 2-3/8 2.375 3.000 7/24/2014 3:27:53PMPage 4 COMPASS 5000.1 Build 61 ORIGINAL WC ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2K-34 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-34:115.8+27.33 @ 143.13usft(Doyon 141) Project: Kuparuk River Unit MD Reference: 2K-34:115.8+27.33 @ 143.13usft(Doyon 141) Site: Kuparuk 2K Pad North Reference: True Well: 2K-34 Survey Calculation Method: Minimum Curvature Wellbore: 2K-34L1 Design: 2K-34L1_wp04 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (usft) (usft) (usft) (usft) Comment 9,875.71 6,148.53 232.27 -7,025.33 TIP 9,955.00 6,170.32 233.84 -7,101.56 KOP 9,980.00 6,176.53 234.42 -7,125.76 End 12 dls,Start 20 dls 10,060.00 6,183.34 236.33 -7,205.19 4 10,130.00 6,180.04 229.51 -7,274.60 End 20 dls,Start 7 dls 10,200.00 6,177.48 211.34 -7,342.13 6 10,700.00 6,161.78 211.41 -7,834.14 7 10,970.00 6,154.52 249.08 -8,100.17 8 11,120.00 6,153.27 258.90 -8,249.63 9 11,220.00 6,156.08 280.09 -8,347.26 10 11,470.00 6,167.62 309.61 -8,594.26 11 11,770.00 6,180.92 354.01 -8,888.96 12 12,085.00 6,194.13 397.78 -9,198.67 13 12,450.00 6,208.19 459.31 -9,555.10 Planned TD at 12450.00 7/24/2014 3:27:53PM Page 5 COMPASS 5000.1 Build 61 _, n , � INAL • — II II II 0 11 II in II `r II N II :1 o cam,.) Y o II m in o N I— I1 CO F — II �i o C m 11 m o 1 II in E Y Y II oYo eL N co CC N 11 0? N ,_ o co C) o II J r I\ E N rn 0 11 o 0 0 O m Y o N II U -, Y - CO I I Et Cr Y I I i� a) -a -a CC a` c ) (o Y c ,_ U C Cl) NY cn o Eco co coY c 11 aa4= g F g co Q CC a `) co I I m - m g oo •� � II TD_ 00 03 03 2 n W 0) m cCO Oo m II cJ U W � m U uu) Li ca II 0 0O o Ct o N 2u_LI) m U W 11 Z cn Jo F- co i� o cn 11 U o - U O 1 E *k Er E c x � xv co a) ca co as ca U Q_ _ - o ova II 9 a U co U o in in in co corn �) II 6 N N N Co N N a) a) a) a) J = F2 45 l' Y - - x1 — C as N N N (o M M MI- co C't) Jmmmm N0 1:1) a) MI i _ N kir i / IN, Abb. 1 CO O N I- p A,At o p O— tit ., ii- (J) < CC) tl Cl) O Om • Y m O i 0_ 0 H U o o HI J Lri N coo g Co 0 M O u) O L u) ORIGINAL • KUP PROD 2K-34 4 Conoco PhillipsOP Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(566) Act Btm(flKB) .71111111, 501032068800 KUPARUK RIVER UNIT PROD 74.58 9,212.37 10,127.0 -,- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-34.723201410.5844 AM SSSV:NIPPLE Last WO: 27.33 6/23/2014 Vertical schematic lacteal) Annotation Depth MKS) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PERFORATIONS lehallf , 7/8/2014 HANGER,23.5- Casing Strings • Casing Description OD 5n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 14.000 28.0 104.0 104.0 164.80 A-106 Welded ---- -- - ` Casing Description OD(in) ID(in) Top(MB) _Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 28.3 3,543.0 2,875.7 45.50 L-80 Hyd563 L Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen 0...Grade Top Thread ,. „ . INTERMEDIATE 7 6276 25.8 9,247.7 5,977.7 26.00 L-80 TN Blue Casing Description OD(in) 'ID(in) Top(ttK8) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread _..._...___._._...._..._...__......._.. _.. ...._..__.. 3.958 8,979.2 10,117.0 6,214.8 12.60 L-80 IBTM LINER 412, 1i r Liner Details Nominal ID Top(flKB) Top(ND)(ftKB) Top not(°) Item Des Com (in) 8,979.2 5,906.0, 74.43 PACKER BAKER 5"x 7"ZXP PACKER w HRDE profile 10' 5.250 8,999.3 5,911.4 74.51 NIPPLE BAKER"RS"NIPPLE TSH-521 Box x Box 4.270 • ,n,AI CONDUCTOR;28.0-104.0 _ 9,002.1 5,9121' 74.52 HANGER BAKER FLEX LOCK LINER HANGER 4.350 9,012.0- 5,914.7 74.51 SBE BAKER 80-40 SEAL BORE ESTENSION 4.000 NIPPLE;643.3 I 7.117Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 312 2.992 23.5 9,024.8 5,918.2 9.30 L-80 EUE 8rd Completion Details o Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I") Item Des Com (in) 123.5 23.5 0.00 HANGER FMC GEN V TUBING HANGER 2.992 GAS LIFT:3.021 1 693.4 641.7 7.28 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 8,935.7 5,894.3 7426 NIPPLE CAMCO DS NIPPLE w/2.813"Profile 2.812 8,983.7 5,9072 74.45 LOCATOR BAKER LOCATOR 3.000 8,984.9 5,907.5 74.45 SEAL ASSY BAKER 8440 GBH LOCATOR SEAL ASSY w/12'of 3000 seals Perforations&Slots Shot SURFACE;28.3.3.543.0-. Dens Top(ND) elm(TVD) Dens Top(ftKB) Btm(MB) (ftKB) (ftKB) ' Zone Date t) Type Com -I 9,955.0 9,960.0 6,170.3 6,171.7' 7/20,12014 0.0 IPERF '6 SPF 60 DEGREE q''' GAS LIFT;5,097.1 PHASING Mandrel Inserts St GAS LIFT;6.589.8 ah N Top(TVD) Valve Latch Port Size TRO Run Top(MB) (ttK8) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com 1 3,021.1 2,572.8 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/21/2014 GAS LIFT;7,705.6 2 5,097.1 3,776.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/21/2014 3 6,589.8 4,638.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.000 0.0 6/2/2014 4 7,705.6 5,282.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.0 6/21/2014 5 8,875.5 5,877.6 CAMCO MMG 1 1/2 GAS LIFT DMY RKP 0000 0.0 7/6/2014 GAS LIFT;8,875.5 Notes:General&Safety End Date Annotation NOTE: NIPPLE;8,935.7 LOCATOR;8983.6 I f11 a alw SEAL ASSY;8,984.9 !al IF el?' a IIa ata st> J L INTERMEDIATE;25.8-8247.7 r IPERF;9.955.09,960.0 } • LINER;8,978.2-10,117.0_a l 'JR ( GINAL Schwartz, Guy L (DOA) From: Ohlinger,James J <JamesJ.Ohlinger@conocophillips.com> Sent: Monday,August 11, 2014 9:50 AM To: Schwartz, Guy L(DOA) Subject: FW:2K-34 CTD PTD Mr.Schwartz—Sharon told me that you'll be picking this file up today. See below. Thank you. From: Ohlinger, James 3 Sent: Monday,August 11, 2014 8:15 AM To: 'Ferguson, Victoria L(DOA)' Subject: 2K-34 CTD PTD Ms.Ferguson Good morning,I apologize but we have rotated our drilling schedule to put 2K-34 in front of 2K-09. At the same time we have saved time on 3Q-14 with drilling only 4 of the 6 planned laterals. Is it possible to get the PTD number for 2K-3411 and a verbal to proceed. The rig will release today and should be at 2K-34L1 tomorrow. James Ohlinger Senior CTD Engineer ConocoPhillips AK, Inc. 907-265-1102 office 907-854-2414 cell 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. WELL NAME: 41`11 f I/5- ; VDevel�pl"ikEC•l" SEIF(ICE E p!c:ra cc.ry SLfaLigrari!lic.Test tion-Convcrktior,E' r tv �n..t� � 7C !'\ if(Ai( � vi i4')i 4') ✓ C'1 Check Eel:far Appropriate Letter/Paragraph!to be included. in 1'ransmitizai Leffler CEECIt OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. OV I.1 - , API No. 50- /C - 02o(o s' -C.0 - . V in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well(name on permit). The permit is approved subject to full compliance with 20 MC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. 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