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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. Q,J...5" - 03� Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Maps: Grayscale Items: s: ❑ Poor Quality Originals: ❑ Other: ❑ Other: Q//s'BY: Mria C1/r(aDate: /s/ ,ry, r Project Proofing BY: Allb Date: q / /6" /s/ YV1 ? Scanning Preparation a. x 30 = (t)0 + 7 = TOTAL PAGES (i2 7 (Count does not include cover sheet) rn F BY: (Maria Date: (i / /s/ Production Scanning toStage 1 Page Count from Scanned File: v (Count does include cov sheet) Page Count Matches Number in Scannin Preparation: YES NO BY: en Date: `�/ 1 g/ 1�6 /s/ t/ I p Ci Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /5/ i 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: /5/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o _ o ' • oN T.:, • O • CE •• oc a • m M J m a •r i bN O OC .O l1o i O T O 1 n E T (1) O O 1 M U UZ Z lla) in co Ws Ts To Ts a. 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O in (0 m m co () (D CD m m cD r N N N N N N N N N N 1 (0 W C co • N a a) Ir o - x y E E Z m aNi w CO U) z 0 0 in Q o o z o , -42 c c 0 p ° -o ° wE I , EaO — a) Q aMw wwwwwww3 LL 0O r 0 ° z O 0 0 0 C h C O 9 O cc) 0 Z N N t A U_ I I o I I ° coco �'1 T o R b Zz _ F. 4 _1 P V Z 1 4 7 . N wcn 1 10 IX Q C. 12 O cna O. J W = I Ce V W Z o Z s Q co d c j o co CL co ONo I o- liC2E M V 01 o U o M J Q inco a Y N In I _ In H 2 N W re 0 re 0 7 Y 1 `° a Q D o Y - m Q c1111 0 i'DZ o 0 coZ m • roN O M m G H 13 N N — a' O cr)O N V ✓ O eav y V +. O E E E 4 2K-15L1 215-033 26160 >2K-150-01 215-035 26161 2K-15L1-02 215-036 26162 PRINT DISTRIBUTION LIST BAKER HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ (mandatory) 795 East 94th Avenue DATA LOGGED /sV201�j WELL NAME 2K-15L1; 15L-01; 15L-02 Anchorage,Alaska 99515 M.K.BENDS (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: May 7,2015 TODAYS DATE: 21-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Patrick Rider EMAIL: 3trick.rider(c�bakerhughes.co (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #Ur I'KIN I S #OF COPIES #OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. I 1 I 1 1 1 Petrotechnical Data Center,LR2-1 R F4' ''s "`' 900 E.Benson Blvd. Anchorage,Alaska 99508 H'1V)1 2 Attn:Dodie Stinson 3 Chevron/KRU Rep I 1 1 1 1 I Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4 State of Alaska -AOGCC I 1 1 2 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5DNR-Division of Oil&Gas *** 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR TOTALS FOR THIS PAGE: 0 3 4 4 4 0 TOTALS FOR ALL PAGES: 0 3 4 4 4 0 U, '-- M l0 Ln (NI . H cv W `W; sz 0, a N 0- I O C� CD W t Z 42) • ._ •1111101 - �as c Cn T • O O N0 • O , co co .4C1.1 c L - .= C� O Q. � 7 o (ci C V Y Y N m 0 0 § z © ® k a o Q UM�� co \ t! { e \ § 77 N: c « � co \ \] « U. i / C co co k � 0 ? \ g � U 3 § CO \CO i 0. j E LC) 0 \ CO 17-0' k k 7 E \ \ \ / \ - # E 8 \ 7 * 2 ` I — ° . _ z co , CO ] / \ \ / / 5 0 \ \ { ) � ° ° \ § \ \ 2 t , _ * a W > > & $ f \ co s— ƒ % % _ _ - - § > 2 D a , a f 06 / 2 .. 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Y 00)) N ((( N 0) CO ca tO Oi W N:0 e - � - O O O 2 (O (0 (O to O (0 NI Nim N (C) O) O 7 to N V C) N Y p f, N (N N No No (0 U F, `=.. (0 (0 to to to to C W N 01 Q .0 O N O to NVN J V ^ (O IO O -. N N O45 d 5..... N N N N N N — > Y N N VI L d' N O O LLC _ Y Y V 7 7 J J O CO (0 N (n (n V W r I-- ••••• C O Cl ,- ,- , _ ,- 7 N N N N S U Y Y N N N C V o, m a) a) a) m N. Q O 0 U o m c m Oio C ` e , r r O N N 8 O^ O 0- v .. 0 C m v 0 0 0 0 0 0 V/ m _ V O O r 0 N m 7 N v a` w 3 3 o (a 03 • RECEIVED STATE OF ALASKA JUN 0 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AJ JC la.Well Status: Oil 2, Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q . Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comb. p.,or.* 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. - Aband.: c /2015 215-035- 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99501 .4/29/2015 50-103-20113-61 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 119'FNL,94'FEL,Sec. 11,T1ON, R8E,UM .. 5/1/2015 KRU 2K-15L1-01- Top of Productive Interval: 9. KB(ft above MSL): 154' 17. Field/Pool(s): 2487'FNL, 1069'FEL,Sec. 12,T1ON, R8E, UM GL(ft above MSL): 114' Kuparuk River Field/Kuparuk River Oil Pool • Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 1160'FSL, 1448'FEL,Sec. 12,T1ON, R8E, UM 10900'MD/6261'TVD ADL 25588 4b. Location of Well(State Base Plane Coordinates, NAD 27): - 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498310 y- 5938185 Zone- 4 .10900'MD/6261'TVD 2674 TPI: x- 502616 y- 5935817 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 502238 y- 5934184 Zone- 4 nipple @ 519'MD/519'TVD 1424'MD/1422'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) •8026'MD/6244'TVD . 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 176 sx AS II 9.625" 36# J-55 35' 3320' 35' 2947' 12.25" 1000 sx AS III,450 sx CI G 7" 26# J-55 2107' 8286' 2053' 6481' 8.5" 225 sx Class G 2.375" 4.7# L-80 8220' 10900' 6220' 6261' 3" slotted liner 24.Open to production or injection? Yes Q No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5"x 5.5" 7916' 7599'MD/5965'TVD slotted liner from 8240'-10899'MD 6219'-6261'TVD f 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. .1. rL; a ., Was hydraulic fracturing used during completion? Yes❑ No Q Per 20 AAC 25.283(i)(2)attach electronic and printed information ....41e /i DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 5/20/2015 _gas lift oil Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 5/20/2015 30 hours Test Period -1665 429 2725 176 bean 360 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 937 113 24-Hour Rate -p 1220 442 2150 4 Py c Form 10-407 Revised 5/2015 ATL g/ `� CONTINUED ON PAGE 2 RBDMS SE 201 11015 �1 RIGINIAL on 28.CORE DATA Conventional Col Yes ❑ No Q Sidewall Cores: ❑ No El If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. None 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1424' 1422' Attach separate pages to this form, if needed,and submit detailed test information, including reports, per 20 AAC 25.071. Kuparuk A4 8026' 6244' Kuparuk A4 9190' 6219' None Formation at total depth: Kuparuk A4 • 31. List of Attachments: Summary of daily operations,schematic,final directional survey Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Pohler Email: Codv.J.Pohlerconocophillips.com Printed Name: Dan Venhaus Title: CTD Engineering Supervisor COC)P/h Signature:W—(7%--,i47‘,011.— —s-15 Phone: 263-4372 Date: C /4 / (vic INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only KUP PROD 2K-15 ConocoPhillips / °- \ Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APlluwi Field Name Wellbore Statue ilnal(•) MD(MB) Act Slm MB) romniell®ps 501032011300 KUPARUK RIVER UNIT PROD 46.42 6,500,00 8,304.0 ••• Comment H2S(ppm) Date Annotation End Date KB•Grd(ft) Rig Release Date 25-15 520,2015 1013:49 AM SSSV:NIPPLE 73 12/30/2012 Last WO: 11/28/2014 40.19 10/16/1989 Vertical schemata facture) Annotation Depth MKS) End Date Annotation Last Mod By End Date - - - --Last Tag:SLR 8,002.0 2/212015 Rev Reason:ADD LATERALS LI(off main smsmith 5202015 • i+ANGER;31.1_--. WV, wellbore),Li-01,71-02 Casing Strings Carting Description OD(In) 10(in) Top(ftKB) Set Depth(fin) Set Depth(TVD)...WULen(1...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED k {� Casing Description OD(In) ID(in) Top(MO) Set Depth(01(8) Set Depth(TVD)...WULen(I...Grade Top Thread II SURFACE 95/8 8.921 35.0 3,319.7 2,946.5 36.00 J-55 BTC Casing Description OD(in) ID(In) Top(MB) Set Depth(1/KB) Set Depth(IVO)...WULen IL..Grade Top Thread 7 6.276 33.0 2,107.4 2,053.2 26.001-80 TC II III III lback WINCasing Description OD(15) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...VA/Len(1...Grade Top Thread LWINDOW 7 6.276 7,901.0 7,907.0 6,196.5 CONDUCTOR,36.0-115.0 Casing Deecrlptlon OD(In) ID(in) Top(MB) Set Depth(MB) Set Depth(TVD)...WULen(i...Grade Top Thread PRODUCTION 7 6.276 2,107.4 6.285.6 6,480.7 26.00 J55 BTC Tubing Strings NIPPLE;519.0 __ Tubing Description String Ma...ID(In) Top(MB) Set Depth(H...Set Depth(TVD)(...Wt(Ibm) Grade Top Connection ' TUBING-W0312xtails 31/2 2.992 31.1 7,916.0 6,203.2 9.30 L-60 EUE BRtl 5 1/2 Completion e Nominal ID TopX7785.13 D (ttK8) Top(TVD)(11Kel Top Incl 1') Item Des Corn (I n) 31.1 31.1 0.05 HANGER FMC GEN V HANGER 2992 PRODUCTION 7"Tieback;33.0. I ■ 519.0 519.0 0.38 NIPPLE CAMCO"DS"NIPPLE 2.875 2,107.4 3,719.6 3,227.1 45.48 BARRIER VLV HES LUBRICATOR ORBIT VALVE(BARRIER VLV) 2.894 GAS LIFT,2,880.6 I 7,567.9 5,9424 41.52 LOCATOR BAKER LOCATOR 2.900 7,568.9 5,943.1 41.52 SEAL ASSY BAKER 80.40 SEAL ASSEMBLY(SPACED OUT 7.13) 3.000 I 7,575.4 5,948.0 41.51 PBR BAKER 80-40 20'PBR 2.980 7,598.5 5,965.2 41.51 PACKER BAKER 4782 FHL PACKER 2.900 SURFACE;35.0-3,3191 - 7,742.8 8,073.4 41.42 NIPPLE HES"C NIPPLE 2.813 7,785.1 6,105.2 41.40 XO Enlarging 312"to 512"PORTED CROSSOVER 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Tap not BARRIER VLV:3.719.6 /. Top(NKR) 01KB) I') Dee Com Run Date ID(In) 7,896.0 6,188.3 41.54 WHIPSTOCK BAKER GENII ORIENTED AT 0 DEGREES OAL 2212015 1297;2 RA TAGS LOCATED 7.35'FROM TOP OF WHIPSTOCK IPerforations&Slots GAS LIFT;4,261.1 I Shot 111 Dens Top(TVD) atm(TVD) (shots/r Top(f[KB) Bun(ttK6) (ttK6) (51(13) Zone Date 1) Type Com 7,824.0 7,832.0 6,134.3 6,140.3 C-7;2K-15 5/25/1997 6.0 IPERF 2.8'HPhasing50,60 deg. GAS LIFT;5,469.2 7,934.0 7,974.0 6,216.7 6,246.7 A-4,2K-15 4/19/1990 4.0 IPERF 4.5"HSC,180 deg. Phasing Mandrel Inserts GAS LIFT;6.384.6 St an on Top(TVD) Valve Latch Port Site TRO Run N, Top(ftKB) (1168) Mahe Model OD(In) Sery Type Type (In) (psi) Run Date Com ® 1 2,660.6 2,487.4 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 12/242014 GAS LIFT.7,084.2 2 4,261.1 3,609.0 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1224/2014 3 5,469.2 4,459.6 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 12242014 GAS LIFT:7,511.8 4 6,387.6 5,105.1 CAMCO MMG 1 12 GAS LIFT DMY RK 0..000 0.0 12/24/2014 5 7,084.2 5,593.2 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 12/24/2014 LOCATOR:7,587.9 0 7,511.8 5,900.4 CAMCO MMG 1 12 GAS LIFT GAUL RK 0.000 0.0 3/18/2015 DCR- E1, SEAL ASSY;7,588.9 = SIDE Peg:7575.4 POCK PACKER;7598.5 ET GAUL E Notes:General&Safety End Date Annotation NIPPLE:7,742.5 i 11 9/3.2000 NOTE:E-LINE IDENTIFIED LEAKS @l 2425',6765',7235'MD 11/3/2010 NOTE:View Schematic w/Alaska Schema0c9.0 1/20/2015 NOTE:BARRIER VLV control lines/system @Wellhead marked Open/Close 1/20/2015 NOTE:BARRIER VLV is NOT a safety valve,it does not fail to closed position IPERF;7,824.0.7,832.0- WHIPSTOCK;7,896.0 . L1 WINDOW;7.901.0-7,907.0 I �\I I SLOTS;7,902.910,923.6- ,�; Lt-02 LINER;7,892.3-10,924.0 IPERF;7,934.0-7.974.0 t PRODUCTION:2.107.4-8,285.6 - - —ID KUP PROD 2K-15L1-01 ConocoPhillips c , Well Attributes Max Angle&MD TD 485,1 1'11: 'Wellbore API/UWl Field Name Wellbore Status 'Inc'CI MD(1109) Act Mtn(ftKB) rrrvrvi,xBMp4 501032011361 KUPAR UK RIVER UNIT PROD 1 100.53 8,175.33 a ••• Comment 1125(ppm) Date Annotation End Date KB-Grd(It) Rig Release Date 2K-15L1-01 5,2020151053'55 AM SSSV:NIPPLE 73 12/30)2012 Last WO: 40.19 10/16/1989 Ve'ticai scnemaric(acluali Annotation Depth(ttKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADD LATERALS LI(off main smsmith 5,20/2015 HANUEF;21_' 'wellbore).L1-01.11-02 Casing Strings _ Casing Description OD(in) ID(In) Top(ROB) Set Depth(/tKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L1-01 LINER 23/8 1.992 8,219.5 10,900.0 6,261.4 4.60 L-80 STL j Liner Details Nominal ID Top(ttKB) Top(TVD)(ttKB) Top Incl(°) Item Des Com (In) 8,219.5 6.220.3 95.53 BILLET BAKER LINER TOP BILLET 1.000 Perforations&Slots Shot JCA/CONDUCTOR.36.0-115,0• .h/�/' '°' Dens Top(TVD) Bill(TVD( (shots/( Top(RKB) Btm(RKB) (ttKB) (11KB) Zone Dale I) Type Com • NIPPLE;519.0 _ 8,240.1 10,899.6 6,218.7 6,261.4 A-5,2K-15L1- 5/2/2015 SLOTS Slotted Liner .28 01 Notes:General&Safety End Dale Annotation NOTE: i PRODUCTION 7'T1.0ccic 33.0- e 2,107.4 OAS LIFT.2660,8 SURFACE;35,0-3,3197 k BARRIER KV:3.719.6 GAS LIFT:4,261.1 la I GAS L IFT,5.469.2 GAS LIFT,6.364.5 GAMEST,7.0642 GAS LIFT:7.511.8 LOCATOR.7,587,9 SEAL ABBY;7,568.5 PBR,7.575.4 PACKER;7,508.5 MK NIPPLE;7,742.8 r IC- IPERF.7.824.0-7.632.0-li f WHIPSTOCK;7,806.0 'I 11 WINDOW;7,901.0.7,907,0 Its' • PRODUCTION'2.107.48,2856 I qI _ SLOTS:7,902.9.10,923.6 L1-02 LINER;7,892.3-10,924.0 SLOTS:8240.1-10099.6 -1.11:1: L1-01 LINER:8.21B0-10.900.0. 2K-15 WELL WORK SUMMARY PRE RIG WELL WORK DATE SUMMARY 2/1/2015 SET CATCHER @ 7535' SLM. PULLED SOV @ 7508' SLM, REPLACED WITH DV. MIT IA 2500 PSI, PASSED. PULLED CATCHER. IN PROGRESS. 2/2/2015 GAUGED TBG TO 2.84"TO 7726' SLM. PULLED PRONG &XN PLUG @7742' RKB. TAGGED @ 8002' SLM. MEASURED BHP @ 7896' RKB: 3483 PSI. DRIFT TBG WITH DUMMY WHIPSTOCK TO 8002' SLM. READY FOR E-LINE. 2/19/2015 MEASURED BHP @ 7896' RKB: 3578 PSI. COMPLETE. 2/21/2015 SET BAKER GEN II WHIPSTOCK WITH TOWS AT 7896' ORIENTED AT 0 DEGREES. (CCL TO TOWS = 15'; CCL STOP DEPTH = 7881')TIED IN TO K1 MARKER AT 7724'. RA TAGS RUN 7.35' BELOW TOWS. 3/17/2015 (PRE-CTD)TREE VALVE TESTS: SV, SSV, MV-ALL PASSED. 3/18/2015 SET CATCHER @ 7724' SLM. PULLED DV, SET SPARTEK GAUGE @ 7503' SLM. MIT IA 2500 PSI, GOOD. IN PROGRESS. 3/19/2015 PULLED CATCHER @ 7724' SLM. MEASURED BHP © 7896' RKB: 3634 PSI. COMPLETE. 4/3/2015 Attempted injectivity. Rolled pump (0.1-0.2 bbls) and reached max test pressure of 1400 psi. Verified valve alignment, bleed back well to 100 psi and got back 0.3 bbls. S/L to verify staus of DH valve when performing future static. Complete. 4/10/2015 MEASURED A-SAND BHP @ 7896' RKB: MAX PSI 3624. JOB COMPLETE. READY FOR BPV POST RIG WELL WORK 5/11/2015 DRIFT TBG W/2.50" MAGNET DOWN TO 9896' RKB' MEASURE BHP @ 7892' (4158 PSI); SET CATCHER @ 7742' RKB; PULL DV& SET OV @ 7084' RKB; PULL DV @ 7511' RKB. IN PROGRESS 5/12/2015 PULLED DVs @ 6384', 5469', 4261', 2660' RKB. SET GLVs @ SAME. PULLED CATCHER @ 7722' SLM. COMPLETE. Conoc Po hiIIips Time Log & Summary Wel[view Web Reporting Report Well Name: 2K-15 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 4/21/2015 5:00:00 AM Rig Release: 5/8/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 34/20/2015 24 hr Summary Nipple down BOPE, install jeeps, Pull off location with help from the cats. Load out yard materals. 12:00 00:00 12.00 MIRU MOVE MOB P Move CDR 2 rig to 2K-15,wait on changeout at 1Q-pad, continue moving, park at CPF2 for ice road traffic,stuck had to hook up cats to pull both modules around CPF2, continued moving to 2K-pad. ****Trucks on location at 12:00 Noon. 04/21/2015 Move in remove jeeps,spot subs over well, load pits, MU interconnect, and start BOPE test. 00:00 00:30 0.50 0 0 MIRU MOVE MOB P Arrive on location, PJSM, Prep well for rig. 00:30 02:30 2.00 0 0 MIRU MOVE MOB P Spot Drilling Sub, install adapter flange, hook up MP line. 02:30 04:00 1.50 0 0 MIRU MOVE MOB P Spot Pit Sub 04:00 09:30 5.50 0 0 MIRU MOVE RURD P Hook up the interconnect, hook up steam lines, rig up stairs and walkways,safe out rig. ***Note: Rig accept @ 0500 09:30 21:30 12.00 0 0 MIRU WHDBO BOPE P Start BOPE test,Test pressure 4200 psi,Annular preventer 2500 psi, Witness waived by Chuck Scheve. 21:30 00:00 2.50 0 0 SLOT WELLPF CTOP P Fill coil,cut CTC off, protect end of wire, perform slack management, heard wire moving at 1.75 bpm for 30-40 sec,shut down test eline good test, 04/22/2015 Finished BOP test, removed upper quick, performed slack management, reheaded BHI upper quick, MU BHA# 1, RIH,tied into the K1,dry tagged TOWS at 7902ft,started milling window. 00:00 00:30 0.50 0 0 SLOT WELLPF CTOP P Finish performing slackmanagement. 00:30 02:00 1.50 0 0 SLOT WELLPF MPSP P PJSM, bring FMC lubricator to the rig floor, RU to pull BPV 02:00 04:00 2.00 0 0 SLOT WELLPF CTOP P PJSM,trim coil to find wire,found wire at 3.8 ft, trim 20ft of coil to remove flat spot, Install CTC, Pull test 31k, rehead BHI upper quick. 04:00 08:00 4.00 0 0 SLOT WELLPF PRTS P PT PDL's and tiger tank line. hold pre spud meeting with day crew. Pumped 40 bbls from the coil to the tiger tank. Page 1 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 0 0 SLOT WELLPF PRTS P T/I/O=980psi/800 psi/0 psi. Test Halliburton Lubricator Valve(HLV), Confirm Open, pump at 4000 psi control line pressure to close valve until 125 ml of fluid were returned from the open side bleeder. Bleed well head to 460 psi, holding steady, bleed well head to 107 psi and monitor for 30 min. Test good. 08:30 10:30 2.00 0 0 PROD1 WHPST PULD P Make up window milling BHA#1. Match pressure and pump open the HLV. 10:30 14:42 4.20 0 7,844 PROD1 WHPST TRIP P RIH,Tie in to K1 marker+2' correction. Circulate the coil and well to 9.2 ppg flow pro. Bleed IA and HLV control lines. Down on the pumps, dry tag whipstock @ 7902' CTMD. 14:42 19:12 4.50 7,844 7,905 PROD1 WHPST WPST P Pick up Wt,32,k lbs, Pump rate up to 1.42 bpm, CT 3750 psi,WH 150 psi, RIH, RIH wt 9.9k Mill dual string exit window. 19:12 00:00 4.80 7,905 7,907 PROD1 WHPST WPST P Time milling 1.42 bpm at 3700 psi, BHP 3784,WHP 157, IA 0, OA 236 psi. 34/23/2015 Finished milling casing exit at 7901ft,and rat hole to 7921ft, LD window milling BHA, MU build section BHA#2 with 2.3°motor,drilled build section. 00:00 01:00 1.00 7,907 7,908 PROD1 WHPST WPST P Continue milling window 1.42 bpm at 3700 psi, BHP 3793,WHP 157, IA 0, OA 252 01:00 03:15 2.25 7,908 7,912 PROD1 WHPST WPST P 7908ft,drill rat hole, ROP 2 fph for 4.0ft.1.42 bpm at 3700psi, DHWOB 750 lbs, BHP 3777,WHP 120, IA 350, OA 0 03:15 05:27 2.20 7,912 7,921 PROD1 WHPST WPST P Continue drilling rat hole 1.42 bpm at 3900 psi, ROP 5-6 fph, DHWOB 2.2k, BHP 3808,WHP 125, IA 350, OA 0. 7921 CTMD 05:27 08:15 2.80 7,921 7,921 PROD1 WHPST REAM P Make reaming passes through window area at 1.0 fpm/60 fph, 30L,30R. Dry drift the window, clean passes down and up. 08:15 09:45 1.50 7,921 88 PROD1 WHPST TRIP P Pull out of hole to pick up build assembly. Jog/wash 5.5"tailpipe. POOH 1.48 bpm,WH 300 psi, CT 3800 psi, 75k lbs. 09:45 11:45 2.00 88 0 PROD1 WHPST PULD P At surface,close Halliburton lubricator valve, bleed&monitor pressure-good, flow test-good. PJSM, lay down BHA#1 milling assembly(2.70"NG on both window mill and string mill), pick up BHA#2 build BHA and deploy. Open Halliburton valve. 11:45 14:03 2.30 0 7,753 PROD1 DRILL TRIP P RIH, pumping min rate,Tie in at the K1 for a-1 'correction. Weight check28.6K. Page 2 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:03 16:03 2.00 7,753 7,921 PROD1 DRILL DRLG P Drill build section. Pumping 1,4 bpm, CT 3860 psi,WH 73 psi, CT weight 9.7 k lbs, 1.05 k lbs WOB. 16:03 18:48 2.75 7,921 8,095 PROD1 DRILL DRLG P BHA outside the window. 1.41 bpm, CT 3900 psi,WH 70 psi,CT weight 10.3 k,WOB 1.37k lbs. 18:48 19:33 0.75 8,095 8,095 PROD1 DRILL WPRT T Short DD wiper up to 8000ft, call town to confirm drilling forward getting less doglegs then expected, 30°'s instead of 45°'s. RBIH to drill. 19:33 21:03 1.50 8,095 8,170 PROD1 DRILL DRLG P BOBD 1.3 bpm at 3650 psi, BHP 3760,WHP 25, IA 400,OA 0 21:03 21:33 0.50 8,170 8,170 PROD1 DRILL WPRT P Wiper up hole to 7950ft, PUW 26 21:33 22:33 1.00 8,170 8,280 PROD1 DRILL DRLG P BOBD 1.3 bpm at 3650, BHP 3833, WHP 26, DHWOB 2.3k, ROP 35 fph. 22:33 23:02 0.49 8,280 8,280 PROD1 DRILL WPRT P Wiper up hole to 7950ft, PUW 26k ****Note: Off bottom CP 4084, Mud check: LSRV 44k, 23:02 23:59 0.96 8,280 8,365 PROD1 DRILL DRLG P BOBD 1.36 bpm at 4000 psi, BHP 3863,WHP 0, IA 500, OA 0 34/24/2015 TD build section 8365ft, MU lateral section BHA with RSM, RIH, drilled lateral section from 8365ft to 9011ft. 00:00 02:30 2.50 8,365 72 PROD1 DRILL TRIP P TD build section at 8365ft, POOH 02:30 03:00 0.50 72 72 PROD1 DRILL SFTY P Close DHV, 816psi WHP, Check well for flow, PJSM 03:00 03:45 0.75 72 0 PROD1 DRILL PULD P LD build BHA#2 03:45 04:45 1.00 0 69 PROD1 DRILL PULD P MU L1 lateral BHA#3 04:45 07:15 2.50 69 8,365 PROD1 DRILL TRIP P RIH,with RSM, open DHV, Log GR and tie in to K1 marker for-2' correction,Wt ck@ 7757'25.5k, Log RA marker @ 7903.5', "***Note:WHP bleed down to 680 07:15 08:03 0.80 8,365 8,519 PROD1 DRILL DRLG P On bottom drilling W RSM, 1.3 bpm, CT 3801 psi, (3750 psi free spin), CT wt 10.5 lbs,WOB 1 k psi, ROP 133 f/hr. 08:03 08:51 0.80 8,519 8,519 PROD1 DRILL WPRT P Unable to build per plan, pull short trip to 8000' while calling town to discuss. Ploan forward drill 100-200' while trying to buildturn to the right. 08:51 10:15 1.40 8,519 8,631 PROD1 DRILL DRLG P BOB drilling 1.32 bpm, CT 3800 psi, WOB 1.6 k psi, ROP 84 f/hr. 10:15 10:27 0.20 8,631 8,631 PROD1 DRILL TRIP P Pull off bottom for swap to Highline power. 28k lbs off bottom. ***Note On High Line Power Page 3 of 14 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:27 15:09 4.70 8,631 8,726 PROD1 DRILL DRLG P BOB drilling 1.30 bpm, CT 4100 psi, WOB 1.29 k psi, ROP 90 f/hr. Run into anchorite @ 8698 CTMD, ROPs down to 4-10 ft/hr,WOB-3k lbs. Slight drilling break @ 8726' CTMD, ROP up to 46 ft/hr,WOB 1.5k lbs. IA 500 psi, OA 0 psi, halliburton valve 1900 psi open side, 0 psi close side. 15:09 16:09 1.00 8,726 8,739 PROD1 DRILL DRLG P Drilling break at 8739'CTMD ROP increased to 60 ft/hr 16:09 16:45 0.60 8,739 8,770 PROD1 DRILL DRLG P Drill L1 Lat, 1.3 bpm, CT 3800 psi, CT weight 8k lbs, ROP 60 ft/min, WOB 1.8k lbs. 16:45 17:09 0.40 8,770 7,950 PROD1 DRILL WPRT P Pull wiper trip#1. 17:09 17:54 0.75 7,950 8,770 PROD1 DRILL WPRT P RBIH 17:54 00:00 6.10 8,770 9,011 PROD1 DRILL DRLG P BOBD 1.42 bpm at 3352 psi, BHP 3843,WHP 0, IA 574, OA 22, DHWOB 1.4k, ROP 60 34/25/2015 Drilled the L1 lateral section from 9011ft to 9770ft. 00:00 00:15 0.25 9,011 9,020 PROD1 DRILL DRLG P OBD 1.42 bpm at 3650 psi, DHWOB 1.7k, ROP 33 fph, BHP 3868,WHP 0, IA 625, OA 0 00:15 00:45 0.50 9,020 7,920 PROD1 DRILL WPRT P Wiper#3 up hole for a tie in, PUW 28k 00:45 01:00 0.25 7,920 7,931 PROD1 DRILL DLOG P 7920ft,Tie into the RA marker correction of plus 1.5ft, 01:00 01:30 0.50 7,931 9,020 PROD1 DRILL WPRT P Wiper back in hole, RIW 11k 01:30 05:00 3.50 9,020 9,150 PROD1 DRILL DRLG P BOBD 1.45 bpm at 3709 psi, BHP 3899,WHP 27, DHWOB 1.9k, ROP 43 fph, IA 585, OA 23 05:00 07:12 2.20 9,150 9,270 PROD1 DRILL DRLG P OBD 1.45 bpm at 3921 psi, BHP 3918, DHWOB 2k, ROP 25 fph, IA 660, OA 0 07:12 08:12 1.00 9,270 9,270 PROD1 DRILL WPRT P Wiper#1 PUW 26k. PUH 870'to 8400, RBIH WT 11k. Start mud swap while RBIH. 08:12 13:12 5.00 9,270 9,520 PROD1 DRILL DRLG P BOBD 1.29 bpm at 3725 psi, BHP 3900,WHP 13, DHWOB 1.4 k, ROP 25 fph. New mud out the nozzle. 1.28 bpm, CT 3815 psi, BHP 3841, WH 88, CT WT6k,WOB 1.3. New mud all the way arround. 'Note, new mud 13:12 14:24 1.20 9,520 9,520 PROD1 DRILL WPRT P Wiper#2 PUW 27 k. PUH 1005'to 8515, RBIH WT 12 k. 14:24 16:06 1.70 9,520 9,589 PROD1 DRILL DRLG P BOBD 1.41 bpm at 3912 psi, BHP 3843,WHP 88, DHWOB 2.0 k, ROP 53 fph. IA 500 psi, OA 0 psi, Halliburton valve, 1900 psi open circuit, 0 psi closed circuit. Page 4 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:06 22:54 6.80 9,589 9,770 PROD1 DRILL DRLG P 1.38 bpm, CT 3766 psi, BHP 3884 psi WHP 98 psi,WOB 1.75, ROP17.4 Having difficulty getting the BHA to drop,adjusting WOB and limiting ROP to attempt to aid RSM. 22:54 23:45 0.86 9,770 7,800 PROD1 DRILL WPRT P 9770ft,Wiper up hole for a tie in, PUW 28k, 23:45 23:59 0.24 7,800 7,848 PROD1 DRILL DLOG P Jet the 5 1/2"up to 7800ft. 04/26/2015 Drilled L1 lateral section from 9770ft to 10496ft 00:00 00:15 0.25 7,848 7,920 PROD1 DRILL TRIP P Wiper back in hole RIH 11k 00:15 00:30 0.25 7,920 7,920 PROD1 DRILL DLOG P 7920ft,Tie into the RA marker correction of plus 1.5ft. 00:30 01:15 0.75 7,920 9,770 PROD1 DRILL WPRT P 7920ft,Wiper back in hole, RIW 11k 01:15 03:45 2.50 9,770 9,876 PROD1 DRILL DRLG P 9770ft, BOBD 1.45 bpm at 3400 psi, BHP 3824,WHP 28, DHWOB 1.7k, ROP 83 fph, IA 628, OA 0 03:45 04:00 0.25 9,876 9,731 PROD1 DRILL TRIP T PUH, and trouble shoot RSM, looks like the RSM has failed. 04:00 06:30 2.50 9,731 76 PROD1 DRILL TRIP T POOH 06:30 07:24 0.90 76 0 PROD1 DRILL PULD T At surface, close the subsurface HLV. Flow check-good. PJSM, laydown BHA#3, 07:24 08:18 0.90 0 79 PROD1 DRILL PULD T PJSM, pick up BHA#4 with replacement RSM orienter. Open sub surface HLV, 08:18 11:18 3.00 79 9,876 PROD1 DRILL TRIP T RIH. IA 400 psi, OA 0 psi. Tie in at K1 for a-1.5'Correction. Close ECD @ 7850',Wtck25.5 k lbs, Saw 1000Ib boble exiting the window. *"*"Note:7 hrs downtime for RSM. 11:18 12:48 1.50 9,876 9,962 PROD1 DRILL DRLG P Off Bottom, 1.40 bpm at 3755 psi. BOBD CT 3950 psi, BHP 3889, WHP 15, DHWOB 1.21k, ROP 70 fp. Limiting WOB<2k psi to help drop tool face. Start stacking weight @ 9930'appears that coi is fighting he RSM. 12:48 13:00 0.20 9,962 9,962 PROD1 DRILL WPRT P Pulled 60'BHA wiper 13:00 14:00 1.00 9,962 10,025 PROD1 DRILL DRLG P BOBD CT 3900 psi, BHP 3949, WHP 30, CTWT 6-4 k Ibs,DHWOB 1.4k, ROP 100 ft/hr. Weight transfer issues, Depth data locked up 9984.75'and 13:16 to13:21. Depth display then jumped ahead— 10'to 9995'. Decision made to pull wiper 100'eaqrly and tie in. 14:00 16:12 2.20 10,025 10,025 PROD1 DRILL WPRT P Wiper trip to7915' for tie in. PUWt 25 k lbs. Tie into the RA tag for no correction. RBIH Page 5 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:12 20:12 4.00 10,025 10,275 PROD1 DRILL DRLG P BOBD CT 3937 psi, BHP 3925, WHP 33, CTWT 6 k lbs,DHWOB 1.9 k, ROP 60 ft/hr. 20:12 21:12 1.00 10,275 10,275 PROD1 DRILL WPRT P Wiper up hole to 9260ft, PUW 28k 21:12 23:36 2.40 10,275 10,496 PROD1 DRILL DRLG P BOBD 1.43 bpm at 3894 psi, BHP 3944,WHP 30, DHWOB 2k, ROP 90 fph, IA 697, OA 24,Trouble getting weight transfer,try to work pipe to bottom. 23:36 00:00 0.40 10,496 10,216 PROD1 DRILL WPRT P Wiper up hole to 9300ft, PUW 25k 34/27/2015 Drilled L1 lateral section from 10496ft to 10900ft. 00:00 00:21 0.35 10,216 9,300 PROD1 DRILL WPRT P Continue wiper up hole, pumping 1.48 bpm at 3976 psi, 00:21 00:51 0.50 9,300 10,496 PROD1 DRILL WPRT P Wiper back in hole. RIW 7k 00:51 02:42 1.85 10,496 10,635 PROD1 DRILL DRLG P BOBD 1.4 bpm at 3800 psi, BHP 3925,WHP 24, DHWOB 1.5k, ROP 98 fph, IA 726, OA 26 02:42 04:12 1.50 10,635 7,920 PROD1 DRILL WPRT P Unable to keep weight on bit,wiper up hole for a tie in, PUW 25k, Jet the 5-1/2"up to 7800ft. 04:12 04:27 0.25 7,920 7,920 PROD1 DRILL DLOG P Tie into the RA marker correction of plus 2.5-ft. 04:27 05:26 0.99 7,920 10,635 PROD1 DRILL WPRT P Wiper back in hole, RIW 11 05:26 08:56 3.50 10,635 10,655 PROD1 DRILL DRLG P BOBD drilling, FS 1.45 bpm at 3600 psi. CT Wt 0 to-9 k lbs,WOB.1 to0.8- 2.8 K psi ROP 5-10. Taking returns to the tiger tank in preparation for a mud swap. 08:56 09:32 0.60 10,655 10,655 PROD1 DRILL DRLG P 1.31 bpm, CT 4167 psi,WH 50 psi, BHP 3987 psi. CT wt-8 k psi,WOB 3.6 kpsi ROP 5.0 Start new mud down the coil. Experienced a few stalls,28k psi clean off bottom. 09:32 11:32 2.00 10,655 10,668 PROD1 DRILL DRLG P New mud at the nozzle. Fighting Ankerite.Temporary drilling break ROP to 55 fph for-10 feet. Fighting weight transfer with low ROPs. 11:32 12:08 0.60 10,668 10,668 PROD1 DRILL WPRT P Wiper trip, PUWT 27 k psi, pull to 10366', RBIH, RIW 8.3 K psi, 12:08 15:08 3.00 10,668 10,680 PROD1 DRILL DRLG P BOBD,CT 1.4 bpm, CT 3800 psi, WH 123 psi, BHP 3968, CT wt 2k, WOB 2.17, ROP 3.7. 15:08 20:08 5.00 10,680 10,698 PROD1 DRILL DRLG P CT 1.43 bpm, CT 3880 psi,WH 27 psi, BHP 3829, CT wt-3k,WOB 3.59, ROP 6. IA 1750, OA 134, HLV open circuit 1750 psi, closed circuit 200 psi. 20:08 23:08 3.00 10,698 10,900 PROD1 DRILL DRLG P Broke through Ankerite, drilling DHWOB 3.3k, ROP 100 fph 23:08 23:59 0.86 10,900 10,900 PROD1 DRILL WPRT P Stacking weight,Wiper up hole to 9896ft, PUW 26k __ ____ ___ _�_ Page 6 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 34/28/2015 24 hr Summary Drilled to called TD© 11,150'.Wiper to tubing tail 7,740'. RBIH for corrected TD @ 11,150'. Pump sweeps. POOH, Paint EOP flags @ 4,600'and 7,900'. MU L1 liner assembly,start in hole with liner, in progress. 00:00 01:30 1.50 10,900 10,913 PROD1 DRILL DRLG P OBD 1.4 bpm at 3666 psi, BHP 3795,WHP 23,work pipe to try and drill ahead. 01:30 06:12 4.70 10,913 11,150 PROD1 DRILL DRLG P 10913ft, broke through,drilling ahead DHWOB 2.1k, ROP 90-106 fph, BHP 3988,WHP 27, IA 755, OA 35 TD well at 11150'CTMD 06:12 08:18 2.10 11,150 7,730 PROD1 DRILL WPRT P PUWt 25k psi,clean and start 10/10 bbl low/high sweep with wiper trip to window. 1.42 bpm, CT 3700,WH 204, BH 3848 psi. IA 700, OA 25 psi.Tie in at window for a+3' correction. 08:18 10:00 1.70 7,730 11,151 PROD1 DRILL WPRT P RBIH, CT WT @ 8000'- 11.9 klbs CT WT @ 9000'- 10.2 klbs CT WT©9500'- 8.67 klbs CTWT@ 10000'-7.83 klbs CTWT@ 11000'-4.21 klbs CT WT @ 11050'-5.50 klbs """Note Tag TD @ 11150.75 10:00 12:00 2.00 11,150 7,969 PROD1 DRILL CIRC P Lay in liner running pill(beads),46 bbls, Paint EOP flag at 7969, 12:00 13:54 1.90 7,969 76 PROD1 DRILL TRIP P Flag Pipe at 4669'Liner shoe at window. Continue out of hole, close HLV and no flow check for 10 minutes. IA 500 psi, OA 17 13:54 15:30 1.60 76 0 PROD1 DRILL PULD P PJSM, LD BHA#3, L1 lateral drilling assembly. Clear floor and prep for liner running. Perform maintenance to link tilt hydraulic ram hose fittings. 15:30 21:39 6.15 75 3,114 COMPZ CASING PUTB P PJSM MU L1 liner assembly. Bull nose, 102 joints slotted and liner top billet. 21:39 22:36 0.95 3,114 3,168 COMPZ CASING PULD P PJSM. PU/MU BHA#5,Test MWD, tag stripper, set depth. RIH to two feet. Equalize, open HES valve. 22:36 23:45 1.15 3,168 7,772 COMPZ CASING RUNL P RIH w/liner assembly, liner top billet. Stop at EOP flag @ 7,772'for-5.5' correction. 23:45 00:00 0.25 7,772 8,330 COMPZ CASING RUNL P Continue in hole with liner 34/29/2015 Run L1 liner assembly to 11,150', release from liner. POOH for KO drilling assembly. LD BHA#5, MU BHA #6'Kick-off billet @ 8,026',drill build/turn section to 8,310'. POOH for lateral drilling assembly. LD BHA#6, MU BHA#7. Start drilling L10-01 lateral to 8,441',drilling in progress. 00:00 01:09 1.15 8,330 11,150 COMPZ CASING RUNL P Continue in hole with liner,tag bottom @ 11,150', PUW=32K,set back down,stack 4K, release from liner, PUW=23K. Subtract liner length from depth. 01:09 02:51 1.70 11,150 50 COMPZ CASING TRIP P POOH KO drilling assembly. Close HES DH valve. Pace 7 of 1" • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:51 04:06 1.25 50 0 COMPZ CASING PULD P PJSM. Unstab wellhead, LD BHA. Function test BOP,check coil above CTC. 04:06 05:42 1.60 0 75 PROD2 STK PULD P PJSM. PU/MU BHA#6, open down hole HLV. 05:42 07:30 1.80 75 7,727 PROD2 STK TRIP P RIH, IA 300, OA 18 psi 07:30 07:42 0.20 7,727 7,772 PROD2 STK DLOG P Tie in for 1'correction. 07:42 07:54 0.20 7,772 8,026 PROD2 STK TRIP P RIH, 1.41 bpm, CT 3800 psi, DHP 3805, free spin diff 405 psi. CTRIHWT 10.5 k. 07:54 10:12 2.30 8,026 8,028 PROD2 STK KOST P OB Drilling on billet, 1.41 bpm, CT 3988, DHP 3892 10:12 11:12 1.00 8,028 8,050 PROD2 DRILL DRLG P Off the billet drilling @ 1.38 bpm, CT 4012, DHP 3806, CT wt 10.8k psi, WOB 0.9 k psi, ROP 13. 11:12 11:24 0.20 8,050 8,050 PROD2 DRILL DRLG P PUH to 8012', WT26k psi,Turn around and dry drift, clean KO. 11:24 16:12 4.80 8,050 8,310 PROD2 DRILL DRLG P DD build and turn @ 1.37 bpm, CT 4110, BHP 3730. Initial CT wt 10.4 k,WOB 1.76, ROP 52 8180' in Ankerite,gradually drilled through. 16:12 16:36 0.40 8,310 7,851 PROD2 DRILL WPRT P TD build and turn, PUWT 28 k lbs, pump 10/10 bbls low/high sweep. Open EDC. 16:36 18:36 2.00 7,851 75 PROD2 DRILL TRIP P POOH, Close subsurface HLV, Flow check PJSM. 18:36 19:36 1.00 74 0 PROD2 DRILL PULD P Lay down BHA#6,service injector, blown down choke B. 19:36 20:48 1.20 0 73 PROD2 DRILL PULD P PJSM. MU BHA#7, check wellhead sensor and pipe thickness, OK.Test MWD and tag stripper. 20:48 22:48 2.00 73 8,310 PROD2 DRILL TRIP P RIH w/lateral drilling assembly.54 AKO motor, Hycalog bit(RB). Equalize and open HES DH valve. Tie-in to K1 for-.5'correction, PUW=25K, close EDC. 22:48 00:00 1.20 8,310 8,441 PROD2 DRILL DRLG P Drill ahead L1-01 lateral. 1.40 BPM ©4,066 PSI, BHP=3,780 PSI, CTW=10K,WOB=1.5K, ROP=120. 34/30/2015 Drill ahead L1-01 lateral from 8,441'to 10,069',drilling in progress. New mud to bit @ 9,215'. 00:00 00:54 0.90 8,441 8,560 PROD2 DRILL DRLG P Continue drilling ahead L1-01 lateral. 1.41 BPM @ 3,990 PSI, BHP=3,760 PSI, CTW=10K,WOB=1K, ROP=130. 00:54 01:39 0.75 8,560 8,560 PROD2 DRILL WPRT P Wiper to window, PUW=25K, RBIH. 01:39 03:18 1.65 8,560 8,810 PROD2 DRILL DRLG P Drill ahead. 1.42 BPM @ 4,020 PSI, BHP=3,765 PSI, CTW=10K, WOB=1.3K, ROP=140. 03:18 04:06 0.80 8,810 8,810 PROD2 DRILL WPRT P Wiper to 7,950', PUW=26K, RBIH. 04:06 05:54 1.80 8,810 9,060 PROD2 DRILL DRLG P Drill ahead. 1.42 BPM @ 4,090 PSI, BHP=3,785 PSI, CTW=9.5K, WOB=1.4K, ROP=150. Page 8 of 14 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:54 07:30 1.60 9,060 9,060 PROD2 DRILL WPRT P Wiper to window. 7,806', PUW=25K, Min rate through billet KO and window, pulled through clean. Turn around at 6:35 RBIH. 07:30 11:36 4.10 9,060 9,310 PROD2 DRILL DRLG P Drill ahead. 1.40 BPM @ 4,000 PSI, BHP=3,941 PSI, CTW=5.8K, WOB=1.24K, ROP=50 Started running out of push, stacking weight,at 9288, pulled short wiper trip, "'*Note: New mud at bit @ 9215' 11:15 11:36 12:48 1.20 9,310 9,310 PROD2 DRILL WPRT P Wiper trip#1 to 8100', PUW=28K, RBIH. 12:48 15:36 2.80 9,310 9,590 PROD2 DRILL DRLG P BOBD 1.40 BPM @ 3750 PSI, BHP=3,828 PSI, CTW=9.12K, WOB=1.23K, ROP=75-130 15:36 16:42 1.10 9,590 9,590 PROD2 DRILL WPRT P Wiper trip#2 to 8500', PUW=28K, RBIH. Turn around @ 16:00, RIH wt 11k lbs 16:42 19:00 2.30 9,590 9,890 PROD2 DRILL DRLG P BOBD 1.39 BPM @ 3750 PSI,WH 0 psi, BHP=3,783 PSI, CTW=7.25 K, WOB=1.6 K, ROP=160-200 IA 654, OA 30 psi 19:00 21:30 2.50 9,890 9,890 PROD2 DRILL DRLG P Tie-in wiper trip. PUW=28K,jet 5 1/2"to 7,800'.Tie-in to RA for+1' correction. RBIH. 21:30 00:00 2.50 9,890 10,069 PROD2 DRILL DRLG P Drill ahead. 1.46 BPM @ 4,150 PSI, BHP=3,910 PSI, CTW=6.5K, WOB=1.6K, ROP=75. 05/01/2015 Drill ahead L1-01 lateral from 10,069'to called TD @ 10,900',pump 10 bbl to/hi vis sweeps. Chase to window @ 7,900',jet 5 1/2". RBIH for corrected TD @ 10, 900, lay in beaded liner pill. POOH w/BHA#7,tripping in progress. 00:00 01:30 1.50 10,069 10,190 PROD2 DRILL DRLG P Continue drilling ahead. 1.46 BPM @ 4,110 PSI, BHP=3,960 PSI, CTW=2.5K,WOB=1.1K, ROP=80. 01:30 02:30 1.00 10,190 10,190 PROD2 DRILL WPRT P Wiper to 8,030', PUW=29K, RBIH. 02:30 04:45 2.25 10,190 10,440 PROD2 DRILL DRLG P Drill ahead1.46 BPM @ 4,110 PSI, BHP=3,960 PSI, CTW=2.5K, WOB=1.1K, ROP=105. Gas and gas cut mud to the shaker @ 0400, cycle mud to TT and inside looking for it to clear up. 04:45 06:27 1.70 10,440 7,822 PROD2 DRILL WPRT P Wiper to window, PUW=28.5K, RBIH. 06:27 06:45 0.30 7,822 7,822 PROD2 DRILL DLOG P Stop above window for static pressure check,3894 BHP, adjust tripping/drilling schedules to EMW of 12.3 ppg at the window. 06:45 08:21 1.60 7,882 10,440 PROD2 DRILL WPRT P RBIH, RIH wt 8.4k lbs. 08:21 12:21 4.00 10,440 10,690 PROD2 DRILL DRLG P Drill ahead1.40 BPM @ 4300 PSI, BHP=4265 PSI, CTW=4 K, WOB=1.6K, ROP=57. 12:21 13:39 1.30 10,690 10,690 PROD2 DRILL WPRT P Wiper to 9190', PUW=28K, RBIH WT 9.4k Pags 9 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:39 17:42 4.05 10,690 10,900 'PROD2 'DRILL DRLG P Drill ahead1.41 BPM @ 4,110 PSI, BHP=4238 PSI, CTW=.45K, WOB=2.2K, ROP=60. Couple BHA wipers """Note New mud at the bit @ 10690' New mud all the way around @ 14:30 17:42 19:27 1.75 10,900 7,800 PROD2 DRILL WPRT P Wiper to window, PUW=26 K, clean-out 5 1/2"to 7,800',tie-in to RA tag for+2'correction. 19:27 21:18 1.85 7,800 10,900 PROD2 DRILL TRIP P RBIH to confirm TD depth,tag TD @ • 10,900'. Start pumping beaded liner pill. 21:18 00:00 2.70 10,900 2,026 PROD2 DRILL CIRC P POOH laying in beaded liner pill, started getting some crude/gas across shaker,took total of 25 bbls to tiger tank, increase choke pressure 100 psi over trip schedule, continue OOH. Paint EOP flags @ 8,100'&5,100'. POOH w/BHA#7. 35/02/2015 LD BHA#7. MU L1-01 liner assembly, MU BHA#8. Run liner assembly,tag TD @ 10,900', release from liner,TOL @ 8,220'. POOH, LD BHA#8. Prep floor for BOP test.Test BOPE,test witnessed by AOGCC(Jeff Jones). Cut 20'of coil, rehead CTC. 00:00 00:36 0.60 2,026 76 PROD2 DRILL TRIP P Continue OOH with BHA#7, close HES DH valve. 00:36 01:06 0.50 76 76 PROD2 DRILL OWFF P Monitor well for flow, no flow. 01:06 02:30 1.40 76 0 PROD2 DRILL PULD P PJSM. LD BHA#7, injector maintenance,check coil thickness above CTC(.135). Prep floor to run liner. 02:30 07:12 4.70 0 2,725 COMPZ CASING PULD P PJSM. MU L1-01 liner assembly: Bull nose, 90 jts slotted,2 solid pups, and liner top billet. Open Subsurface lubricator valve. Wellhead 11,50 psi, IA 0, OA 0 psi. 07:12 09:12 2.00 2,725 10,385 COMPZ CASING RUNL P RIH with liner, correction at window -4.2', RIH Wt11.2 klbs. 09:12 09:24 0.20 10,389 10,414 COMPZ CASING DLOG P Tie in at the K1,for+2(overall-2.2) -did not stop to reset counter display. 09:24 09:36 0.20 10,414 10,897 COMPZ CASING RUNL P RIH with liner. EOP flag zero correction. 09:36 09:48 0.20 10,897 8,189 COMPZ CASING RUNL P Stack 3k lbs @ 10897.36, PUH Wt 30k lbs, set down 3k lbs, bring pumps up to 1.3 bpm, Pick up,WT 22k lbs. Correct depth. ***Set Liner at 10899.6,top of billet @ 8219.1 09:48 11:00 1.20 8,189 50 COMPZ CASING TRIP P POOH,close Down Hole Lubricator valve. Bleed off, flow check,good. 11:00 11:45 0.75 50 0 COMPZ CASING PULD P Lay down BHA#8, L1-01 liner running assembly. Page 10 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 14:00 2.25 0 0 PROD3 WHDBO BOPE P Prepare tree, rig and BOP for test, valve(grease crew)on location @ 12:00. AOGCC notified-Jeff Jones, scheduled to be on location at 14:00. 14:00 21:30 7.50 0 0 PROD3 WHDBO BOPE P Jeff Jones on location to witness, Flood up&start shell test/BOP test 250/4,200 psi, annular 2,500 psi. No failures. 21:30 00:00 2.50 0 0 PROD3 STK CTOP P Check coil thickness above CTC. Cut coil past bad spot(20'). Install CTC, pull test 35K. Install UQC,test E-Llne,good test. 05/03/2015 Rehead CTC and test. MU BHA#9, RIH w/drilling assembly, kick-off billet @ 8,217'. Drill ahead L1-02 lateral to 9,089',drilling in progress. 00:00 01:30 1.50 0 0 PROD3 STK CTOP P Pressure test CTC, install nozzle, reload coil with mud, unstab, remove nozzle. Remove ice from tugger. 01:30 02:45 1.25 0 73 PROD3 STK PULD P PJSM. MU BHA#9,drilling assembly, equalize and open HES DH valve. 02:45 04:39 1.90 73 8,217 PROD3 STK TRIP P RIH w/drilling assembly, +.5 AKO motor,rebuilt HHC built.Tie-in to K1 for zero correction, continue in hole, dry tag billet @ 8,217'. 04:39 05:51 1.20 8,217 8,218 PROD3 STK KOST P Start kicking off billet; 1.40 BPM @ 4,050 psi, BHP=4,230', CTW=11.5K,WOB-.2K. Getting gas back divert temporarily to TT. Aluminum at the shakers.Time drilling 1ft/hr WOB 1.4k. 05:51 07:03 1.20 8,218 8,245 PROD3 STK KOST P Up ROP to 2 ft/hr,Wt fell off at 8218, Start pushing on it,WOB 2.4k. PUH,WT 25k lbs, Dry drift billet KO clean, 07:03 07:33 0.50 8,245 8,245 PROD3 DRILL WPRT P Wiper trip to 7926', RBIH. 07:33 12:33 5.00 8,245 8,540 PROD3 DRILL DRLG P OBD, CT 4200,WH 471, BHP 4118 psi. CT WT 8.5 k,WOB 1.7 k lbs, ROP 25-75 12:33 13:15 0.70 8,540 8,540 PROD3 DRILL WPRT P Wiper trip#1 to 7935, PUWT 26k lbs RBIH WT 10.8, 1.44 bpm, CT 4230. WH 442, BHP 4128. Free spin 460 psi. 13:15 17:03 3.80 8,540 8,750 PROD3 DRILL DRLG P BOBD RBIH WT 10.8, 1.43 bpm, CT 4456. WH 447, BHP 4091. CT WT 8.64k, WOB 2.05k lbs, ROP90 fph. IA 117, OA 33. @ 8680'WOB fell from 2.4 to.8, 30 min later, returns mud weight dropped to 8.2 ppg. Sent mud outside,for total of 45 bbls, increased choke to 150 psi over published trip schedule. 9.2 ppg returns. �� Page 11 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:03 18:33 1.50 8,750 8,840 PROD3 DRILL DRLG P 1.42 bpm, CT 4240,WH 500, BHP 4213 psi, CT WT 6.9k,WOB 2.55k, ROP 50 ft/min 18:33 19:39 1.10 8,840 8,840 PROD3 DRILL WPRT P Wiper to window, PUW=26.5K, RBIH. 19:39 00:00 4.35 8,840 9,089 PROD3 DRILL DRLG P Drill ahead: 1.40 BPM @ 4,250 PSI, BHP=4,240 PSI, CTW=8.5K, WOB=1.9K, ROP=55. 05/04/2015 Drill ahead L1-02 lateral from 9,089'to 9,927', new mud system @ 9,630',drilling in progress. 00:00 01:09 1.15 9,089 9,140 PROD3 DRILL DRLG P Continue drilling: 1.40 BPM @ 4,250 PSI, BHP=4,255 PSI, CTW=7K, WOB=2.5K. ROP=50 01:09 03:15 2.10 9,140 9,140 PROD3 DRILL WPRT P Tie-in wiper, PUW=25.5,jet 5 1/2" max rate,tie-in for+3.5 correction, RBIH. 03:15 09:03 5.80 9,140 9,440 PROD3 DRILL DRLG P Drill ahead: 1.40 BPM @ 4,290 PSI, BHP=4,260 PSI, CTW=7.8K, WOB=2K. ROP=45 Down Hole Lubricator(DHL)valve,3k psi on open circuit, 1k psi on closed. Bled close to zero then open to 1 kpsi. 09:03 10:15 1.20 9,440 9,440 PROD3 DRILL WPRT P Wiper#1 1,200' to 8240, PUW=25 k, Chase high low sweep out of hole. RBIH. RIH WT 9.6k lbs/ft 1.34 bpm free spin 420 diff 10:15 14:27 4.20 9,440 9,636 PROD3 DRILL DRLG P BOBD, 1.36 bpm, CT 4450, BHP 4238,WH 392 psi, CTWT 7.53, WOB 1.89, ROP 86 ft/hr. Mud swap 9.2 ppg for 9.8 ppg FlowPro. """ Note: New mud at the bit 9616'. 14:27 15:39 1.20 9,636 9,740 PROD3 DRILL DRLG P New 9.8 mud all the way around PU WT 26k psi, Free spin 420 psi, 1.33 bpm, CT 4500, BHP ,WH 192 psi, CTWT 4.2 k,WOB 2.2 , ROP 63 ft/hr. @ 9695 took 25 bbls of light mud, 8.2 ppg to the Tiger tank. Increased choke pressure another 25 psi over published trip. 15:39 16:39 1.00 9,740 9,740 PROD3 DRILL WPRT P Wiper#2 1200' to 8540, PUW=24 k, RBIH. RIH WT 8.1 k lbs/ft 16:39 21:39 5.00 9,740 9,927 PROD3 DRILL DRLG P BOBD, 1.33 bpm, CT 4460, BHP 4307,WH 238 psi, CTWT 7.0,WOB 1.82, ROP 40 ft/hr. Had to increase choke pressure another 50 PSI, small influx of gas to surface. Losing push, negative surface weight, BHA wiper @ 9,925', little help. Make early wiper for tie-in. 21:39 23:24 1.75 9,927 7,880 PROD3 DRILL WPRT P Wiper to TT, PUW=25K,open EDC. jet 5 1/2"at max rate, close EDC. RBIH,tie-in to RA for+6'correction. 23:24 00:00 0.60 7,880 9,052 PROD3 DRILL DLOG P RBIH,tie-in to RA for+6'correction. Continue in hole. 05/05/2015 Drill ahead L1-02 lateral from 9,927'to 10,572', drilling in progress. Page 12 of 14 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 00:24 0.40 9,052 9,927 PROD3 DRILL WPRT P Continue in hole. 00:24 05:24 5.00 9,927 10,088 PROD3 DRILL DRLG P BOBD: 1.31 BPM @ 4,310 PSI, BHP=4,400, CTW=5.3K, WOB=2.3K, ROP=35 05:24 06:42 1.30 10,088 10,088 PROD3 DRILL WPRT P Wiper#1290' to 8798, PUW=25 k, RBIH. RIH WT 8.0 k lbs/ft 06:42 11:00 4.30 10,088 10,220 PROD3 DRILL DRLG P BOBD: 1.31 BPM @ 4,300 PSI, BHP=4,367, CTW=4.0K, WOB=1.88K, ROP=29,Three BHA wipers, losing push, PUWs clean at 24k 11:00 12:00 1.00 10,220 10,220 PROD3 DRILL WPRT P Wiper up hole to 9,230-ft, PUW 24k, RBIH, RIW 7k 12:00 16:30 4.50 10,220 10,396 PROD3 DRILL DRLG P 10,220-ft, BOBD 1.32 bpm at 4,322 psi, BHP 4,407 psi, CWT 4.5k,WOB 1.7k, ROP 40, losing push, several pickups in attempt to get started, PUWs 25k and clean 16:30 19:45 3.25 10,396 10,396 PROD3 DRILL WPRT P Wiper trip to window for tie-in, PUW 24k,jet/jog 5.5"BTP,tie in at RA, +2-ft correction. RBIH. 19:45 00:00 4.25 10,396 10,572 PROD3 DRILL DRLG P BOBD: 1.30 BPM @ 4,390 PSI, BHP=4,440 PSI, CTW=5.3K, WOB=1.8K, ROP=55 35/06/2015 Drill ahead L1-02 lateral from 10,572'to called TD @ 10,923'. Pump 10 bbl sweeps, chase to window.Jet 5 1/2"big tail pipe. RBIH for corrected TD @ 10,295'. POOH laying in beaded liner pill. LD BHA#9. 00:00 01:09 1.15 10,572 10,610 PROD3 DRILL DRLG P Continue drilling: 1.30 BPM©4,390 PSI, BHP=4,440 PSI, CTW=5.3K, WOB=1.8K, ROP=55 01:09 02:18 1.15 10,610 10,610 PROD3 DRILL WPRT P Wiper to 9,400', PUW=23K, RBIH. 02:18 08:06 5.80 10,610 10,790 PROD3 DRILL DRLG P BOBD: 1.28 BPM @ 4,340 PSI, BHP=4,440 PSI, CTW=3.5K, WOB=1.4K, ROP=55,took 20 bbls light mud(8.2 ppg)to TT at 10,780-ft, hold 25 psi above pressure schedule, brought back in,still light,take 40 more bbls out for bottoms up, mud 9.8 ppg, losing push. 08:06 09:06 1.00 10,790 10,790 PROD3 DRILL WPRT P Wiper up hole to 9,610-ft, PUW 25k, RBIH, RIW 6k 09:06 14:30 5.40 10,790 10,922 PROD3 DRILL DRLG P 10,792-ft, BOBD 1.29 bpm at 4,375 psi, BHP 4,468 psi, CWT 1.1k,WOB 1.5k, ROP 30, several BHA wipers, PUWs 25k and clean. 14:30 17:27 2.95 10,922 7,800 PROD3 DRILL WPRT P 10,922-ft, TD called, pump to/hi sweeps,chase to window,jet/jog 5.5"BTP,tie in at RA,+5.5-ft correction 17:27 18:45 1.30 7,800 10,925 PROD3 DRILL TRIP P RBIH for corrected TD,tag up @ 10,925' 18:45 22:30 3.75 10,925 75 PROD3 DRILL CIRC P POOH laying in beaded liner pill. Paint EOP flags @ 7,700'and 4,700'. Continue OOH with BHA#9. Close HES DH valve. 22:30 23:00 0.50 75 75 PROD3 DRILL OWFF P Flow check, no flow. Page 13cf14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 75 0 PROD3 DRILL PULD P PJSM. Check pipe thickness. LD BHA#9. 05/07/2015 MU L1-02 liner assembly. RIH w/liner assembly,tag up, release from liner @ 10,924'. Swap well over to seawater. Freeze protect with diesel. Set BPV,secure tree and wellhead. RDMO CDR2 00:00 00:39 0.65 0 0 COMPZ CASING PUTB P Prep rig floor to run liner,service top drive. 00:39 03:54 3.25 0 3,030 COMPZ CASING PUTB P PJSM. PU/MU 103 jts slotted liner and one solid pup. 03:54 05:00 1.10 3,030 3,075 COMPZ CASING PULD P PJSM. MU BHA#10,test tools, skid injector over wellhead,tag up, open HES DH valve. 05:00 07:30 2.50 3,075 10,924 COMPZ CASING RUNL P RIH w/L1-02 liner assembly, bull nose, 103 jts slotted, one solid pup, and shorty deployment sleeve.Tie in at flag, minus 3.5-ft correction, PUW 28k,continue in hole 07:30 07:42 0.20 10,924 10,924 COMPZ CASING RUNL P 10,924-ft, Stack 3k down, PUW 33k, WOB-11k, stack 3k,would not release at 1.25 bpm, stack 5k, same at 1.29 bpm, release off liner pumping 1.35 bpm at 4575 psi, PUW 26k,WOB-3k, TOL at 7,892-ft, remove liner length from counter, PUH. 07:42 09:30 1.80 7,880 2,500 COMPZ CASING DISP P 7,880-ft, roll well over to seawater, POOH to 3,600-ft, WHP 1,400 psi, close DHLV, bleed tubing above DHLV to 0 psi, flow check 15 minutes. 09:30 11:24 1.90 2,500 44 COMPZ CASING FRZP P PJSM with LRS, pump 30 bbls diesel down coil, RD LRS. continue OOH freeze protecting well. 11:24 12:24 1.00 42 0 DEMOB WHDBO RURD P On surface, flow check, PJSM-blow down, LD BHA#10, pull checks. 12:24 14:54 2.50 0 0 DEMOB WHDBO RURD P Circulate 30 bbl flush, 30 bbl inhibitor, 30 bbl flush through coil, BOPE and rig lines 14:54 16:00 1.10 0 0 DEMOB WHDBO MPSP P PJSM-RU FMC equipment, PT 2,200 psi, open DHLV,WHP 1,560 psi, lubricate in BPV, RD FMC equipment. 16:00 17:30 1.50 0 0 DEMOB WHDBO RURD P PJSM-Blow down coil and surface lines, bleed off pressure. Blow down steam,secure reel and injector. 17:30 19:00 1.50 0 0 DEMOB WHDBO SFTY P Pre-tour meeting. Hands free safety presentation. SLT meeting. 19:00 00:00 5.00 0 0 DEMOB WHDBO NUND P PJSM. ND BOP stack&secure. Secure tree,check tree flange bolts. Prep for rig move. Move shop and spot at 2T-Pad Note: Rig Release @ 24:00 on 5-7-15 Page 14 of 14 ® W iii . lotio `mo Q= m N O. I ci a t Te O co 0 0) W ce a 1- ,, a. C z> • a. - - &- •_ •- - s •- co a.U s 'EMO > a CD 0 _ m. O O NC r • �_ e- c rO C N _ 3 � _ ��V 22o 0 Y N CO 0 o ra W ' f N O co V O O a)) O Ili 5 II O i N € - T!0 O O O A C Z O N is N O O r ,- 'a U) C N N ((0 N W V U) Q & U. 2 0 c o (l � o 0 1 o a0000 N N N N N U) y rN N d N V V > .. d W J W 7 2 C w C O 2 J J 0 6) 00 C - °0 o 0. co - Lil LO N N o o ._ N 7 > > a .- O O C O O N 0Y _ j 3 I- @) E N c o a a m o N IA V) E < a w 1�': + O• N co co p Y Y c 0 O N 7 C m ▪ N N H , W N U j .a J U) CO N N m p OD 0 i Cr: N C/) 7 = f. 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CDtO t . k E § m , Co „ V } ± \ CN N j _J\ _@ , ; \ :.cO } } \ \ 0 \ u ! Co \ \ \ 0 §c \ � = \ oaaa Co tm �U / � _ ]3J ) \u 0. Cl) 115035 25 00 1 Letter of Transmittal FIN! RECEIVED BAKERDate: DATA LOGGED HUGHES May 8, 2015 MAY 11 2015 G i t /2015 M.K.BENDER AOGCC To: From: Makana Bender 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-15L1 2K-15L1-01 2K-15L1-02 (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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'a c0 m U) O W r U) W C O QD U) O d t p) Di (,1 (O pO (O `? m c 2 0 'rn• a, U) U) rn U) O N Z xi. )p V) Ui Li, Ui co U) O N c U d C 'a = O N 0 0 .O ` o- @ C O a" w d 0 N O U) R - - O o t6 0 R' t (O S_' O U) N W a p >>> 0 O 7 i0 N .= a Ps M as U) _1 F z Z co O W -3— Off) r CO (0 0 0N) ✓ . (U) of Z 2 chi• ri 1 ri ri q C) )` U) 0 — M m N U) CO O O • 3 c0 U) (D cos-- co'-- N MNmQ --;----t _YJ CO N OCO Q H CVN NN N N 3CO (O O (O O (O cn Q C O '' V (V ad O ONNN N ii U 7 7 J J �w ,,,. • O co co — — N 7 V N N N N c a a S U Y Y N N N Y, _ „, „i°: "<r- n ON) ONi g (3 x k MO U o g) () m (Io 8ui ts O m « 0 = >, 2 v 0 0 0 0 0 0 (0 Q U U £ •O of T" Alaska Oil and Gas w\ �j,s� THE STATE la ofALASI�:A Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main. 907.279.1433 OF ALAS' ' Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-15L1-01 ConocoPhillips Alaska, Inc. Permit No: 215-035 Surface Location: 119' FNL, 94' FEL, Sec. 11, T1ON, R8E, UM Bottomhole Location: 1168' FSL, 1428' FEL, Sec. 12, T1ON, R8E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 189-089, API No. 50-103- 20113-00-00. 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, Cathy P. F•erster Chair DATED this l0 day of March, 2015. RECEIVED STATE OF ALASKA FEB 2 4 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 la Type of Work 1 b Proposed Well Class Development-Oil Q • Service-Winj ❑ Single Zone Q• 1c Specify if well is proposed for. Drill ❑ , Lateral Q Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name. 5. Bond , U Blanket U Single Well 11 Well Name and Number: ConocoPhillips Alaska, Inc. Bond No 59-52-180 . KRU 2K-15L1-01 3 Address: 6 Proposed Depth. 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 ' MD 10900' • TVD. 6239' ' 4a Location of Well(Governmental Section) 7 Property Designation(Lease Number) Kuparuk River Field V;` Surface: 119'FNL, 94'FEL,Sec 11,T1ON, R8E, UM i ADL 25588 ' Kupruk River Pool Top of Productive Horizon 8 Land Use Permit 13.Approximate Spud Date 1584'FNL, 995'FEL, Sec. 12,T1ON, R8E, UM 2674 3/15/2015 Total Depth 9 Acres in Property 14 Distance to 1168'FSL, 1428'FEL, Sec 12,T1ON, R8E, UM , 2560 ' Nearest Property 11822' 4b Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL . 154 feet 15 Distance to Nearest Well Open Surface:x- 498310 y- 5938185 Zone- 4 ' GL Elevation above MSL 113 7 feet to Same Pool 2K-17,85 16 Deviated wells Kickoff depth , 8025 ft. 17 Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle. • 97° deg Downhole 4483 psig , Surface:3820 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 2645' 8255' 6219' ' 10900' 6239' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth TVD(ft): Junk(measured) 8304 6495 7742 8202 6417 none Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 176 sx AS II 115' 115' ,1 Surface 3285' 9.625" 1000 sx AS III,450 sx CI G 3320 2947' Intermediate Production 8253' 7" 225 sx Class G 8286' 6481' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7824-7832, 7934-7974 6134-6140, 6217-6247 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program O Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 MC 25.050 requirements ❑� 21.Verbal Approval. Commission Representative Date 22. I hereby certify that the foregoing is true and correct Contact Jaso urke @ 265-6097 Email Jason.Burkecop.com Printed Name D. Vfihaus Title CTD Engineering Supervisor Signatureit..---- -2-4----7 -1,--- --7----k__ Phone 263-4372 Date 2 — Z 3 —/5 Commission Use Only Permit to Drill API Number: I Permit ApprovalSee cover letter Number a 15— (3,33— 50- 103-(7,Z0 113-61_CO Date 7 /(n I1 9 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m hane,gas hydrates,or gas contained in shales I rJ Other. 6,3 fly�p r-,-- is 2.0c. 5 Samples req'd Yes 2 No [ Mud log req'd: Yes❑ No Er /9-//,-)(- I ' - �l5 J-p vc•55 yr r- /5 X50, H2S measures: Yes No Directional svy req'd: Yes[ ' No Sp ig exception req'd. Yes ❑ No Inclination-only svy req'd: Yes❑ No[2' f ^JAPPROVED BY THE / C'Approved by /� ;2, ._ COMMISSIQNER COMMISSION Date:-3—�O / J Form 10- 01V yis 3/3 JJJ/`�2���"""""�" This permit is valid o©'2 o�tl ti�d c#approva l<QAA3A�gi518))�3 z - RECEIVED FEB 2 4 2015 ConocoPhillips �±�+ Alaska AOGCC P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 19, 2015 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 from the existing well bore on KRU 2K-15 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin on March 15, 2015. The CTD objective will be to drill 3 laterals(2K-15L1, L1-01 & L1-02), targeting the A4&A5 sands. This well will be classified as a development well. Attached to this application are the following documents: — Permit to Drill Application Form 10-401 for 2K-15L1, L1-01 & L1-02 — Detailed Summary of Operations — Directional Plans — Current Schematic — Proposed Schematic If you have any questions or require additional information please contact me at 907-265-6097. Sincerely, 4/ ason Burke Coiled Tubing Drilling Engineer 907-231-4568 Kuparuk CTD Laterals NdBOAS ALASXA CDq 2K-15L1, L1-01 & L1-02 n `n° '° Application for Permit to Drill Document 2f C 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 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 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 7 Attachment 1: Directional Plans for 2K-15L1, L1-01 &L1-02 7 Attachment 2: Current Well Schematic for 2K-15 7 Attachment 3: Proposed Well Schematic for 2K-15L1, L1-01 &L1-02 7 Page 1 of 7 2/19/2015 FINAL PTD Application: 2K-15L1, L1-01 & L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) The proposed laterals described in this document 2K-15L1, L1-01 & L1-02. This lateral will be classified as "Development—Oil"well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This lateral will target the A4 &A5 sand packages in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 2K-15L1, L1-01 & L1-02. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4200 psi. Using the maximum formation pressure in the area of 4483 psi in the 2K-25, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3820 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-15 in February 2015 indicated a reservoir pressure of 3483 psi or 10.8 ppg equivalent mud weight. The recent work over done on this well was done with a 11.5 ppg NaBr. The maximum down hole pressure in the 2K-15 pattern is at 2K-25 with 4483 psi. It is not expected that reservoir pressure as high as 2K-25 will be encountered while drilling the 2K-15L1, L1-01 & L1-02 because this is a very old pressure and the surrounding wells are of a lower pressure. Using the 2K-25 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3820 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed on the 2K pad, so cuttings will be monitored for entrained 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-15 laterals will be drilling an unstable shale in our build section. Managed pressure drilling will be used to reduce this risk. 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 7 2/19/2015 RIGINAL PTD Application: 2K-15L1, L1-01 & L1-02 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-15L1 8025' 11150' 6087' 6055' 2% , 4.7#, L-80, ST-L slotted liner; with an aluminum billet on top. 2K-15L1-01 8255' 10900' 6065' 6085' 23/", 4.7#, L-80, ST-L slotted liner; with an aluminum billet on top. 2%", 4.7#, L-80, ST-L slotted liner; 2K-15L1-02 7790' 11000' 5812' 6064' with a shorty deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Conn. Top MD Btm Top Btm Burst Collapse (POMD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 36' 115' 0' 115' 1640 630 Surface 9-5/8" 36 J-55 BTC 35' 3320' 0' 2946' 3520 2020 Casing 7" 26 L-80 TCII 33' 2107' 0' 2053' 7240 5410 Casing 7" 26 J-55 BTC 2107' 8285' 2053' 6481' 4980 4330 Liner 5'/2" 14.0 H-40 EUE 7796' 7916' 6188' 6203' 3110 2620 Tubing 3'h" 9.3 L-80 EUE 8rd 31' 7796' 0' 6188' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Power-Vis mud (9.7 ppg) — Drilling operations: Chloride-based Power-Vis mud (9.7 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure. — Completion operations: 2K-15 contains a new style deployment valve. This valve will allow the deployment of tool strings and liner without pumping kill weight fluid. However, in the case the valve will not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.4 ppg NaBr completion fluid in order to provide formation over-balance while running completions. — Kill Weight fluid: Two wellbores ofell weight fluid will be stored at a central location in the Kuparuk field and accessible for trucking to the rig during CTD operations. Page 3 of 7 o G I A i 2/19/2015 PTD Application: 2K-15L1, L1-01 & L1-02 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. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case a constant BHP of 11.4 ppg will be initially targeted at the window based on the recent static bottom-hole pressure and the fault blocks being drilled into. 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-15 Window(7896' MD, 6188' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure(10.8 ppg) 3475 psi 3475 psi Mud Hydrostatic(9.7 ppg) 3121 psi 3121 psi Annular friction (i.e. ECD, 0.070 psi/ft) 553 psi 0 psi Mud + ECD Combined 3674 psi 3121 psi (no choke pressure) (overbalanced (underbalanced —199 psi) —354 psi) Target Li, at Window(11.4 ppg) 3668 psi 3668 psi Choke Pressure Required to Maintain Target BHP 0 psi 547 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. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Page 4 of 7 I r l N n L 2/19/2015 PTD Application: 2K-15L1, L1-01 & L1-02 Summary of Operations Background Well 2K-15 is a Kuparuk A-sand development well equipped with 31/2"tubing and a 5 'h"big tail pipe liner. Three laterals will be drilled from the mother bore towards the suspended well bore at 2K-17. A mechanical whip-stock will be placed in the 5 '/2"liner at the planned kickoff point of 7896' MD. We will mill a window and land the build section at 8294' MD. From there we will pick up lateral drilling tools and drill the L1 to a depth of 11150' in the A4 sand. We will run 2-3/8"slotted liner with an aluminum billet back up to 8025'. We will kick off the L1-01 and drill to a depth of 10900' in the A4 sand:'We will run 2-3/8"slotted liner with an aluminum billet back up to 8255'. We will kick off the L1-02 and drill to a depth of 11000' in the A5 sand. We will run 2-3/8"slotted liner a shorty deployment sleeve back up to 7790'. Pre-CTD Work • Slick-line:Perform dummy whip-stock run,dummy off all gas lift valves and obtain a SBHP • E-Line: Set a mechanical whip-stock at 7896' MD • Slick-line: Set a down hole gauge in the lower most gas lift mandrel Ria Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2K-15L1 Lateral(A4 sand-Northwest) i. Mill 2.80"window at 7896' MD ii. Drill 2.74"x 3.00"bi-center lateral to TD of 11150' MD iii. Run 2%"slotted liner with an aluminum billet from TD up to 8025' MD 3. 2K-15L1-01 Lateral(A4 sand-South) i. Kick off the billet at 8025' ii. Drill 2.74"x 3.00"bi-center lateral to TD of 10900' MD iii. Run 2%"slotted liner with an aluminum billet from TD up to 8255' MD 4. 2K-15L1-02 Lateral(A5 sand-South) i. Kick off the billet at 8255' ii. Drill 2.74"x 3.00"bi-center lateral to TD of 11000' MD iii. Run 2%"slotted liner with a shorty deployment sleeve from TD up to 7790' MD 5. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Page 5 of 7 ORIGINAL 2/19/2015 PTD Application: 2K-15L1, L1-01 & L1-02 3. Return to operations Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a down hole deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. 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 slick-line lubricator can be used. 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-15 has a new down hole deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals will be displaced to an overbalancing fluid (11.4 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 (1 R-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). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) Page 6 of 7 2/19/2015 ORIGINAL PTD Application: 2K-15L1, L1-01 & L1-02 — 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-15L1 14417' 2K-15L1-01 11822' 2K-15L1-02 11829' — Distance to Nearest Well within Pool (measured to offset well) Lateral Name Distance Well 2K-15L1 271' 2K-07 2K-15L1-01 85' 2K-17 2K-15L1-02 112' 2K-17 16. Attachments Attachment 1: Directional Plans for 2K-15L1, L1-01 & L1-02 Attachment 2: Current Well Schematic for 2K-15 Attachment 3: Proposed Well Schematic for 2K-15L1, L1-01 & L1-02 Page 7 of 7 ORIGINAL 2/19/2015 KUP PROD 2K-15 ConocoPhillips ir , . Well Attributes Max Angle&MD TD AlaskaInc Wellbore API/UWI Field Name Wellbore Status not(1) MD(BOB) Act Btm(BOB) LanorOp4.1bps 501032011300 KUPARUK RIVER UNIT PROD 46.42 6,500.00 8,304.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 21,-15.2/3/2015 1.11.28 PM SSSV:NIPPLE 73 12/30/2012 Last WO'. 11/28/2014 40.19 10/16/1989 Vertical sctnmabc(actual) 1 Annotation Depth(BOB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,002.0 2/2/2015 Rev Reason:TAG,GLV C/O lehallf 2/3/2015 HANGER;31.1 Casing Strings Casing Description OD(In) ID(In) Top(RKB) Set Depth(BOB) Set Depth(ND)... WVLen fl...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED - •- `' Casing Description OD(In) ID(In) Top(ftKB) Set Depth(BOB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • I SURFACE 95/8 8.921 35.0 3,319.7 2.946.5 36.00 J-55 BTC ••.• V!, Casing Description OD(In) ID(in) Top(BOB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7" 7 6.276 33.0 2,107.4 2.053.2 26.00 L-80 TC II ,:pttut NIB,Tieback Casing Description OD(in) ID(In) Top(BOB) Set Depth(ftKB) Set Depth(ND)...W6Len 0...Grade Top Thread PRODUCTION 7 6.276 2,107.4 8,285.6 6,480.7 26.00 J-55 BTC Tubing Strings M/CONDUCTOR 36.0-1150 /,3.J J`:Vv!/8,'robing Desodption String Ma...I ID(in) Top(ROB) Set Depth(R..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-WO 31/2x 31/2 2.992 311 7,916.0 6.2032 9.30 L-80 EUE 8Rd 5 1/2 @7785.13 NIPPLE 5190 .; Completion Details Nominal ID Top(ftKB) Top(ND)(ft(B) Top Incl(•) Item Des Corn (in) 31.1 31.1 0.05 HANGER FMC GEN V HANGER 2.992 x 519.0 519.0 0.38 NIPPLE CAMCO"DS"NIPPLE 2.875 :,.� 3,719.6 3,227.1 45.48 BARRIER VLV HES LUBRICATOR ORBIT VALVE(BARRIER VLV) 2.894 7,567.9 5,942,4 41.52 LOCATOR 'BAKER LOCATOR 2.900 PRODUCTION 7"Toback.330- _ 2.107.4 7,568.9 5,943.1 41.52 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY(SPACED OUT 7.13') 3.000 7,575.4 5,948.0 41.51 PBR BAKER 80-40 20'PBR 2.980 GAS LIF T.26606 1 ;E 7,598.5 5,965.2 41.51 PACKER BAKER 4782 FHL PACKER 2.900 7,742.8 6,073.4 41.42 NIPPLE HES"X"NIPPLE 2.813 7,785.1 6.105.2 41.40 XO Enlarging 3 1/2"to 5 1/2"PORTED CROSSOVER 2.992 iPerforations&Slots Shot SURFACE.35 0-3 --319 7 Dens Top(TVD) BM,(ND) (shots/1 Top(BOB) Btm(ftKB) (R(B) (BOB) Zone Date ti Type Corn 7,824.0 7,832.0 6.134.3 6.140.3 C-4,2K-15 5/25/1997 6.0 IPERF 2.5"HSD.60 deg. Phasing BARR.ER VLA 3 719 6 7,934.0 7,974.0 6,216.7 6246.7 A-4,2K-15 4/19/1990 4.0 IPERF 4.5"HSC,180 deg. Phasing Mandrel Inserts o�st N Top(ND) Valve Latch Port TRO Run Top(BOB) (ftKB) Make Model OD(In) Sery Type Type (In) (psi) Run Date Com GAS LIFT,42611 2,660.6 2,487.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 12/24/2014 2 4,261.1 3,609.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/24/2014 3 5,4692 4,459.6 CAMCO MMG 1 1)2 GAS LIFT DMY RK 0.000 0.0 12/24/2014 GAS LIFT 5,4602I -li 4 6,384.6 5,105.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/24/2014 5 7,0842 5,5932 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/24/2014 GAS LIFT.6.3846 6 7,511.8 5,900.4 CAMCO MMG 11/2 GAS LIFT SOV RKP 0.000 0.0 2/2/2015 DCR- 1 Notes:General&Safety End Date Annotation II 9/3/2000 NOTE:E-LINE IDENTIFIED LEAKS @ 2425',6765',7235'MD GAS LIFT.7 084 2 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/20/2015 NOTE:BARRIER VLV control lines/system @Wellhead marked Open/Close 1/20/2015 NOTE:BARRIER VLV is NOT a safely valve,I does not fail to closed position GAS LIFT,7.511 0 4 LOCATOR.7.567.9 SEAL ASSY.7,5E8 9 PBR,7575 4- PACKER,7.598.5 NIPPLE:7.7428 V 4 IPERF;7.8240.7,832.0 I I __. ~ IPERF;7,934.0.7,974.0- PRODUCTION;2,107.48,288.6 ORIGINAL 0 • °• `' 0 0 cz CI o o 2 o in i II � • 0o it H a CD I-4.. cc 0 O _ n9 c a� Qw 141 E co to CV O'o O co c Lo 141 p N N N Y Cs-? CO N N N S `C 03 M b 0 . 1\\ 2 0 E rn (0 t0 c \\ o in in• 0 O N .!2 \\\ �-in 0o0 co U Ch \ —o cV c mu) p O a 0 \\\ ti co CO a id > of ✓ v� O o a a) \\ a" in In 0 0 _ rr, cV U -a _j w 1\ 0 3 ca X h L N. N c m u) cm 1 1 o a) W U X 0 ti 0_ * .o U c c I ' 0. CO � i r-- 0 • 0 d t m �is c I co- 0. J J � U �Q Q N aai o a� co I YM Cp a co M O -a c C m = CN a) 0U (n c i N N 0 rn 't n 0 - n. u_ X 'co co " n a) N o I N N C Nto Y .Y N N N�6 ,(7' c' w m o o Q I `' •' co * N— h ca co '- 0) a3 a) a / 1 M () I Mco mm c) inLoc 0= ami X00 @ / / �° Evo0 �00c @ / / '+ O y / / /j 4.4P c� o r6 �0 �� // / E a @ 0 >-o m w a)_ a) as ' Ao O- Ommm / cl) (`n/a c ti M s �"� VIII C/ ------- t. I. ..,--40 . II C) N o , LC) a — , � V v 1,7 v i !IT 1 N o op 13 0 `r; o a) co J J J J y N "p U)2 (O �CV� WWWW 2 � 0 C =)� M 0 O) (mil V0d COOZD CO �N O to �� �N (0 C n co co co co 0� x Qr` N�M` Eh E, N r V c00 Om fRIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-15 2K-15L1-01 Plan: 2K-15L1-01_wp01 Standard Planning Report 18 February, 2015 Vail ; BAKER HUGHES ORIGINAL .-- Fa.- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2K-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-15 @ 154.00usft(2K-15) Site: Kuparuk 2K Pad North Reference: True Well: 2K-15 Survey Calculation Method: Minimum Curvature Wellbore: 2K-15L1-01 Design: 2K-15L1-01_wp01 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-15 Well Position +N/-S 0.00 usft Northing: 5,938,185.12 usft Latitude: 70°14'32.437 N +E/-W 0.00 usft Easting: 498,310.16 usft Longitude: 150°0'49.131 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2K-15L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 4/1/2015 18.78 80.83 57,550 Design 2K-15L1-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,025.00 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 135.31 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (0) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 8,025.00 93.59 104.18 6,086.45 -1,331.36 4,206.25 0.00 0.00 0.00 0.00 8,095.00 97.08 117.80 6,079.91 -1,356.24 4,271.16 20.00 4.99 19.46 75.00 8,165.00 97.35 131.91 6,071.08 -1,395.82 4,328.00 20.00 0.39 20.16 88.00 8,265.00 89.92 150.53 6,064.68 -1,473.27 4,390.14 20.00 -7.43 18.62 111.00 9,165.00 89.97 213.53 6,065.64 -2,328.07 4,359.84 7.00 0.00 7.00 90.00 9,365.00 89.97 199.53 6,065.75 -2,506.57 4,270.73 7.00 0.00 -7.00 270.00 9,665.00 89.00 178.55 6,068.48 -2,801.17 4,223.85 7.00 -0.32 -6.99 267.30 10,065.00 89.12 206.55 6,075.18 -3,187.68 4,137.78 7.00 0.03 7.00 90.00 10,465.00 89.36 178.55 6,080.59 -3,574.21 4,051.71 7.00 0.06 -7.00 270.30 10,900.00 89.45 209.00 6,085.20 -3,991.71 3,949.32 7.00 0.02 7.00 90.00 2/18/2015 4:19:05PM Page 2 COMPASS 5000.1 Build 61 ORIGINAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2K-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-15 @ 154.00usft(2K-15) Site: Kuparuk 2K Pad North Reference: True Well: 2K-15 Survey Calculation Method: Minimum Curvature Wellbore: 2K-15L1-01 Design: 2K-15L1-01_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (o) (0) (usft) (usft) (usft) (usft) (°7100ft) (0) (usft) (usft) 8,025.00 93.59 104.18 6,086.45 -1,331.36 4,206.25 3,904.77 0.00 0.00 5,936,852.95 502,515.69 TIP/KOP 8,095.00 97.08 117.80 6,079.91 -1,356.24 4,271.16 3,968.12 20.00 75.00 5,936,828.06 502,580.59 Start 20 dls 8,100.00 97.11 118.81 6,079.29 -1,358.59 4,275.53 3,972.86 20.00 88.00 5,936,825.70 502,584.96 8,165.00 97.35 131.91 6,071.08 -1,395.82 4,328.00 4,036.23 20.00 88.12 5,936,788.47 502,637.42 3 8,200.00 94.80 138.47 6,067.37 -1,420.50 4,352.51 4,071.01 20.00 111.00 5,936,763.78 502,661.92 8,265.00 89.92 150.53 6,064.68 -1,473.27 4,390.14 4,134.98 20.00 111.69 5,936,711.02 502,699.53 End 20 dls,Start 7 dls 8,300.00 89.92 152.98 6,064.72 -1,504.10 4,406.70 4,168.55 7.00 90.00 5,936,680.19 502,716.08 8,400.00 89.93 159.98 6,064.85 -1,595.73 4,446.58 4,261.74 7.00 90.00 5,936,588.55 502,755.94 8,500.00 89.93 166.98 6,064.98 -1,691.54 4,475.00 4,349.84 7.00 89.99 5,936,492.74 502,784.33 8,600.00 89.93 173.98 6,065.11 -1,790.10 4,491.53 4,431.53 7.00 89.98 5,936,394.19 502,800.84 8,700.00 89.94 180.98 6,065.22 -1,889.95 4,495.92 4,505.59 7.00 89.97 5,936,294.35 502,805.21 8,800.00 89.94 187.98 6,065.33 -1,989.58 4,488.11 4,570.93 7.00 89.96 5,936,194.73 502,797.38 8,900.00 89.95 194.98 6,065.43 -2,087.52 4,468.22 4,626.56 7.00 89.95 5,936,096.81 502,777.47 9,000.00 89.95 201.98 6,065.52 -2,182.30 4,436.55 4,671.66 7.00 89.95 5,936,002.04 502,745.77 9,100.00 89.96 208.98 6,065.59 -2,272.52 4,393.55 4,705.55 7.00 89.94 5,935,911.84 502,702.76 9,165.00 89.97 213.53 6,065.64 -2,328.07 4,359.84 4,721.33 7.00 89.94 5,935,856.31 502,669.04 5 9,200.00 89.97 211.08 6,065.66 -2,357.65 4,341.13 4,729.20 7.00 -90.00 5,935,826.73 502,650.33 9,300.00 89.97 204.08 6,065.72 -2,446.23 4,294.86 4,759.63 7.00 -90.00 5,935,738.17 502,604.05 9,365.00 89.97 199.53 6,065.75 -2,506.57 4,270.73 4,785.54 7.00 -89.99 5,935,677.85 502,579.90 6 9,400.00 89.85 197.08 6,065.81 -2,539.79 4,259.73 4,801.43 7.00 -92.70 5,935,644.63 502,568.90 9,500.00 89.52 190.09 6,066.36 -2,636.93 4,236.26 4,853.97 7.00 -92.70 5,935,547.50 502,545.40 9,600.00 89.20 183.10 6,067.47 -2,736.20 4,224.78 4,916.47 7.00 -92.66 5,935,448.24 502,533.90 9,665.00 89.00 178.55 6,068.48 -2,801.17 4,223.85 4,962.00 7.00 -92.58 5,935,383.28 502,532.96 7 9,700.00 89.00 181.00 6,069.09 -2,836.16 4,223.98 4,986.97 7.00 90.00 5,935,348.29 502,533.08 9,800.00 89.02 188.00 6,070.83 -2,935.78 4,216.14 5,052.26 7.00 89.96 5,935,248.69 502,525.22 9,900.00 89.04 195.00 6,072.52 -3,033.69 4,196.21 5,107.85 7.00 89.84 5,935,150.79 502,505.27 10,000.00 89.08 202.00 6,074.16 -3,128.45 4,164.50 5,152.91 7.00 89.72 5,935,056.05 502,473.54 10,065.00 89.12 206.55 6,075.18 -3,187.68 4,137.78 5,176.22 7.00 89.60 5,934,996.83 502,446.81 8 10,100.00 89.13 204.10 6,075.71 -3,219.31 4,122.81 5,188.18 7.00 -89.70 5,934,965.21 502,431.84 10,200.00 89.18 197.10 6,077.19 -3,312.84 4,087.65 5,229.94 7.00 -89.66 5,934,871.69 502,396.65 10,300.00 89.24 190.10 6,078.57 -3,409.97 4,064.14 5,282.45 7.00 -89.56 5,934,774.58 502,373.13 10,400.00 89.31 183.10 6,079.84 -3,509.23 4,052.65 5,344.93 7.00 -89.46 5,934,675.33 502,361.62 10,465.00 89.36 178.55 6,080.59 -3,574.21 4,051.71 5,390.46 7.00 -89.37 5,934,610.36 502,360.67 9 10,500.00 89.36 181.00 6,080.98 -3,609.20 4,051.85 5,415.43 7.00 90.00 5,934,575.37 502,360.79 10,600.00 89.37 188.00 6,082.08 -3,708.82 4,044.00 5,480.73 7.00 89.97 5,934,475.76 502,352.92 10,700.00 89.39 195.00 6,083.17 -3,806.75 4,024.07 5,536.33 7.00 89.90 5,934,377.85 502,332.97 10,800.00 89.42 202.00 6,084.21 -3,901.51 3,992.35 5,581.39 7.00 89.82 5,934,283.10 502,301.24 10,900.00 89.45 209.00 6,085.20 -3,991.71 3,949.32 5,615.24 7.00 89.75 5,934,192.92 502,258.19 Planned TD at 10900.00 2/18/2015 4:19:05PM Page 3 COMPASS 5000.1 Build 61 ORG1NAL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2K-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-15 @ 154.00usft(2K-15) Site: Kuparuk 2K Pad North Reference: True Well: 2K-15 Survey Calculation Method: Minimum Curvature Wellbore: 2K-15L1-01 Design: 2K-15L1-01_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2K-15 CTD Polygon Sot 0.00 0.00 0.00 -1,365.641,144,844.66 5,936,563.00 1,643,040.00 70°0'10.155 N 140°50'41.087 W -plan misses target center by 1140364.99usft at 8700.00usft MD(6065.22 TVD,-1889.95 N,4495.92 E) -Polygon Point 1 0.00 0.00 0.00 5,936,563.00 1,643,040.00 Point2 0.00 -1,257.15 -88.66 5,935,306.00 1,642,951.07 Point3 0.00 -2,968.50 -721.26 5,933,594.96 1,642,318.15 Point4 0.00 -2,847.59 -1,110.33 5,933,715.94 1,641,929.14 Point5 0.00 -1,217.36 -850.75 5,935,345.95 1,642,189.06 Point6 0.00 104.81 -722.10 5,936,667.96 1,642,318.00 Point 7 0.00 0.00 0.00 5,936,563.00 1,643,040.00 2K-15 CTD Polygon Nor 0.00 0.00 0.00 1,034.071,142,451.88 5,938,963.00 1,640,648.00 70°0'36.977 N 140°51'38.665 W -plan misses target center by 1137975.88usft at 8700.O0usft MD(6065.22 TVD,-1889.95 N,4495.92 E) -Polygon Point 1 0.00 0.00 0.00 5,938,963.00 1,640,648.00 Point2 0.00 349.14 364.94 5,939,312.02 1,641,012.98 Point3 0.00 -1,434.61 1,930.59 5,937,528.10 1,642,578.08 Point4 0.00 -2,399.58 2,392.90 5,936,563.12 1,643,040.12 Point5 0.00 -2,294.77 1,670.80 5,936,668.09 1,642,318.12 Point 6 0.00 0.00 0.00 5,938,963.00 1,640,648.00 2K-15L1-01_T03 0.00 0.00 6,070.00 -2,910.901,144,364.95 5,935,018.00 1,642,560.00 69°59'55.857 N 140°51'1.342 W -plan misses target center by 1139869.49usft at 8700.00usft MD(6065.22 TVD,-1889.95 N,4495.92 E) -Point 2K-15L1_Fault2 0.00 0.00 0.00 -246.741,143,881.31 5,937,682.00 1,642,077.00 70°0'22.437 N 140°51'3.606 W -plan misses target center by 1139402.72usft at 8700.00usft MD(6065.22 TVD,-1889.95 N,4495.92 E) -Rectangle(sides W685.00 H1.00 D0.00) 2K-15L1_Fault3 0.00 0.00 0.00 -2,910.901,144,364.95 5,935,018.00 1,642,560.00 69°59'55.857 N 140°51'1.342 W -plan misses target center by 1139885.63usft at 8700.00usft MD(6065.22 TVD,-1889.95 N,4495.92 E) -Rectangle(sides W695.00 H1.00 D0.00) 2K-15L1-01_T04 0.00 0.00 6,085.00 -3,986.071,144,096.17 5,933,943.00 1,642,291.00 69°59'45.813 N 140°51'13.587 W -plan misses target center by 1139602.18usft at 8700.00usft MD(6065.22 TVD,-1889.95 N,4495.92 E) -Point 2K-15L1-01_T01 0.00 0.00 6,086.00 -1,325.741,144,352.60 5,936,603.00 1,642,548.00 70°0'11.267 N 140°50'54.875 W -plan misses target center by 1139856.82usft at 8700.00usft MD(6065.22 TVD,-1889.95 N,4495.92 E) -Point 2K-15L1-01_T02 0.00 0.00 6,065.00 -1,454.721,144,529.64 5,936,474.00 1,642,725.00 70°0'9.754 N 140°50'50.407 W -plan misses target center by 1140033.81 usft at 8700.O0usft MD(6065.22 TVD,-1889.95 N,4495.92 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,900.00 6,085.20 2-3/8" 2.375 3.000 2/18/2015 4:19:05PM sP g COMPASS 5000.1 Build 61 iN. AL ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 2K-15 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-15 @ 154.00usft(2K-15) Site: Kuparuk 2K Pad North Reference: True Well: 2K-15 Survey Calculation Method: Minimum Curvature Wellbore: 2K-15L1-01 Design: 2K-15L1-01_wp01 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,025.00 6,086.45 -1,331.36 4,206.25 TIP/KOP 8,095.00 6,079.91 -1,356.24 4,271.16 Start 20 dls 8,165.00 6,071.08 -1,395.82 4,328.00 3 8,265.00 6,064.68 -1,473.27 4,390.14 End 20 dls,Start 7 dls 9,165.00 6,065.64 -2,328.07 4,359.84 5 9,365.00 6,065.75 -2,506.57 4,270.73 6 9,665.00 6,068.48 -2,801.17 4,223.85 7 10,065.00 6,075.18 -3,187.68 4,137.78 8 10,465.00 6,080.59 -3,574.21 4,051.71 9 10,900.00 6,085.20 -3,991.71 3,949.32 Planned TD at 10900.00 2/18/2015 4:19:05PMORGU\ AL Page 5 COMPASS 5000.1 Build 61 v.- Baker Hughes INTEQ r�� ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-15 Project: Kuparuk River Unit TVD Reference: 2K-15 @ 154.00usft(2K-15) Reference Site: Kuparuk 2K Pad MD Reference: 2K-15 @ 154.00usft(2K-15) Site Error: 0.00usft North Reference: True Reference Well: 2K-15 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 2K-15L1-01 Database: OAKEDMP2 Reference Design: 2K-15L1-01_wp01 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 2K Pad 2K-14-2K-14A-2K-14A Out of range 2K-15-2K-15-2K-15 8,025.00 8,075.00 82.20 11.10 71.72 Pass-Major Risk 2K-15-2K-15L1-2K-15L1_wp02 8,025.00 8,025.00 0.00 0.35 -0.22 FAIL-Major Risk 2K-15-2K-15L1-02-2K-15L1-02_wp01 8,274.98 8,275.00 0.63 0.52 0.27 Pass-Minor 1/10 2K-16-2K-16-2K-16 Out of range 2K-17-2K-17-2K-17 10,714.10 8,800.00 85.33 5.77 85.11 Pass-Minor 1/10 2K-18-2K-18-2K-18 Out of range 2K-19-2K-19-2K-19 Out of range 2K-19-2K-19A-2K-19A Out of range 2K-19-2K-19AL1-2K-19AL1 Out of range 2K-20-2K-20-2K-20 Out of range 2K-21-2K-21-2K-21 Out of range 2K-21-2K-21A-2K-21A Out of range 2K-22-2K-22-2K-22 Out of range 2K-22-2K-22A-2K-22A Out of range 2K-22-2K-22AL1-2K-22AL1 Out of range 2K-22-2K-22AL1-01-2K-22AL1-01 Out of range 2K-23-2K-23-2K-23 Out of range 2K-24-2K-24-2K-24 Out of range 2K-25-2K-25-2K-25 Out of range 2K-26-2K-26-2K-26 Out of range 2K-28-2K-28-2K-28 Out of range 2K-28-2K-28A-2K-28A Out of range 2K-28-2K-28AL1-2K-28AL1 Out of range 2K-28-2K-28AL1 PB1-2K-28AL1 PB1 Out of range 2K-28-2K-28AL1 PB2-2K-28AL1 PB2 Out of range 2K-28-2K-28APB1-2K-28APB1 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/18/2015 1:34:51PM Page 3 of 11 COMPASS 5000.1 Budd 65 0 O M ^ N r u 6 1�1 ,N �+ u G r 1111 a` 4 I- 8 ? `cv`\ 8 4 - - ` ) N 8 N g n a S _ ' e = h gg - .* s.4 ° .o o� -a r gi �i= N 1 �� 11 M o LL I hZ; N = /I .8 + z n g Mil 1 8//I , Nn _H N - q N h .O .N i -- - MaN. r 1h N to C O C N n J r V • n UO N• Y ON cc cc kr) N CO ,. 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IV O \ 0 0 0 0 0 0 0 0 0 0 0 h S • 0 0 0 0 0 0 0 0 0 0 N N O H vl O - o CC G Co Co Co Co Co Co Co O r CO yy 0 r N 00 oN OMCo00 VO 0) c0 h „ b Co b b b U) U COCCooCoo)C0)000 C3 m O 1 O U,_N M cr Co 00 Co o 6 co (uvusn SS)y1dau reaivan anal ti Bettis, Patricia K (DOA) From: Burke,Jason <Jason.Burke@conocophillips.com> Sent: Monday, March 02, 2015 1:10 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]FW: KRU 2K-15 Laterals: Permit to Drill Applications Yes, sorry Patricia, we've been discussing new ways to present this and my supervisor was out last week.The weight will be 12.8 ppg. Sorry for the delay. Jason Sent with Good (www.good.com) From: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Sent: Monday, March 02, 2015 4:03:41 PM To: Burke,Jason Subject: [EXTERNAL]FW: KRU 2K-15 Laterals: Permit to Drill Applications Jason, Did you received this email? Thanks, Patricia From: Bettis, Patricia K (DOA) Sent:Tuesday, February 24, 2015 4:02 PM To: Burke,Jason (Jason.Burke@conocophillips.com) Subject: KRU 2K-15 Laterals: Permit to Drill Applications Good afternoon Jason, On page 3 of the Application for Permit to Drill Document, it is stated that two wellbores of kill weight fluid will be stored at a central location in the Kuparuk Field and accessible. What is the weight of the KWF that will be available? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 1 s CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907) 793- 1238 or patricia.bettis@alaska.gov<mailto:patricia.bettis a(�alaska.gov>. 2 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, February 24, 2015 4:02 PM To: Burke, Jason (Jason.Burke@conocophillips.com) Subject: KRU 2K-15 Laterals: Permit to Drill Applications Good afternoon Jason, On page 3 of the Application for Permit to Drill Document, it is stated that two wellbores of kill weight fluid will be stored at a central location in the Kuparuk Field and accessible. What is the weight of the KWF that will be available? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 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. TRANSMITTAL LETTER CHECKLIST WELL NAME: Q02K 15 L I -O ( PTD: 02/5- 637 /Development _Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: K ,..3k POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. /89-089 , API No. 50-103 - aO/13 -C - OO. (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( 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 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception 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 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. 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