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215-172
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E a 2w w WWWUJ 3 3 0 00 0 0 W 0 0 • o o N 9 3 N N O O '.a r Z <3 N d) U_ T N .� mt o 6 CO O z ca 0 H g co ce < O U) ` a ci CL J J W = IX a 0 0 W 0 z J V 0• o Z 8 Qco J o. w O. 0 c � � o O N N a Nr E M V M N U o M J m Q M O tha Q G Z N CO 1 CO z .11111. 11 • a> ii Q a H • 6 Q c a Z E o G 733 0 co Z 1 al 3 o . >, Nm N a 1 a) D 3 Na) ai cG w a) CO U O. C7 21 5172 21 5168 21 51 21 5170 215171 RECEIVE 2 6 6 4 9 16 6 5 U 2 6651 16652 NMI JAN 13 2016 BAKER PRINT DISTRIBUTION LIST HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska,Inc. Ricky Elgarico.ATO 3-334. DATA LOGGED WELL NAME 3A-03BL1•BL1-01• BL1-02; BL2;BL2-01 700 G Street. K.2-/2./201GB DER , , .i K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE December 6,2015 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(ct�bakerhughes.com TODAYS DATE January 11,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS f FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #01-PKIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope I 0 0 0 EOA,PBOC,PRB-20(Office 109) Ir D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 0 0 I 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 1 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 • • C4p() N. ID .1--4.0 LI") ko 1ma e-- 7.4 CNI allZ ala 0 IMO g 2 ei g z > ZZI 0 Ili Cf? 0 = iiial ---) Cir 0 Uall .no ) CN > - 0 a . LLI - . 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CO CCi 2 3- 22 too 2 — 2 2 C. 2, .2., 2 CCC 2 2 C .‘, ''' P 9 e .: e; •,', ,-, H. '.,,,.., ,', .,, ',.,., ‘!. - , -, 7 7 ' + 2 2 2 2 2 2 -"- -2 •,s, 2 2 In CC) CCC J, r=> v t., ,, u, C, CO V '' ' ", C. C. '''.. 't O 0' " ' ' 'C C- C Q, , ,C, CO CD CCC CCC ,,,, CCC ,„,) "C a .Y., OC' l, 'A 'A, ''''' Y', !-2. ',2., ,: '' ''' C CCC CC) CC.CCC.0 CCC CCC CCC C)) CCC CCC '1 ,„„„, 'Ji. < 2 li 2 E ,4 22, — 2 f 0 OM am. 0 ,?,3 Es 2 `9 `) 2 a a ..... 0 -7 4 ,:i CC C ',:...- o.,, cr.) 'C . C", CC) C) al a; CCC C 2.:›, ,2 ,. , g E .2 A 2 . ,. . 2 2 2 2 ,, ,. 2-• LC) ,--. ,,,, , c,.. ,y, .C1 C) 0) ,,,,, C) = C.i t...„,... co • t ir • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20/MC 25.110 Development ❑ • Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No. of Completions: t Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 12/6/2015 i 215-172 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 12/4/2015 50-029-21432-64-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 527 FSL, 749 FEL, Sec 7,T12N, R9E, UM 12/5/2015 o KRU 3A-03BL2-01 Top of Productive Interval: 9. Ref Elevations: KB: 69 17. Field/Pool(s): 4100 FNL,654 FEL,Sec. 18,T12N, R09E, UM GL: 41 BF:43 Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3343 FNL, 1262 FEL, Sec 18,T12N, RO9E, UM n/a ADL 25631,25632 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 507699 y- 5996908 Zone-4 9602/6119 2564,2565 TPI: x- 507816 y- 5992282 Zone-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 507204 y- 5993037 Zone-4 2265/2013 1550/1550 5. Directional or Inclination Survey: Yes 0 (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) 8448/6158 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 RECEIVED JAN 0 6 2016 23. CASING, LINER AND CEMENTING RECORD '"10c 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 31 106 31 106 18 187sx AS II 9 5/8 36 J-55 31 3888 31 3097 11.625 1200 sx AS III, 320sx CI G 7 26 J-55 24 4250 24 3329 9 425 sx CI G,250 sx CI G 5 1/2 15.5 L-80 3913 8285 3113 6444 7.5 79sx LiteCRETE, 125 sx Class G w/GasBLOK 2 3/8 4.6 L-80 7854 9600 6065 6118 3 Slotted Liner 24. Open to production or injection? Yes 0 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 7723 3912/3113 Slotted Liner from 7854-9600=MD,6065-6118=TVD 7661//5900 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. COMPLETION Was hydraulic fracturing used during completion? Yes❑ No 2 DAT Per 20 AAC 25.283(i)(2)attach electronic and printed information `� DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED LL 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift, etc.): 12/17/2015 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 12/21/2015 16hrs 9mins Test Period -0-477 BO 346 291 136 725 scf/STB Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 145psi 1017 24-Hour Rate -► 709 514 432 n/a Form 10-407 Revised 11/2015 V'TL J/ -(p //0 CONTINUE O PAGE 2 RBDMS (.L, JAN 2 2 2016 Submit ORIGINIAL only • • 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No RI Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1550 1550 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 7921 6121 information, including reports, per 20 AAC 25.071. Total Depth"AjSannd) 9602 6119 kliiglIC Formation at total depth: A Sand 31. List of Attachments: Operations Summary, Definitive Survey,Schematics Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclinatio rvey,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. vi 4/4. Contact: Keith Herring @ 263-4321 Email: Keith.E.Herring@cop.com Printed Name: D.Venhaus Title: CTD Engineer Supervisor Signature: ,...- - Phone: 263-4372 Date: I Iv /`f 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 la: 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,Ground Level,and Base Flange 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 11/2015 Submit ORIGINAL Only KUP PROD • 3A-03B CC}t"lC1c PhiIIips5 ,, Well Attributes Max Angle&MD TD �k Wellbore API/UWI Field NamOMB)Wellbore Status ncl(') MD KB) Act Btm(ftKB) Alaska,Inc. con,,,,,,,,,,,,, 500292143202 KUPARUK RIVER UNIT PROD 54.38 4,161.12 9,735.0 .-. Comment H25(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 3A-0313,1/6/2016t0:0633 AM SSSV:TRDP 130 3/10/2014 Last WO: 2/14/2008_ 35.29 9/16/1985 Veneta schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,134.0 8/16/2014 Rev Reason:ADD LATERALS lehallf 12/30/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 106.0 106.0 62.50 H-40 WELDED -----' """ ------ ------- ""'-'Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(ND)...WtlLen(L..Grade Top Thread HANGER;24.2 a,� I SURFACE 9 5/8 8.921 30.6 3,888.1 3,096.7 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread IIIWINDOW B 8 7.000 4,107.0 4,117.0 3,249.1 26.00 J-55 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I PRODUCTION POST 7 6.276 24.0 4,250.0 3,329.4 26.00 J-55 BTC t : I I S/T B 1I. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1. B LINER 5 1/2 4.950 3,912.9 8,285.0 6,443.9 15.50 L-80 Hyd 511 auv Liner Details Nominal ID CONDUCTOR;31.0106.0-1 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 3,912.9 3,113.0 48.66 PACKER BAKER LINER TOP PACKER 5.500 III 3,923.7 3,120.2 48.66 HANGER HMC LINER HANGER 4.960 SAFETY VLV;2,265.4 p I i Tubing Strings al Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 24.2 7,723.7 5,953.3 9.30 L-80 IBTM ill Completion Details Nominal ID GAS LIFT;3,056.8 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 24.2 24.2 0.00 HANGER FNC GEN IV TUBING HANGER 3.500 2,265.4 2,013.5 46.88 SAFETY VLV CAMCO TRMAXX-5E SAFETY VALVE W/2.812"X 2.812 PROFILE 7,645.6 5,887.0 32.74 LOCATOR LOCATOR 3.000 SURFACE;306-3,888.1-. 7,646.4 5,887.7 32.73 PBR BAKER 80-40 PBR 3.000 7,660.0 5,899.2 32.49 ANCHOR BAKER KBH-22 ANCHOR 2.970 7,660.7 5,899.8 32.48 PACKER BAKER SABL-3 PRODUCTION PACKER 2.760 7,664.9 5,903.3 32.40 XO BUSHING BAKER CROSSOVER BUSHING 2.970 7,715.5 5,942.0 31.63 NIPPLE HALLIBURTON X NIPPLE 2.750 7,723.2 5,952.9 31.41 WLEG WIRELINE ENTRY GUIDE 2.750 WINDOW B;4,107.0.4,117.0 PRODUCTION POST Sri B•; Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 24.0.4,250.0 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date 10(in) GAS LIFT;4,818.3 r, 7,860.0 6,070.7 29.80 WHIPSTOCK Baker Gen 112 5/8 X 5 1/2 11/30/2015 1.000 .,� -THRU TBG iI 7,890.0 6,096.8 29.30 WHIPSTOCK BAKER GEN II 10/4/2015 R Perforations&Slots GAS LIFT;6,122.2 Tr Shot MDens IN Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn II 7,930.0 7,975.0 6,131.8 6,171.4 A-1,3A-03B 5/21/2008 6.0 APERF 2.6"PJ,60 deg phase GAS LIFT;7,112.2 7,975.0 7,995.0 6,171.4 6,189.0 A-2,3A-03B 12/24/2007 6.0 IPERF 2.5"HJ,60 deg random II Stimulations&Treatments N Min Top Max Btm GAS LIFT;7,596.4 i. Depth Depth Top(ND) Btm(ND) El (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 7,975.0 7,995.0 6,171.4 6,189.0 A-SAND FRAC 12/28/200 PUMPED 292,767#OF 16/20 CARBOLITE SAND in 7 in Mandrel Inserts LOCATOR;7,645.6 St PER;7,646.4 I t ati ANCHOR;7E60.0 N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Scm Type Type (in) (psi) Run Date Com PACKER;7,660.7 1� 3,056.8 2,546.5 CAMCO KBG-2- 1 GAS LIFT GLV INT 0.156 1,331.0 12/16/2015 4:00 XO BUSHING;7,664.9 9 2 4,818.3 3,693.9 CAMCO KBG-2- 1 GAS LIFT GLV INT 0.188 1,335.0 12/16/2015 2:00 9 3 6,122.2 4,698.5 CAMCO KBG-2- 1 GAS LIFT OV INT 0.250 0.0 12176/2015 (1:30 9 NIPPLE;7,710.5 4 7,112.2 5,465.0 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 8/23/2015 11:00 9 5 7,596.4 5,845.9 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 8/24/2015 12:00 WLEG;7,723.2 9 Notes:General&Safety End Date Annotation 12/17/2000 NOTE:WELL SIDETRACKED TO'A' WHIPSTOCK-THRUTBG; 11/14/2007 NOTE:WELL SIDETRACKED TO'B',TUBING PULLED FOR SIDETRACK 7,860.0 4/6/2008 NOTE:IA TEST PRESSRE DOWNRATED DUE TO LINER TOP PACKER @ 3898' 1 i1aa= 3/8/2011 NOTE:View Schematic w/Alaska Schematic9.0 10/4/2015 NOTE:RA Tags at 7897' WHIPSTOCK;7,890.0 X11 r SLOTS;7,806.0.9,0290, r"-...,APERF;7,930.0.7,975.D\ , :4.- IPERF;7,975.0-7,995 0 A-SAND FRAC;7,975.0 LINER L1-02;7,886.4-9,031.0 SLOTS;7,854.0.9,583.0 4 am. -aha i'.- 13 LINER;3,912.98,285.01 LINER 8L2-01;7,854.0-9,600.0 111 KUP PROD • 3A-03BL2-01 o Cono c©Phillips Well Attributes Max Angle&MD TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Status incl(3 MD(ftKB) Act Btm(ftKB) Canocaitinfir 500292143264 KUPARUK RIVER UNIT PROD 101.85 8,540.39 9,602.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-03BL2-01,1/6/2016 10:16.59 AM SSSV:TRDP 130 3/10/2014 Last WO 35.29 9/16/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason ADD LATERALS lehallf 12/30/2015 Casing Strings Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER BL2-01 23/8 1.992 7,854.0 9,600.0 6,118.3 4.60 L-80 ST-L Liner Details HANGER:242 /11 . Nominal ID Top(ftKB) Top(ND)(ftKB)_Top Incl(°) Item Des Com (in) 7,854.0 6,065.5 29.86 SLEEVE Shorty Deployment Sleeve 1.000 i Ii Perforations&Slots II J Do�_ ia:.I. Top(TVD) Btm(ND) Dens Top(ftKB) Btm(ORB) (ftKB) (ftKB) Zone Date t) Type Com 11f4,i. 7,854.0 9,583.0 6,065.5 6,116.3 A-3,3A- 12/6/2015 SLOTS SLOTTED LINER CONDUCTOR;31.0-106.0 03BL2-01 Notes:General&Safety End Date Annotation SAFETY VLV;2,265.4 P,.' '. NOTE: 4 se 117 GAS LIFT,3056.8 SURFACE;30 6-3,888.1 • WINDOW S;4,107.0-4,117.0 PRODUCTION POST S/f'B'; 24.0-4,250.0 GAS LIFT;4,818.3 II GAS LIFT;6,122.2 fr GAS LIFT;7,112.2 II GAS LIFT;7,596.4 a II JE LOCATOR;7,645.6 PBR,7,646.4 1.;. >.;.t ANCHOR;7,660.0 I. PACKER,7,660.7— X0 BUSHING;7,664.9 - II 4 NIPPLE;7,710.5 1a 4.4 11 4 WLEG;7,723.2 WHIPSTOCK-THR7 TBG; 7,8600 is I WHIPSTOCK;7,860.0 SLOTS;7,886.0-9,029.0 APERF;7,930.0-7,975.04 (PERF,7,9720-7,9950 4 • A-SAND FRAC;7,975.0 'moi ' LINER L1-02,7,886.4-9,037.0 I B LINER;3,912.9-8,2850�e SLOTS;7,854.09,583.0 qtr irLINER BL2-01;7,854.05,600.0 ! • 3A-03B CTD Final Schematic Modified by KH 12-os->5 nEme 3-1/2"Camco TRMAXX-5E SCSSV at 2265 MD (2.812'X-profile) 16"62.5#H-40 at 106'MD 3-1/2"9.2#L-80 IBT-Mod 0-7723'MD 3-1/2"Camco KBG2-9 gas lift mandrels at 3057,4818',6122', 9-5/8"36#J-55 @ 7112',8 7596'(min ID=2.900"for alt GLMs) 3888'MD 5-1/2"Linertoo Baker CPH liner top packer at 3913'MD 1Baker HMC liner hanger at 3924'MD L r 26#J-55 Baker 80-40 PBR(12'length with 4"ID seal bore)at 7646'RKB(7641' window @ 4107' PDC) MD Baker KBH-22 Anchor at 7660' Baker SABL-3 Packer at 7661'(ID=2.76) 3-1/2"X-nipple at 7711'RKB(7706'PDC)(2.75"min ID) 'W Wireline re-entry guide at 7723'RKB(7718'PDC) 3A-03BL1-02,TD=9051'MD Whipstock @ 2-3/8"slotted liner with deployment sleeve 3A-03BL2-01,TO=9602'MD ,' 7860'MD TOL=7886'MD,BOL-9031'MD 2-3/8"slotted liner with deployment sleeve r "� TOL8=7854'MD,BOL=9600'MD j,/ 3A-038L1-01,TD=10250'MD / �„.i-. __ 2 3/6 slotted liner with billet i +, I* TOL 7999 MD BOL 10250'MD V�r�.f."....-"'r " hipstock(� �' +1�"rr.�" 'r• 7r•,w` ..�.,' ' ..1+: 7890'MD .n�„• '*"" '''''''''S''.''''''' -_-:....---a ..___:-_—_-.-74.---= '''7''''7'''''''•',':.7%4,' ' rig!'-'.!!;!;1::::11:01 ' 3A-03BL2,TD=9614'MD A-sand perfs 7930' -- -- ^" •'""� 2-3/8"slotted liner with anchored billet -7995'MD 3A-03BL1,TD=10241'MD TOL=8448'MD,BOL=9613'MD 2-3/8"slotted liner with billet 5-1/2"15.5#L-80 T2-03L/8." OL=8682'MD,BOL=10241'MD shoe @ 8285'MD • 0 Operations Summary (with Timelog Depths) 12 011 3A-03 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/19/2015 11/19/2015 3.00 MIRU MOVE RURD P Prep for rig move to 3A-Pad.Load and 0.0 0.0 18:00 21:00 secure tree,check all tree flange bolts, found four bolt loose,took 1.25 HRS. 11/19/2015 11/20/2015 3.00 MIRU MOVE RURD P Complete RD checklist.Prep shop for 0.0 0.0 21:00 00:00 move.Prep for sow arrival at midnight. 11/20/2015 11/20/2015 5.00 MIRU MOVE MOB P PJSM.Peak and rig crew,Pull rig 0.0 0.0 00:00 05:00 modules off of 2E-15,install jeeps, ready for move. 11/20/2015 11/20/2015 5.50 MIRU MOVE MOB P Move rig modules and shop to 3A-Pad 0.0 0.0 05:00 10:30 11/20/2015 11/20/2015 3.00 MIRU MOVE MOB P Remove jeeps,release Peak,LD 0.0 0.0 10:30 13:30 herculite,spot rig modules over 3A-03. 11/20/2015 11/20/2015 3.50 MIRU MOVE RURD P MIRU CDR2, RU checklist,check tree 0.0 0.0 13:30 17:00 flange bolts,casing head tree flange bolts were all loose,45 mins to tighten.Work on tree alignment, change rotary table drip pan.MU MP and cellar lines. 11/20/2015 11/20/2015 1.00 MIRU WHDBOP NUND P PJSM.NU BOP stack. 0.0 0.0 17:00 18:00 Rig Accept:17:00 HRS on 11/20/15 11/20/2015 11/20/2015 2.00 MIRU WHDBOP RURD P Re-check torque on tree bolts. Install 0.0 0.0 18:00 20:00 BHI UQC.Circulate and load surface lines.Shell test BOP stack to 4,300 psi. 11/20/2015 11/21/2015 4.00 MIRU WHDBOP BOPE P Start initial BOP test 250/4100 psi, 0.0 0.0 20:00 00:00 annular 2,500 psi.Test witnessed by AOGCC(Johnny Hill). 11/21/2015 11/21/2015 3.00 MIRU WHDBOP BOPE P Start initial BOP test 250/4100 psi, 0.0 0.0 00:00 03:00 annular 2,500 psi.Test witnessed by AOGCC(Johnny Hill). 11/21/2015 11/21/2015 0.50 MIRU WHDBOP RURD P LD BOP test equipment. 0.0 0.0 03:00 03:30 11/21/2015 11/21/2015 3.15 MIRU WHDBOP PRTS P Load coil,Test and Chart,shell test, 0.0 03:30 06:39 inner reel valve and stripper, install BHI checks into the upper quick,P/T UQC 4,000 psi. 11/21/2015 11/21/2015 1.50 MIRU WHDBOP PRTS P PJSM,test PDL's and tiger tank line, 0.0 0.0 06:39 08:09 11/21/2015 11/21/2015 2.00 MIRU WHDBOP MPSP P PJSM,RU FMC equipment,P/T,pull 0.0 0.0 08:09 10:09 BPV,945 psi WHP,LD FMC equipment. 11/21/2015 11/21/2015 0.50 PROD1 WHPST SFTY P Prespud with crew and third party. 0.0 0.0 10:09 10:39 11/21/2015 11/21/2015 0.85 PROD1 WHPST PRTS P PJSM-Pressure test replaced valve 0.0 0.0 10:39 11:30 C14,blow down TT lines,valve check list. 11/21/2015 11/21/2015 2.20 PROD1 WHPST PULD P PJSM-Load and pressure deploy 0.0 63.7 11:30 13:42 BHA#1,straight motor with 2.74" window mill,string reamer,MU to CoilTrak,surface test. 11/21/2015 11/21/2015 0.30 PROD1 WHPST TRIP P RIH with BHA#1,lost tool 63.7 875.0 13:42 14:00 communication,check surface lines, good. 11/21/2015 11/21/2015 0.50 PROD1 WHPST TRIP T POOH to troubleshoot lose of tool 875.0 63.7 14:00 14:30 communication. Page 1/15 Report Printed: 12/31/2015 • Operations Summary (with Timelog Depths) 3A-03 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/21/2015 11/21/2015 2.00 PROD1 WHPST PULD T PJSM-PUD,strip off,e-line pulled out 63.7 0.0 14:30 16:30 of head,complete un-deployment. 11/21/2015 11/21/2015 3.75 PROD1 WHPST CTOP T PJSM-Strip on,perform slack 0.0 0.0 16:30 20:15 management,cut 62 ft pipe to find e- line,rehead CC,pull test 35K,rehead UQC,meg test. 11/21/2015 11/21/2015 2.50 PROD1 WHPST PULD T PJSM.PU/MU/PD BHA#2,make 0.0 63.5 20:15 22:45 choke repair,pump slack forward. 11/21/2015 11/21/2015 0.25 PROD1 WHPST TRIP T RIH w/BHA#2 straight motor milling 63.5 875.0 22:45 23:00 assembly. Note:Off trouble time at 875', 11/21/2015 11/22/2015 1.00 PROD1 WHPST TRIP P Continue RIH w/BHA#2 straight 875.0 6,640.0 23:00 00:00 motor milling assembly, 11/22/2015 11/22/2015 1.50 PROD1 WHPST TRIP P Continue in hole w/BHA#2 straight 6,640.0 7,850.0 00:00 01:30 motor milling assembly,tie-in to K1 for -14'correction,RBIH.Start pumping used drilling mud,mud at bit. 11/22/2015 11/22/2015 1.00 PROD1 WHPST CIRC P Mud to surface,lost 25 bbls during 7,850.0 7,850.0 01:30 02:30 circulation,normal drilling parameters losing 12 bph,continue monitoring losses whille MU 11.8 ppg 100K LSRV pill. 11/22/2015 11/22/2015 2.00 PROD1 WHPST CIRC P Start pumping 10 bbl heavy pill down 7,850.0 7,896.0 02:30 04:30 coil as per email,pill at bit,squeeze to formation @.25 BPM @ 4,180 psi,let set 10 minutes,check for losses at same parameters,minimal losses. Shut down pump,RIH,dry tag WS @ 7,896'. 11/22/2015 11/22/2015 5.20 PROD1 WHPST WPST P Start milling window as per well plan: 7,895.0 7,901.2 04:30 09:42 1.53 bpm @ 3,590 psi,BHP=3,745 psi,CTW=14K,WOB-.2K. 11/22/2015 11/22/2015 2.60 PROD1 WHPST WPST P 7,900.2'appears like the mill has 7,901.2 7,915.0 09:42 12:18 exited the casing.Continue milling ahead,rathole. Note:Bled OA down from 700 psi to 200 psi. 11/22/2015 11/22/2015 1.50 PROD1 WHPST REAM P 7,915', Make slow back ream pass, 7,915.0 7,915.0 12:18 13:48 pumps off,dry drift window exit,clean, pump sweep chase with 11.8 ppg completion fluid. 11/22/2015 11/22/2015 1.55 PROD1 WHPST DISP P POOH displaceing well to 11.8 ppg 7,915.0 63.5 13:48 15:21 completion fluid. 11/22/2015 11/22/2015 0.50 PROD1 WHPST OWFF P Monitor well for flow,PJSM-LD BHA 63.5 63.5 15:21 15:51 11/22/2015 11/22/2015 1.15 PROD1 WHPST PULD P LD BHA#2,2.73"no-go both DSM 63.5 0.0 15:51 17:00 and string reamer. 11/22/2015 11/22/2015 2.00 PROD1 DRILL PULD P PJSM-MU build drilling BHA#3,2.3° 0.0 72.2 17:00 19:00 AKO motor and HCC RB Bi-center bit. Stimulate PD with PDL,several attempts to work BHA through tree were unsuccessful.Pop off,move forward,stab injector. Page 2/15 Report Printed: 12/31/2015 0 114 Operations Summary (with Timelog Depths) 3A-03 no CocoPh hf-La Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 11/22/2015 11/22/2015 3.05 PROD1 DRILL TRIP P RIH w/build section drilling assembly, 72.2 7,915.0 19:00 22:03 pumping at min.rate.Tie-in to K1 for- 14'correction,continue in hole,start circulating out 11.8 PPG for new 9.1 ppg drilling mud. 11/22/2015 11/23/2015 1.95 PROD1 DRILL DRLG P Drill ahead: 1.48 BPM @ 3,485 PSI, 7,915.0 8,036.0 22:03 00:00 BHP=3,760 PSI,CTW=11K, WOB=1.5K,ROP=85.New mud at bit 7,960'. 11/23/2015 11/23/2015 0.40 PROD1 DRILL DRLG P Drill to EOB:Drill ahead: 1.48 BPM @ 8,036.0 8,052.0 00:00 00:24 3,530 PSI,BHP=3,760 PSI, CTW=11K,WOB=2K,ROP=95. 11/23/2015 11/23/2015 1.70 PROD1 DRILL TRIP P POOH for lateral drilling assembly,jet 8,052.0 62.5 00:24 02:06 5.5",continue OOH. 11/23/2015 11/23/2015 1.05 PROD1 DRILL PULD P PJSM. PUD BHA#3,LD BHA.Bit 62.5 0.0 02:06 03:09 condition 1-2-CT-G-X-I-PN-BHA 11/23/2015 11/23/2015 1.00 PROD1 DRILL PULD P PJSM.PD BHA#4 0.0 72.5 03:09 04:09 11/23/2015 11/23/2015 2.10 PROD1 DRILL TRIP P RIH w/L1 lateral drilling assembly,0.5 72.5 8,052.0 04:09 06:15 AKO motor,RB HYC bit,tie-in-14' correction,continue in hole. 11/23/2015 11/23/2015 0.65 PROD1 DRILL DRLG P 8,052 ft, OBD 1.6 bpm at 3,545 psi 8,052.0 8,083.0 06:15 06:54 FS,BHP 3,770 psi,CWT 10.5k,WOB 1.7k,ROP 40 11/23/2015 11/23/2015 1.85 PROD1 DRILL TRIP T 8,083 ft,MWD tool malfunction, 8,083.0 72.5 06:54 08:45 POOH to change out tools,jet 5.5", set up back up tools while continueing OOH. 11/23/2015 11/23/2015 1.10 PROD1 DRILL PULD T PJSM-PUD BHA#4,chang out DGS 72.5 0.0 08:45 09:51 and USR. 11/23/2015 11/23/2015 1.90 PROD1 DRILL PULD T PJSM-MU/PD BHA#5,0.5°AKO 0.0 72.5 09:51 11:45 motor with RB HYC bi-center bit,MU to CoilTrak,surface test. 11/23/2015 11/23/2015 1.35 PROD1 DRILL TRIP T RIH with BHA#5, 72.5 7,650.0 11:45 13:06 11/23/2015 11/23/2015 0.15 PROD1 DRILL DLOG T Tie in at K1 for-14 ft correction, 7,650.0 7,685.0 13:06 13:15 continue in hole,PUW above window 31k 11/23/2015 11/23/2015 0.40 PROD1 DRILL TRIP T RIH,PUW above window 31k. 7,685.0 8,083.0 13:15 13:39 11/23/2015 11/23/2015 1.55 PROD1 DRILL DRLG T 8,083 ft,OBD 1.6 bpm at 3,936 psi, 8,083.0 8,184.0 13:39 15:12 BHP 3,812 psi,CWT 9.0k,WOB 2.0k, ROP 80,near bit inclination and rez tool concerns,vibration,slow pump rate to 1.5 bpm at 3,797 psi,BHP 3,807 psi,CWT 9.0k,WOB 2.3k,ROP 90,less vibration,tool concerns still exist. 11/23/2015 11/23/2015 0.60 PROD1 DRILL DLOG T Perform MADD pass thru build section 8,184.0 8,184.0 15:12 15:48 8,046 ft to 7,930 ft at 6 fpm.PUW 30k. RBIH 11/23/2015 11/23/2015 0.55 PROD1 DRILL DLOG T Perform MADD pass thru lateral 8,184.0 8,184.0 15:48 16:21 section 8,184 ft to 8,046 ft at 6 fpm. PUW 31k.RBIH 11/23/2015 11/23/2015 1.00 PROD1 DRILL DRLG T 8,184 ft, OBD 1.5 bpm at 3,924 psi, 8,184.0 8,269.0 16:21 17:21 BHP 3,817 psi,CWT 9.0k,WOB 2.2k, ROP 90 Page 3/15 Report Printed: 12/31/2015 • • 0 . Operations Summary (with Timelog Depths) .a 3A-03 ConocoPhilbps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/23/2015 11/23/2015 2.20 PROD1 DRILL TRIP T POOH to change out tools,jet 5.5", 8,269.0 57.5 17:21 19:33 set up back up tools while continuing OOH. 11/23/2015 11/23/2015 2.25 PROD1 DRILL PULD T PJSM.PUD BHA#5.Lost high line 57.5 0.0 19:33 21:48 power,back on generator power. Check motor and bit,re-sribe. 11/23/2015 11/23/2015 0.95 PROD1 DRILL PULD T PJSM.PD BHA#6,surface test. 0.0 72.5 21:48 22:45 11/23/2015 11/24/2015 1.25 PROD1 DRILL TRIP T RIH w/lateral drilling assembly 72.5 7,660.0 22:45 00:00 11/24/2015 11/24/2015 0.75 PROD1 DRILL TRIP T Continue in hole with drilling 7,660.0 8,270.0 00:00 00:45 assembly,tie-in GR for-14'correction. Continue in hole. 11/24/2015 11/24/2015 1.20 PROD1 DRILL DLOG T MADD pass build and lateral section. 8,270.0 8,270.0 00:45 01:57 RBIH. 11/24/2015 11/24/2015 6.10 PROD1 DRILL DRLG P Drill ahead: 1.58 BPM @ 3,875 PSI, 8,270.0 8,670.0 01:57 08:03 BHP=3,810 PSI,CTW=10K, WOB=1.9K,ROP=95.Resistivity looks better. 11/24/2015 11/24/2015 0.30 PROD1 DRILL WPRT P Wiper trip out,PUW 32k. 8,670.0 7,950.0 08:03 08:21 11/24/2015 11/24/2015 0.30 PROD1 DRILL WPRT P Wiper trip in,RIW 10k 7,950.0 8,670.0 08:21 08:39 11/24/2015 11/24/2015 4.75 PROD1 DRILL DRLG P 8,670 ft, OBD 1.6 bpm at 3,980 psi, 8,670.0 8,970.0 08:39 13:24 BHP 3,827 psi,CWT 8.6k,WOB 1.8k, ROP 65,WHP 271,IA 530,OA 524 11/24/2015 11/24/2015 0.40 PROD1 DRILL WPRT P Wiper trip out,PUW 32k.5x5 sweep 8,970.0 7,940.0 13:24 13:48 pumped. 11/24/2015 11/24/2015 0.40 PROD1 DRILL WPRT P Wiper trip in,RIW 10.5k 7,940.0 8,970.0 13:48 14:12 11/24/2015 11/24/2015 6.00 PROD1 DRILL DRLG P 8,970 ft, OBD 1.57 bpm at 4,024 psi, 8,970.0 9,370.0 14:12 20:12 BHP 3,853 psi,WHP 267,IA 638,OA 588 11/24/2015 11/24/2015 0.50 PROD1 DRILL WPRT P 9370 ft,Wiper up hole PUW 9,370.0 7,723.0 20:12 20:42 11/24/2015 11/24/2015 0.50 PROD1 DRILL WPRT P 7723 ft,Jog twice pumping 1.6 bpm 7,723.0 7,885.0 20:42 21:12 11/24/2015 11/24/2015 0.25 PROD1 DRILL WPRT P 7723 ft,RIH to tie in depth. 7,885.0 7,920.0 21:12 21:27 11/24/2015 11/24/2015 0.25 PROD1 DRILL DLOG P 7920 ft,tie into the RA marker 7,920.0 7,933.0 21:27 21:42 correction of plus 4.0 ft 11/24/2015 11/24/2015 0.50 PROD1 DRILL WPRT P 7933 ft,continue wiper trip in hole 7,933.0 9,370.0 21:42 22:12 RIW 9 k 11/24/2015 11/25/2015 1.80 PROD1 DRILL DRLG P 9370 ft,BOBD 1.5 bpm at 3945 psi, 9,370.0 9,538.0 22:12 00:00 BHP 3862,WHP 248,IA 230,OA 414 11/25/2015 11/25/2015 3.00 PROD1 DRILL DRLG P 9538 ft,OBD 1.58 bpm at 4200 psi, 9,538.0 9,770.0 00:00 03:00 ROP 73 fph,2.7 k DHWOB 11/25/2015 11/25/2015 0.50 PROD1 DRILL WPRT P 9770 ft,wiper up hole to 8770 ft,PUW 9,770.0 8,770.0 03:00 03:30 30 k 11/25/2015 11/25/2015 0.25 PROD1 DRILL WPRT P 8770 ft,wiper back in hole.RIW 10 k 8,770.0 9,400.0 03:30 03:45 11/25/2015 11/25/2015 0.10 PROD1 DRILL DLOG P 9400 ft,re-log down to 9500 ft,to 9,400.0 9,500.0 03:45 03:51 check USR data. 11/25/2015 11/25/2015 0.25 PROD1 DRILL WPRT P 9500 ft,continue wiper back in hole. 9,500.0 9,770.0 03:51 04:06 RIW 10 k Page 4/15 Report Printed: 12/31/2015 •0 8 perations Summary (with ith Timelog Depths) 114 3A-03 ConocoPhil s A%.r.4a Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/25/2015 11/25/2015 3.35 PROD1 DRILL DRLG P 9770 ft,BOBD 1.6 bpm at 3580 psi 9,770.0 10,170.0 04:06 07:27 FS,BHP 3871,WHP 328,IA 314,OA 452.getting crude and trace gas back, drilling 1.6 bpm at 4,042 psi,BHP 4,080 psi(160 psi over schedule) WHP 553, IA 300,OA 430,minimal losses. 11/25/2015 11/25/2015 1.55 PROD1 DRILL WPRT P 10,170 ft, Wiper to window for 10,170.0 7,885.0 07:27 09:00 callibration,jet/jog 5 1/2"liner 7,880 ft to 7,725 ft. 11/25/2015 11/25/2015 0.50 PROD1 DRILL DLOG P 7,885.5 ft bit depth,DPS sensor depth 7,885.0 7,885.0 09:00 09:30 7,843 ft,DPS SSTVD 5,988 ft,shut in WHP 863,BHP 3,840,actual mud weight 9.1 ppg, 15 minutes WHP 837,BHP 3,759, Calibrate choke, pump 1.6 bpm at 3,660 psi,BHP 3,809 psi,WHP 455,confer with town. 12.0 ppg at window 11/25/2015 11/25/2015 0.25 PROD1 DRILL DLOG P RIH,RA tie in for no correction. 7,885.0 7,940.0 09:30 09:45 11/25/2015 11/25/2015 0.90 PROD1 DRILL WPRT P Wiper trip in,RIW 10k. 7,940.0 10,170.0 09:45 10:39 11/25/2015 11/25/2015 1.90 PROD1 DRILL DRLG P 10,170 ft, OBD 1.6 bpm at 3,744 psi 10,170.0 10,240.0 10:39 12:33 FS,BHP 3950 psi,WHP 445,IA 239, OA 419. TD called early,pump 10x10 sweep 11/25/2015 11/25/2015 1.85 PROD1 DRILL WPRT P 10,240 ft, Chase sweeps to window, 10,240.0 7,885.0 12:33 14:24 jet/jog 5 1/2"liner,7,885 ft bit depth, DPS sensor depth 7,843 ft,DPS SSTVD 5,988 ft,confirm 12.0 EMW, Open EDC. NOTE:lost power from 12:56 to 13:09, BHP to 3,722 psi. 11/25/2015 11/25/2015 1.30 PROD1 DRILL WPRT P Wiper to swab,tag up,re-set 7,885.0 72.2 14:24 15:42 counters. 11/25/2015 11/25/2015 1.30 PROD1 DRILL TRIP P RIH for tie in,corrected TD. 72.2 7,640.0 15:42 17:00 11/25/2015 11/25/2015 0.20 PROD1 DRILL DLOG P Tie in to K1 for minus 14 ft. 7,640.0 7,685.0 17:00 17:12 11/25/2015 11/25/2015 2.00 PROD1 DRILL TRIP P RIH,Close EDC,PUW above window 7,685.0 10,241.0 17:12 19:12 28 k,continue in hole, 11/25/2015 11/25/2015 0.50 PROD1 DRILL TRIP P 10241 ft confirmed TD,start pumping 10,241.0 10,241.0 19:12 19:42 liner pill 11/25/2015 11/25/2015 1.70 PROD1 DRILL DISP P 10241 ft,POOH laying in 12.0 ppg 10,241.0 72.2 19:42 21:24 completion fluid w/alpine beads. Painting EOP flags 11/25/2015 11/25/2015 0.50 PROD1 DRILL OWFF P At surface,perform no-flow check, 72.2 72.2 21:24 21:54 PJSM for LD drilling assembly on a dead well. 11/25/2015 11/25/2015 0.50 PROD1 DRILL PULD P LD drilling BHA#6 72.2 0.0 21:54 22:24 11/25/2015 11/25/2015 0.50 COMPZ1 CASING PUTB P PJSM,and prep rig floor for MU L1 0.0 0.0 22:24 22:54 liner assembly, 11/25/2015 11/26/2015 1.10 COMPZ1 CASING PUTB P MU 50 jts of 2-3/8"slotted liner 0.0 930.5 22:54 00:00 11/26/2015 11/26/2015 1.00 COMPZ1 CASING PUTB P Continue MU L1 liner completion 930.5 1,549.6 00:00 01:00 Page 5115 Report Printed: 12/31/2015 ;4OS • • Operations Summary (with Timelog Depths) 3A-03 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 11/26/2015 11/26/2015 1.00 COMPZ1 CASING PULD P PJSM,MU BHI coiltrak tools to liner, 1,549.6 1,603.0 01:00 02:00 change out check valves out of upper quick,swap FVS. 11/26/2015 11/26/2015 2.00 COMPZ1 CASING RUNL P 1603 ft,RIH,BHA#7,with 50 jts of 1,603.0 10,241.0 02:00 04:00 slotted liner and liner top billet. correcting to EOP flag at 6200 ft, minus 17 ft. 11/26/2015 11/26/2015 0.25 COMPZ1 CASING RUNL P 10241 ft,PUW 35 k,Release from 10,241.0 8,682.0 04:00 04:15 liner, 1.4 bpm 4300 psi,0.85 bpm returns,PUW 28 k,remove liner from counters. 11/26/2015 11/26/2015 1.75 COMPZI CASING TRIP P POOH 8,682.0 44.2 04:15 06:00 11/26/2015 11/26/2015 0.50 COMPZ1 CASING OWFF P Check well for flow,PJSM for LD 44.2 44.2 06:00 06:30 setting tools 11/26/2015 11/26/2015 0.50 COMPZI CASING PULD P LD BHA#7 setting tools. 44.2 0.0 06:30 07:00 11/26/2015 11/26/2015 0.50 PROD2 STK SVRG P Service injector and top drive. 0.0 0.0 07:00 07:30 11/26/2015 11/26/2015 1.30 PROD2 STK PULD P PJSM-MU drilling BHA#8,0.8°AKO 0.0 72,2 07:30 08:48 motor with RB HCC Bi-cemter bit. 11/26/2015 11/26/2015 1.35 PROD2 STK TRIP P RIH with BHA#8 72.2 7,640.0 08:48 10:09 11/26/2015 11/26/2015 0.20 PROD2 STK DLOG P Tie in to K1 for minus 14 ft, PUW 30k. 7,640.0 7,675.0 10:09 10:21 11/26/2015 11/26/2015 0.55 PROD2 STK TRIP P RIH,dry tag billet at 8,683 ft,PUW 7,675.0 8,683.0 10:21 10:54 32k 11/26/2015 11/26/2015 1.10 PROD2 STK DISP P Dispalce 12.0 ppg completion fluid out 8,683.0 8,683.0 10:54 12:00 to 9.1 ppg drilling mud. 11/26/2015 11/26/2015 2.00 PROD2 STK KOST P 8,683 ft,Time mill off billet per 8,683.0 • 8,688.0 12:00 14:00 recomended practice. 11/26/2015 11/26/2015 0.75 PROD2 DRILL DRLG P 8,688 ft, Drill ahead 1.52 bpm at 8,688.0 8,740.0 14:00 14:45 3,857 psi,BHP 3,889 psi,WHP 307, IA 190,OA 437 11/26/2015 11/26/2015 0.10 PROD2 DRILL WPRT P 8,740 ft, PUH to 8,662',RBIH,drift 8,740.0 8,740.0 14:45 14:51 billet clean. 11/26/2015 11/26/2015 3.90 PROD2 DRILL DRLG P 8,740 ft, OBD 1.56 bpm at 4,103 psi, 8,740.0 9,080.0 14:51 18:45 BHP 3,889,WHP 367,IA 221,OA 449 11/26/2015 11/26/2015 0.50 PROD2 DRILL WPRT P 9080 ft,Wiper up hole.7950 ft PUW 30 9,080.0 7,950.0 18:45 19:15 k 11/26/2015 11/26/2015 0.50 PROD2 DRILL WPRT P 7950 ft,Wiper back in hole,RIW 11 k 7,950.0 9,080.0 19:15 19:45 11/26/2015 11/27/2015 4.25 PROD2 DRILL DRLG P 9080 ft,BOBD 1.54 bpm at 3765 psi 9,080.0 9,450.0 19:45 00:00 FS,BHP 3888,WHP 321,IA 331,OA 540 11/27/2015 11/27/2015 0.15 PROD2 DRILL DRLG P OBD 1.54 bpm at 4063 psi,BHP 9,450.0 9,480.0 00:00 00:09 3886,WHP 423, IA 385,OA 583 11/27/2015 11/27/2015 0.50 PROD2 DRILL WPRT P 9480 ft,wiper up hole PUW 29 k 9,480.0 8,700.0 00:09 00:39 11/27/2015 11/27/2015 0.50 PROD2 DRILL WPRT P 8700 ft,wiper back in hole,RIW 9 k 8,700.0 9,480.0 00:39 01:09 Page 6/15 Report Printed: 12/31/2015 0:1114, Operations Summary (with Timelog Depths) 3A-03 ConocoPhinip Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/27/2015 11/27/2015 3.00 PROD2 DRILL DRLG P 9480 ft,BOBD 1.55 bpm at 3800 psi 9,480.0 9,850.0 01:09 04:09 FS,BHP 4000,WHP 475,IA 429,OA 612, Note:9645 ft,9.1 ppg mud seems to be gas cut,apply additional 75-100 psi over MP schedule. 11/27/2015 11/27/2015 1.00 PROD2 DRILL WPRT P 9850 ft,wiper up hole to 7725 ft,2 9,850.0 7,725.0 04:09 05:09 passes jetting 5-1/2"from 7725 ft to 7890 ft, PUW 30 k 11/27/2015 11/27/2015 0.25 PROD2 DRILL WPRT P RIH,down to tie in depth. 7,725.0 7,915.0 05:09 05:24 11/27/2015 11/27/2015 0.25 PROD2 DRILL DLOG P 7915 ft,log RA marker correction of 7,915.0 7,935.0 05:24 05:39 plus 3.0 ft. 11/27/2015 11/27/2015 0.45 PROD2 DRILL WPRT P 7935 ft,continue wiper in hole,RIW 7,935.0 9,850.0 05:39 06:06 11 k 11/27/2015 11/27/2015 3.75 PROD2 DRILL DRLG P 9850 ft,OBD 1.55 bpm at 3,938 psi, 9,850.0 10,250.0 06:06 09:51 BHP 3,990 psi,WHP 432,IA 402,OA 609 Note:New 9.3 ppg FloPro SF,System #3 at bit 9,850 ft 11/27/2015 11/27/2015 3.05 PROD2 DRILL WPRT P 10,250 ft, TD L1-01 lateral,chase 10,250.0 72.2 09:51 12:54 sweeps to window,PUW 29,jet/jog 5 1/2"liner,check BHP at window,open EDC,wiper to sawb.Tag up,re-set counters. 11/27/2015 11/27/2015 1.35 PROD2 DRILL TRIP P RBIH from surface for tie in,corrected 72.2 7,640.0 12:54 14:15 TD. 11/27/2015 11/27/2015 0.20 PROD2 DRILL DLOG P Tie in to K1 for minus 13 ft correction. 7,640.0 7,670.0 14:15 14:27 11/27/2015 11/27/2015 1.05 PROD2 DRILL TRIP P RIH,Close EDC,PUW above window 7,670.0 10,250.0 14:27 15:30 29k,continue in hole 11/27/2015 11/27/2015 0.45 PROD2 DRILL DISP P 10,250 ft,Confirmed TD,start 10,250.0 10,250.0 15:30 15:57 pumping liner pill. 11/27/2015 11/27/2015 2.30 PROD2 DRILL DISP P POOH laying in 12.0 ppg completion 10,250.0 72.2 15:57 18:15 fluid w/alpine beads.Paint EOP flags at 7,950 ft and 5,500 ft. 11/27/2015 11/27/2015 0.50 PROD2 DRILL OWFF P At surface,perform no-flow check, 72.2 72.2 18:15 18:45 PJSM for LD drilling assembly on a dead well.Crew changeout perform valve check list. 11/27/2015 11/27/2015 0.50 PROD2 DRILL SFTY P LD drilling BHA,BHA#8 72.2 72.2 18:45 19:15 11/27/2015 11/27/2015 1.00 PROD2 DRILL PULD P LD drilling BHA 72.2 0.0 19:15 20:15 11/27/2015 11/27/2015 0.25 COMPZ2 CASING PUTB P PJSM,prep rig floor for MU L1-01 liner 0.0 0.0 20:15 20:30 assembly. 11/27/2015 11/28/2015 3.50 COMPZ2 CASING PUTS P MU L1-01 liner assembly with Bull 0.0 2,250.8 20:30 00:00 Noze,72 jts of slotted liner,and liner top billet. 11/28/2015 11/28/2015 1.00 COMPZ2 CASING PUTB P PJSM,MU BHI coiltrak tools, 2,250.8 2,295.0 00:00 01:00 changeout BHI upper quick check valves.Stab onto well with INJH. Nabors weight cell reading 7500 lbs hanging on Top Drive. 11/28/2015 11/28/2015 1.50 COMPZ2 CASING RUNL P 2295 ft,RIH pumping min rate,correct 2,295.0 7,814.2 01:00 02:30 to the EOP flag at 5501.7 ft minus 17.5 ft, Page 7/15 Report Printed: 12/31/2015 ,t Operations Summary (with Timelog Depths) 0 Pit 3A-03 ConocoPhilbps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/28/2015 11/28/2015 1.00 COMPZ2 CASING RUNL P Continue RIH through window to TD. 7,814.2 10,250.0 02:30 03:30 11/28/2015 11/28/2015 0.25 COMPZ2 CASING RUNL P 10250 ft,PUW 35 k,Release from 10,250.0 7,980.0 03:30 03:45 liner, 1.4 bpm 4300 psi,0.85 bpm returns,PUW 32 k,remove liner from counters. 11/28/2015 11/28/2015 1.75 COMPZ2 CASING TRIP P 7980 ft,POOH pumping 1.0 bpm at 7,980.0 44.2 03:45 05:30 2740 psi 11/28/2015 11/28/2015 0.50 COMPZ2 CASING OWFF P At surface,check well for flow, 44.2 44.2 05:30 06:00 perform valve checklist,PJSM for LD liner setting tools. 11/28/2015 11/28/2015 0.75 COMPZ2 CASING PULD P LD BHA#9 44.2 0.0 06:00 06:45 11/28/2015 11/28/2015 0.50 PROD3 STK BOPE P Perform Bi weekly BOPE function test 0.0 0.0 06:45 07:15 11/28/2015 11/28/2015 0.75 PROD3 STK PULD P PJSM-MU BHA#10,2.3°+AKO 0.0 72.2 07:15 08:00 motor and RR 1-1 HYC bi-center bit. 11/28/2015 11/28/2015 0.50 PROD3 STK TRIP P RIH with BHA#10,EDC open. 72.2 3,071.0 08:00 08:30 11/28/2015 11/28/2015 0.50 PROD3 STK CTOP T 3,071 ft,stacked in top GLM(3,057 ft 3,071.0 3,260.0 08:30 09:00 RKB), 120°R orientation,PU hole to 2,958 ft to check pipe,all good, orientate to 0°HS,no problem past GLM,stop at 3,260 ft,pump 3 bbls, cycle EDC closed/open,good.tools communicating. 11/28/2015 11/28/2015 0.90 PROD3 STK TRIP P RIH with BHA#10,stacked in GLM#2 3,260.0 7,650.0 09:00 09:54 at 6,133 ft,orientate 90°R,no problem passing GLM#2,continue in hole. 11/28/2015 11/28/2015 0.20 PROD3 STK DLOG P Tie in to K1 for minus 13 ft correction, 7,640.0 7,880.0 09:54 10:06 continue in hole, 11/28/2015 11/28/2015 1.50 PROD3 STK DISP P Dispalce 12.0 ppg completion fluid out 7,880.0 7,998.0 10:06 11:36 to 9.3 ppg drilling mud,choke callibration 1.6 bpm at 3,639 psi,BHP 3810 psi,WHP 218 psi EDC open. Close EDC,PUW 29k,RBIH thru window. 11/28/2015 11/28/2015 1.10 PROD3 STK KOST P 7,998 ft,Dry tag top of Billet,PUW 7,998.0 8,005.0 11:36 12:42 29k.Time mill off billet per recomended practice from 7,997.6 ft.. 11/28/2015 11/28/2015 0.85 PROD3 DRILL DRLG P 8,005 ft, OBD 1.6 bpm at 4,064 psi, 8,005.0 8,040.0 12:42 13:33 BHP 3,836 psi,WHP 230,IA 100,OA 362, 11/28/2015 11/28/2015 0.15 PROD3 DRILL WPRT P 8,040 ft,PU to 7,960 ft,PUW 29k, 8,040.0 8,040.0 13:33 13:42 RBIH and drift billet clean. 11/28/2015 11/28/2015 4.75 PROD3 DRILL DRLG P 8,040 ft,OBD 1.53 bpm at 4,008 psi, 8,040.0 8,180.0 13:42 18:27 BHP 3,864 psi,WHP 258,IA 124,OA 380 11/28/2015 11/28/2015 1.50 PROD3 DRILL TRIP P 8180 ft,TD build section,PUW 30 k, 8,180.0 72.2 18:27 19:57 POOH "*` Note:746'from surface noticed 7" o-ring leaking on quicktest sub, continue POOH to spaceout. 11/28/2015 11/28/2015 2.80 PROD3 DRILL PULD P At surface,PJSM,PUD L1-02 build 72.2 0.0 19:57 22:45 section BHA,BHA#10,re-install new o-ring on quicktest sub and P/T to 4100 psi. Page 8115 Report Printed: 12/31/2015 Operations Summary (with Timelog Depths) 08 sl 3A-03 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X_ Operation (ftKB) End Depth(ftKB) 11/28/2015 11/29/2015 1.25 PROD3 DRILL PULD P PU/MU,PD L1-02 lateral drilling 0.0 72.2 22:45 00:00 assyembly. 11/29/2015 11/29/2015 1.75 PROD3 DRILL TRIP P RIH with L1-02 lateral drilling BHA, 72.2 7,645.0 00:00 01:45 BHA#11 11/29/2015 11/29/2015 0.25 PROD3 DRILL DLOG P 7645 ft,Tie into the K1 marker 7,645.0 7,674.0 01:45 02:00 correction of minus 13.5 ft,PUW 30 k 11/29/2015 11/29/2015 0.50 PROD3 DRILL TRIP P Continue RIH through window 7,674.0 8,180.0 02:00 02:30 11/29/2015 11/29/2015 5.35 PROD3 DRILL DRLG P 8180 ft,BOBD 1.49 bpm at 3720 psi 8,180.0 8,615.0 02:30 07:51 FS,BHP 3864,WHP 249,IA 139,OA 389,pump 5x5. 11/29/2015 11/29/2015 0.35 PROD3 DRILL WPRT P 8,615 ft,wiper up hole,PUW 29k 8,615.0 8,180.0 07:51 08:12 11/29/2015 11/29/2015 0.55 PROD3 DRILL DLOG P 8,180 ft, MADD pass,6 fpm to 7,975 8,180.0 7,940.0 08:12 08:45 ft 11/29/2015 11/29/2015 0.30 PROD3 DRILL WPRT P 7,940 ft, Wiper in hole 7,940.0 8,615.0 08:45 09:03 11/29/2015 11/29/2015 3.20 PROD3 DRILL DRLG P 8,615 ft, OBD 1.55 bpm at 3,977 psi 8,615.0 9,050.0 09:03 12:15 FS,BHP 3,969 psi,WHP 312,IA 217, OA 438,pump 10x10 sweeep. 11/29/2015 11/29/2015 2.90 PROD3 DRILL WPRT P 9,050 ft,TD L1-02 lateral,chase 9,050.0 72.2 12:15 15:09 sweeps to window,PUW 31k,jet/jog 5 1/2"liner,check BHP at window,open EDC,wiper to sawb.Tag up,re-set counters. 11/29/2015 11/29/2015 1.40 PROD3 DRILL TRIP P RIH for tie in,corrected TD. 72.2 7,640.0 15:09 16:33 11/29/2015 11/29/2015 0.15 PROD3 DRILL DLOG P Tie in to K1 for minus 14 ft. 7,640.0 7,670.0 16:33 16:42 11/29/2015 11/29/2015 0.60 PROD3 DRILL TRIP P RIH,Close EDC,PUW above window 7,670.0 9,051.0 16:42 17:18 30k,continue in hole 11/29/2015 11/29/2015 0.50 PROD3 DRILL DISP P 9,051 ft,Confirmed TD,start pumping 9,051.0 9,051.0 17:18 17:48 beaded liner pill,PUW 29k. 11/29/2015 11/29/2015 2.15 PROD3 DRILL DISP P POOH laying in 12.0 ppg completion 9,051.0 72.2 17:48 19:57 fluid w/alpine beads.Paint EOP flags. 11/29/2015 11/29/2015 0.50 PROD3 DRILL OWFF P At sureface observe well for no flow, 72.2 72.2 19:57 20:27 PJSM for laying down drilling tools 11/29/2015 11/29/2015 1.15 PROD3 DRILL PULD P LD drilling BHA,BHA#11 72.2 0.0 20:27 21:36 11/29/2015 11/29/2015 0.50 COMPZ3 CASING PULD P Prep Rig floor for PU liner,PJSM for 0.0 0.0 21:36 22:06 MU L1-02 liner assembly 11/29/2015 11/30/2015 1.90 COMPZ3 CASING PUTB P MU 37 jts of slotted liner. 0.0 1,143.4 22:06 00:00 11/30/2015 11/30/2015 0.65 COMPZ3 CASING PUTB P PU/MU BHI coiltrak tools to liner, 1,143.4 1,188.8 00:00 00:39 lower into slips,strip down on to well, test tools 11/30/2015 11/30/2015 1.25 COMPZ3 CASING RUNL P 1189 ft,RIH w/L1-02 liner assembly 1,188.8 7,794.0 00:39 01:54 with 37 jts,shorty deployment sleeve, and non-ported bull noze. 11/30/2015 11/30/2015 0.25 COMPZ3 CASING RUNL P Correct to the EOP flag at 6600 ft, 7,794.0 7,794.0 01:54 02:09 correction of minus 16 ft.PUW 30.5 k 11/30/2015 11/30/2015 0.75 COMPZ3 CASING RUNL P 7794 ft,continue RIH to 9030 ft. 7,794.0 9,030.0 02:09 02:54 Page 9/15 Report Printed: 12/31/2015 •0 • g.1Operations Summary (with Timelog Depths) ra 3A-03 no cot)Phillips Al.,Ae Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 11/30/2015 11/30/2015 0.25 COMPZ3 CASING RUNL P 9030 ft,PUW 34 k,RIBIH to 9030 ft, 9,030.0 9,030.0 02:54 03:09 bring rig pump online at 1.3 bpm at 4000 psi, 1 bpm returns,PUW 28 k, remove liner length from counters 11/30/2015 11/30/2015 1.25 COMPZ3 CASING TRIP P POOH,pumping 1 bpm at 2837 psi. 9,030.0 44.2 03:09 04:24 11/30/2015 11/30/2015 0.50 COMPZ3 CASING OWFF P At surface,check well of flow,PJSM 44.2 44.2 04:24 04:54 for LD liner setting tools 11/30/2015 11/30/2015 1.50 COMPZ3 CASING PULD P LD liner setting BHA,BHA#12 44.2 0.0 04:54 06:24 11/30/2015 11/30/2015 1.00 PROD4 .RPEQPT PULD P PJSM,PU/MU WS setting BHA,BHA# 0.0 74.8 06:24 07:24 13 11/30/2015 11/30/2015 2.00 PROD4 RPEQPT TRIP P RIH with BHA#13,EDC closed 74.8 7,640.0 07:24 09:24 11/30/2015 11/30/2015 0.20 PROD4 RPEQPT DLOG P Tie in to K1 for-15 ft correction.PUW 7,640.0 7,670.0 09:24 09:36 30k. 11/30/2015 11/30/2015 0.20 PROD4 RPEQPT TRIP P RIH to set depth 7,670.0 7,873.0 09:36 09:48 11/30/2015 11/30/2015 0.15 PROD4 RPEQPT WPST P 7,872.98 ft, On depth,oriented 15°, 7,873.0 7,873.0 09:48 09:57 release off whipstock at 2,300 psi,set down 3k,PUW 31k,TOWS at 7,860 ft. 11/30/2015 11/30/2015 1.45 PROD4 RPEQPT TRIP P POOH with whipstock setting tools 7,873.0 74.8 09:57 11:24 BHA#13 11/30/2015 11/30/2015 0.50 PROD4 RPEQPT OWFF P Monitor well for flow,PJSM-LD BHA 74.8 74.8 11:24 11:54 11/30/2015 11/30/2015 0.60 PROD4 RPEQPT PULD P LD setting tools BHA#13 74.8 0.0 11:54 12:30 11/30/2015 11/30/2015 0.80 PROD4 WHPST PULD P PJSM-PU/MU milling BHA#14 0.0 63.2 12:30 13:18 11/30/2015 11/30/2015 1.45 PROD4 WHPST TRIP P RIH with BHA#14,EDC open. 63.2 7,640.0 13:18 14:45 11/30/2015 11/30/2015 0.15 PROD4 WHPST DLOG P Tie in to K1 for-15 ft correction. 7,640.0 7,670.0 14:45 14:54 11/30/2015 11/30/2015 0.30 PROD4 WHPST TRIP P Continue RIH to tag pinch point at 7,670.0 7,845.0 14:54 15:12 7,865 ft,PUW 31k to 7,845 ft 11/30/2015 11/30/2015 1.65 PROD4 WHPST DISP P 7,845 ft,Pump 10 bbl of 12.2 ppg, 7,845.0 7,845.0 15:12 16:51 100k Isry pill down coil as per email, attempt to squeeze to formation at 0.15 bpm,formation tight,pressures up and have to shut down,bleeds back very slow, 1.86 bbls squeezed, call town. 11/30/2015 11/30/2015 1.15 PROD4 WHPST DISP P Displace high vis pill out chased by 7,845.0 7,845.0 16:51 18:00 9.3 ppg milling fluid,RIH 11/30/2015 12/1/2015 6.00 PROD4 WHPST WPST P 7,865 ft, dry tag pinch point,PUW 7,865.0 7,870.0 18:00 00:00 29k,bring on pumps,RBIH sat down at top of WS at 7,860 ft, PU,RBIH pumps off to 7,861 ft,bring on pumps, high differential,PU,RBIH pumps off to 7,865.48 ft,did not see TOWS,PU to 7,863 ft,bring on pumps,begin time milling window.Looks like we exited the casing at 7869 ft. 12/1/2015 12/1/2015 3.25 PROD4 WHPST WPST P 7870 ft,continue drilling rat hole,1.46 7,870.0 7,885.0 00:00 03:15 bpm at 3789 psi,BHP 3794,WHP 232,IA 118,OA 415 Page 10115 Report Printed: 12/31/2015 0 • • 4' Operations Summary (with Timelog Depths) ,ti 3A-03 • ConocoPhillips hf:r.Fa Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code lime P-T-X Operation (ftKB) End Depth(ftKB) 12/1/2015 12/1/2015 1.50 PROD4 WHPST REAM P 7885 ft,Back ream window area up to 7,885.0 7,885.0 03:15 04:45 7850 ft.pumping 1.5 bpm at 3720 psi. PUW 30 k "**"Note:On reaming pass down stalled motor on top of WS tray.PUH PUW 30 k,RBIH pumps off clean drift pass top of tray.RIH and perform 2 more reaming passes up. 12/1/2015 12/1/2015 1.25 PROD4 WHPST TRIP P Displace well to 12.0 ppg completion 7,885.0 63.2 04:45 06:00 fluid,while POOH to surface. 12/1/2015 12/1/2015 0.50 PROD4 WHPST OWFF P At surface,check well for flow,PJSM 63.2 63.2 06:00 06:30 for LD milling tools. 12/1/2015 12/1/2015 1.50 PROD4 WHPST PULD P LD Milling BHA,BHA#14 63.2 0.0 06:30 08:00 12/1/2015 12/1/2015 3.00 PROD4 WHDBOP PULD P PJSM,grease R valves,grease crew 0.0 0.0 08:00 11:00 on location to service tree valves. Verify test joint is torqued,and measured,swap coil to water while jetting stack.PT inner reel valve and pac-off.calibrate Out Mirco Motion, displace coil back to 12.0 ppg completion fluid,unstab INJH. 12/1/2015 12/1/2015 1.00 PROD4 WHDBOP SFTY P PJSM,prep rig floor for BOP test 0.0 0.0 11:00 12:00 12/1/2015 12/1/2015 7.00 PROD4 WHDBOP BOPE P Start bi-weekly BOP test 250/4100 psi, 0.0 0.0 12:00 19:00 annular 2,500 psi.Witnessed wavied by AOGCC(Matthew Herrera). 12/1/2015 12/1/2015 1.80 PROD4 DRILL CTOP P PJSM,Open up drilling choke to clear 0.0 0.0 19:00 20:48 and inspect,Install new UQC with checks,Freeze protect test equipment 12/1/2015 12/1/2015 1.30 PROD4 DRILL PULD P PJSM,M/U build section BHA#15 0.0 72.2 20:48 22:06 with 1.8°AKO motor and re build Hughes bi center,M/U to coil and surface test.Pump 12 BBIs before RIH @ 1.5 BPM 12/1/2015 12/1/2015 1.50 PROD4 DRILL TRIP P Trip in well,EDC open pumping 1 72.2 7,660.0 22:06 23:36 BPM 12/1/2015 12/1/2015 0.20 PROD4 DRILL DLOG P Log K1 for-14.5'correction 7,660.0 7,673.0 23:36 23:48 12/1/2015 12/1/2015 0.10 PROD4 DRILL TRIP P Continue in well,pump spacer 7,673.0 7,840.0 23:48 23:54 followed by new 9.3PPG mud 12/1/2015 12/2/2015 0.10 PROD4 DRILL CIRC P Displace well to new 9.3 PPG mud 7,840.0 7,840.0 23:54 00:00 12/2/2015 12/2/2015 0.90 PROD4 DRILL CIRC P Displaceing well to new 9.3 PPG 7,840.0 7,840.0 00:00 00:54 drilling mud 12/2/2015 12/2/2015 0.20 PROD4 DRILL TRIP P new 9.3 PPG mud around,trap 856 7,840.0 7,885.0 00:54 01:06 PSI WHP,Close EDC,PUW=30K, Trip in to drill,clean pass through window 12/2/2015 12/2/2015 2.30 PROD4 DRILL DRLG P 7885',Drill, 1.5 BPM @ 3705 PSI FS, 7,885.0 7,950.0 01:06 03:24 BHP=3799,WHP=330. 12/2/2015 12/2/2015 0.10 PROD4 DRILL WPRT P Stacking out,Pull mini wiper, 7,950.0 7,950.0 03:24 03:30 PUW=32K 12/2/2015 12/2/2015 4.50 PROD4 DRILL DRLG P 7950',Drill, 1.49 BPM @ 3463PSI FS, 7,950.0 8,285.0 03:30 08:00 BHP=3868 12/2/2015 12/2/2015 0.50 PROD4 DRILL WPRT P 8285 ft,TD build section,wiper up 8,285.0 7,730.0 08:00 08:30 hole to window. Page 11/15 Report Printed: 12/31/2015 httperaflon: surnrnary (wi;hTirneki; pths) 0 3A-03 ConocoPhillips Atskn Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/2/2015 12/2/2015 0.75 PROD4 DRILL TRIP P 7730 ft,Perform jog in 5.5"to clean up 7,730.0 7,850.0 08:30 09:15 the annulus,pump bottoms-up. 12/2/2015 12/2/2015 0.25 PROD4 DRILL TRIP P 7850 ft,perform choke calibration, 7,850.0 7,850.0 09:15 09:30 12.0 ECD,pumping 1.6 bpm at 3960 psi,300 psi,choke pressure,BHP 3723 12/2/2015 12/2/2015 1.50 PROD4 DRILL TRIP P 7850 ft,Open EDC,POOH 7,850.0 72.2 09:30 11:00 12/2/2015 12/2/2015 1.00 PROD4 DRILL PULD P At surface,PJSM,PUD Build section 72.2 0.0 11:00 12:00 BHA,BHA#15 12/2/2015 12/2/2015 1.25 PROD4 DRILL PULD P PJSM, PU/MU,and PD lateral drilling 0.0 72.2 12:00 13:15 BHA,BHA#16 12/2/2015 12/2/2015 1.50 PROD4 DRILL TRIP P RIH with Lateral BHA, BHA#16,with 72.2 7,845.0 13:15 14:45 a 0.8°AKO motor and new 3"bi- center bit. EDC open.Pumping 0.3 BPM. 12/2/2015 12/2/2015 0.25 PROD4 DRILL DLOG P 7845 ft,Tie into the K1 marker 7,845.0 7,866.0 14:45 15:00 correction of minus 14.0 ft, 12/2/2015 12/2/2015 0.50 PROD4 DRILL TRIP P 7866 ft,continue RIH 7,866.0 8,285.0 15:00 15:30 12/2/2015 12/2/2015 1.00 PROD4 DRILL DRLG P 8285 ft,OBD 1.55 bpm at 4030 psi 8,285.0 8,391.0 15:30 16:30 FS,BHP 3886 psi,WHP 297 psi,IA 168,OA 445 12/2/2015 12/2/2015 0.20 PROD4 DRILL WPRT P Geo wiper from 8391 to 8328 ft. 8,391.0 8,391.0 16:30 16:42 12/2/2015 12/2/2015 3.20 PROD4 DRILL DRLG P 8391 ft,Continue drilling 1.57 BPM @ 8,391.0 8,690.0 16:42 19:54 4030 psi FS,BHP 3870 psi,WHP 280 psi, 12/2/2015 12/2/2015 1.00 PROD4 DRILL WPRT P Wiper trip from 8690 ft to 7950 ft.PU 8,690.0 8,690.0 19:54 20:54 weight3lklbs. 12/2/2015 12/3/2015 3.10 PROD4 DRILL DRLG P 8690 ft,Continue drilling 1.47 BPM @ 8,690.0 8,977.0 20:54 00:00 3700 psi FS,BHP 3942 psi,WHP 250 psi.IA 277 psi,OA 528 psi. 12/3/2015 12/3/2015 1.20 PROD4 DRILL DRLG P 8977 ft. Drill ahead 1.46 BPM @ 3700 8,977.0 9,090.0 00:00 01:12 psi,BHP 3942 psi, 12/3/2015 12/3/2015 0.90 PROD4 DRILL WPRT P Wiper trip from 9090 ft to 8050 ft.PU 9,090.0 9,090.0 01:12 02:06 weight of 33klbs.Clean trip up and down 12/3/2015 12/3/2015 5.25 PROD4 DRILL DRLG P 9080',Drill, 1.42 BPM @ 3660 PSI 9,090.0 9,490.0 02:06 07:21 FS,BHP=3864 12/3/2015 12/3/2015 0.50 PROD4 DRILL WPRT P 9490 ft,Wiper up hole to 7725 ft, 9,490.0 7,725.0 07:21 07:51 PUW 30 k,perform 2 jogs 7725 ft- 7850 ft.in 5.5"with sweep 12/3/2015 12/3/2015 0.25 PROD4 DRILL DLOG P 'RIH to tie in depth 7885 ft,Log RA 7,725.0 7,912.0 07:51 08:06 marker correction of plus 2.0 ft. 12/3/2015 12/3/2015 0.50 PROD4 DRILL WPRT P 7912 ft,wiper back in hole RIW 11 k 7,912.0 9,490.0 08:06 08:36 12/3/2015 12/3/2015 1.25 PROD4 DRILL DRLG P 9490 ft, BOBD 1.6 bpm at 3750 psi 9,490.0 9,614.0 08:36 09:51 FS,BHP 3986,WHP 239,IA 349,OA 571 12/3/2015 12/3/2015 1.15 PROD4 DRILL WPRT P 9614 ft,TD BL2 laterall,circulate 9,614.0 7,725.0 09:51 11:00 10x10 sweep,wiper up hole to the window. 12/3/2015 12/3/2015 0.50 PROD4 DRILL WPRT P 7725 ft.Perform jog in 5.5"from 7725 7,725.0 7,725.0 11:00 11:30 ft.to 7850 ft.with sweeps. 12/3/2015 12/3/2015 1.50 PROD4 DRILL WPRT P 7725 ft.Open EDC,POOH 7,725.0 72.2 11:30 13:00 12/3/2015 12/3/2015 1.50 PROD4 DRILL TRIP P At surface reset counters,RBIH 72.2 7,640.0 13:00 14:30 Page 12/15 Report Printed: 12/31/2015 .1 1 i tperations Summary (with Timelogipths) 0 rpt 3A-03 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/3/2015 12/3/2015 0.25 PROD4 DRILL DLOG P 7640 ft,tie into the K1 marker 7,640.0 7,712.0 14:30 14:45 correction of minus 14.5 ft. 12/3/2015 12/3/2015 1.00 PROD4 DRILL TRIP P 7712 ft,Continue RIH. Close EDC 7,712.0 9,614.0 14:45 15:45 prior to exiting the window.Confirm TD at 9614 ft.RIW=12klbs 12/3/2015 12/3/2015 3.00 PROD4 DRILL DISP P POOH while laying in 12.0 ppg 9,614.0 67.0 15:45 18:45 completion fluid with Alpine beads. Paint EOP flags. Note:Observed 3k overpull with bit passing the TOWS at 7860 ft. 12/3/2015 12/3/2015 0.75 PROD4 DRILL OWFF P Observe well for flow. Static. 67.0 67.0 18:45 19:30 PJSM for LD BHA 16. 12/3/2015 12/3/2015 0.75 PROD4 DRILL PULD P Lay down BHA 16. 67.0 0.0 19:30 20:15 12/3/2015 12/3/2015 0.75 COMPZ4 CASING PUTB P PJSM and prepare for liner run. 0.0 0.0 20:15 21:00 12/3/2015 12/4/2015 3.00 COMPZ4 CASING PUTB P Pick up NP bull nose,2 liner pups and 0.0 1,225.6 21:00 00:00 37 jpoints of slotted liner. PU anchored billet assembly and make up coiltrak tools to liner assembly. 12/4/2015 12/4/2015 0.30 COMPZ4 CASING PUTB P M/U anchored billet to liner,M/U to 1,225.6 1,225.6 00:00 00:18 Coil and surface test.Strip on injector 12/4/2015 12/4/2015 1.70 COMPZ4 CASING RUNL P RIH with ancor billet and liner,EDC 1,225.6 7,743.0 00:18 02:00 closed, Pump tagged out. 12/4/2015 12/4/2015 0.20 COMPZ4 CASING RUNL P Correct to 6500'EOP flag for-18' 7,743.0 7,725.0 02:00 02:12 12/4/2015 12/4/2015 0.60 COMPZ4 CASING RUNL P Continue in well,Perform weight 7,725.0 8,805.0 02:12 02:48 check @ 7840 for 32K.Clean trip through window 12/4/2015 12/4/2015 0.20 COMPZ4 CASING RUNL P Log K1 for+2,Did not update 8,805.0 8,840.0 02:48 03:00 counters,continue in hole 12/4/2015 12/4/2015 0.50 COMPZ4 CASING RUNL P RIH with liner,Tag @ 9613,PUW=34, 8,840.0 9,613.0 03:00 03:30 RBIH to 9613,PUH to 30K.Oriented to 30°ROHS,Pumps on see tool shift 4000 PSI,Set down 2.5K 12/4/2015 12/4/2015 0.25 COMPZ4 CASING RUNL P Lift off liner,PUW=31K,Stopp and 9,613.0 8,449.2 03:30 03:45 remove liner length left in hole- 1164.4' 12/4/2015 12/4/2015 1.50 COMPZ4 CASING TRIP P POOH,to surface 8,449.2 61.1 03:45 05:15 12/4/2015 12/4/2015 0.50 COMPZ4 CASING PULD P PJSM,check well for flow. 61.1 61.1 05:15 05:45 12/4/2015 12/4/2015 1.00 COMPZ4 CASING PULD P Good flow check,LD BHA#17 61.1 0.0 05:45 06:45 12/4/2015 12/4/2015 1.00 PROD5 STK PULD P PJSM,PU/MU coiltrak tools, 0.0 72.2 06:45 07:45 kickoff/drilling BHA#18 12/4/2015 12/4/2015 1.50 PRODS STK TRIP P Stab INJH,test coiltrak tools,RIH, 72.2 7,650.0 07:45 09:15 w/1.0°ako motor and new bi-center bit. 12/4/2015 12/4/2015 0.25 PROD5 STK DLOG P 7650 ft,Tie into the K1 marker 7,650.0 7,850.0 09:15 09:30 correction of minus 17 ft.RIH 12/4/2015 12/4/2015 1.50 PRODS STK DISP P 7840 ft,displace well to used 9.3 ppg 7,850.0 7,850.0 09:30 11:00 drilling fluid. 12/4/2015 12/4/2015 0.25 PRODS STK TRIP P RIH thru window,clean. 7,850.0 8,448.0 11:00 11:15 Page 13/15 Report Printed: 12/31/2015 operations Summary (with Timelogipths) 0 3A-03 conocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 12/4/2015 12/4/2015 4.25 PRODS STK KOST P 8448 ft.dry tag TOB at 8448 ft,PUH 8,448.0 8,485.0 11:15 15:30 bring pump on 1.42 bpm at 3650 psi FS,BHP 3834,WHP 151, IA 124,OA 415 12/4/2015 12/4/2015 0.25 PROD5 STK REAM P 8485 ft,PUH to 8430 ft.and dry drift 8,485.0 8,485.0 15:30 15:45 kickoff area clean 12/4/2015 12/4/2015 2.25 PROD5 DRILL DRLG P 8485 ft.BOBD 1.4 bpm at 3400 psi 8,485.0 8,648.0 15:45 18:00 FS, BHP 3895,WHP 217,IA 155,OA 443 Mud swap,new mud at bit at 8494 ft. 12/4/2015 12/5/2015 6.00 PRODS DRILL DRLG P 8648 ft.Continue drilling lateral. 1.4 8,648.0 8,885.0 18:00 00:00 BPM at 3,600 FS,BHP 3,890,WHP 380. IA=225,OA=511. Losses observed at-4 BPH from 8836 ft. 12/5/2015 12/5/2015 0.10 PROD5 DRILL DRLG P Drilling to wiper trip depth of 8890 ft. 8,885.0 8,890.0 00:00 00:06 12/5/2015 12/5/2015 1.00 PROD5 DRILL TRIP P 8890 ft.Wiper trip above the window 8,890.0 7,843.0 00:06 01:06 into the 5-1/2"tubing. 12/5/2015 12/5/2015 0.10 PROD5 DRILL WPRT P 7843 ft.Perform friction pressure 7,843.0 7,843.0 01:06 01:12 verification test.Pump 1.6 BPM holding 12.0 ppg(3,788psi)at the window.WHP=320 psi. Calculated friction pressure for this mud system is 68psi/1000'. 12/5/2015 12/5/2015 0.10 PROD5 DRILL WPRT P Run back in hole. 7,843.0 7,890.0 01:12 01:18 12/5/2015 12/5/2015 0.10 PROD5 DRILL DLOG P Tie into to RA tag for a+2'correction. 7,890.0 7,910.0 01:18 01:24 12/5/2015 12/5/2015 0.60 PROD5 DRILL WPRT P 7910 ft.Conintue RIH. 7,910.0 8,890.0 01:24 02:00 12/5/2015 12/5/2015 7.50 PROD5 DRILL DRLG P 8890 ft. Continue drilling ahead with 8,890.0 9,290.0 02:00 09:30 1.45 BPM at 4232 psi FS,3935 psi BHP,350 psi WHP. 12/5/2015 12/5/2015 0.50 PROD5 DRILL WPRT P 9290 ft,wiper up hole PUW 30 k, 9,290.0 8,500.0 09:30 10:00 12/5/2015 12/5/2015 0.50 PRODS DRILL WPRT P 8500 ft,wiper back in hole,RIW 11 k 8,500.0 9,290.0 10:00 10:30 12/5/2015 12/5/2015 6.00 PROD5 DRILL DRLG P 9290 ft,BOBD 1.45 bpm at 3730 psi 9,290.0 9,602.0 10:30 16:30 FS,BHP 3980,WHP 350, IA 317,OA 582 Call TD at 9602 ft. 12/5/2015 12/5/2015 5.00 PRODS DRILL WPRT P 9602 ft,TD L2-01 lateral,pump 10x10 9,602.0 72.0 16:30 21:30 sweep and chase to window. Continue wiper to the swabs. Open EDC at 3120 ft. 12/5/2015 12/5/2015 1.50 PRODS DRILL WPRT P 72 ft.Run back in hole. Tie in to K1 72.0 9,602.0 21:30 23:00 for a-14.5'correction.Close EDC at 7670 ft.Tag bottom and confirm TD at 9602 ft. 12/5/2015 12/6/2015 1.00 PROD5 DRILL TRIP P POOH pumping 12.0 ppg completion 9,602.0 9,590.0 23:00 00:00 fluid with Alpine beads. 12/6/2015 12/6/2015 1.25 PRODS DRILL TRIP P Continue POOH pumping 37 bbls 9,590.0 72.0 00:00 01:15 beaded liner pill followed by 12.0 ppg NaCI completion fluid. 12/6/2015 12/6/2015 0.50 PRODS DRILL OWFF P Observe well for flow.Well is static. 72.0 72.0 01:15 01:45 12/6/2015 12/6/2015 0.75 PRODS DRILL PULD P PJSM and LD lateral drilling BHA 18. 72.0 0.0 01:45 02:30 Page 14/15 Report Printed: 12/31/2015 0 Aerations Summary (with Timelog�pths) 3A-03 Conoco hiH ps Rt:rk. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/6/2015 12/6/2015 2.20 COMPZ5 CASING PUTB P PJSM, PU/MU L2-01 liner assembly 0.0 1,746.0 02:30 04:42 with slotted liner. 12/6/2015 12/6/2015 0.80 COMPZ5 CASING PUTB P PJSM,PU/MU Coiltrak tools,and MU 1,746.0 1,790.2 04:42 05:30 INJH 12/6/2015 12/6/2015 1.75 COMPZ5 CASING RUNL P RIH,with L2-01 slotted liner 1,790.2 7,806.0 05:30 07:15 completion with 56 jts of slotted liner, non-ported bull noze,and shorty deployment sleeve. 12/6/2015 12/6/2015 0.75 COMPZ5 CASING RUNL P Correct to 6000 ft,EOP flag, 7,806.0 9,360.0 07:15 08:00 correction of minus 16.0 ft.PUW 37 k, Continue RIH 12/6/2015 12/6/2015 0.25 COMPZ5 CASING RUNL P Log GR tie in at the K1 marker, 9,360.0 9,360.0 08:00 08:15 correction of+0.5 ft. 12/6/2015 12/6/2015 0.50 COMPZ5 CASING RUNL P Continue RIH 9,360.0 9,600.0 08:15 08:45 12/6/2015 12/6/2015 0.25 COMPZ5 CASING RUNL P 9600 ft,Tag bottom,PUW 37 K,set 9,600.0 9,600.0 08:45 09:00 back down 3.5 k,bring on pump 1.3 bpm at 4100 psi,0.8 bpm returns, PUW 26 k,remove liner from counters 12/6/2015 12/6/2015 2.50 COMPZ5 CASING DISP P Displace well to SW, 9,600.0 2,500.0 09:00 11:30 12/6/2015 12/6/2015 1.50 COMPZ5 CASING FRZP P PJSM,Little Red on locatoin,RU/PT 2,500.0 44.2 11:30 13:00 lines,fill with with 30 bbls of diesel, freeze protect well from 2500 ft. 12/6/2015 12/6/2015 1.50 COMPZ5 CASING RURD P PJSM,Undeploy setting tools.BHA# 44.2 0.0 13:00 14:30 19 12/6/2015 12/6/2015 3.50 DEMOB WHDBOP RURD P Flush all surface lines and coil with 0.0 0.0 14:30 18:00 inhibited water. 12/6/2015 12/6/2015 1.00 DEMOB WHDBOP RURD P Line up valves.PJSM.PU and MU 0.0 0.0 18:00 19:00 FMC lubricator and BPV.PT lubricator to 1800 psi,leak observed at BOP door seals. 12/6/2015 12/6/2015 1.00 DEMOB WHDBOP RURD T Repair door seal on upper 2-3/8"ram. 0.0 0.0 19:00 20:00 1 hr Nabors NPT for door seal repair. 12/6/2015 12/6/2015 1.50 DEMOB WHDBOP RURD P MU FMC lubricator and pressure test 0.0 0.0 20:00 21:30 to 1800 psi.Set BPV. RD FMC lubricator and LD tools. 12/6/2015 12/7/2015 2.50 DEMOB WHDBOP RURD P Blow down injector and surface lines. 0.0 0.0 21:30 00:00 Begin working rig down checklist. 12/7/2015 12/7/2015 3.00 DEMOB WHDBOP RURD P Continue R/D check list,Nipple down 0.0 0.0 00:00 03:00 stack,Check tree bolts,4 loose on flange between SSV and master. RIG RELEASE 03:00 Page 15/15 Report Printed: 12/31/2015 i S ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3A Pad 3A-03BL2-01 50-029-21432-64 Baker Hughes INTEQ BAKER Definitive Survey Report HUGHES 07 December,2015 0 • COtIOG lw".. ConocoPhillips y(l l Definitive Survey Report MAMNIS Company: 1Ii' ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-03 Project: Kuparuk River Unit TVD Reference: 3A-03B:@ 68.60usft(3A-03B) Site: Kuparuk 3A Pad MD Reference: 3A-03B:@ 68.60usft(3A-03B) Well: 3A-03 North Reference: True i Wellbore: 3A-03 Survey Calculation Method: Minimum Curvature Design: 3A-03 Database: EDM Alaska ANC Prod i Project Kuparuk River Unit,North Slope Alaska,United States 11 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 '''''''',11:','1',1,111,111'41.,-, A:Al' : 1,121'L,(t,t Well Position +N/-S 0.00 usft Northing: 5,996,908.32usft Latitude: 70"24'9.995 N +EI-W 0.00 usft Easting: 507,699.06usft Longitude: 149°56'14.397 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft w -......... _ .w ...-......__.... ......... ........ elbore 3A 038L2 Ot ®, � 11 I ) 1 � dli , h - . _ P,` ( � g �ti r� I 7� i it Magnetics Model Name i � �1 e Dat* [ .. 0 S, � � r f1,10 Strength 111,111 �„ Ili,dI ''„ 11, �_- i!1atii:1i hh 1((.I 1(I11�I,1 :d',W1 o� — TI'1, E _ r r i{ii 1,d''lli,il°ia,l'1111:111416;:,11- 141i 1; �11 BGGM2015 12/1/2015 18.61 81.00 57,492 Design..... 3A-036L2-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,425 78 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction i �k11rq (usft) (usft) (usft) 1°) 11111�1,1 ,. +,:11x1 �i,1j1, 28.00 0.00 0.00 315.00 Survey Program Date From To '11P'111111,' Survey Survey (usft) (usft( Survey(Wellbore) r Tool Name Description Start Date End Date 96.60 3,996.60 3A-03(3A-03) GCT-MS Schlumberger GCT multishot 8/31/2000 4,104.00 7,766.19 3A-03B IIFR+MS+SAG(3A-03B) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/12/2007 7,860.00 8,425.78 3A-03BL2(3A-03BL2) MWD MWD-Standard 11/29/2015 12/3/2015 8,447.00 9,560.32 3A-03BL2-01(3A-038L2-01) MWD MWD-Standard 12/4/2015 12/6/2015 12/72015 1:44:33PM Page 2 COMPASS 5000.1 Build 74 • • 1.- ConocoPhillips MINI ConocoPhillips Definitive Survey Report ��. . f. .,,�,':, --..... W, „,. m .,� _. ..: <. ...��... _: a ..�. .ter � ,. i (�tr�t IU yx .. '+-�5 4� Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-03 >i t.Project: Kuparuk River Unit TVD Reference: 3A-03B:@ 68.60usft(3A-03B) Site: Kuparuk 3A Pad MD Reference: 3A-03B:@ 68.60usft(3A-03B) -[ " I Well: 3A-03 North Reference: True '.Wellbore: 3A-03 Survey Calculation Method: Minimum Curvature [[ Design: 3A-03 Database: EDM Alaska ANC Prod Survey...._ Map Map Vertical MD Inc Azi TVD TVDSS +N/-5 +E/-W Northing Easting DLS Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) 8,42578 98.86 285.90 6,16066 6,092.06 -4,86746 -202.34 5,992,041 14 507,501 76 14.52 -3,298.74 MWD(3) TIP 8,447.00 96.68 286.78 6,157.79 6,089.19 -4,861.54 -222.51 5,992,047.04 507,481 58 11.06 -3,280.29 MWD(4) KOP 8,480.32 100.16 292.69 6,152.91 6,084.31 -4,850.43 -253.52 5,992,058.12 507,450.56 20.42 -3,250.50 MWD(4) 8,510.40 101.43 298.09 6,147.27 6,078.67 -4,837.76 -280.20 5,992,070.75 507,423.87 18.13 -3,22268 MWD(4) 8,540.38 101.85 303.96 6,141.22 6,072.62 -4,822.64 -305.36 5,992,085.85 507,398.70 19.23 -3,194.20 MWD(4) 8,570.36 100.04 308.88 6,135.52 6,066.92 -4,805.17 -329.03 5,992,103.30 507,375.01 17.21 -3,165.11 MWD(4) 8,600.17 98.25 313.97 6,130.78 6,062.18 -4,785.70 -351.09 5,992,122.74 507,352.94 17.89 -3,135.74 MWD(4) 8,630.29 97.48 319.69 6,126.66 6,058.06 -4,763.95 -371.49 5,992,144.47 507,332.52 18.98 -3,105.94 MWD(4) 8,660.25 97.42 324.80 6,122.77 6,054.17 -4,740.47 -389.67 5,992,167.93 507,314.31 16.91 -3,076.48 MWD(4) 8,690.34 97.85 330.01 6,118.77 6,050.17 -4,715.35 -405.73 5,992,193.03 507,298.23 17.22 -3,047.36 MWD(4) 8,720.24 97.51 329.05 6,114.77 6,046.17 -4,689.81 -420.76 5,992,218.55 507,283.17 3.38 -3,018.68 MWD(4) 8,750.27 97.92 323.87 6,110.74 6,042.14 -4,665.02 -437.20 5,992,243.32 507,266.72 17.15 -2,989.52 MWD(4) 8,780.34 96.96 319.60 6,106.84 6,03824 -4,641.61 -455.66 5,992,266.70 507,248.23 14.44 -2,959.92 MWD(4) 8,810.07 95.08 316.60 6,103.72 6,035.12 -4,619.61 -475.40 5,992,288.68 507,228.47 11.86 -2,930.40 MWD(4) 8,840.34 94.00 319.39 6,101.33 6,032.73 -4,597.19 -495.59 5,992,311.08 507,208.26 9.86 -2,900.27 MWD(4) 8,870.34 93.57 325.19 6,099.35 6,030.75 -4,573.52 -513.89 5,992,334.73 507,189.93 19.34 -2,870.59 MWD(4) 8,90026 90.06 327.60 6,098.40 6,029.80 -4,548.62 -530.44 5,992,359.61 507,173.36 14.23 -2,841.28 MWD(4) 8,930.34 89.57 332.77 6,098.50 6,029.90 -4,522.53 -545.39 5,992,385.69 507,158.38 17.26 -2,812.26 MWD(4) 8,960.42 88.04 336.67 6,099.12 6,030.52 -4,495.34 -558.23 5,992,412.86 507,145.52 13.92 -2,783.96 MWD(4) 8,990.48 89.23 341.35 6,099.84 6,031.24 -4,467.29 -568.99 5,992,440.89 507,134.73 16.06 -2,756.51 MWD(4) 8,018.14 88.34 345.11 6,100.43 6,031.83 -4,440.82 -576.97 5,992,467.35 507,126.72 13.97 -2,732.15 MWD(4) 9,050.46 88.37 348.75 6,101.35 6,032.75 -4,409.35 -584.27 5,992,498.81 507,119.39 11.26 -2,704.74 MWD(4) 9,080.34 89.23 353.48 6,101.98 6,033.38 -4,379.85 -588.89 5,992,528.31 507,114.75 16.09 -2,680.61 MWD(4) 8,110.32 88.86 357.77 6,102.48 6,033.88 -4,349.97 -591.17 5,992,558.18 507,112.43 14.36 -2,657.87 MWD(4) 9,140.53 89.36 3.71 6,102.95 6,034.35 -4,319.78 590.78 5,992,588.37 507,112.79 19.73 -2,636.80 MWD(4) 9,171.32 88.65 7.26 6,103.49 6,034.89 -4,289.14 -587.84 5,992,619.01 507,115.70 11.76 -2,617.21 MWD(4) 9,200 26 88.74 11.80 6,104.14 6,035.54 -4,260.61 583.05 5,992,647.54 507,120.46 15.69 -2,600.43 MWD(4) 9,230.32 88.46 17.10 6,104.88 6,036.28 -4,231.52 -575.55 5,992,676.63 507,127.92 17.65 -2,585.16 MWD(4) 9,260.29 87.54 21.67 6,105.93 6,037.33 -4,203.27 -565.62 5,992,704.88 507,137.83 15.55 -2,572.21 MWD(4) 9,290.36 68.50 26.12 6,106.97 6,038.37 -4,175.81 -553.45 5,992,732.36 507,149 97 15.13 -2,561.39 MWD(4) 12/72015 1:44:33PM Page 3 COMPASS 5000.1 Build 74 • • ✓ ConocoPhillips Will ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-03 Project: Kuparuk River Unit TVD Reference: 3A-03B:@ 68.60usft(3A-03B:) Site: Kuparuk 3A Pad MD Reference: 3A-03B:@ 68.60usft(3A-03B:) Well: 3A-03 North Reference: True Wellbore: 3A-03 Survey Calculation Method: Minimum Curvature Design: 3A-03 Database: EDM Alaska ANC Prod Sala:sIr/i i:l: 'olrmoriolvttai@i/II rrr. .1u.z Survey _- ...a- °°c �o- rift III ' I':Ili lil iii'l l'41,114411Fir I- , I IrklililiVIIIIV'l MD Inc Azi ND TVDSS ON/-S +E/-W Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100) Section Survey Tool Name Annotation (ft) (ft) (ft) 9,32042 88.40 2028 6,107.78 6,039.18 -4,148.20 -541.61 5,992759.98 507,16177 19.42 -255024 MWD(4) 9,350.44 89.17 15.03 6,108.42 6,039.82 -4,119.61 -532.51 5,992,788.58 507,17084 17.67 -2,536.46 MWD(4) 9,380.18 90.15 11.04 6,108.59 6,039.99 -4,090.64 -525.81 5,992,817.55 507,177.52 1381 -2,520.72 MWD(4) 9,410.31 88.40 5.60 6,108.97 6,040.37 -4,060.84 -521.45 5,992,847.35 507,181.85 18.96 -2,502.73 MWD(4) 9,440.36 88.46 0.82 6,109.80 6,041.20 -4,030.86 -519.77 5,992,877.33 507,183.50 15.90 -2,482.72 MWD(4) 9,470.41 89.57 1.02 6,110 31 6,041.71 -4,000.82 -519.29 5,992,907.37 507,183.95 3.75 -2,461.82 MWD(4) 9,500.15 88.89 5.80 6,110.71 6,042.11 -3,971.14 -517.52 5,992,937.04 507,185.68 16.23 -2,442.08 MWD(4) 9,530.27 88.09 10.52 6,111.51 6,042.91 -3,941.35 513.25 5,992,966.84 507,189.93 15.89 -2,424.03 MWD(4) 9,560.32 83.44 11.77 6,113.73 6,045.13 -3,911.95 -507.46 5,992,996.24 507,195.69 16.02 -2,407.34 MWD(4) 9,602.00 83.44 11.77 6,118.49 6,049.89 -3,871.42 -499.01 5,993,036.78 507,204.09 0.00 -2,384.65 PROJECTED to TD 12/72015 1:44:33PM Page 4 COMPASS 5000.1 Build 74 • • Letter of Transmittal OG CC BAKER Date: DATA LOGGED , December 16, 2015 M.K.BENDER HUGHES 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): 3A-03BL1 2151680 KRU 3A-03BL1 26556 3A-03BL1-01 2151690 KRU 3A-03BL1-01 26557 3A-03BL1-02 2151700 KRU 3A-03BL1-02 26558 3A-03BL2 2151710 KRU 3A-03BL2 26559 3A-03BL2-01 2151720 KRU 3A-03BL2-01 26560 (5) 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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N N y O CV L of rift • • THE STATE Alaska Oil and Gas of TT � Conservation Commission - L i • x _ y _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F 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 3A-03BL2-01 ConocoPhillips Alaska, Inc. Permit No: 215-172 Surface Location: 527' FSL, 749' FEL, SEC. 7, T12N, R9E, UM Bottomhole Location: 1904' FSL, 1248' FEL, SEC. 18, T12N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 207-131, API No. 50-029- 21432-02-00. 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 . Foerster Chair DATED this tay of October, 2015. S111 RECEIVED STATE OF ALASKA SEP 1 8 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 Ell' Service-Winj ❑ Single Zone Q• ic.Specify if well is proposed for: Drill ❑ -Lateral E. Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry I 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 3A-03BL2-01 , 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:9675' • TVD: 6066' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:527'FSL,749'FEL,Sec.7,T12N,R9E, UM • ADL 25631,25632- Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1223'FSL,652'FEL,Sec. 18,T12N, R9E, UM 2564,2565 11/15/2015 Total Depth: 9.Acres in Property: 1145 14.Distance to 1904'FSL, 1248'FEL,Sec. 18,T12N, R9E, UM - 2 Sj Nearest Property: 14083' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 69 feet 15.Distance to Nearest Well Open Surface:x- 507699 y- 5996908 Zone- 4- GL Elevation above MSL: 41 feet to Same Pool: 3F-13B,256' 16.Deviated wells: Kickoff depth: • 8100 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: , 104° deg Downhole:4440 psig . Surface:3831 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 1825' 7850' 5995' 9675' 6066' 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) 8285' 6444' none 8164' 6337' 7800' Casing Length Size Cement Volume MD TVD Conductor/Structural 106' 16" 187sx AS II 106' 106' Surface 3888' 9.625" 1200 sx AS III,320 sx CIG 3888' 3098' Production 4104' 7" 425 sx CI G,250 sx CI G 4104' 3240' Scab Liner 4372' 5.5" 79 sx LiteCRETE, 125 sx 8285' 6444' Class G w/GasBLOK Perforation Depth MD(ft): Perforation Depth TVD(ft): 7930'-7995' 6132'-6189' 20.Attachments: Property Plat ❑ BOP Sketch❑ Drilling Prograrr Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑J 20 AAC 25.050 requirements ❑ 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact ason Burke @ 265-6097 _ Email Jason.Burkei cop.com Printed Name D. Venha S Title CTD Engineering Supervisor Signature ' Z;1-1r1- 4jy/ Phone:263-4372 Date 7 //7'45 Commission Use Only Permit to Drill API Number: Permit Approval/ / See cover letter • Number: at5- /�z ♦�50- 3— j'j32.-6y_W I Date: /01 '3('6 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed, bane,,gas hydrates,or gas contained in shales: d Other: SOP rt5 74- 11a 41 db fins/:9 Samples req'd: Yes ❑ No [✓ Mud log req'd: Yes❑ No[✓� ft»nvl et fr-prt r/fv1 I-t r"f t5'-to 2-5-UUr(-142-.1 measures: Yes V. No V Directional svy req'd: Yes[" No Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No APPROVED BY THE Approved by /-0 �0 IS I N R*tom COMMISSION Date: /0—l —l SFor 10-401 (Rev' ed 10/2012) TOpRtls d oN the date of approval(20 AAC 25.005(g)) <02.5/3"" /'7/7 z// • • ConocoPhillips Alaska RECEIVED P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 SEP 1 8 2015 September 14, 2015, 2015 AOGCC 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 applications for permits to drill a penta-lateral out of the KRU 3A-03B using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin late November 2015. The CTD objective will be to drill five laterals(3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01), targeting the Kuparuk A- sand intervals. Note the current A sand perforations will be open below the whipstock. Attached to this application are the following documents: — Permit to Drill Application Forms(10-401)for 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 — Detailed Summary of Operations — Directional Plans for 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at 907-263-6097. Sincerely, as. r e Coiled Tubing Drilling Engineer • • I Kuparuk CTD Laterals NAdpRKA$KA 03A-03BLI, BLI-01, BLI-02, BL2 & BL2-01 IJ ConacPhilLps Application for Permit to Drill Document 2 1 I C 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 MC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 MC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 MC 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 MC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 MC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 MC 25.005(c)(9)) 4 10. Seismic Analysis - • 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 7 Attachment 1: Directional Plans for 3A-03BL1, BL1-01, BL1-02, BL2&BL2-01 7 Attachment 2: Current Well Schematic for 3A-03B 7 Attachment 3: Proposed Well Schematic for 3A-03BL1, BL1-01, BL1-02, BL2&BL2-01 7 Page 1 of 7 June 30, 2015 ! ! PTD Application: 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01. All laterals will be classified as "Development—Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01. 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 4100 psi. Using the maximum formation pressure in the area of 4440 psi in 3F-13A(i.e. 14.2 ppg EMW), the maximum potential surface pressure in 3A-03B, assuming a gas gradient of 0.1 psi/ft, would be 3831 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)) The formation pressure in KRU 3A-03B was measured to be 3135 psi (9.5 ppg EMW) on 8/28/2014. The maximum downhole pressure in the 3A-03B vicinity is to the southwest in the 3F-13A injector at 4440 psi (14.2 ppg EMW)from June 2012. Due to a large fault between the 3F-13A and the 3A-03B, that high pressure is not • expected during operations. The southern BL1 and BL1-01 laterals will cross a major E-W fault that could encounter formation pressure as high as 11.5 ppg, which is what was measured in 3F-19A in November of 2014. The western L2 and L2-01 laterals will be into an unproduced block with an expected pressure of—9.2 ppg. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Offset injection wells to 3A-03B are under active MI gas injection. However the active well is behind a sealing fault so there is a low probability of encountering free gas while drilling the 3A-03B laterals. Nevertheless, if significant gas is detected in the returns, the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected risk of hole problems are 2 large fault crossings. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3A-03B laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 August 10, 2015 • S PTD Application: 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 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 3A-03BL1 8550' 10700' 6089' 6022' 23/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3A-03BL1-01 7965' 10700' 6037' 5991' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3A-03BL1-02 7885' 9050' 6015' 6089' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top 3A-03BL2 8100' 9650' 6118' 6107' 23/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3A-03BL2-01 7850' 9675' 5995' 6066' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 31' 106' 0' 106' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 31' 3881' 0' 3096' 3520 2020 Production 7" 26.0 J-55 BTC 24' 4250' 0' 3329' 4980 4330 Liner 5-1/2" 15.5 L-80 Hyd 511 3912' 8285' 3112' 6444' 7000 4990 Tubing 3-1/2" 9.3 L-80 IBTM 24' 7723' 0' 5953' 10160 10530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) • Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based FloVis mud (9.1 ppg) — Drilling operations: Chloride-based FloVis mud (9.1 ppg).' This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over-balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". Page 3 of 7 August 10,2015 • • PTD Application: 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 In the 3A-03B laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. 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 3A-03B Window(7890' MD, 6083'TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (9.5ppg) 3012 psi 3012 psi Mud Hydrostatic(9.1 ppg) 2885 psi 2885 psi Annular friction (i.e. ECD, 0.090 psi/ft) 710 psi 0 psi Mud+ECD Combined 3595 psi 2885 psi (no choke pressure) (overbalanced (underbalanced —583 psi) —127 psi) Target BHP at Window(11.8 ppg) 3741 psi 3741 psi Choke Pressure Required to Maintain Target BHP 146 psi 856 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 for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3A-03B is a Kuparuk A-sand production well equipped with 3V2"tubing and 5 '/2"liner. Five laterals will be drilled to the south, east and northwest of the parent well with the laterals targeting the A2 and A3 sands. A thru-tubing whip-stock has already been set inside the 5V2"liner at the planned kickoff point of 7890' MD to drill the first 3 laterals. An additional whip-stock will be set and window milled at 7860' MD to drill the final 2 laterals. The 3A-03BL 1 southern lateral will exit through the 5'/2"liner at 7890' MD and TD at 10,700' MD, targeting the A2 sand. It will be completed with 2%"slotted liner from TD up to 8550' MD with an aluminum billet for kicking off the 3A-03BL1-01 lateral. Page 4 of 7 August 10,2015 • i PTD Application: 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 The 3A-03BL1-0l will drill south to a TD of 10700' MD targeting the A3 sand. It will be completed with 2%"slotted liner from TD up to 7965' MD with an aluminum billet for kicking off the 3A-03BL1-02 lateral. The 3A-03BL1-02 will turn east and drill to a TD of 9050' MD targeting both the A2 and A3 sands. It will be completed with 2%"slotted liner from TD up to 7885' MD,back into the 5 '/2"liner and completed with a deployment sleeve. The 3A-03BL2 northwestern lateral will exit through the 5'h"liner at 7860'MD and TD at 9650' MD, targeting the A2 sand. It will be completed with 2%"slotted liner from TD up to 8100' MD with an aluminum billet for kicking off the 3A-03BL2-01 lateral. The 3A-03BL2-02 will drill northwest to a TD of 9675' MD targeting the A3 sand. It will be completed with 2%"slotted liner from TD up to 7855' MD,back into the 5 'A"liner and completed with a deployment sleeve. Pre-CTD Work 1. RU Slickline:Dummy all gas lift valves and obtain an A-sand SBHP, drift a dummy whip-stock to TD. 2. RU E-line: Set Baker Hughes 3%2"x 5'h"thru-tubing whip-stock at 7890' MD 3. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3A-03BL1 Lateral(A2 sand south) a. Mill 2.74"window at 7890' MD. b. Drill 3"bi-center lateral to TD of 10700' MD. c. Run 2%"slotted liner with an aluminum billet from TD up to 8550' MD. 3. 3A-03BL1-01 Lateral(A3 sand south) a. Kick off of the aluminum billet at 8550' MD. b. Drill 3"bi-center lateral to TD of 10700' MD. c. Run 2%"slotted liner from TD up to 7965' MD 4. 3A-03BL1-02 Lateral(A2/A3 sand east) a. Kick off of the aluminum billet at 7965' MD. b. Drill 3"bi-center lateral to TD of 9050' MD. c. Run 2%"slotted liner from TD back into the liner at 7885' MD 5. 3A-03BL2 Lateral(A2 sand northwest) a. Mill 2.74"window at 7890' MD. b. Drill 3"bi-center lateral to TD of 10700' MD. c. Run 2%"slotted liner with an aluminum billet from TD up to 8550' MD. 6. 3A-03BL2-01 Lateral(A3 sand northwest) a. Kick off of the aluminum billet at 8550' MD. b. Drill 3"bi-center lateral to TD of 9675' MD. c. Run 2%"slotted liner from TD back into the liner at 7855' MD Page 5 of 7 August 10, 2015 r • PTD Application: 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 7. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's and return to production. 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. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick line lubricator. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slick line. — 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 un-deployment, the steps listed above are observed, only in reverse. Liner Running — The 3A-03B laterals will be displaced to an overbalancing fluid (11.8 ppg NaBr) prior to running liner. See "Drilling Fluids"section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 August 10,2015 • S PTD Application: 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 3A-03BL1 14605' 3A-03BL1-01 14605' 3A-03BL1-02 14741' 3A-03BL2 14031' 3A-03BL2-01 14083' — Distance to Nearest Well within Pool Lateral Name Distance Well 3A-03BL1 153' 3F-19 3A-03BL1-01 193' 3F-19 3A-03BL1-02 980' 3F-13 3A-03BL2 180' 3F-13B 3A-03BL2-01 256' 3F-13B 16. Attachments Attachment 1: Directional Plans for 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 Attachment 2: Current Well Schematic for 3A-03B Attachment 3: Proposed Well Schematic for 3A-03BL1, BL1-01, BL1-02, BL2 & BL2-01 Page 7 of 7 August 10, 2015 • i Loepp, Victoria T (DOA) From: Burke,Jason <Jason.Burke@conocophillips.com> Sent: Tuesday, October 06, 2015 3:22 PM To: Loepp, Victoria T (DOA) Cc: Venhaus, Dan E Subject: RE: KRU 3A-03BL1(PTD 215-168); 3A-03BL1-01(PTD 215-169); 3A-03BL2(PTD 215-171); 3A-03BL2-01(PTD 215-172)Anti-collision Follow Up Flag: Follow up Flag Status: Flagged Victoria, Here is the analysis of each 1/10 minor risked wellbore Kuparuk 3F Pad 3F-07-3F-07-3F-07 3F-13- Plan 3F-13B-3F-13B(wp01) 8,700.00 8,825.00 863.50 3F-19-3F-19-3F-19 9,700.00 8,000.00 193.59 3F-19-3F-19A-3F-19A 9,300.00 8,125.00 343.20 3F-21 -3F-21 -3F-21 3F-19 • Is an abandoned well bore • The 3F-19 was abandoned and sidetracked back in 2002 • The original 5.5" casing was cemented in place with 250 sxs Class G cement • For the sidetrack a CIBP was set at 7000' MD and a plug of 168 sxs of 17.0 ppg class G was set from 3615'— 4435' MD Kuparuk 3F Pad 3F-13-3F-13A-3F-13A 8,813.26 9,350.00 895.24 3F-13- Plan 3F-13B-3F-13B(wp01) 9,241.75 9,925.00 180.04 3F-13B • Is for a well that was planned but never drilled Please let me know if this is the information you require. Thanks ConocoPhillips ' „,..',15,„ KUP PROD • 3A-03B ConocoPhillipsY Well Attributes Max Angle&MD TD Alaska,IncWelibore Lrxn'tuIDFs API/0W] Field Name Well bore Status Incl r) MD(ftKB) Act Btm(ftKB) ['7 500292143202 KUPARUK RIVER UNIT PROD 54.38 4,161.12 9,735.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-036,11/1320137:12:32 PM SSSV:TR DP 125 11/22/2010 Last WO: 2/14/2008 35.29 9/16/1985 Verocal schematic tactual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8.069.0 11/6/2013 Rev Reason:TAG lehallf 11/13/2013 Casing Strings Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WhLen(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 106.0 106.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NO),..Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 30.6 3,888.1 3,096.7 36.00 J-55 BTC Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOW B 8 7.000 4,107.0 4,117.0 3,249.1 26.00 J-55 CasingDescription OD(In) ID HANGER;24.2 p (in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...W1/Len(I...Grade Top Thread PRODUCTION POST 7 6.276 24.0 4,250.0 3,329.4 26.00 J-55 BTC S/T'B' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)ND)...Wt/Len(I...Grade Top Thread B LINER 5 1/2 4,950 3,912.9 8,285.0 6,443.9 15.50 L-80 Hyd 511 Liner Details ,. j Nominal ID .. ., . . . ., i,e, 1,1 .LLL Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (i) 3,912.9 3,113,0 48.66 PACKER BAKER LINER TOP PACKER 5.500 ^_n"`4 -'A'-,--4 3,923.7 3,120.2 48.66 HANGER HMC LINER HANGER 4.960 CONDUCTOR;31.0-1060-A• A. Tubing Strings TTUBIubing Description IString Ma.1/2..I ID(In)2.992!Top(ftKB) I Set Depth(ft..l Set Depth)ND)(...I Wt(Iblft) !Grade I Top Connection NG 3 242 7,7237 5,9533 9.30 L-80 1BTM SAFETY VLV;2,265.4 ril Completion Details Nominal ID Top(ftKB) Top)ND)(ftKB) Top Incl(') Item Des Corn /n) 24.2 24.2 0.00 HANGER FNC GEN IV TUBING HANGER 3.500 2,265.4 2,013.5 46.88 SAFETY VLV CAMCO TRMAXX-5E SAFETY VALVE WI 2.812"X 2.812 GAS LIFT;3,056.8 PROFILE 7,645.6 5,887.0 32.74 LOCATOR LOCATOR 3.000 7,646.4 5,887.7 32.73 PBR BAKER 80-40 PBR 3.000 7,660.0 5,899.2 32.49 ANCHOR BAKER KBH-22 ANCHOR 2.970 7,660.7 5,899.8 32.48 PACKER BAKER SABL-3 PRODUCTION PACKER 2.760 7,664.9 5,903.3 32.40 XO BUSHING BAKER CROSSOVER BUSHING 2.970 SURFACE;30.6-3,8119.1-. 7,710.5 5,942.0 31.63 NIPPLE HALLIBURTON X NIPPLE 2.750 I i7,7232 5,952.9 31.41 WLEG WIRELINE ENTRY GUIDE 2 750 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 1 F 7,800.0 6,018.8 30.37 FISH SPRING CENTRALIZING SPRING LOST 2/21/2008 2/21/2008 WINDOW B;4,107.0.4,117.0 PRODUCTION POST S/713; Perforations&Slots 24.04,250.0 Shot Dens GAS LIFT;4.018,3 Top(TVD) Btm(ND) (shots/f GAS LIFT;4.618.3-111a Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,930.0 7,975.0 6,131.8 6,171.4 A-1,3A-03B 521/2008 6.0 APERF 2.6"PJ,60 deg phase �-} 7,975.0 7,995.0 6,171.4 6,189.0 A-2,3A-03B 12/24/2007 6.0 IPERF 2.5"HJ,60 deg random l GAS LIFT;6,122.2 ® Stimulations&Treatments �•-i Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) )ftKB) (ftKB) (ftKB) Type Date Corn 7,975.0 7,995.0 6,171.4 6,189.0 A-SAND FRAC 12/28/200 PUMPED 292,767#OF 16/20 CARBOLITE SAND 7 Mandrel Inserts GAS LIFT;7,112.2UE St as C on Top(ND) Valve Latch Port Size TRO Run Na Top(1tK6) (ftKB) Make Model OD(in) Sam Type Type (In) (psi) Run Date m 1 3,056.8 2,546.5 CAMCO KBG-2-9 1 GAS LIFT GLV BK 0.125 1,337.0 7/7/2010 GAS LIFT;7,596.4 2 4,818.3 3,693.9 CAMCO KBG-2-9 1 GAS LIFT GLV BK 0.156 1,345,0 7/7/2010 3 6,122.2 4,698.5 CAMCO KBG-2-9 1 GAS LIFT GLV BK 0.188 1,363.0 7/7/2010 4 7,112.2 5,465.0 CAMCO KBG-2-9 1 GAS LIFT OV BK 0.188 1,342.0 7/6/2010 LOCATOR:7,645.6 it p' 5 7,596.4 5,845.9 CAMCO KBG-2-9 1 GAS LIFT OV BKO-3 0.188 0.0 7/9/2010 PBR;7,646.4 ANCHOR;7,660.0 Notes:General&Safety PACKER;7,660.7 End Date Annotation SO BUSHING;7,664.9 12/17/2000 NOTE:WELL SIDETRACKED TO'A' 11/14/2007 NOTE:WELL SIDETRACKED TO'B',TUBING PULLED FOR SIDETRACK 4/6/2008 NOTE:IA TEST PRESSRE DOWNRATED DUE TO LINER TOP PACKER @ 3898' 3/8/2011 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;7,710.5 WLEG;7,723.2 FISH;7,670.0 .4 APERF;7,930.0.7.975.0 A-SAND FRAC;7,975.0 !P -..2I-' ERF;7.975.0-7,995.0 B LINER;3,5/20.02850 . • a O 0 r o ,- co o n m © o o o v 0 o m m b N -N N- O W 8 O ^ O1 m I- @) CO O d N O 01 >. m m m N N O 0.1 Q O ib m r -o co ,,- o O m N- C0•-•• m v Q — m Lo CO 0 o_ a i0 N id N o r c0 U N N O a toil Q N LC (U t=/1 TP:O _ Q Q C p O C O) M CO OS RI N O>V. 1 i0 II M U 3 0' U) O rQ N ci)M LO c0 N U.I I- N C NOS Q ^ u _ X O m_ N v N (0(p 0 rn 2,0 mN m 0 O) O L U U O t- Crd , L W N. a 0 W W m Q d L- O O°� O p-NM W C U X J U - O N J d 0 CEI H N N CISCam p07Q C Um ai Ur... ''1U= 0 U) X N c cg' N CV (V (V N ' US N N (V Y Y Y Y M M M V1 mm comm M A ,.., o 2 \1 i G a O A" I CD ^ inAi t. n n fr) n ,1. U . I ) I III1Ill O h C — L p O Q M m O J Ca o N. Cn M I �,j) y m 0 m G N Q u S Nm ag D 3 a Q O C m (V 0 M 2 coo0 NI .0 ti n^ `oQ Co Tao CO 0Q,M t0 O in b N O^ T H @J 0 o I-- o o `w m m @ m o pa6Q d — m Fa m m ConocoPhillips NADConversion Kuparuk River Unit Kuparuk 3A Pad 3A-03 3A-03BL2-01 Plan: 3A-03BL2-01_wp02 Standard Planning Report 11 September, 2015 BAKER HUGHES I • yr Baker Hughes INTEQ FGail ConocoPhillips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 3A-03 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-03B:@ 68.60usft(3A-03B) Site: Kuparuk 3A Pad North Reference: True Well: 3A-03 Survey Calculation Method: Minimum Curvature Wellbore: 3A-03BL2-01 Design: 3A-03 B L2-01_wp02 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 3A Pad Site Position: Northing: 5,996,860.05 usft Latitude: 70°24'9.520 N From: Map Easting: 507,712.01 usft Longitude: 149°56'14.019 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.06° Well 3A-03 Well Position +N/-S 0.00 usft Northing: 5,996,908.32 usft Latitude: 70°24'9.995 N +E/-W 0.00 usft Easting: 507,699 06 usft Longitude: 149°56'14.397 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 3A-03BL2-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 12/1/2015 18.61 81.00 57,492 Design 3A-03BL2-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,100.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) -40.60 0.00 0.00 315.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 8,100.00 90.00 198.16 6,117.78 -4,782.35 78.05 0.00 0.00 0.00 0.00 8,170.00 103.70 207.98 6,109.44 -4,846.09 50.99 24.00 19.56 14.04 35.00 8,240.00 103.97 225.29 6,092.58 -4,900.41 10.61 24.00 0.39 24.72 87.00 8,330.00 94.87 245.17 6,077.73 -4,950.55 -61.97 24.00 -10.11 22.09 113.00 8,430 00 94.44 269.25 6,069.49 -4,972.45 -158.45 24.00 -0.42 24.08 90.00 8,610.00 93.58 312.55 6,056.27 -4,909.90 -322.17 24.00 -0.48 24.06 89.50 8,760.00 93.59 327.58 6,046.84 -4,795.45 -418.00 10.00 0.00 10.02 89.50 8,860.00 93.62 337.60 6,040.54 -4,706.96 -463.89 10.00 0.03 10.02 89.50 8,960.00 89.37 346.65 6,037.93 -4,611.94 -494.52 10.00 -4.25 9.06 115.00 9,060.00 87.56 356.49 6,040.61 -4,513.18 -509.16 10.00 -1.80 9.84 100.50 9,210.00 87.64 11.51 6,046.92 -4,364.11 -498.73 10.00 0.06 10.01 90.00 9,310.00 87.54 1.50 6,051.13 -4,264.97 -487.44 10.00 -0.10 -10.01 -90.80 9,410.00 87.58 11.51 6,055.40 -4,165.83 -476.14 10.00 0.04 10.01 90.00 9,675.00 87.83 344.99 6,066.20 -3,903.53 -484.17 10.00 0.10 -10.01 -90.00 9/11/2015 8:06:13AM Page 2 COMPASS 5000.1 Build 74 I 0 r,- Baker Hughes INTEQ ,AI. COIIOCOPhiflipS Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 3A-03 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-03B:@ 68.60usft(3A-03B:) Site: Kuparuk 3A Pad North Reference: True Well: 3A-03 Survey Calculation Method: Minimum Curvature Wellbore: 3A-0 3 B L2-01 Design: 3A-03 B L2-01_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 8,100.00 90.00 198.16 6,117.78 -4,782.35 78.05 -3,436.82 0.00 0.00 5,992,126.53 507,782.03 TIP/KOP 8,170.00 103.70 207.98 6,109.44 -4,846.09 50.99 -3,462.76 24.00 35.00 5,992,062.77 507,755.04 Start 24 dls 8,200.00 103.96 215.39 6,102.26 -4,870.86 35.71 -3,469.46 24.00 87.00 5,992,037.99 507,739.78 8,240.00 103.97 225.29 6,092.58 -4,900.41 10.61 -3,472.61 24.00 88.77 5,992,008.42 507,714.72 3 8,300.00 98.02 238.65 6,081.10 -4,936.53 -35.69 -3,465.42 24.00 113.00 5,991,972.25 507,668.46 8,330.00 94.87 245.17 6,077.73 -4,950.55 -61.97 -3,456.75 24.00 115.56 5,991,958.20 507,642.19 4 8,400.00 94.66 262.03 6,071.88 -4,970.18 -128.65 -3,423.48 24.00 90.00 5,991,938.51 507,575.54 8,430.00 94.44 269.25 6,069.49 -4,972.45 -158.45 -3,404.02 24.00 91.41 5,991,936.20 507,545.75 5 8,500.00 94.40 286.10 6,064.06 -4,963.17 -227.36 -3,348.72 24.00 89.50 5,991,945.41 507,476.83 8,600.00 93.69 310.15 6,056.90 -4,916.50 -314.68 -3,253.97 24.00 90.81 5,991,991.99 507,389.47 8,610.00 93.58 312.55 6,056.27 -4,909.90 -322.17 -3,244.01 24.00 92.53 5,991,998.58 507,381.98 End 24 dls,Start 10 dls 8,700.00 93.61 321.57 6,050.61 -4,844.22 -383.30 -3,154.34 10.00 89.50 5,992,064.19 507,320.79 8,760.00 93.59 327.58 6,046.84 -4,795.45 -418.00 -3,095.32 10.00 90.07 5,992,112.92 507,286.04 7 8,800.00 93.61 331.59 6,044.32 -4,761.03 -438.21 -3,056.70 10.00 89.50 5,992,147.32 507,265.80 8,860.00 93.62 337.60 6,040.54 -4,706.96 -463.89 -3,000.31 10.00 89.75 5,992,201.35 507,240.07 8 8,900.00 91.92 341.22 6,038.60 -4,669.57 -477.93 -2,963.93 10.00 115.00 5,992,238.73 507,225.98 8,960.00 89.37 346.65 6,037.93 -4,611.94 -494.52 -2,911.45 10.00 115.18 5,992,296.33 507,209.34 9 9,000.00 88.64 350.59 6,038.62 -4,572.74 -502.41 -2,878.16 10.00 100.50 5,992,335.52 507,201.41 9,060.00 87.56 356.49 6,040.61 -4,513.18 -509.16 -2,831.27 10.00 100.43 5,992,395.07 507,194.60 10 9,100.00 87.57 0.50 6,042.31 -4,473.24 -510.21 -2,802.29 10.00 90.00 5,992,435.00 507,193.51 9,200.00 87.63 10.51 6,046.51 -4,373.92 -500.64 -2,738.82 10.00 89.83 5,992,534.33 507,202.97 9,210.00 87.64 11.51 6,046.92 -4,364.11 -498.73 -2,733.23 10.00 89.41 5,992,544.14 507,204.87 11 9,300.00 87.55 2.50 6,050.71 -4,274.95 -487.78 -2,677.93 10.00 -90.80 5,992,633.30 507,215.73 9,310.00 87.54 1.50 6,051.13 -4,264.97 -487.44 -2,671.12 10.00 -90.42 5,992,643.28 507,216.07 12 9,400.00 87.57 10.51 6,054.98 -4,175.63 -478.04 -2,614.59 10.00 90.00 5,992,732.61 507,225.37 9,410.00 87.58 11.51 6,055.40 -4,165.83 -476.14 -2,609.01 10.00 89.62 5,992,742.42 507,227.26 13 9,500.00 87.61 2.50 6,059.19 -4,076.67 -465.18 -2,553.71 10.00 -90.00 5,992,831.58 507,238.12 9,600.00 87.71 352.49 6,063.28 -3,976.97 -469.55 -2,480.13 10.00 -89.62 5,992,931.26 507,233.66 9,675.00 87.83 344.99 6,066.20 -3,903.53 -484.17 -2,417.85 10.00 -89.21 5,993,004.69 507,218.96 Planned TD at 9675.00 Casing Points I Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C.) C') 9,675.00 6,066.20 2 3/8" 2-3/8 3 9/11/2015 8:06:13AM Page 3 COMPASS 5000.1 Build 74 0 0 ,,,' Baker Hughes INTEQ Wahl ConocoPhiltips Planning Report BAKER HUGHES Database: OAKEDMP2 Local Co-ordinate Reference: Well 3A-03 Company: NADConversion TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3A-03B:@ 68.60usft(3A-03B:) Site: Kuparuk 3A Pad North Reference: True Well: 3A-03 Survey Calculation Method: Minimum Curvature Wellbore: 3A-03 B L2-01 Design: 3A-03BL2-01_wp02 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,100.00 6,117.78 -4,782.35 78.05 TIP/KOP 8,170.00 6,109.44 -4,846.09 50.99 Start 24 dls 8,240.00 6,092.58 -4,900.41 10.61 3 8,330.00 6,077.73 -4,950.55 -61.97 4 8,430.00 6,069.49 -4,972.45 -158.45 5 8,610.00 6,056.27 -4,909.90 -322.17 End 24 dls,Start 10 dls 8,760.00 6,046.84 -4,795.45 -418.00 7 8,860.00 6,040.54 -4,706.96 -463.89 8 8,960.00 6,037.93 -4,611.94 -494.52 9 9,060.00 6,040.61 -4,513.18 -509.16 10 9,210.00 6,046.92 -4,364.11 -498.73 11 9,310.00 6,051.13 -4,264.97 -487.44 12 9,410.00 6,055.40 -4,165.83 -476.14 13 9,675.00 6,066.20 -3,903.53 -484.17 Planned TD at 9675.00 • 9/11/2015 8:06:13AM Page 4 COMPASS 5000.1 Build 74 • • • ConocoPhillips K' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3A-03 Project: Kuparuk River Unit TVD Reference: 3A-03B:@ 68.60usft(3A-036:) Reference Site: Kuparuk 3A Pad MD Reference: 3A-038:@ 68.60usft(3A-03B:) Site Error: 0.00 usft North Reference: True Reference Well: 3A-03 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 3A-03BL2-01 Database: EDM Alaska ANC Prod Reference Design: 3A-03BL2-01_wp02 Offset TVD Reference: Offset Datum Reference 3A-038L2-01_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,100.00 to 9,675.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,164.70 usft Error Surface: Elliptical Conic Survey Tool Program Date 9/10/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 96.60 3,996.60 3A-03(3A-03) GCT-MS Schlumberger GCT multishot 4,104.00 7,766.19 3A-03B IIFR+MS+SAG(3A-03B) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,766.19 8,100.00 3A-03BL2_wp02(3A-03BL2) MWD MWD-Standard 8,100.00 9,675.00 3A-03BL2-01_wp02(3A-03BL2-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C) C') 3,884.60 3,094.32 9 5/8" 9-5/8 12-1/4 9,675.00 6,134.80 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 3A Pad 3A-02-3A-02-3A-02 Out of range 3A-03-3A-03-3A-03 8,739.93 8,050.00 39.34 6.56 35.27 Pass-Minor 1/10 3A-03-3A-03A-3A-03A 8,544.78 8,275.00 55.12 0.70 54.59 Pass-Minor 1/10 3A-03-3A-03B-3A-03B 8,100.00 8,275.00 248.93 2.67 248.05 Pass-Minor 1/10 3A-03-3A-03BL1-3A-03BL1_wp08 8,114.85 8,125.00 34.17 1.42 33.03 Pass-Minor 1/10 3A-03-3A-03BL1-01-3A-03BL1-01_wp04 8,114.85 8,125.00 34.17 1.42 33.03 Pass-Minor 1/10 3A-03-3A-038L1-02-3A-03BL1-02_wp04 9,310.00 7,275.00 780.01 3.44 778.97 Pass-Minor 1/10 3A-03-3A-03BL2-3A-03BL2_wp02 8,100.00 8,100.00 0.00 0.28 -0.22 FAIL-Minor 1/10 Kuparuk 3F Pad 3F-13-3F-13A-3F-13A 8,786.89 9,350.00 925.87 243.02 686.90 Pass-Major Risk 3F-13-Plan 3F-13B-3F-13B(wp01) 9,225.78 9,850.00 256.25 2.01 256.02 Pass-Minor 1/10 Offset Design Kuparuk 3A Pad- 3A-03-3A-03-3A-03 Offset site Error: 0.00 usft Survey Program: 100-GCT-MS Rule Assigned:Minor 1/10 Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/S +EI-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) II (usft) (usft) (") (usft) (usft) (waft) 8,610.00 6.124.87 8,390.00 6.378.45 6.27 28.48 171.41 -5,046.93 -471.74 3-3/4 322.09 6.87 315.26 Pass-Minor 1/10 8,615.76 6,124.51 8,375.00 6,366.78 6.27 28.38 172.21 -5,037.63 -470.19 3-3/4 308.33 6.86 301.51 Pass-Minor 1/10 8,623.26 6,124.04 8,350.00 6,347.34 6.27 28.22 173.36 -5,022.14 -467.60 3-3/4 285.49 6.84 278.68 Pass-Minor 1/10 8.631.03 6,123.55 8,325.00 6,327.89 6.27 28.06 174.64 -5,006.65 -465.01 3-3/4 262.75 6.83 255.94 Pass-Minor 1/10 8,639.08 6,123.04 8,300.00 6,308.44 6.28 27.90 176.05 -4,991.15 -462.42 3-3/4 240.12 6.81 233.32 Pass-Minor 1/10 8,650.00 6,122.36 8,275.00 6,288.99 6.28 27.73 177.91 -4,975.66 -459.84 3-3/4 217.63 6.79 210.85 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor.ES-min ellipse separation 9/10/2015 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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: f(p.111/4, 3A - 03,i L a,-.0 PTD: c21S - 17-z /Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: K POOL: k ►_k A X si . r2JV a') 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. 4t?-/31 , API No. 50-'044 -02148 (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. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 0 NI F Co , , N ' CT 0 , a) 0 7 co O w ci_ or 2 c o O @ 0 • Q U' Q' O N' ' (4 O , O' C, E Z 6a c co 0 o' a , 0, �' O) Ly J, C E O ' .0 o' 17 a .0 ti 3 a a c' ate)' 0' = - F' Ty v`' o c' 3 > v. a) 3 a te a : LL W; o' c `� 0. 0-' p' to U' a Mol 3, a a oa E 0 .' U) .0 a)' t -O, Y. N' O' ' -ci' I-- , M' O. i 0 , � a a rn o' 2. d ' �' Z CO �' O' 0' a)' 0. •N' 0' dy Q' Qn' a 4-'C 3 0' v' N 0' S C O m' m 2, Q ° p. Y' 0 0' �, o' c m. 3; �, aCi 00 �, �' �, rai' ar m Y' T 0? m I CO m. 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