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COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE July 2,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE August 5,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION n #OF PRINTS #UI-THIN IS #OF COPIES #OF COPIES #OF COPIES v 1 BP North Slope I 0 0 0 EOA,PBOC,PRB-20(Office 109) 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 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC I 1 I 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 I 1 I 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 1***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I 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 t"-- • • O LO CD N N Wi In IIIall 1 mto Ca N 0- M I C.) 0 _ wain a, i.! 0 0 CO 0 L0. ,L! Q < CO 0) C1 D er Q W y Z CD •� 0- - - - - 0 = •- - s .-P ... 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Q C` 0 N Q r N- -O ^ MMM 2MMMQ CDQMQM MMQQM QMMM COMQQQ Q CN co co MM co co co co coa U)) °- o a. d J J/ U 2 2 Q Q _ C NN Qn rn o tn` o o M m Wn N o NW CN m m o 8 A 2 8 8 8 co a 8 o or p_ p_ N 0 0 coco co a) O) co D CD r ND n O O O rnO O O OO OOO O O OO o J J CN C � WWWmm m W rnrnU YY ZS� O o 4A V CN-O Co N rm M 0 N Cn N N W M CrO 0 m M m M M N Cm m m M CO O cn oC O O O OO O O O O O O O O O 6 0O O O O O O OO O O Om pp O r OMp m N T N Op O M m 0 N N N h O M ? 7 Q < 0.. 0 0 (OCDOD G C T o O O O O O O O rrr .-o co VG .. a CC d co NU 6ryO 0 .. Nm 3 V G. Nn fa U) N 0 m. _, ECES D • STATE OF ALASKA • AUG 0 3 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT A 1 1 CiRc la.Well Status: Oil Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q 1 Exploratory ❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp#0l /«P 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 7/0/2013216-050 r 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 7/4/2016 50-029-22170-60-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 567'FNL, 143'FEL,Sec 31,T11N, R10E, UM 7/6/2016 KRU 1L-24AL1 Top of Productive Interval: 9. Ref Elevations: KB: 130' 17. Field/Pool(s): 1417'FNL, 1160'FEL, Sec 6,T1 ON, R10E, UM GL 87' BF: 87' Kuparuk River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: Plb 4778'FNL,2216'FEL, Sec 31,T11N, R10E, UM 11588'/6105' ADL 25664,t5457 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 539924 y- 5948401 Zone- 4 11609'/6105' ALK 473 TPI: x- 538961 y- 5942266 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 537889 y- 5944180 Zone- 4 N/A 1500'/1442' 5. Directional or Inclination Survey: Yes , Q(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) 8970'/6095' 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16" 62.5 H-40 44' 122' 44' 122' 24" 235 SX AS 1 9-5/8" 36 J-55 43' 5081' 43' 3610' 12-1/4" 750 SX Type E,550 SX G 7" 26 J-55 28' 9241' 28' 6287' 8.5" 250 SX Class G Prem. 2-3/8" 4.6 L-80 8614' 11588' 5888' 6105' 3" Slotted Liner 24.Open to production or injection? Yes Q No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 8655' 8604'/5882' Slotted Liner from: 8614'-11588'/5888'-6105' COMPLETION 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. �DA�TE Was hydraulic fracturing used during completion? Yes❑ No Q __-.�-"-Av Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L L'. _- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 7/18/2016 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 7/20/2016 18 Test Period 396 765 85 176 2134 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 741 967 24-Hour Rate , -► 497 1061 114 23 deg Form 10-407 Revised V rt._ 51 3L / 1 ` �CONTTU'4UED ON PAGE 2 RBDMS AUG - 4 2016 Submit ORIGINIAL on • • 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 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1741 1470 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 8973 6094 information, including reports,per 20 AAC 25.071. TD Kuparuk A Sand 11609 6105 Formation at total depth: Kuparuk A i • 31. List of Attachments: Daily Operations Summary, Definitive Survey,Schematics Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that th- foregoing is rue and correct to the best of my knowledge. Contact: Jason Bu • 265-609,1 Email: Jason.Burke(cilcop.com Printed Name: G. Eller � Title: CTD ENGINEERING SUPR Signature: , Phone: 263-4172 Date: K6 r 1� 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 P OD 1L-24AL1 ConOCOPhiiiips6.,;,:i.1 ,,,,„ ' Well Attribu Max Angle TD Alaska,Inc. a Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) 020rocophilhp$ 500292217060 KUPARUK RIVER UNIT PROD 92.92 10,500.79 11,609.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1L-24AL1,7/29/20168:48;02 AM SSSV: NONE 60 8/2/2015 Last WO: 42.99 5/23/1991 Vertical schematw IbAnim) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADD LATERALS lehallf 7/13/2016 HANGER;39.2 ,....::H�i.ral: Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread AL1 LATERAL LINER 23/8 1.992 8,613.9 11,588.0 6,105.1 4.60 L-80 ST-L *. Liner Details 111 Nominal ID , i Top(ftKB) Top(ND)(ftKB) Top Incl(..) Item Des Com (in) 8,613.9 5,888.4 49.96 SBR SBR-Seal Bore Receptacle 1.992 AR Perforations&Slots Shot .,tib CONDUCTOR,44.0-122.0. -Y\4 r 4.4 '-.. Dens Top(ND) Btm(ND) (shots/ lir Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com GAS LIFT,3,338.6 8,944.0 11,587.0 6,088.6 6,105.1 'A-5,1L-24 7/7/2016 SLOTS Alternating solid/slotted pipe.0125"x 2.5"@ 4 circumberential adjacent 11 rows GAS LIFT,4,994.3 -- SURFACE:43.0-5,081.2-. II 1 GAS LIFT,6,219.9 1 T. 011 GAS LIFT;7,199.4 : 1. 11 11111 11111 GAS LIFT,7,870.9 i - lip it 21 GAS LIFT;8,299.3 4 LOCATOR;8355.3 Eiti SEAL ASSY;8,356.3 -- P06,8,363.4 �I PACKER,8,385.8 'j NIPPLE,8,438.5 4 OVERSHOT;8,456.1 .1:1--I I _ SEAL ASSY,8,476.0 PBR;8,477 3 PACKER;8,491.0 .. i NIPPLE;8,572.5 :-j I SEAL ASSV;8,5896 _- PBR 8,590.9 MI PACKER,8,603.7 Tl ISI NIPPLE;8,621 0 SOS;8,653.6Ai (PERF,0735.0-8,7820- ! I CEMENT SQUEEZE;8,735.0 I ftKB 4p 9 PRODUCTION;28.3-9,2409 AL1-02 LATERAL LINER, + 8,970 2-12,190.0 1 1 SLOTS,8,944.0-11587.0 ' I- AL1 LATERAL LINER;8,613.9- 1 I 11588 0 r • • 1 L-24 CTD Schematic ' odf zed by"KEH 71-11/16 3-1/2"9.3#J-55 EUE Brd Tubing to surface 16"62#H-40 shoe @ — — 3-1/2"Camco MMG gas lift mandrel @ 3339',4994',6220',7200',7871', 122'MD 8299'RKB 9-5/8"36#J-55 shoe @ ME& Baker 80-40 PBR @ 8363'RKB(4.0"ID) 5081'MD —' Baker FHL packer @ 8386'RKB(2.93"ID)MIBP 3-1/2"Camco DS nipple @ 8439'RKB(2.875"min ID) MBOI Baker Poorboy Overshot @ 8456'RKB(3.00"min ID) • Baker 80-40 PBR @ 8477'RKB(2.98"ID) Baker FHL packer @ 8491'RKB(2.93"ID) 3-1/2'Camco DS nipple @ 8573"RKB(8568'PDC)(2.812"min ID) I TIW Seal Assy @ 8590'RKB(3.00"ID) -{T TIW PBR @ 8591'RKB(3.00"ID) I TIW HM-1 Retrievable Packer @ 8604'RKB(8598'PDC) 3-1/2"Camco D nipple @ 8621'RKB(8616'PDC)(2.80"min ID) 3-1/2"SOS @ 8654'RKB(8649'PDC) 2-3/8"Baker Seal Bore Deployment Sleeve at8614'MD C-sand perfs --_ 1 L-24AL1(A5 sand-Northwest) 8735'-8782'MD TD @ 11609'MD TOL at 8614'MD and BOL at 11588'MD 2-3/8"solid liner 8620'-8947'MD 2-3/8"slotted liner 8947'-11588'MD KOP @ 6874'PDC 1 L-24APB7(AS sand-Southeast) A-sand perfs —. ., TD @ 11610'MD 8920'-8949'MD .. 4 �'- Openhole anchor @ 10258'MD 9010'-9029'MD _ 1L-24A(A5 sand-Southeast) 1 L-24AL1-02(AS sand-Southeast) -, TD @ 11690'MD BOL @ 10299 MD 7"26#J-55 shoe @ 9241' TD @ 12259'MD BOL @ 12190'MD Openhole anchor @ 9850'MD MD - Openhole anchor at 8970'MD 1 L-24AL1-02PB1(A5 sand-Southeast) TD @ 12310'MD Openhole anchor @ 10420'MD • i - `` Operations Summary (with Timelog Depths) s ''-t*-'.,;!,,V, 1 L-24 le ConocoPhiilips 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) 6/7/2016 6/7/2016 1.00 MIRU MOVE RURD P Complete rig down check list. 0.0 0.0 00:00 01:00 6/7/2016 6/7/2016 0.50 MIRU MOVE SFTY P PJSM with Peak and Nabors crews. 0.0 0.0 01:00 01:30 6/7/2016 6/7/2016 1.00 MIRU MOVE MOB P Jack up pits and pull away from sub, 0.0 0.0 01:30 02:30 soft pad,trouble with truck,call Peak mechanic,using CAT to assist staging pits 6/7/2016 6/7/2016 2.00 MIRU MOVE MOB T Peak truck broke down backing pits in 0.0 0.0 02:30 04:30 soft pad,wait on mechanic another Peak truck,prep well cellar,fill in ruts on pad with scraper,housekeeping around rig.. 6/7/2016 6/7/2016 1.00 MIRU MOVE MOB P Peak on site.PJSM,move pits back 0.0 0.0 04:30 05:30 further back out of the way.Pull sub from 1L-13A with CAT assist. 6/7/2016 6/7/2016 2.00 MIRU MOVE MOB P Spot sub over 1L-24 with CAT assist, 0.0 0.0 05:30 07:30 lay mats,set down. 6/7/2016 6/7/2016 1.25 MIRU MOVE MOB P Spot Pits with CAT assist 0.0 0.0 07:30 08:45 6/7/2016 6/7/2016 1.25 MIRU MOVE RURD P Perform rig up checklist complete 0.0 0.0 08:45 10:00 6/7/2016 6/7/2016 1.50 MIRU MOVE NUND 'P Nipple up BOPE,change out riser, 0.0 0.0 10:00 11:30 check torque on flange bolts(30 min) good. 6/7/2016 6/7/2016 1.50 MIRU MOVE RURD P Perform pre spud check list,circulate 0.0 0.0 4 11:30 13:00 surface lines,body test BOPE 4,000 psi. Rig Accept at 13:00 on 06/07/2016 6/7/2016 6/7/2016 2.50 MIRU WHDBOP CTOP P Prepand load coil,perform slack 0.0 0.0 13:00 15:30 management,25'until wire found. 6/7/2016 6/8/2016 8.50 MIRU WHDBOP CTOP P Rig up coil tubing cutter,cut 1,480 ft 0.0 0.0 15:30 00:00 coil,pump slack back,no movement, cut additional 20 ft for 1,500 total coil tubing cut.Test cable.LD cutter,clear floors,get RKB's. 6/8/2016 6/8/2016 2.50 MIRU WHDBOP RURD P Fluid pack stack,prep for BOPE test. 0.0 0.0 00:00 02:30 6/8/2016 6/8/2016 3.50 MIRU WHDBOP -BOPE P Perform Initial BOPE test 250/4,000 0.0' 0.0 02:30 06:00 psi,Annular 2,500 psi. Witness waived by AOGCC Guy Cook at 16:53 on 06/07/2016 by phone message. 6/8/2016 6/8/2016 6.00 MIRU WHDBOP BOPE P Crew change,PJSM with rig crew, 0.0 0.0 06:00 12:00 continue testing BOPE. 6/8/2016 6/8/2016 2.50 MIRU WHDBOP BOPE P Simops while testing BOPE, Install 0.0 0.0 12:00 14:30 CTC,pull test 40k,headup BHI upper quick,test a-line good test 6/8/2016 6/8/2016 2.50 MIRU WHDBOP BOPE T Swap failed R1 valve and continue 0.0 0.0 14:30 17:00 testing BOPE "Note: 2.5 hrs of Nabors down time 6/8/2016 6/8/2016 5.50 MIRU WHDBOP PRTS P PJSM-Test inner reel iron,stripper, 0.0 0.0 17:00 22:30 PDL's and TT lines.Test CTC 3,500 psi.RD test equipment • 6/8/2016 6/9/2016 1.50 MIRU WHDBOP MPSP P PJSM-bring in BPV equipment,P/T, 0.0 0.0 22:30 00:00 lubricate out BPV,WHP 50 psi. LD and load out BPV equipment Page 1/27 Report Printed: 7/11/2016 • • Operations Summary (with Timelog Depths) i r.4 tii t 1 L-24 ConocoPhitiips Rig: NABORS CDR2-AC Jobs DRILLING SIDETRACK Time Log Start Depth Operation (ftKB) End Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X O P 6/9/2016 6/9/2016 0.50 SLOT WELLPR SFTY P Pre spud with Luke Jury's crew 0.0 0.0 00:00 00:30 6/9/2016 6/9/2016 1.00 SLOT WELLPR MILL P PJSM-Bleed down well,flow check 30 0.0 0.0 00:30 01:30 minutes. """Note:Flow check pass with no-flow. 6/9/2016 6/9/2016 1.75 PROD1 RPEQPT PULD P PJSM- MU/PU BHA#1 cement pilot 0.0 62.5 01:30 03:15 hole milling assembly with 2.80"go/ 2.79"no-go HCC D331GEB mill. Checks installed,make up to CoilTrak, surface test. 6/9/2016 6/9/2016 2.50 PROD1 RPEQPT TRIP P RIH,pump slack forward,EDC open. 62.5 8,365.0 03:15 05:45 6/9/2016 6/9/2016 0.25 PROD1 RPEQPT DLOG P Log HRZ correction of plus 11.0 ft. 8,365.0 8,414.0 05:45 06:00 PUW 32 k 6/9/2016 6/9/2016 0.50 PROD1 RPEQPT TRIP P Continue IH,tag TOC at 8593 ft. 8,414.0 8,593.0 06:00 06:30 6/9/2016 6/9/2016 0.75 PROD1 RPEQPT DISP P 8593 ft.PUH,displace well to milling 8,593.0 8,593.0 06:30 07:15 fluid. 6/9/2016 6/9/2016 2.50 PROD1 RPEQPT MILL P 8592 ft.OB Milling cement 1.7 bpm at 8,593.0 8,616.0 07:15 09:45 2560 psi FS,BHP 2958,Open choke, IA 578,OA 151 6/9/2016 6/9/2016 3.25 PROD1 RPEQPT MILL P 8616 ft.Stalling on nipple,work thru 8,616.0 8,616.0 09:45 13:00 rotating TF 210° 6/9/2016 6/9/2016 1.50 PROD1 RPEQPT MILL P 8616 ft,OB milling ahead 1.5 bpm at 8,616.0 8,656.0 13:00 14:30 2141 psi,BHP 2946,IA 412,OA 390 6/9/2016 6/9/2016 1.50 PROD1 RPEQPT MILL P 8656 ft,casing contact milling ahead 8,656.0 8,659.5 14:30 16:00 1.5 bpm at 2210 psi FS,BHP 3023, open choke,IA 390,OA 398 6/9/2016 6/9/2016 6.00 PROD1 RPEQPT MILL P 8659 ft,OB milling ahead,1.7 bpm at 8,659.5 8,727.5 16:00 22:00 2657 psi FS,BHP 3025,open choke, IA 419,OA 398 6/9/2016 6/9/2016 0.45 PROD1 RPEQPT MILL P 8,727 ft.Stalling at 7"collar,PUW 8,727.5 8,729.0 22:00 22:27 45k,work thru rotating TF 180° 6/9/2016 6/10/2016 1.55 PROD1 RPEQPT MILL P 8,729 ft.OB milling ahead,TF 20R, 8,729.0 8,738.0 22:27 00:00 1.73 bpm at 2,658 psi FS,BHP 3,117 psi,open choke, IA 645,OA 605. ""8,732 ft.stalled,work thru rotating TF 180° ""8,734 ft.rotate TF 20R 6/10/2016 6/10/2016 0.50 PROD1 RPEQPT MILL P 8,738 ft.OB milling ahead,TF 20R, 8,738.0 8,743.0 00:00 00:30 1.73 bpm at 2,671 psi FS,BHP 3,153 psi,open choke,IA 664,OA 631. "Note:Bled IA to 30 psi&OA to 70 psi 6/10/2016 6/10/2016 0.45 PROD1 RPEQPT MILL P 8,743 ft.Rotating TF 180°2 ft.prior to 8,743.0 8,746.2 00:30 00:57 first known 7"casing restriction.rotate TF 20R 6/10/2016 6/10/2016 2.00 PROD1 RPEQPT MILL P 8,746.19 ft. Stalling at first 7"casing 8,746.2 8,746.3 00:57 02:57 restriction,PUW 41k,unable to work thru rotating TF 180°,attempt at multiple TF settings from 120L/R, 140L/R Page 2/27 Report Printed: 7/11/2016 el,,,;-,-.. , "¢° Operations Summary (with Timelog Depths) a 1 L-24 ConocoPtsiilips t.Lxka 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) 6/10/2016 6/10/2016 2.00 PROD1 RPEQPT MILL P 8746.3 ft.rotating TF 30°L, 180°,and 8,746.3 8,746.5 02:57 04:57 120°L,resulted in more weight on bit Note:trace amount of metal shavings coming across shaker at 04:00 6/10/2016 6/10/2016 3.00 PROD1 RPEQPT MILL P 8746.5 ft,pump 20 bbl 1%safe lube 8,746.5 8,746.5 04:57 07:57 pill,seeing a little more surface weight,and lighter PUW 37k ****Note:MU and pump 1%safe lube pill 6/10/2016 6/10/2016 0.25 PROD1 RPEQPT MILL P 8746.5 ft,wiper to the TOC 8553 ft. 8,746.5 8,553.0 07:57 08:12 PUW 38 k. 6/10/2016 6/10/2016 0.25 PROD1 RPEQPT MILL P 8553 ft,RBIH to bottom, RIW 11 k 8,553.0 8,746.5 08:12 08:27 6/10/2016 6/10/2016 3.50 PROD1 RPEQPT MILL P 8746.5 ft.continue milling ahead, 1:53 8,746.5 8,746.6 08:27 11:57 bpm at 2580 FS,BHP 3144,open choke,IA 95,OA 162 ****Note:MU and pump 20 bbl beaded pill with no change in milling. 6/10/2016 6/10/2016 4.30 PROD1 RPEQPT MILL P 8746.6 ft.discuss with town,adjust TF 8,746.6 8,754.0 11:57 16:15 270°and 90°,continue milling ahead OB. 1.53 bpm at 2730 psi. 6/10/2016 '6/10/2016 2.50 PROD1 RPEQPT MILL P 8,754 ft.continue milling ahead,OB 8,754.0 8,763.7 16:15 18:45 1.7 bpm at 2,970 psi FS. 6/10/2016 6/11/2016 5.25 PROD1 RPEQPT MILL P 8,763.7 ft.Stalling at 20R,PUW 39k, 8,763.7 8,764.0 18:45 00:00 rotate at 200R,stalling,pump 10 bbl 1%safe lube pill,OB 1.55 bpm at 2,709 psi FS,no significant help from lube pill.stalling at same. 6/11/2016 6/11/2016 1.35 PROD1 RPEQPT MILL P 8,764.03 ft. OB 1.55 bpm at 2,797 8,764.0 8,764.1 00:00 01:21 psi,mutiple stalls 6/11/2016 6/11/2016 0.20 PROD1 RPEQPT MILL P 8,764.13 ft. Wiper to 8,562 ft.PUW 8,764.1 8,562.0 01:21 01:33 42k 6/11/2016 6/11/2016 0.35 PROD1 RPEQPT MILL P Wiper back in hole,log K1 for plus 4 ft. 8,562.0 8,767.9 01:33 01:54 correction.RIW 12k. 6/11/2016 6/11/2016 3.10 PROD1 RPEQPT MILL P 8767.89 ft.Stalled, PUW 44k,OB 1.6 8,767.9 8,768.0 01:54 05:00 bpm at 2,765 psi,TF 200,pump 10 bbl 1%lube pill, 6/11/2016 6/11/2016 5.00 PROD1 RPEQPT MILL P OBM,1.5 bpm at 2410 psi FS, BHP 8,768.0 8,768.4 05:00 10:00 3035,full open choke, IA 237,OA 326 ***TF 90°L, 110°L, 150°L,40°L ***pumping 20 bbl 1%safe lube pill 6/11/2016 6/11/2016 5.50 PROD1 RPEQPT MILL P OBM 1.5 bpm at 2480 psi FS,BHP 8,768.4 8,773.0 10:00 15:30 3091,full open choke, IA 220,OA 321 ***TF 40°L-20°R,and 100°R 6/11/2016 6/11/2016 5.00 PROD1 RPEQPT MILL P Stalling motor on reduced ID section 8,773.0 8,780.5 15:30 20:30 at 8773 ft.,adjust TF 280°R, 120R,80 -120L,Milling ahead 1.52 bpm at 2,580 psi,20R,rotate 160L 8,776.3 ft. to 8,778 ft.rotate to 20R,restart at 8,779.10 ft. Page 3/27 Report Printed: 7/11/2016 . • Operations Summary (with Timelog Depths) "'4 1 L-24 �Wia . � � 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) 6/11/2016 6/12/2016 3.50 PROD1 RPEQPT MILL P 8,780.5 ft.Stalling motor in casing, 8,780.5 8,781.1 20:30 00:00 adjust TF 90-120R,160L,90R 1.6 bpm at 2,656 psi,reducerate to 1.50 bpm at 2,475 psi,slow milling in clear casing. 6/12/2016 6/12/2016 0.15 PROD1 RPEQPT MILL P 8,781.11 ft. Trying to restart at 8,781.1 8,781.1 00:00 00:09 variable TF,Call from town to POOH for fresh Motor(170 stalls)and mill. 6/12/2016 6/12/2016 2.25 PROD1 RPEQPT TRIP P POOH at 20R into tubing,flow check, 8,781.1 62.5 00:09 02:24 no flow,continue POOH. 6/12/2016 6/12/2016 0.50 PROD1 RPEQPT OWFF P On surface,flow check. PJSM-LD 62.5 62.5 02:24 02:54 BHA on dead well. 6/12/2016 6/12/2016 1.60 PROD1 RPEQPT PULD P LD BHA#1 mill&motor,2.79"no-go 62.5 0.0 02:54 04:30 on mill,3 rows of cutters worn off just above mill gauge.MU BHA#2 motor and new D331 mill,MU to CoilTrak, surface test. 6/12/2016 6/12/2016 1.50 PROD1 RPEQPT TRIP P RIH,w/new D331 and 0.9°bend 0.0 8,490.0 04:30 06:00 motor. 6/12/2016 6/12/2016 0.50 PROD1 RPEQPT DLOG - P 8490 ft.tie into the lower HRZ 8,490.0 8,686.0 06:00 06:30 correction of plus 2.0 ft,log the K1 correction of plus 5.0 ft. 6/12/2016 6/12/2016 0.25 PROD1 RPEQPT TRIP P 8686 ft.continue RIH thru pilot hole to 8,686.0 8,781.0 06:30 06:45 bottom.RIW 11 k. 6/12/2016 6/12/2016 7.00 PROD1 RPEQPT MILL P 8781 ft,1.5 bpm at 2476 psi FS,BHP 8,781.0 8,905.0 06:45 13:45 3125,WHP 0,IA 253,OA 321 6/12/2016 6/12/2016 0.25 PROD1 RPEQPT TRIP P TD cement pilot hole,PUW 36 k. PUH 8,905.0 8,500.0 13:45 14:00 for tie in 6/12/2016 6/12/2016 0.25 PROD1 RPEQPT DLOG P 8500 ft.tie into the HRZ,plus 2.0 ft 8,500.0 8,522.0 14:00 14:15 correction. 6/12/2016 6/12/2016 0.25 PROD1 RPEQPT TRIP P 8522 ft,continue RIH,dry drift pilot 8,522.0 8,907.0 14:15 14:30 hole ***Note:weight bobble 8665 ft,8760 ft. 6/12/2016 6/12/2016 1.50 PROD1 RPEQPT REAM P 8907 ft,PUH,back ream from 8784 ft 8,907.0 8,645.0 14:30 16:00 up hole at 200 ROHS to 8730 ft.PUH 8,730 ft.to 8,665 ft,back ream transition 200R to 8645 ft. 6/12/2016 6/12/2016 0.40 PROD1 RPEQPT REAM P 8,645 ft.Ream down transition 5 fpm 8,645.0 8,788.0 16:00 16:24 at 200R to 8,670 ft.RIH 20R to 8,730 ft.ream down 5 fpm to 8,788 ft. 6/12/2016 6/12/2016 1.40 PROD1 RPEQPT REAM P 8,788 ft. Back ream deformed casing 8,788.0 8,581.0 16:24 17:48 area 20R to 8,728 ft.PUH to 8,662 ft. back ream transition 200R to 8,650 ft. PUH to 8,581 ft. 6/12/2016 6/12/2016 0.30 PROD1 RPEQPT TRIP P 8,581 ft.RBIH dry drift pilot hole 20R, 8,581.0 8,906.0 17:48 18:06 .5k WOB 8,590 ft.to 8,793 ft.clear to 8,905 ft 6/12/2016 6/12/2016 2.20 PROD1 RPEQPT TRIP P 8,906 ft.POOH,flow check at 8,545 ft. 8,906.0 62.5 18:06 20:18 continue POOH. 6/12/2016 6/12/2016 1.20 PROD1 RPEQPT PULD P On surfcae,flow check during PJSM, 62.5 0.0 20:18 21:30 LD BHA#2,2.79"no-go,mill looks good. 6/12/2016 6/12/2016 1.00 PROD1 RPEQPT PULD P PJSM with Halliburton.MU Halliburton 0.0 26.1 21:30 22:30 real time Caliper BHA#3,MU to Coil, surface test caliper. 6/12/2016 6/13/2016 1.50 PROD1 RPEQPT TRIP P RIH with BHA#3 26.1 8,370.0 22:30 00:00 Page 4/27 Report Printed: 7/11/2016 • = Operations Summary (with Timelog Depths) -2 , 1L-24 +Coc►ocoP'hi ps 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) 6/13/2016 6/13/2016 0.20 PROD1 RPEQPT DLOG P Log HRZ for plus 2.31 ft.correction. 8,370.0 8,419.0 00:00 00:12 6/13/2016 6/13/2016 0.40 PROD1 RPEQPT TRIP P Continue RIH,RIW 12k. 8,419.0 8,896.0 00:12 00:36 6/13/2016 6/13/2016 0.55 PROD1 RPEQPT DLOG P 8,896 ft.Open caliper,PUH 30 fpm, 8,896.0 8,200.0 00:36 01:09 39k 6/13/2016 6/13/2016 0.50 PROD1 RPEQPT TRIP P 1 lose caliper at 8,200 ft,RBIH,RIW 8,172.0 • 8,896.0 01:09 01:39 6/13/2016 6/13/2016 0.45 PROD1 RPEQPT DLOG P 8,896 ft.Open caliper, PUH 30 fpm, 8,896.0 8,200.0 01:39 02:06 PUW 39k,close caliper at 8,200 ft, 6/13/2016 6/13/2016 1.55 PROD1 RPEQPT TRIP P Continue POOH for whipstock run. 8,200.0 26.1 02:06 03:39 6/13/2016 6/13/2016 0.50 PROD1 RPEQPT OWFF P Onll Halliburtonsurface, cflow ,rush w check, PJSM with 26.1 26.1 03:39 04:09 ata. 6/13/2016 6/13/2016 0.85 PROD1 RPEQPT PULD P LD BHA#3,Load out caliper 26.1 0.0 04:09 05:00 equipment,bring in Baker equipment. 6/13/2016 6/13/2016 1.25 PROD1 RPEQPT PULD P PJSM-MU BHA#4 0.0 73.8 05:00 06:15 6/13/2016 6/13/2016 2.00 PROD1 RPEQPT TRIP P RIH,with WS setting BHA#4,w/J- 73.8 8,385.0 06:15 08:15 hydraulic setting tool.Open EDC. puming 0.25 bpm 6/13/2016 6/13/2016 0.50 PROD1 RPEQPT DLOG P 8385 ft,tie into the HRZ correction of 8,385.0 8,415.0 08:15 08:45 plus 2.0 ft.log K1 to confirm tie in no correction.PUW 36 k.close EDC 6/13/2016 6/13/2016 0.50 PROD1 RPEQPT TRIP P 8686 ft,continue RIH to setting depth. 8,415.0 8,885.8 08:45 09:15 6/13/2016 6/13/2016 0.25 PROD1 RPEQPT WPST P 8875 ft,shear setting tool at 4400 psi, 8,885.8 8,885.8 09:15 09:30 good indication of set,set down 1500 lb DHWOB,PUW 36 6/13/2016 6/13/2016 1.50 PROD1 RPEQPT TRIP P 8885 ft.,POOH,pumping 0.5 bpm. 8,885.8 73.8 09:30 11:00 6/13/2016 6/13/2016 0.50 PROD1 RPEQPT OWFF P At tr surface,BHA check well for flow,PJSM 73.8 73.8 11:00 11:30 6/13/2016 6/13/2016 0.50 PROD1 RPEQPT PULD P LD settting tools 73.8 0.0 11:30 12:00 6/13/2016 6/13/2016 1.50 PROD1 WHPST PULD P PU/MU millintest g CoiltrakHA# tools 0.0 74.4 12:00 13:30 6/13/2016 6/13/2016 1.25 PROD1 WHPST TRIP . P RIH,w/milling BHA#5 0.6°bend 74.4 8,385.0 13:30 14:45 6/13/2016 6/13/2016 0.25 PROD1 WHPST DLOG P 8385 ft,of plus 2.og5'cHrRr HRZ for ie in.,correction 8,385.0 8,415.0 14:45 15:00 6/13/2016 6/13/2016 0.25 PROD1 WHPST TRIP P 8415 ft.continue RIH to bottom 8,415.0 8,860.0 15:00 15:15 6/13/2016 6/13/2016 1.25 PROD1 WHPST DISP P 8860 ft.displace well to milling fluid, 8,860.0 8,500.0 15:15 16:30 perform flow survey above TOC at 8500 ft.holding 11.8ppg at the window. 6/13/2016 6/13/2016 0.25 PROD1 WHPST TRIP P 8500 ft,RBIH to dry tag TOWS. 8,500.0 8,875.0 16:30 16:45 6/13/2016 6/13/2016 0.45 PROD1 WHPST TRIP P 8875 ft,dry tag TOWS,bring pump up 8,875.0 8,874.0 16:45 17:12 1.5 bpm at 3200 psi,BHP 3469,WHP 0, IA 33,OA 125,RBIH,milling at 8,873.6 ft.lost prime PU off bottom. Page 5/27 Report Printed: 7/11/2016 • . ' Operations Summary (with Timelog Depths) If,,J. 1 L-24 connaccolitlips < 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) 6/13/2016 6/14/2016 6.80 PROD1 WHPST WPST P 8,874 ft. Mill window per recomended 8,874.0 8,877.7 17:12 00:00 practice 5°LOHS, 1.5 bpm at 3,200 psi, 1.5k WOB,metal across shaker. "8,875 ft had sudden increase in WOB 2.6k to 3.65k,let mill off to 1.7k, had to rotate TF 360°due to up against stops. "8,876.4 ft.Stall,restart 6/14/2016 6/14/2016 3.00 PROD1 WHPST WPST P 8,877.7 ft.Milling 1.57 bpm at 3,252 8,877.7 8,879.0 00:00 03:00 psi,WOB 2.6k,IA 300,OA 374. 6/14/2016 6/14/2016 5.75 PROD1 WHPST WPST P 8,879 ft.Mill out side casing,continue 8,879.0 8,895.0 03:00 08:45 at 1 fph per recomended practice for 2 ft,following tripping schedule, 1.56 bpm at 3,539 psi,BHP 3,687 psi, WHP 235,IA 340,OA 410 6/14/2016 6/14/2016 0.25 PROD1 WHPST TRIP P 8o895r eft MD.TD'd rathole,pull up hole 8,895.0 8,680.0 08:45 09:00 -in. 6/14/2016 6/14/2016 0.25 PROD1 WHPST DLOG P Log K1 for correction of+1 ft 8,680.0 8,896.0 09:00 09:15 6/14/2016 6/14/2016 0.50 PROD1 WHPST WAIT P Call town for path forward 8,896.0 8,896.0 09:15 09:45 6/14/2016 6/14/2016 0.25 PROD1 WHPST TRIP P Dry tag TD 8,896.0 8,895.0 09:45 10:00 6/14/2016 6/14/2016 1.00 PROD1 WHPST TRIP P Backreamedm 8883t 5L,35L, o 868 ft R,MandDr8,895.0 8,868.0 10:00 11:00 160L drift to 8895 ft MD. 6/14/2016 6/14/2016 1.75 PROD1 WHPST TRIP P POOH while pumping 1.5 bpm at 3404 8,868.0 74.3 11:00 12:45 psi pump pressure using trip sheet. Open EDC,cont POOH. 6/14/2016 6/14/2016 0.75 PROD1 WHPST SFTY P At surface,PJSM for PUD 74.3 74.3 12:45 13:30 74.3 0.0 6/14/2016 6/14/2016 1.50 PROD1 WHPST PULD P Break off injector,cont PUD 13:30 15:00 0.0 0.0 6/14/2016 6/14/2016 0.50 PROD1 DRILL SFTY P PJSM for PD and MR on PUD 15:00 15:30 6/14/2016 6/14/2016 1.00 PROD1 DRILL PULD P injector,D BHA#6. Che ePchecks,make up 0.0 72.2 15:30 16:30 6/14/2016 6/14/2016 2.50 PROD1 DRILL TRIP P Bump up.Reset counters.RIH with 72.2 8,895.0 16:30 19:00 BHA#6.Tie in to HRZ for+3 ft correction.Close EDC.Pump minimum rate tripping through pilot hole.Clean trip through window. 6/14/2016 6/15/2016 5.00 PROD1 DRILL DRLG P Back on bottom drilling build section. 8,895.0 8,996.0 19:00 00:00 Pumping 1.6 BPM at 3580 psi.FS= 3160 psi.WOB=1.5KIbs.CTW= 11 Klbs.ROP=20 FPH.WHP=220 psi BHP=3755 psi. 6/15/2016 6/15/2016 6.25 PROD1 DRILL DRLG P Back on bottom drilling.Pumping 1.6 8,996.0 9,125.0 00:00 06:15 BPM at 3540 psi.FS=3160 psi.WOB =1.4-1.6Klbs.CTW=10KIbs.ROP= 10-20 FPH.WHP=220 psi BHP=, 3760 psi. 6/15/2016 6/15/2016 0.75 PROD1 DRILL TRIP P 9125 ft,TD build section,PUW 28 k 9,125.0 8,560.0 06:15 07:00 Page 6/27 Report Printed: 7/11/2016 • • ,...i,,,,I.,,,,ift Operations Summary (with Timelog Depths) '.1. 1 L-24 ConocoPhitlips ' iL:kr. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth O eration (ftKB) End Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X P 8,560.0 8,560.0 6/15/2016 6/15/2016 0.25 PROD1 DRILL TRIP P 8573 ft,PUH 1 fpm,w/open EDC 07:00 07:15 .*•°Note:Pressure survey,pumping 1.5 bpm,11.8 ECD,annular pressure 3498, 170 WHP 6/15/2016 6/15/2016 1.25 PROD1 DRILL TRIP P POOH to surface 8,560.0 72.2 07:15 08:30 6/15/2016 6/15/2016 0.25 PROD1 DRILL SFTY P Tagup at surface space out,PJSM for 72.2 72.2 08:30 08:45 PUD 72.2 0.0 6/15/2016 6/15/2016 3.00 PROD1 DRILL PULD P PUD,build section BHA#6 08:45 11:45 0.0 72.2 6/15/2016 6/15/2016 1.50 PROD1 DRILL PULD P PD,lateral BHA#7 11:45 13:15 6/15/2016 6/15/2016 1.75 PROD1 DRILL TRIP P RIH with lateral section BHA,0.4°bent 72.2 8,375.0 13:15 15:00 motor with RB HYC 6/15/2016 6/15/2016 0.25 PROD1 DRILL DLOG P 8,371'MDUion titie-in f plus 3 5Z R marker d wito 8,375.0 8,407.0 15:00 15:15 confirm tie-in with plus 0.5'correction. 6/15/2016 6/15/2016 0.25 PROD1 DRILL TRIP P 8898' Db5 bpm @/5344' DSS:400 Pressure psi pump 8,407.0 9,125.0 15:15 15:30 pressure, 11.83 ECD,3633 psi annular pressure,in MM 8.83 ppg/out MM 8.79 ppg RBIH. 6/15/2016 6/15/2016 4.00 PROD1 DRILL DRLG P BPM at bottom 570 psi.FS drilling.4 u pinW06 g 1.5 9, 125.0 9,332.0 15:30 19:30 =1.4-1.7Klbs.CTW=10KIbs.ROP= 50-70 FPH.WHP=290 psi BHP= 3800 psi.Begin mud swap at 19:00hrs. 6/15/2016 6/15/2016 3.00 PROD1 DRILL DRLG P New mud at the bit at 9332 ft. 9,332.0 9,525.0 19:30 22:30 Continue drilling ahead pumping 1.5 BPM at 3700 psi.FS=3405 psi.WOB =1.4-1.7Klbs.CTW=10Kibs.ROP= 50-70 FPH.WHP=430 psi BHP= 3820 psi. 6/15/2016 6/15/2016 0.50 PROD1 DRILL WPRT P Planned netlCle wiper n trip in and ,000 ft.PUW 9,525.0 9,525.0 22:30 23:00 out. 6/15/2016 6/16/2016 1.00 PROD1 DRILL DRLG P BPM auet 7d8bingiahead pumpin1.55 3 0 psg WOB 9,525.0 9,588.0 23:00 00:00 =1.6Klbs.CTW=9.5Klbs.ROP=100 -120 FPH.WHP=430 psi BHP-- 3870 3870 psi. 6/16/2016 6/16/2016 3.00 PROD1 DRILL DRLG P Cont at 3800ingiaheaS tl3 ming WOB 1.50 9,588.0 9,925.0 00:00 03:00 =1.8-2.0Klbs.CTW=9.2Klbs.ROP= 100-160 FPH.WHP=442 psi BHP= 3896 psi. 6/16/2016 6/16/2016 1.00 PROD1 DRILL WPRT P Begin planned wiper trip to 9,100 ft. 9,925.0 9,925.0 03:00 04:00 6/16/2016 6/16/2016 4.00 PROD1 DRILL DRLG P 9,925,BOBD 1.6 diff,BHP 3,880,pm at WHP 3 3,650 psi IA 9,925.0 10,325.0 04:00 08:00 515,OA 527 6/16/2016 6/16/2016 1.00 PROD1 DRILL WPRT P 10,325 ft,PUW 30 k wiper up hole to 8,900 ft, 10,325.0 10,325.0 08:00 09:00 6/16/2016 6/16/2016 2.75 PROD1 DRILL DRLG P FS3BHP,BOBD 1.5 296 a t 3,56266 66,psi 10,325.0 10,532.0 09:00 11:45 529 6/16/2016 6/16/2016 0.50 PROD1 DRILL WPRT P 10,532 ft500 ft,10,532 ft,PUW wiper up hole to 10,532.0 10,532.0 11:45 12:15 Page 7/27 Report Printed: 7/11/2016 • • ` Operations Summary (with Timelog Depths) A 1 L-24 c000contillips 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) 6/16/2016 6/16/2016 2.00 PROD1 DRILL DRLG P 10, 32 ft.F656HP BOBD 1 .6 2P 95 at bpm 3A 650,psi O10,532.0 10,714.0 12:15 14:15 609 6/16/2016 6/16/2016 1.00 PROD1 DRILL WPRT P 10,714 ft,wiper up hole to 9,704 ft. 10,714.0 10,714.0 14:15 15:15 PUW 31 k.Wiper back in hole 80° LOHS,stack out at 10,514 ft,PUH orient TF 100°LOHS,stack out again, PUH,orient high side and lower pump rate to 0.75 bpm pass thru clean, continue RIHTB. 6/16/2016 6/16/2016 2.75 PROD1 DRILL DRLG P 10,721 ft,off,PUH inspect,clean not consistent r 7 ft 10,714.0 10,880.0 15:15 18:00 and reset INJH counter to CTES counter, 10,714 ft,depth change minus 7.0 ft.BOBD 1.6 bpm at 3,770 psi,BHP 3852,WHP 299,IA 680,OA 647 *00 Note:Bleed IA 205 psi and OA 198 psi. ***Note:mud swap,new mud at the bit at 10743 ft. 6/16/2016 6/16/2016 0.75 PROD1 DRILL DRLG P Continue to drill ahead pumping 1.59 10,880.0 10,963.0 18:00 18:45 bpm at 3930 psi.WHP 315 psi,BHP 3900 psi.WOB 1.6 Klbs.ROP 110 fph. 6/16/2016 6/16/2016 1.75 PROD1 DRILL WPRT P Start tie-in out.wiper trip.in to WA=f34Klbs. 10,963.0 10,963.0 18:45 20:30 foot correction.RBIH.Took weight at 10,515 ft.Stacked out at 10,775 ft. PUH,PUW=37KLbs. RBIH with TF at HS,continue to bottom. 6/16/2016 6/16/2016 0.50 PROD1 DRILL DRLG P Continue drilling ahead pumping 1.60 10,963.0 11,014.0 20:30 21:00 bpm at 3900 psi.WHP 319 psi,BHP 3980 psi.WOB 2-2.2Klbs ROP 80-110 fph. Annular presure indicating possible packoff above BHA.Begin precautionary BHA wiper trip. 6/16/2016 6/16/2016 0.50 PROD1 DRILL WPRT P BHA wiper trip.PUW=37KIbs. 11,014.0 11,014.0 21:00 21:30 6/16/2016 6/17/2016 2.50 PROD1 DRILL DRLG P Back on bottom drilling,pumping 1.6 11,014.0 11,175.0 21:30 00:00 bpm at 4000 psi.WHP=240 psi,BHP =3980.WOB 2.4KIbs ROP=60-80 fph. 6/17/2016 6/17/2016 1.00 PROD1 DRILL DRLG P Back on bottom drilling,pumping 1.6 11,175.0 11,213.0 00:00 01:00 bpm at 4000 psi.FS=3630 psi,WHP =240 psi,BHP=3980.ROP=60-80 fph. h. 6/17/2016 6/17/2016 1.00 PROD1 DRILL WPRT P Begin planned wiper trip.PUW 37 11,213.0 11,213.0 01:00 02:00 Several minor pack off events, RBIH,stacked out at 10,500.PUH, reduced pump rate from 1 BPM to 0.5 BPM.Run through trouble section to 10,800 ft. Bring pumps back up and continue to bottom. 6/17/2016 6/17/2016 5.50 PROD1 DRILL DRLG P Back on bottom drilling,pumping 1.5 11,213.0 11,463.0 02:00 07:30 bpm at 3600 psi.WHP=238psi,BHP =3980.WOB 2.4KIbs ROP=60-80 fph. Page 8127 Report Printed: 7/11/2016 • • Operations Summary (with Timelog Depths) 1 L-24 ConocoPhitiips 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) 6/17/2016 6/17/2016 0.75 PROD1 DRILL WPRT P 11,463 ft,PUW 33 k wiper up hole to 10,600 ft, 11,463.0 10,600.0 07:30 08:15 6/17/2016 6/17/2016 0.50 PROD1 DRILL WPRT P 10,600 ft,wiper back in hole,RIW 8 k. 10,600.0 11,265.0 08:15 08:45 6/17/2016 6/17/2016 0.25 PROD1 DRILL WPRT P 11,26 HS5lowerft, ar to o Ot.PU, ,orient TF 11,265.0 11,463.0 08:45 09:00 M. Successfully pass through. 6/17/2016 6/17/2016 2.00 PROD1 DRILL DRLG P 11 46HP 4005B,WHP 207,IAat 365 2500 psi 11,463.0 11,561.0 09:00 11:00 FA 288 6/17/2016 6/17/2016 0.25 PROD1 DRILL WPRT P 11,561 ft,200'wiper,PU wt=28klbs. 11,561.0 11,561.0 11:00 11:15 6/17/2016 6/17/2016 1.50 PROD1 DRILL DRLG P 11,561 ft,BOBD 1.51 BPM @ 3640 11,561.0 11,610.0 11:15 12:45 psi FS,BHP 4471 psi,ROP=80-25 fph 6/17/2016 6/17/2016 0.50 PROD1 DRILL WPRT P CTSW 11,610 ft,early&to window wiper trip tonegain 11,610.0 10,770.0 12:45 13:15 6/17/2016 6/17/2016 1.75 PROD1 DRILL WPRT T 10,770 ampromd1 fight. ftBIH 1.5 BPM. 10,770.0 8,890.0 13:15 15:00 Pulled tight again @ 10,770 ft, CTSW=50klbs @ 1 FPM(-11 klbs= WOB).RBIH 15 ft.Pumped 5x5 sweep.PUH @ 15 FPM, 1.5 BPM, successfully pulled through. 6/17/2016 6/17/2016 0.25 PROD1 DRILL DLOG T 8890 ft,tie-in to RA for a plus 5 ft 8,890.0 10,250.0 15:00 15:15 correction. Decision made to plug back due to high GR.1.3%DS seen in returns from sweep. 6/17/2016 6/17/2016 2.75 PROD1 DRILL WPRT T 10,250 buiumped a hi-vis ld section clean. weepPOOto 10,250.0 700.0 15:15 18:00 Open EDC once inside tubing tail,and continue out of the hole. 6/17/2016 6/17/2016 2.25 PROD1 DRILL WPRT T Packed RBIHoff Choke lean B.p Switch to Choke 700.0 8,500.0 18:00 20:15 hole. SIMOPS:Also observed MMout not reading correctly.Isolated Choke B and MM,blow down with air and water.Back online with choke B. MM still not reading correctly. 6/17/2016 6/17/2016 0.75 PROD1 DRILL WPRT T hole. Tie line D ,continue EDC, r a e in the n foot 8,500.0 9,212.0 20:15 21:00 correction.Send 5x5 sweep.Continue in the hole 9212 ft. 6/17/2016 6/17/2016 2.50 PROD1 DRILL WPRT T 9212 ft.POOH chasing sweep. Stop 9,212.0 72.0 21:00 23:30 above tubing tail and open EDC. Continue out of the hole to surface. Shale obseved over the shakers after 700 ft. 6/17/2016 6/18/2016 0.50 PROD1 DRILL PULD T 72 ft.PJSM.PUD lateral BHA#7. 72.0 72.0 23:30 00:00 6/18/2016 6/18/2016 1.50 PROD1 DRILL PULD T Continue to PUD BHA#7.Bit grade 3- 72.0 0.0 00:00 01:30 1. SIMOPS: Inspect Choke B,replace seat. Inspect and clean counter. Attempt to flush micromotion with air and water.MM out still reading incorrectly. Page 9/27 Report Printed: 7/11/2016 • r Operations Summary (with Timelog Depths) ,At Zs( , ', ;., 1 L-24 ConocoPhyillips 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) 6/18/2016 6/18/2016 2.50 PROD1 STK PULD T PD BHA#8,Aluminum billet with open 0.0 72.0 01:30 04:00 hole anchor. Change out floats in UQC.Check packoffs. • 6/18/2016 6/18/2016 2.25 PROD1 STK WPST T RIH BHA#8 72.0 8,385.0 04:00 06:15 6/18/2016 6/18/2016 0.25 PROD1 STK DLOG T Tie-in to HRZ+3.5 ft correction 8,385.0 8,550.0 06:15 06:30 6/18/2016 6/18/2016 0.50 PROD1 STK DLOG T Close EDC,no pumping.Check tie-in 8,550.0 8,761.0 06:30 07:00 @ K1,+1 ft correction. 6/18/2016 6/18/2016 0.50 PROD1 STK DLOG T RIH.Tie-in @ RA,+4 ft correction.No 8,761.0 8,900.0 07:00 07:30 good compared to K1 correction. Check counter,lubricate chain.PUH to 8650'to log K1 again.Pressure up annular. 6/18/2016 6/18/2016 0.25 PROD1 STK DLOG T Log K1 again,+2 ft correction. 8,900.0 8,694.0 07:30 07:45 6/18/2016 6/18/2016 0.50 PROD1 STK DLOG T RIH.Tie-in @ RA,+1.5 ft.No good 8,694.0 8,900.0 07:45 08:15 (1.5 ft off after 223 ft). 6/18/2016 6/18/2016 1.50 PROD1 STK SVRG T PUH to replace counter 8,900.0 8,650.0 08:15 09:45 6/18/2016 6/18/2016 0.25 PROD1 STK DLOG T RIH.Log K1 again,+0.5 ft correction. 8,650.0 8,699.0 09:45 10:00 6/18/2016 6/18/2016 0.25 PROD1 STK DLOG T RIH.Tie-in @ RA,no correction. 8,699.0 8,699.0 10:00 10:15 6/18/2016 6/18/2016 1.25 PROD1 STK DLOG T RIH to 10,262'.PU to neutral&pump 8,699.0 10,262.0 10:15 11:30 up to set anchor.Top of billet @ 10,250',TF©170ROHS 6/18/2016 6/18/2016 1.00 PROD1 STK WPST T Set down 3klbs,PU off billet,POOH. 10,262.0 8,550.0 11:30 12:30 6/18/2016 6/18/2016 1.50 PROD1 STK TRIP T Open EDC,cont POOH. 8,550.0 72.0 12:30 14:00 6/18/2016 6/18/2016 3.50 PROD1 STK PULD T PJSM,PUD BHA#8,anchored billet 72.0 0.0 14:00 17:30 running tools. LD BOT tools.Change lower MWD. Swap UQC and flush micromotion. Micomotion is now reading correct mud density. 6/18/2016 6/18/2016 2.50 PROD1 STK PULD T PJSM,PD BHA#9,with 0.5°AKO and 0.0 72.0 17:30 20:00 RB HYC bit. Change out pack offs.Test MWD, strip on well. Bump up and reset counters. 6/18/2016 6/18/2016 1.25 PROD1 STK TRIP T RIH with BHA#9.Tie in to the HRZ for 72.0 10,258.0 20:00 21:15 a+19 foot correction.Continue in the hole.Confirmed tie-in at the RA. Dry tag top of billet at 10,258 ft. 6/18/2016 6/19/2016 2.75 PROD1 STK KOST T Begin drilling off of billet per 10,258.0 10,259.0 21:15 00:00 procedure. Stalled 3 times while getting kicked off.Aluminum observed over the shakers. 6/19/2016 6/19/2016 2.00 PROD1 STK KOST T Continue drilling off of billet per 10,259.0 10,261.0 00:00 02:00 procedure.Stall.PUH and restart. Continue drilling. 6/19/2016 6/19/2016 1.25 PROD1 DRILL DRLG T Drill off of billet,continue to drill to 10,261.0 10,310.0 02:00 03:15 10310 ft. 6/19/2016 6/19/2016 0.75 PROD1 DRILL WPRT T Clean dry drift through billet area. 10,310.0 10,310.0 03:15 04:00 PUH to RA and tie in for a+2 ft ' correction.RBIH. Page 10/27 Report Printed: 7/11/2016 • • ' Operations Summary (with Timelog Depths) i , rel z _ 1 L-24 ConocoPhi[lips Fda ks 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) 6/19/2016 6/19/2016 0.50 PROD1 DRILL -WPRT T RIH,stacked weight at 9,095 ft with 10,310.0 10,310.0 04:00 04:30 HS tool face.Orient 50 LOHS, Continue in the hole to bottom at 10,310 ft. 6/19/2016 6/19/2016 3.50 PROD1 DRILL DRLG T Drill ahead from 10,310 to10,489 ft. 10,310.0 10,489.0 04:30 08:00 1.5 bpm at 3725-3950 psi pump pressure.BHP=4500 psi.WOB 1.2- 2.2Klbs.ROP=40-60 fph.. 6/19/2016 6/19/2016 3.50 PROD1 DRILL DRLG T Short PU,RBIH,&drill ahead to 10,489.0 10,672.0 08:00 11:30 10,672.Encountered Fault#1 @ 10,511 ft. 6/19/2016 6/19/2016 0.25 PROD1 DRILL DLOG T PU to 10,628 ft to re-log data gap 10,672.0 10,672.0 11:30 11:45 where MWD tool shut off. 6/19/2016 6/19/2016 0.75 PROD1 DRILL DRLG T Drill ahead to 10,710 ft. 10,672.0 10,710.0 11:45 12:30 6/19/2016 6/19/2016 1.00 PROD1 DRILL WPRT T Planned wiper trip to window after 400' 10,710.0 8,890.0 12:30 13:30 of drilling. 6/19/2016 6/19/2016 0.25 PROD1 DRILL DLOG T Tie-in to RA for+0.5 ft correction. 8,890.0 8,915.0 13:30 13:45 6/19/2016 6/19/2016 1.00 PROD1 DRILL WPRT T 8915 ft,continue wiper in hole.RIW 7 8,915.0 10,710.0 13:45 14:45 k,stacked out©10,511'.PUH, oriented DTF 80°LOHS,and passed through. 6/19/2016 6/19/2016 1.25 PROD1 DRILL DRLG T 10710 ft,BOBD 1.54 bpm at 3505 psi 10,710.0 10,810.0 14:45 16:00 FS,BHP 3885,WHP 436, IA 125,OA 260 ****Note:New mud system#3 to bit 10710 ft. 6/19/2016 6/19/2016 0.25 PROD1 DRILL DRLG T Experience partial losses @ 10,810 ft. 10,810.0 10,812.0 16:00 16:15 PUH 18 ft,re-establish pump rate& annular pressure.Cont.drilling ahead. 6/19/2016 6/19/2016 0.25 PROD1 DRILL WPRT T PUH for BHA wiper to improve drilling. 10,812.0 10,812.0 16:15 16:30 6/19/2016 6/19/2016 5.50 PROD1 DRILL DRLG T 10812ft,BOBD 1.55 bpm at 3700 psi 10,812.0 11,111.0 16:30 22:00 FS,BHP 3920,WHP 417,IA 189,OA 319 Several motor stalls.PU and restart at 10815 ft, 10828 ft, 11007 ft. ROP 60-80 fph. 6/19/2016 6/19/2016 0.75 PROD1 DRILL WPRT T 11,111 ft.Wiper up to 10,275 ft. 11,111.0 11,111.0 22:00 22:45 RBIH,stack out at 10420 ft, 10534 ft, and 10648 ft. 6/19/2016 -6/20/2016 1.25 PROD1 DRILL DRLG T 11,111ft,BOBD 1.58 bpm at 3470 psi 11,111.0 11,201.0 22:45 00:00 FS,BHP 3920,WHP 280,IA 196,OA 322 Losses—1 BPH. 6/20/2016 6/20/2016 5.50 PROD1 DRILL DRLG T 11,201ft,BOBD 1.56 bpm at 3480 psi 11,201.0 11,493.0 00:00 05:30 FS,BHP 3980,WHP 330,IA 201,OA 330 Losses 3-4 BPH. 6/20/2016 6/20/2016 0.50 PROD1 DRILL DRLG T 11,493 ft.Wiper up to 10,700 ft.Pump 11,493.0 11,493.0 05:30 06:00 5x10 sweep, no shale seen in returns. RBIH clean. 6/20/2016 6/20/2016 2.75 PROD1 DRILL DRLG T 11,493 ft.BOBD,BHP 4458 11,493.0 11,610.0 06:00 08:45 Losses—1 BPH.Total losses(incl yesterday)=34 bbls @ 0700. Page 11/27 Report Printed: 7/11/2016 • • ' Operations Summary (with Timelog Depths) _ 1 L-24 nocoP Cohi(lips 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) 6/20/2016 6/20/2016 1.50 PROD1 DRILL DRLG P 11,610 ft.Drilling ahead,back on"P" 11,610.0 11,679.0 08:45 10:15 time(passed plug back TD). 1.53 BPM @ 3670 psi,WOB 1.2klbs,ROP 58 FPH,653 psi differential,WHP 307,IA 208,OA 340. 6/20/2016 6/20/2016 0.25 PROD1 DRILL WPRT P BHA wiper to 11,578 ft.PUW=35klbs 11,679.0 11,679.0 10:15 10:30 6/20/2016 6/20/2016 0.25 PROD1 DRILL DRLG P Drill ahead.Mini-wiper @11,689 ft, 11,679.0 11,690.0 10:30 10:45 pump 5x10 sweep. ROP=20-40 FPH 6/20/2016 6/20/2016 2.25 PROD1 DRILL WPRT P Tie-in wiper @ 11,690 ft.Pull tight 11,690.0 8,890.0 10:45 ' 13:00 (CTSW=45klbs)@ 11,540 ft.RBIH. Work through. Cont.PUH,pulling tight @ 11,517', 11,490',10,507'.Pulled tight(WOB=- 5klbs)10,397'-10,380'.Work through. 6/20/2016 6/20/2016 0.25 PROD1 DRILL DLOG P Tie-in to RA(+5 ft correction). 8,890.0 8,908.0 13:00 13:15 . 6/20/2016 6/20/2016 1.50 PROD1 DRILL WPRT P RBIH.Stack out @ 9035', 10415', 8,908.0 11,524.0 13:15 14:45 10662', 11471', 11520. CTSW-48klbs when PUH. 6/20/2016 6/20/2016 0.50 PROD1 DRILL WPRT P 11,524 ft.PUH to clean up.Packing 11,524.0 10,979.0 14:45 15:15 off. Decision made to plug back(PB2)due to deteriorating hole conditions. 6/20/2016 6/20/2016 0.25 PROD1 DRILL WPRT T RBIH to clean up to 11,231'in prep for 10,979.0 11,231.0 15:15 15:30 next billet+OH anchor setting area. 6/20/2016 6/20/2016 0.75 PROD1 DRILL WPRT T 11,230 ft.PUH.CTSW 35klbs.Pump 11,231.0 10,650.0 15:30 16:15 5x10 sweep.Jog—80'until sweep exits bit,then,chase up hole. 6/20/2016 6/20/2016 1.75 PROD1 DRILL WPRT T 10,650 ft.Pull tight.Work up&down 10,650.0 10,350.0 16:15 18:00 to clean hole between 10,650& 10,490'.Starting to pack off and pull heavy.Continue to work up hole to 10,300 ft. 6/20/2016 6/20/2016 3.00 PROD1 DRILL WPRT T Pump low vis sweep,begin swab 10,350.0 1,500.0 18:00 21:00 wiper trip. 6/20/2016 6/20/2016 0.25 PROD1 DRILL WPRT T Jog down to 2500 ft.Substantial 1,500.0 1,500.0 21:00 21:15 amount of material observed over the shaker including cuttings and cavings. Density out peaked at 10.5 ppg on micromotion. 6/20/2016 6/20/2016 0.75 PROD1 DRILL WPRT T Continue out of the hole to the swabs. 1,500.0 72.0 21:15 22:00 Bump up and reset depths. 6/20/2016 6/21/2016 2.00 PROD1 DRILL WPRT T RBIH.Tie in to the HRZ for a+14 foot 72.0 9,227.0 22:00 00:00 correction.Weight check=30KIbs. Continue in the hole and confirm tie in at the RA.RIH. 6/21/2016 6/21/2016 0.50 PROD1 DRILL WPRT T Continue to RIH.Clean trip through 9,227.0 10,300.0 00:00 00:30 the pilot hole,window and build.Clean trip to 10,300ft. 6/21/2016 6/21/2016 1.00 PROD1 DRILL -WPRT T RIH additional 50 feet. Initial PUW= 10,300.0 10,371.0 00:30 01:30 32KIbs.Began dragging 39Klbs.Made multiple attempts to work past 10,371 ft.Beginning to pack off and pull heavy. Last pick up at 10371 was 42KIbs. Pump 5x5 sweep. Page 12/27 Report Printed: 7/11/2016 . • ..e ,-,,., OperationsSummary (with Timelog Depths) 1L-24 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) 6/21/2016 6/21/2016 1.25 PROD1 DRILL WPRT T Begin POOH to tubing.Call town to 10,371.0 8,700.0 01:30 02:45 discuss plan forward. 6/21/2016 6/21/2016 0.75 PROD1 DRILL WPRT T Made decision to run liner from 8,700.0 10,300.0 02:45 03:30 10,300ft with top of anchored billet at 9850 ft. RBIH to condition the hole for liner run. 6/21/2016 6/21/2016 2.75 PROD1 DRILL WPRT T Pumped 8x32 sweep to clear pits for 10,300.0 72.0 03:30 06:15 liner running pill.POOH.No excessive cuttings/cavings seen at surface. 6/21/2016 6/21/2016 3.85 PROD1 DRILL WPRT T RBIH to ensure hole is clean&lay in 72.0 10,650.0 06:15 10:06 liner running pill(11.8ppg Sodium Bromide).Tie-in to HRZ for+12.5' ' correction,K1 for+.5'correction,and RA for-1'corection,continue in hole. 6/21/2016 6/21/2016 3.15 PROD1 DRILL CIRC T Pump liner pill. POOH laying in 10,650.0 95.5 10:06 13:15 completion fluid.Paint EOP flag @ 8,300'. 6/21/2016 6/21/2016 0.50 PROD1 DRILL OWFF T Monitor well for flow,no flow. 95.5 95.5 13:15 13:45 6/21/2016 6/21/2016 1.25 PROD1 DRILL PULD T PJSM.LD BHA#9.Prep floor for liner 95.5 0.0 13:45 15:00 run. 6/21/2016 6/21/2016 2.50 COMPZ1 CASING PUTB T PJSM.MU Liner assembly bull nose, 0.0 510.0 15:00 17:30 14 jts slotted,anchored billet.MU BHA #10. 6/21/2016 6/21/2016 3.50 COMPZ1, CASING RUNL T RIH with liner to setting depth.Close 510.0 10,299.0 17:30 21:00 EDC.Tie in at HRZ for a+1.5 ft correction.Clean trip through tubing, pilot hole,window and build.Clean trip in OH to set depth 10,299 ft. PU to neutral weight.Bring pumps up, - set anchors at 3,500 psi.Set down 4KIbs to confirm set. 6/21/2016 6/21/2016 2.00 COMPZ1 CASING TRIP T POOH with liner running tools. 10,299.0 61.0 21:00 23:00 6/21/2016 6/21/2016 0.50 COMPZ1 CASING OWFF T Flow check at surface.Static. 61.0 61.0 23:00 23:30 6/21/2016 6/22/2016 0.50 COMPZ1 CASING PULD T Lay down liner running BHA#10. 61.0 0.0 23:30 00:00 6/22/2016 6/22/2016 0.50 COMPZ1 CASING PULD T Finish LD BHA#10. 0.0 0.0 00:00 00:30 6/22/2016 6/22/2016 2.00 PROD2 WHDBOP RURD P Clean up floor. MU nozzle.Stab 0.0 0.0 00:30 02:30 injector.Swap reel to water for BOPE test. 6/22/2016 6/22/2016 2.50 PROD2 WHDBOP RURD P PT inner reel iron and pack offs. 0.0 0.0 02:30 05:00 Grease choke manifold valves.Prep for BOPE test. 6/22/2016 6/22/2016 10.00 PROD2 WHDBOP BOPE P Perform bi-weekly 250/4100 psi, 0.0 0.0 05:00 15:00 annular 2500 psi.Test waived by AOGCC(Johnnie Hill).No failures, grease and retest R1 and C11.LD test equipment.Prep rig for visitors. 6/22/2016 6/22/2016 2.25 PROD2 STK PULD T PJSM.PU/MU BHA#11,with 0.5° 0.0 72.5 15:00 17:15 AKO motor and RB HCC bit. Install floats in UQC,skid and MU QC. Test MWD.Stab on well head.Bump up,open EDC. 6/22/2016 6/22/2016 1.00 PROD2 STK CIRC T Line up and swap reel from water to 72.5 72.5 17:15 18:15 11.8ppg NaBr. Page 13/27 Report Printed: 7/11/2016 • • :,,,.,,',,c` Operations Summary (with Timelog Depths) .iv, -� , e , „ 1 L-24 Conoccehmips `, 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) 6/22/2016 6/22/2016 2.50 PROD2 STK TRIP T RIH with BHA#11.Tie in to the HRZ 72.5 9,850.0 18:15 20:45 for a+14.5 foot correction.Close EDC.Weight check=31 Klbs.RIH and dry tag billet at 9850 ft. 6/22/2016 6/22/2016 1.50 PROD2 STK CIRC T PUH,roll hole from NaBr completion 9,850.0 9,832.0 20:45 22:15 fluid to 8.7 ppg FloPro. 6/22/2016 6/22/2016 1.50 PROD2 STK TRIP T RBIH,and dry tag billet.PUH.Bring 9,832.0 9,850.0 22:15 23:45 up pumps and prep to drill off of billet. 6/22/2016 6/23/2016 0.25 PROD2 STK KOST T Begin drilling off of billet. 9,850.0 9,851.0 23:45 00:00 6/23/2016 6/23/2016 2.00 PROD2 STK KOST T Continue drilling off of billet.Drill rat 9,851.0 9,880.0 00:00 02:00 hole to 9880 ft. 6/23/2016 6/23/2016 0.50 PROD2 DRILL TRIP T PUH,3OKlbs PUW. 9,880.0 9,880.0 02:00 02:30 RBIH and dry drift kick off area.Clean. 6/23/2016 6/23/2016 2.50 PROD2 DRILL DRLG T Back on bottom drilling.Pumping 1.6 9,880.0 10,000.0 02:30 05:00 BPM at 3600 psi.FS=353 psi.WOB =1.5 Klbs,CTW=9.5Klbs.Pumped new mud system with additional KlaStop/KCL,new mud at bit 9,942'. 6/23/2016 6/23/2016 5.00 PROD2 DRILL DRLG T Continue drilling: 1.65 BPM @ 3,725 10,000.0 10,280.0 05:00 10:00 PSI,BHP=3,940 PSI,CTW=7.5K, FS=325,WOB=1.6,ROP=60. 6/23/2016 6/23/2016 0.85 PROD2 DRILL WPRT T Wiper to 9,500',PUW=34K,hold TF 10,280.0 10,280.0 10:00 10:51 thru high gamma area.RBIH. 6/23/2016 6/23/2016 3.70 PROD2 DRILL DRLG T BOBD: 1.65 BPM @ 3,775 PSI, 10,280.0 10,465.0 10:51 14:33 BHP=3,865 PSI,CTW=7.9K,FS=315, WOB=1.5,ROP=50.ROP down to 20. Pull wiper. 6/23/2016 6/23/2016 0.50 PROD2 DRILL WPRT T 200'wiper,PUW=36K,RBIH. 10,465.0 10,465.0 14:33 15:03 6/23/2016 6/23/2016 3.95 PROD2 DRILL DRLG T BOBD:1.65 BPM @ 3,790 PSI, 10,465.0 10,680.0 15:03 19:00 BHP=3,885 PSI,CTW=8.5K,FS=320, WOB=1.3,ROP=50. 6/23/2016 6/23/2016 0.50 PROD2 DRILL WPRT T Planned wiper trip.PUH.PUW= 10,680.0 9,900.0 19:00 19:30 34Klbs. 6/23/2016 6/23/2016 0.50 PROD2 DRILL WPRT T RBIH.SOW=7 Klbs.Clean trip in and 9,900.0 10,680.0 19:30 20:00 out. 6/23/2016 6/23/2016 0.75 PROD2 DRILL DRLG T BOBD:1.64 BPM @ 3,840 PSI, 10,680.0 10,717.0 20:00 20:45 BHP=3,940 PSI,CTW=7.5K,FS=400, WOB=1.0,ROP=50-60. Motor stalled. 6/23/2016 6/23/2016 1.00 PROD2 DRILL DRLG T Work free and PUH after motor stall. 10,717.0 10,719.0 20:45 21:45 49Klbs PUW.Restart. Second stall. PUH,PUW 45Klbs. Third stall,PUH with 41 Klbs PUW. RBIH 6/23/2016 6/24/2016 2.25 PROD2 DRILL DRLG T Continue drilling ahead.1.59 BPM @ 10,719.0 10,840.0 21:45 00:00 3,890 PSI,BHP=3,940 PSI,CTW=6K, FS=380,WOB=1.0-1.2KIbs,ROP=50- 60. 6/24/2016 6/24/2016 3.00 PROD2 DRILL DRLG T Continue drilling ahead. 1.59 BPM @ 10,840.0 11,080.0 00:00 03:00 3,805 PSI,BHP=3,920 PSI,CTW=4K, FS=388,WOB=1.6KIbs,ROP=60-90 FPH. 6/24/2016 6/24/2016 2.00 PROD2 DRILL WPRT T Wiper trip,PUW=32K,saw 10,500'to 11,080.0 11,080.0 03:00 05:00 10,700',log RA for+6.5'correction, RBIH.Saw same interval,cut pump rate to.5 bpm. Page 14/27 Report Printed: 7/11/2016 0 i :$z*,41'`', „, Operations Summary (with Timelog Depths) x .,.: t 1 L-24 C itii ,;. 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) 6/24/2016 6/24/2016 4.25 PROD2 DRILL DRLG T BOBD:1.60 BPM @ 3,950 PSI, 11,080.0 11,480.0 05:00 09:15 BHP=3,960 PSI,CTW=4K, WOB=1.6K,ROP=100. 6/24/2016 6/24/2016 0.65 PROD2 DRILL WPRT T Wiper to 10,700',PUW=32K,RBIH. 11,480.0 11,480.0 09:15 09:54 6/24/2016 6/24/2016 0.40 PROD2 DRILL DRLG T BOBD: 1.60 BPM @ 3,925 PSI, 11,480.0 11,524.0 09:54 10:18 BHP=3,990 PSI,CTW=3K, WOB=1.2K,ROP=50.Start pumping new mud system.BHA wiper @ 10,717',trouble getting started again, fault?ROP below 10'. 6/24/2016 6/24/2016 4.25 PROD2 DRILL DRLG P BOBD: 1.60 BPM @ 3,925 PSI, 11,524.0 11,754.0 10:18 14:33 BHP=3,990 PSI,CTW=3K, WOB=1.2K,ROP=50.Start pumping new mud system.BHA wiper @ 10,717',trouble getting started again, fault?ROP below 10'.New mud at bit 11,748',no improvement.Off of trouble time. 6/24/2016 6/24/2016 0.45 PROD2 DRILL WPRT P 500'wiper,PUW=34K,RBIH. 11,754.0 11,754.0 14:33 15:00 6/24/2016 6/24/2016 3.00 PROD2 DRILL DRLG P BOBD: 1.60 BPM @ 3,680 PSI, 11,754.0 11,910.0 15:00 18:00 BHP=3,980 PSI,CTW=3K, WOB=1.5K, ROP=65.BHA wiper @ 11,812'. 6/24/2016 6/24/2016 0.50 PROD2 DRILL WPRT P Wiper trip from 11,910 to 10,900 ft. 11,910.0 11,910.0 18:00 18:30 PUW=33Klbs. RBIH.SOW=7Klbs. 6/24/2016 6/24/2016 3.25 PROD2 DRILL DRLG P BOBD: 1.61 BPM @ 3,600 PSI,FS= 11,910.0 12,055.0 18:30 21:45 375 psi BHP=4,000 PSI,CTW=3-5K, WOB=1.5K,ROP=40. 6/24/2016 6/24/2016 0.50 PROD2 DRILL WPRT P Wiper trip from 12055 to 11500 ft. 12,055.0 12,055.0 21:45 22:15 PUW=32Klbs.RBIH.SOW=6 Klbs. 6/24/2016 6/24/2016 1.50 PROD2 DRILL DRLG P BOBD: 1.62 BPM @ 3,770 PSI,FS= 12,055.0 12,135.0 22:15 23:45 370 psi BHP=4,020 PSI,CTW=-- 4KIbs to+3Klbs,WOB=1.5K, ROP=50. 6/24/2016 6/25/2016 0.25 PROD2 DRILL WPRT P Wiper trip from 12135 to 11600 ft. 12,135.0 12,135.0 23:45 00:00 PUW=32Klbs. RBIH.SOW=6 Klbs. 6/25/2016 6/25/2016 0.25 PROD2 DRILL WPRT P RBIH from wiper trip.SOW=6 Klbs. 12,135.0 12,135.0 00:00 00:15 6/25/2016 6/25/2016 1.75 PROD2 DRILL DRLG P BOBD: 1.61 BPM @ 3,615 PSI,FS= 12,135.0 12,219.0 00:15 02:00 370 psi BHP=4,030 PSI,CTW=-- , 6KIbs to+3Klbs,WOB=0.5-1.0K, ROP=20-50. 6/25/2016 6/25/2016 0.50 PROD2 DRILL WPRT P 500 foot wiper trip to help weight 12,219.0 12,219.0 02:00 02:30 transfer.RBIH,start pumping beaded pills at 0.5ppb. 6/25/2016 6/25/2016 1.75 PROD2 DRILL DRLG P BOBD: 1.58 BPM @ 3,590 PSI,FS= 12,219.0 12,305.0 02:30 04:15 375 psi BHP=4,060 PSI,CTW=-- 6KIbs to+3Klbs,WOB=0.5-1.5K, ROP=20-50.Beads at bit at 12220 ft. Saw improvement in weight transfer and ROP.ROP increased to 80 FPH. 6/25/2016 6/25/2016 2.00 PROD2 DRILL WPRT P Wiper to determine hole condition,jog 12,305.0 8,888.0 04:15 06:15 10760'to 10,975',continue OOH. Reduce rate thru high gamma,no issues. Page 15/27 Report Printed: 7/11/2016 • • Operations Summary (with Timeiog Depths) ‘‘4,s@-':,''''',:,,', ,, 1 L-24 cox ocoPhitiips ; ' Si:r,Aa 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) 6/25/2016 6/25/2016 2.45 PROD2 DRILL TRIP P Tie-in RA for+8.5'correction,RBIH. 8,888.0 12,310.0 06:15 08:42 Stacked 2K @ 10,010',PU,RBIH. stacking @ 10,631-10,636',work pipe free,49K to pull free, PUH to 10,500'. RBIH,stacking @ 10,610',PU was clean,35K,RBIH,no issue.Call town, called TD.Continue in hole for corrected TD,tag bottom @ 12,310'. 6/25/2016 6/25/2016 3.90 PROD2 DRILL WPRT P Pump 10 x 10 sweeps and liner pill. 12,310.0 75.5 08:42 12:36 POOH laying in beads,chasing sweeps.Slight overpull thru 10,660'to 10,510'.Increase pump, POOH,jog @ 9,165'to 9,350',continue OOH, overpull @ 8,616'(milled DS Nip). Continue OOH.Small jog at surface for cuttings clean up. 6/25/2016 6/25/2016 3.00 PROD2 DRILL TRIP P Bump up,reset counter.RBIH to 75.5 10,500.0 12:36 15:36 laying completion fluid.Tie-in HRZ for +10'correction,log RA for zero correction,small bobble©9,108', 10,006',and 10,046',small jog @ 10,000'.Continue in hole to 10,500+. 6/25/2016 6/25/2016 2.90 PROD2 DRILL CIRC P Pump liner pill.POOH laying in 11.8 10,500.0 72.5 15:36 18:30 completion fluid,paint EOP flags @ 8,920'&5,400'.Continue OOH. 6/25/2016 6/25/2016 0.50 PROD2 DRILL OWFF P At surface,flow check.Static. 72.5 72.5 18:30 19:00 6/25/2016 6/25/2016 2.00 PROD2 DRILL PULD P PJSM.LD BHA#11 over dead well. 72.5 0.0 19:00 21:00 BHA in good shape.Bit has some broken cutters on the nose.Bit grade 2-1-BT-A-X-I-PN-TD. Clean and clear rig floor. 6/25/2016 6/26/2016 3.00 COMPZ2 CASING PUTB P PJSM.RU and run liner.Non ported 0.0 2,650.0 21:00 00:00 bull nose, 109 joints slotted,5.56'pup and liner top billet. *Kick while tripping drill.All safe. 6/26/2016 6/26/2016 0.75 COMPZ2 CASING PUTB P Finish picking up liner joints. 2,650.0 3,341.0 00:00 00:45 6/26/2016 ' 6/26/2016 1.00 COMPZ2 CASING PULD P MU Coiltrak BHA.Test MWD.Stab 3,341.0 3,384.0 00:45 01:45 injector on well.Bump up and reset counters.Prepare to run in the hole. 6/26/2016 6/26/2016 2.50 COMPZ2 CASING RUNL P RIH with liner assembly,non ported 3,384.0 10,699.0 01:45 04:15 bullnose, 109 joints of slotted liner, 5.56'blank pup and liner top billet. PUW with shoe at window 35Klbs. WOB=(-)12Klbs.Continue in the hole. Starting taking weight at 10,560 ft.Tough hole conditions.Working liner down.46Klbs PUW.(-)16Klbs' WOB. Work liner down to 10,699 ft,lost PUW. PUW=27Klbs.Suspect running tool released from liner. 6/26/2016 6/26/2016 1.25 COMPZ2 CASING TRIP T POOH to inspect liner running BHA. 10,699.0 75.5 04:15 05:30 PUW=22Klbs. 6/26/2016 6/26/2016 2.25 COMPZ2 CASING PULD T PJSM.Space out.Strip up,LD MWD. 75.5 0.0 05:30 07:45 GS in good space,surface test with GS profile was also good.Discuss plan forward with town. Page 16/27 Report Printed: 7/11/2016 • • Operations Summary (with Timelog Depths) Pi 0 1 L-24 CortocoPhillips 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) 6/26/2016 6/26/2016 3.25 COMPZ2 CASING SVRG T Service rig while waiting on Slick 0.0 0.0 07:45 11:00 Catch GS from Prudhoe. Injector maintenance,blow down choke, calibrate choke,perform BOP function test 6/26/2016 ' 6/26/2016 0.75 COMPZ2 CASING PULD T PJSM.PU BHA#13,with BOT 3"Slick 0.0 44.5 11:00 11:45 Catch GS Spear.Stab on well.Test MWD. 6/26/2016 6/26/2016 1.75 COMPZ2 CASING TRIP T RIH w/BHA#13,CCL log over GLM 44.5 7,358.0 11:45 13:30 for depth control.PUH for weight check.PUW=29 Klbs,SOW=5.9 Klbs.Tag top of fish at 7348 ft. 6/26/2016 6/26/2016 0.50 COMPZ2 CASING FISH T Attempt to engage GS profile on top of 7,358.0 7,538.0 13:30 14:00 the aluminum billet with BOT Slick Catch GS spear.Unsuccessful after two attempts.Suspect GS profile is damaged.Discuss options with town. Made decision to POOH and try other fishing options. 6/26/2016 6/26/2016 1.00 COMPZ2 CASING TRIP T POOH with fishing BHA#13.PUW= 7,538.0 44.0 14:00 15:00 29 Klbs. 6/26/2016 6/26/2016 0.50 COMPZ2 CASING OWFF T Flow check well at surface.Static. 44.0 44.0 15:00 15:30 6/26/2016 6/26/2016 0.75 COMPZ2 CASING PULD T PJSM.Unstab.Break off and inspect 44.0 0.0 15:30 16:15 GS.No damage observed on BHA/Slick Catch GS Spear. 6/26/2016 6/26/2016 2.00 COMPZ2 CASING WAIT T Wait on fishing tools from Deadhorse. 0.0 0.0 16:15 18:15 SIMOPS:Perform dropped object rig inspection and general rig maintenance.Discuss plan forward with town. 6/26/2016 6/26/2016 3.75 COMPZ2 CASING PULD T Confirmed plan forward for fishing 0.0 7,348.0 18:15 22:00 operations.PJSM.MU BHA#14 with 3"GS,3"GS Bait Sub,XO,1"ITCO spear.Surface test MWD.Open EDC, Run in hole.Log CCL for depth control.Confirm BHA overpull limits. Tag up on fish. 6/26/2016 6/26/2016 0.50 COMPZ2 CASING FISH T Weight check.PUW=28 Klbs.Close 7,348.0 7,348.0 22:00 22:30 EDC. RIH to engage fish. 1st attempt:Set down 9.6Klbs WOB. PUH 36Klbs and broke over to PUW. 2nd attempt:Set down 9.0Klbs WOB. PUH 40KIbs and broke over to PUW. 3rd-6th attempts:Set down 11 Klbs WOB.PUH at PUW each time. Suspect grapples have failed or billet ID got to large to engage. POOH to inspect ITCO spear. 6/26/2016 6/26/2016 1.25 COMPZ2 CASING TRIP T Discuss with town. Open EDC,POOH 7,348.0 70.0 22:30 23:45 with BHA#14. 6/26/2016 6/27/2016 0.25 COMPZ2 CASING OWFF T Flow check at surface. 70.0 70.0 23:45 00:00 6/27/2016 6/27/2016 0.25 COMPZ2 CASING OWFF T Flow check at Surface.Static. 70.0 70.0 00:00 00:15 Page 17/27 Report Printed: 7/11/2016 • • `i" Operations Summary (with Timelog Depths) .�fi 1L-24 conocoi'himps t,L^sk,a 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) 6/27/2016 6/27/2016 1.25 COMPZ2 CASING PULD T PJSM.Unstab injector.PU and 70.0 70.0 00:15 01:30 inspect 1"ITCO Spear.Spear body is intact,but grapple segments are missing. Break off GS tools and spear(BHA #14).MU 2-1/8"BOT motor and 1.81" 3 bladed junk mill below the FSV (BHA#15). 6/27/2016 6/27/2016 1.25 COMPZ2 CASING TRIP T RIH with BHA#15,BOT motor and• 70.0 7,348.0 01:30 02:45 1.81"mill.Dry tag fish at 7348 ft. 6/27/2016 6/27/2016 1.50 COMPZ2 CASING DISP T Displace hole from 11.8 ppg NaBr to 7,348.0 7,348.0 02:45 04:15 8.7 ppg FloPro in preparation for milling operations. 6/27/2016 6/27/2016 2.90 COMPZ2 CASING MILL T Close EDC.RIH and tag billet.Begin 7,348.0 7,348.5 04:15 07:09 milling.Stalled and restarted at 7347.88 ft.Pumping 1.5 BPM.WOB 0.15-0.3 Klbs. Seven total stall during milling operations,no more than 0.3K WOB before stall occurs,aluminum at shaker.No further progress,just stalling,confirm with town. 6/27/2016 6/27/2016 2.30 COMPZ2 CASING CIRC T Pump sweeps,circulate hole back to 7,348.5 75.5 07:09 09:27 KWF,POOH. 6/27/2016 6/27/2016 0.50 COMPZ2 CASING OWFF T Monitor well for flow,no flow. 75.5 75.5 09:27 - 09:57 6/27/2016 6/27/2016 1.30 COMPZ2 CASING PULD T PJSM.LD BHA#15,mill showed 75.5 44.5 09:57 11:15 polished ring at No-GO,check above CC,re-configure BHA.MU BHA#16 6/27/2016 6/27/2016 1.55 COMPZ2 CASING TRIP T RIH w/BHA#16,PUW=28K at 7,295', 44.5 7,348.0 11:15 12:48 tag fish while pumping @ 1 bpm, 7,348',set down 6K WOB,shut down pump,set down 9K WOB,-6K string. PU to 35K,40K,45K,50K pulled free. 6/27/2016 6/27/2016 3.20 COMPZ2 CASING PULL T POOH with fish at 10 fpm,pumping 7,348.0 5,470.0 12:48 16:00 across top,inside cased hole at 20 fpm.(Bottom of fish at 10699). 6/27/2016 6/27/2016 4.50 COMPZ2 CASING PULL T Full length of fish is inside tubing. 5,470.0 43.0 16:00 20:30 POOH 20 fpm,pumping across top. 30 minute flow check at surface. Static. 6/27/2016 6/27/2016 0.50 COMPZ2 CASING OWFF T 30 minute flow check at surface. 43.0 43.0 20:30 21:00 Static. 6/27/2016 6/27/2016 1.00 COMPZ2 CASING PULL T PJSM.Tag up,space out BHA. 43.0 0.0 21:00 22:00 Secure BHA in deployment rams. Unstab injector.Skid injector cart. Instal lift sub,pull BHA out of the hole, instal C plate and slip bowls.Set slips on first full joint of liner. Install dog collar,Secure fish. Slick Catch GS was fully engaged with the liner top billet fish.Removed billet with GS from liner assembly and moved to bench for inspection. 6/27/2016 6/28/2016 2.00 COMPZ2 CASING PULL T Prep floor to run liner.PJSM to 0.0 0.0 22:00 00:00 discuss LD liner. Begin laying down liner joints 109-69. Page 18/27 • Report Printed: 7/11/2016 110 . Operations Summary (with Timelog Depths) 1 L-24 Conoccehillips , 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) 6/28/2016 6/28/2016 3.00 COMPZ2 CASING PULL T Continue to lay down liner joints.Stop 0.0 0.0 00:00 03:00 at jt 52.Strap first row in pipe shed. Continue laying down liner joints 52-1 including non ported bull nose. Note:Found grapple segments from 1"ITCO spear in bull nose. 6/28/2016 6/28/2016 1.25 COMPZ2 CASING PULD T Clear rig floor.PJSM.PU BHA#17 0.0 63.0 03:00 04:15 with 0.5°AKO motor and 2.73"NG HCC D331 mill. 6/28/2016 6/28/2016 4.00 COMPZ2 CASING TRIP T RIH with BHA#17 for clean-out run, 63.0 10,500.0 04:15 08:15 log HRZ for+16.5'correction,zero correction @ RA,RIH to 10,500'. Pump spacer. 6/28/2016 6/28/2016 1.00 COMPZ2 CASING CIRC T Circulate hole back to 8.8 ppg mud 10,500.0 10,500.0 08:15 09:15 6/28/2016 6/28/2016 0.90 COMPZ2 CASING TRIP T Continue in hole @ 1 bpm,stacking @ 10,500.0 10,636.0 09:15 10:09 10,525', 10.595, 10,614'and 10,636'. PUH,packing-off,cut pump cut,PUH to 10,495'.Pump rate.75 bpm, stacking 10,523',PUW=38K,packing- off,shut down pump,relax pipe,pull up,PUW=51K. 6/28/2016 6/28/2016 1.25 COMPZ2 CASING WPRT T Wiper to TT,clean up hole above at 10,636.0 8,890.0 10:09 11:24 1,56 bpm,just small cutting across shaker,tie-in RA for+3.5'. 6/28/2016 6/28/2016 1.50 COMPZ2 CASING TRIP T RBIH for second attempt clean up 8,890.0 10,580.0 11:24 12:54 high gamma area,tag up 10,001', PUH,lower pump rate,continue in hole,stacking 10,514',work thru tight areas to 10,580'at.75 bpm.Call town, decide to make another,clean up jog, PUW=thru tight area 39K. 6/28/2016 6/28/2016 0.75 COMPZ2 CASING WPRT T Wiper to 10,150,PUW=36K.Town 10,580.0 10,150.0 12:54 13:39 called,keep working thru high gamma area,RBIH. 6/28/2016 6/28/2016 1.15 COMPZ2 CASING TRIP T Continue working trouble area at.85 10,150.0 10,611.0 13:39 14:48 bpm from 10,525'to 10,611',Make another clean up trip,try to increase pump rate,start packing off,decrease rate back to.80. 6/28/2016 6/28/2016 0.50 COMPZ2 CASING WPRT T Wiper to 10,200',PUW=37.RBIH,try 10,611.0 10,611.0 14:48 15:18 1 bpm thru trouble area. 6/28/2016 6/28/2016 2.50 COMPZ2 CASING TRIP T Continue working trouble area at.81 10,611.0 10,669.0 15:18 17:48 bpm from 10,575'to 10,669'before town had seen enough. 6/28/2016 6/28/2016 2.40 COMPZ2 CASING TRIP T Pump two 5 bbl hi vis sweeps,chase 10,669.0 62.4 17:48 20:12 to swab.Jog at 1,800 ft to 3,000 ft, nothing significant across shaker. Continue POOH. 6/28/2016 6/28/2016 1.50 COMPZ2 CASING TRIP T PJSM- PUD BHA#17.Mill 2.73"OD 62.4 0.0 20:12 21:42 no-go 6/28/2016 6/28/2016 1.15 PROD2 STK PULD T PJSM-MU/PD BHA#18,OHA Billet 0.0 72.8 21:42 22:51 assembly,MU to CoilTrak.Surface test. 6/28/2016 6/29/2016 1.15 PROD2 STK TRIP T RIH with BHA#18 to 5,125 ft as of. 72.8 5,125.0 22:51 00:00 midnight. 6/29/2016 6/29/2016 0.75 PROD2 STK TRIP T Contiue RIH with BHA#18. 5,125.0 8,355.0 00:00 00:45 Page 19/27 Report Printed: 7/11/2016 ! ! Operations Summary (with Timelog Depths) �gt 1 L-24 ' rg ConocoPhiltips 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) 6/29/2016 6/29/2016 0.40 PROD2 STK DLOG T Tie in at HRZ for a plus 10 ft 8,355.0 9,417.0 00:45 01:09 correction.Close EDC.PUW 31k 6/29/2016 6/29/2016 1.25 PROD2 STK TRIP T RBIH pumps off,HS orientation,clean 9,417.0 10,431.8 01:09 02:24 thru window,stack weight 2.45k at 9,860 ft,PU 32k,RBIH 10 fpm,WOB 4k at 9,864 ft,PU 35k(Billet at 9,850 ft)RBIH 10 fpm from 9,840 ft, 1.4k to 1.8k WOB from 9,854 ft to 9,871 ft, continue RIH 6/29/2016 6/29/2016 0.20 PROD2 STK TRIP T 10,431.75 ft.Orient HS,pick up to 10,431.8 10,420.0 02:24 02:36 neutral,release off OHAB at 4,350 psi, stack 5.5k,top of billet at 10,420 ft. 6/29/2016 6/29/2016 2.10 PROD2 STK TRIP T POOH,PUW 31k,Open EDC at 8,200 10,420.0 72.8 02:36 04:42 ft 6/29/2016 6/29/2016 1.90 PROD2 STK PULD T PJSM-PUD/LD BHA#18 72.8 0.0 04:42 06:36 6/29/2016 6/29/2016 4.00 PROD2 STK PULD T PJSM.Change-out UQC,test,check 0.0 72.5 06:36 10:36 pack-offs.PD BHA#19.Test MWD. 6/29/2016 6/29/2016 2.85 PROD2 STK TRIP T RIH w/Drilling assembly,.5 ako ' 72.5 10,421.0 10:36 13:27 motor,RB Hughes bit.Tie-in HRZ for +10.5'correction,zero correction at RA,close EDC,PUW=32K.Dry tag billet@ 10,421'. 6/29/2016 6/29/2016 8.10 PROD2 STK KOST T Starting pump 1.55 bpm,RIH,stall, 10,421.0 10,440.0 13:27 21:33 PU restart.Attempt to lightly tag billet, stall three times.BHA wiper,try lower pump rate,small orientation change. Multiple stalls.Trough low side,time drill.back ream 30°ROHS up 10 ft. RBIH,stalling,weight transfer issue, pump bead pills.time drill per recommended practice 1,2,5, 10,20 fph.PUW 33k,RBIH,dry drift billet clean. 6/29/2016 . 6/30/2016 2.45 PROD2 DRILL DRLG T 10,440 ft. OBD 1.6 bpm at 3,446 psi 10,440.0 10,510.0 21:33 00:00 FS,BHP 3,905 psi,CWT 8.0k,WOB 1.7k,ROP 40,WHP 309, IA 40,OA 208 6/30/2016 6/30/2016 3.00 PROD2 DRILL DRLG T 10,510 ft..OBD 1.6 bpm at 3,646 psi, 10,510.0 10,630.0 00:00 03:00 BHP 3,884 psi,CWT 4.5k,WOB 2.2k, ROP 45,WHP 267, IA 66,OA 232 6/30/2016 6/30/2016 0.85 PROD2 DRILL WPRT T Wiper trip to window,PUW 34k,30 10,630.0 8,890.0 03:00 03:51 fpm at TF from 10,075 ft to 9,900 ft,no over pulls,200 ft jog at EOB. 6/30/2016 6/30/2016 0.15 PROD2 DRILL DLOG T Log RA marker for a plus 1.5 ft 8,890.0 8,910.0 03:51 04:00 correction. 6/30/2016 6/30/2016 0.80 PROD2 DRILL WPRT T Wiper back in hole,RIW 11.0k,clean 8,910.0 10,630.0 04:00 04:48 past billet at 9,850 ft,no problems thru high gama area to 10,075 ft,25 fpm at.5 bpm pump rate.clean past billet at 10,421 ft. 6/30/2016 6/30/2016 4.15 PROD2 DRILL DRLG T 10,630 ft. OBD 1,60 bpm at 3,700 psi 10,630.0 10,880.0 04:48 08:57 FS,BHP 3,914 psi,CWT 6.0k,WOB 1.6k,ROP 60,WHP 286, IA 64,OA 248. 6/30/2016 6/30/2016 0.75 PROD2 DRILL WPRT T 750'wiper trip,PUW=33K,RBIH. 10,880.0 10,880.0 08:57 09:42 Page 20/27 Report Printed: 7/11/2016 • • • r " 1 • Operations Summary (with Timelog Depths) :,'-,'*4, � r '3 .. . 1 L-24 CcoP'hiflips 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) 6/30/2016 6/30/2016 4.45 PROD2 DRILL DRLG T 10,880 ft. OBD 1,62 bpm at 3,850 psi 10,880.0 11,122.0 09:42 14:09 FS,BHP 3,930psi,CWT 4.5 k,WOB 1.6k,ROP 55,WHP 293,IA 200,OA 350.Mini wiper @ 11,113'.Pull wiper early. 6/30/2016 6/30/2016 0.80 PROD2 DRILL WPRT T 800'wipertrip,PUW=35K,RBIH. 11,122.0 11,122.0 14:09 14:57 6/30/2016 6/30/2016 7.70 PROD2 DRILL DRLG T 11,122 ft. OBD 1,61 bpm at 3,950 psi 11,122.0 11,380.0 14:57 22:39 FS,BHP 3,945 psi,CWT 3.5 k,WOB 2.2k,ROP 50, IA 200,OA 350.High Gama at 11,110 ft,100 ft wiper at 11,200 ft,PUW 40k,broke over to 35k,RBIH no problems,broke out of high gama area at 11,220 ft. 6/30/2016 6/30/2016 1.20 PROD2 DRILL WPRT T Wiper trip for tie in,PUW 35k,chase 11,380.0 8,890.0 22:39 23:51 5x5 to window adjusting speed and TF accordingly thru problem areas and past billets,saw small spike at 10,116 ft,jog at EOB. 6/30/2016 7/1/2016 0.15 PROD2 DRILL DLOG T Log RA marker for 3.5 ft.correction 8,890.0 8,910.0 23:51 00:00 7/1/2016 7/1/2016 1.30 PROD2 DRILL WPRT T Wiper in hole adjusting speed,pump 8,910.0 11,380.0 00:00 01:18 rate and TF accordingly thru problem areas and past billets,stacked at 10,187 ft RIH 50 fpm,HS TF at 1.2 bpm,PUW 34k,stack at same at 20 fpm,HS TF at.5 bpm,PU clean,RBIH 25 fpm,70°L TF at.5 bpm,took weight 2k at 10,520 ft RIH 40 fpm, HS TF, 1.15 pbm,slow to 30 fpm, pumping 1 bpm.No proplem 11,100 ft to 11,250 ft 25 fpm at.8 bpm,RIW 7.2k. 7/1/2016 7/1/2016 3.85 PROD2 DRILL DRLG T 11,380 ft. OBD 1.6 bpm at 3,959 psi 11,380.0 11,630.0 01:18 05:09 FS,BHP 3,981 psi,CWT 5.0k,WOB 1.8k,ROP 48,WHP 145, IA 248,OA 396 **Mud swap-new mud out bit at 11,441 ft. 7/1/2016 7/1/2016 1.00 PROD2 DRILL WPRT T Wiper trip, PUW=35K,WOB spike @ 11,630.0 11,630.0 05:09 06:09 11,135'pack-off, RBIH,tight spots @ 10,790',10,825',and 11,130'. 7/1/2016 7/1/2016 6.75 PROD2 DRILL DRLG T 11,630 ft. OBD 1.6 bpm at 4,025 psi 11,630.0 12,030.0 06:09 12:54 FS,BHP 4,025 psi,CWT 3 k,WOB 1.8k,ROP 60,WHP 315,IA 175,OA 346.Mini wiper @ 11,986'.Started pumping 5 bbl beaded pills regiment for total of 25 bbls. 7/1/2016 7/1/2016 1.00 PROD2 DRILL WPRT T Wiper trip, PUW=36K,another WOB 12,030.0 12,030.0 12:54 13:54 spike @ 11,135'pack-off,RBIH,no issues. 7/1/2016 7/1/2016 3.75 PROD2 DRILL DRLG T 12,030 ft. OBD 1.6 bpm at 4,090 psi 12,030.0 12,226.0 13:54 17:39 FS,BHP 4,060 psi,CWT 3 k,WOB 1.2k,ROP 55,WHP 335, IA 175,OA 346.Mini wiper @ 11,986'.Continue pumping 5 bbl beaded pills regiment for total of 15 bbls. 7/1/2016 7/1/2016 0.60 PROD2 DRILL WPRT T Wiper trip 800 ft for weight transfer, 12,226.0 12,226.0 17:39 18:15 PUW 36k, faulted into high gama at 12,194 ft. Page 21/27 Report Printed: 7/11/2016 0 • :x ' Operations Summary (with Timelog Depths) 6 -..'-:'''.;..,';.„,4,, 1 L-24 ConocaPhillips t,1.7,ka 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) 7/1/2016 7/1/2016 2.20 PROD2 DRILL DRLG T 12,226 ft. OBD 1.59 at 3,883 psi FS, 12,226.0 12,259.0 18:15 20:27 BHP 4,059 psi,CWT 0.0k,WOB 1.5k, ROP 16, WHP 330,IA 228,OA 379 7/1/2016 7/1/2016 2.60 PROD2 DRILL WPRT T 12,259 ft.Geo's called TD,PU,pump 12,259.0 8,730.0 20:27 23:03 10x10.Chase sweeps to swab adjusting speed and TF accordingly, pulled 42k at 9,985 ft,RBIH and stacked,lower pump rate to.7 bpm, PU 37k,pulled heavy to 9,950 ft, continue POOH,jog at EOB,pull 41.5k in pilot hole at 8,764 ft,RBIH 25 ft,PUW 34k,overpull to 45k at 8,730 ft,WOB-.85k,cuttings above,build low-vis pill. 7/1/2016 7/1/2016 0.70 PROD2 DRILL WPRT T 8,730 ft. RBIH to EOB,30 fpm 8,730.0 9,700.0 23:03 23:45 pumping 1.59 bpm from 9150 ft. to 9,700 ft. 7/1/2016 7/2/2016 0.25 PROD2 DRILL WPRT T 9,700 ft.PUH waiting for sweeps. 9,700.0 9,380.0 23:45 00:00 7/2/2016 7/2/2016 3.25 PROD2 DRILL WPRT T PUH 15 fpm,pump and Circulate 9,380.0 72.0 00:00 03:15 bottoms up 10x10 Lo/Hi sweep 1.7 bpm,nothing unusual across shaker. POOH,small spike at 9,133 ft,clean thru window and pilot hole,continue POOH to swab.Jog at 420 ft,coarse shale's unloading at shaker,bump up, reset counters. 7/2/2016 7/2/2016 1.80 PROD2 DRILL TRIP T RIH with BHA#19 72.0 8,365.0 03:15 05:03 7/2/2016 7/2/2016 0.25 PROD2 DRILL DLOG T Tie in at HRZ for plus 9.5 ft correction. 8,365.0 8,410.0 05:03 05:18 7/2/2016 7/2/2016 2.15 PROD2 DRILL TRIP T Continue in hole,saw weight @ 8,410.0 12,190.0 05:18 07:27 9,892',9,990', 10,495', 10,534', 10,790',10,824', 11,163', 11,206', 11,216',11,248'&11,343'.Continue to 12,190'.Pump 40 bbl beaded liner pill. 7/2/2016 7/2/2016 3.45 PROD2 DRILL CIRC T POOH laying ns completion 9fluids, 12,190.0 75.5 07:27 10:54 Continue OOH. 7/2/2016 7/2/2016 1.00 PROD2 DRILL OWFF T Monitor well for flow,no flow. LD BHA 75.5 0.0 10:54 11:54 #19. 7/2/2016 7/2/2016 1.00 COMPZ2 CASING PUTB T Prep floor for liner runs. 0.0 0.0 11:54 12:54 7/2/2016 7/2/2016 2.80 COMPZ2 CASING PUTB T PJSM.MU Lower liner assembly:BN, 0.0 2,442.0 12:54 15:42 80 jts slotted,shorty deployment sleeve. 7/2/2016 7/2/2016 1.00 COMPZ2 CASING PULD T PJSM.MU BHA#20,change floats in 2,442.0 2,487.0 15:42 16:42 UQC,test MWD. 7/2/2016 7/2/2016 3.40 COMPZ2 CASING RUNL T RIH w/lower liner assembly,tie-in for 2,487.0 12,190.0 16:42 20:06 plus 6.6 ft correction at flag,PUW 36.5k,WOB-8.98k,RBIH,plus 2 ft correction at HRZ,continue in hole. Release off liner at 12,190 ft,PUW 32k,WOB-0.2k,reset counters,top of lower liner 9,747 ft.line up pump. 7/2/2016 7/2/2016 2.40 COMPZ2 CASING TRIP T POOH pumping over the top,paint 9,747.0 44.2 20:06 22:30 EOP flags at 8,900 ft and 7,900 ft. , continue OOH. Page 22/27 Report Printed: 7/11/2016 • • > Operations Summary (with Timelog Depths) 1L-24 16 ConocoPhitlips µ'' 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) 7/2/2016 7/2/2016 0.50 COMPZ2 CASING OWFF T Monitor well for flow,no flow.PJSM- 44.2 44.2 22:30 23:00 LD BHA. 7/2/2016 7/3/2016 1.00 COMPZ2 CASING PUTB T LD BHA#20,prep floors to run liner. 44.2 0.0 23:00 00:00 PJSM-MU liner assembly. 7/3/2016 7/3/2016 1.85 COMPZ2 CASING PUTB T MU Ported bullnose,pup jt,25 jts 0.0 777.2 00:00 01:51 slotted,OH Anchored Billet,tripping drill. 7/3/2016 7/3/2016 1.60 COMPZ2 CASING PULD T PJSM-MU Upper AL1-02 liner 777.2 838.3 01:51 03:27 assembly to BHA#21,MU to CoilTrak, surface test. 7/3/2016 7/3/2016 3.00 COMPZ2 CASING RUNL T RIH w/Upper AL1-02 liner assembly, 838.3 9,751.0 03:27 06:27 EDC Open,tie-in for plus 10 ft correction at flag,down on pump, close EDC,PUW 32k,WOB-3.5k, RBIH to set depth, PUW=36K,orient for 60 degree kick-off,tag up on lower liner assembly @ 9,751',pressure up 3,200 psi,release from liner, PUW=32K. 7/3/2016 7/3/2016 2.00 COMPZ2 CASING TRIP P POOH w/BHA#21 9,751.0 55.5 06:27 08:27 7/3/2016 7/3/2016 1.05 COMPZ2 CASING PULD P Monitor well for flow,no flow.PJSM. 55.5 0.0 08:27 09:30 LD BHA#21. 7/3/2016 7/3/2016 2.50 PROD3 WHDBOP RURD P Prep for bi-weekly BOPE test.Load 0.0 0.0 09:30 12:00 coil,test inner reel iron,valve crew greased tree,grease stack. • 7/3/2016 7/4/2016 12.00 PROD3 WHDBOP BOPE P Perform bi-weekly BOP test,250/4100 0.0 0.0 12:00 00:00 psi,annular 2,500 psi,test witnessed by Guy Cook(AOGCC).Two failures, change out choke"A"lower and upper Blind/Shear ram bodies. 7/4/2016 7/4/2016 8.00 PROD3 WHDBOP BOPE T Continue testing BOPE,witnessed by 0.0 0.0 00:00 08:00 AOGCC Guy Cook.F/P both blind/shear rams,choke"A", C3,C4,R2,and H2S pit sensor. 7/4/2016 7/4/2016 1.75 PROD3 STK CIRC P LD test equipment.Circulate coil to 0.0 0.0 08:00 09:45 drilling mud. 7/4/2016 7/4/2016 0.95 PROD3 STK PULD P PJSM.MU BHA#22 0.0 72.2 09:45 , 10:42 7/4/2016 7/4/2016 2.00 PROD3 STK TRIP P RIH w/drilling assembly:2.0 AKO 72.2 8,900.0 10:42 12:42 motor and RR Hughes bit,tie-in for+9' correction,continue in hole to 8,900'. 7/4/2016 7/4/2016 1.05 PROD3 STK CIRC P Circulate well back to drilling mud. 8,900.0 8,973.0 12:42 13:45 Continue in hole,dry tag billet @ 8,973'. 7/4/2016 7/4/2016 3.50 PROD3 STK KOST P Time mill off billet @ 1 fph,then 2 fph, 8,973.0 9,022.0 13:45 17:15 Pump rate 1.52 bpm @ 3,395 psi, CTW=10,WOB=.4K.Aluminum across shaker.Off billet,drill to 9,022 ft,pump sweep,PUW 33k,dry drift billet area clean. 7/4/2016 7/4/2016 3.50 PROD3 DRILL DRLG P Drill ahead AL1 build section: 1.70 9,022.0 9,275.0 17:15 20:45 bpm at 3,669 psi FS,BHP3,762 psi, CTW 10.0k,WOB 1.5k,ROP 60-80, WHP 289, IA 20,OA 188.EOB called, pump sweep. 7/4/2016 7/4/2016 2.00 PROD3 DRILL TRIP P POOH for lateral BHA,jog at 400 ft. 9,275.0 72.2 20:45 22:45 Page 23/27 Report Printed: 7/11/2016 • • Operations Summary (with Timelog Depths) 7. 1 L-24 Conc P hiHlips `"Y o M1Erks 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) 7/4/2016 7/5/2016 1.25 PROD3 DRILL PULD P PJSM-PUD BHA#22 72.2 72.2 22:45 00:00 7/5/2016 7/5/2016 0.50 PROD3 DRILL PULD P LD BHA#22,bit condition:4-1-BT-N-X 72.2 0.0 00:00 00:30 -I-PN-BHA,3 leading cutters broken, 1 plugged nozzle. 7/5/2016 7/5/2016 2.10 PROD3 DRILL PULD P PJSM-MU/PD drilling BHA#23,0.4+° 0.0 72.2 00:30 02:36 motor and RB HCC bi-center bit, change out pack offs,MU to CoilTrak, surface test. 7/5/2016 7/5/2016 1.55 PROD3 DRILL TRIP P RIH with BHA#23 72.2 8,365.0 02:36 04:09 7/5/2016 7/5/2016 0.50 PROD3 DRILL DLOG P Tie in at HRZ for plus 10 ft.correction, 8,365.0 8,350.0 04:09 04:39 PUW 32k 7/5/2016 7/5/2016 0.50 PROD3 DRILL TRIP P RIH,clean thru window and past billet. 8,350.0 9,275.0 04:39 05:09 7/5/2016 7/5/2016 1.10 PROD3 DRILL DRLG P 9,275 ft. OBD 1.66 bpm at 3,644 psi 9,275.0 9,328.0 05:09 06:15 FS,BHP 3,784 psi,CWT 9.0k,WOB 1.2k,ROP 60,WHP 271,IA 0,OA 116. PU to swap from Gen power to ' Highline. 7/5/2016 7/5/2016 4.00 PROD3 DRILL DRLG P 9,328 ft.BOBD 1.68 bpm at 3,692 psi 9,328.0 9,670.0 06:15 10:15 FS.BHP 4,214 psi,CWT 7.7k,WOB 2.1k,ROP 73. 7/5/2016 7/5/2016 0.25 PROD3 DRILL WPRT P Wiper from 9,670'to 9,000'.PU 9,670.0 9,000.0 10:15 10:30 weight=33k, 1.7 BPM.Pumped sweep. 7/5/2016 7/5/2016 0.25 PROD3 DRILL WPRT P RBIH to 9,670'. 9,000.0 9,670.0 10:30 10:45 7/5/2016 7/5/2016 4.80 PROD3 DRILL DRLG P Drill ahead from 9,670'.Pumped 9,670.0 10,070.0 10:45 15:33 sweep @ 9,800'.PU,swap back to Highline power.Good parameters so continuing with mud system#6(1915' drilled,8.9 ppg,0.9%DS,LSRV 40K) so lat TD(11,750')is attainable with mud system#7. 7/5/2016 7/5/2016 0.45 PROD3 DRILL WPRT P Wiper from 10,070'to 9,070'.PU 10,070.0 9,070.0 15:33 16:00 weight=34k, 1.7 BPM.Pumped sweep. 7/5/2016 7/5/2016 0.35 PROD3 DRILL WPRT P RBIH to 10,070'. 9,070.0 10,070.0 16:00 16:21 7/5/2016 7/5/2016 4.65 PROD3 DRILL DRLG P Drill ahead from 10,070'. 10,070.0 10,470.0 16:21 21:00 **Mud swap,new mud out bit at 10,383 ft. 7/5/2016 7/5/2016 0.75 PROD3 DRILL WPRT P Wiper for tie in,PUW 33k,jog at EQB 10,470.0 8,890.0 21:00 21:45 7/5/2016 7/5/2016 0.20 PROD3 DRILL DLOG P Log RA for plus 4.0 ft correction,RIH. 8,890.0 8,910.0 21:45 21:57 7/5/2016 7/5/2016 0.65 PROD3 DRILL WPRT P Wiper in hole,RIW 8.5k 8,910.0 10,470.0 21:57 22:36 7/5/2016 7/6/2016 1.40 PROD3 DRILL DRLG P 10,470 ft.OBD 1.7 bpm at 3,735 psi 10,470.0 10,618.0 22:36 00:00 FS,BHP 3,845 psi,CWT 5.3k,WOB 1.9k, ROP 90,WHP 444, IA 139,OA 321 7/6/2016 7/6/2016 2.50 PROD3 DRILL DRLG P 10,618 ft. OBD 1.70 bpm at 3,720 psi 10,618.0 10,870.0 00:00 02:30 FS,BHP 3,886 psi,CWT 3.6k,WOB 1.7k,ROP 115,WHP 447, IA 188,OA 338. Page 24/27 Report Printed: 7/11/2016 • • Operations Summary (with Timelog Depths) f >r .,. 1L-24 ConocoPhiiiips . 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) 7/6/2016 7/6/2016 0.45 PROD3 DRILL WPRT P Wiper up hole,PUW 37k. 10,870.0 9,570.0 02:30 02:57 7/6/2016 7/6/2016 0.45 PROD3 DRILL WPRT P Wiper in hole,RIW 8.2k 9,570.0 10,870.0 02:57 03:24 7/6/2016 7/6/2016 3.85 PROD3 DRILL DRLG P 10,870 ft.OBD 1.68 bpm at 3,718 psi 10,870.0 11,270.0 03:24 07:15 FS,BHP 3,897 psi,CWT 4.5k,WOB 1.1k,ROP 122,WHP 458, IA 226,OA 364 7/6/2016 7/6/2016 0.50 PROD3 DRILL WPRT P Wiper up hole from 11,270 to 10,070'. 11,270.0 10,062.0 07:15 07:45 PUW 38k. 7/6/2016 7/6/2016 0.50 PROD3 DRILL WPRT P RBIH to 11,270'.RIW 8.8k. 10,062.0 11,270.0 07:45 08:15 7/6/2016 7/6/2016 2.75 PROD3 DRILL DRLG P 11,270'.BOBD 1.69 bpm @ 3898 psi 11,270.0 11,540.0 08:15 11:00 FS,BHP 4370 psi,WOB 1.6k,ROI 87 FPH. 7/6/2016 7/6/2016 0.25 PROD3 DRILL WPRT P Wiper up hole from 11,540'to 10,740 11,540.0 10,740.0 11:00 11:15 7/6/2016 7/6/2016 0.25 PROD3 DRILL WPRT P RBIH to 11,540'.RIW 6.6k.Minimal 10,740.0 11,540.0 11:15 11:30 tbg wt change seen @ 10,790'; 10,832'; 10,999'. 7/6/2016 7/6/2016 1.25 PROD3 DRILL DRLG P 11,540'.BOBD 1.7 @ 3887 psi FS, 11,540.0 11,592.0 11:30 12:45 BHP 4395 psi,WOB-3 to-5k,ROP 20 -90 FPH.Stacking,multiple(9)PUs. 7/6/2016 7/6/2016 0.25 PROD3 DRILL WPRT P BHA wiper,PUW 38k. 11,592.0 11,592.0 12:45 13:00 7/6/2016 7/6/2016 0.50 PROD3 DRILL DRLG P 11,592'BOBD.Stacking,multiple(5) 11,592.0 11,600.0 13:00 13:30 PUs. 7/6/2016 7/6/2016 0.25 PROD3 DRILL WPRT P 500 ftwiperto 11,100',PUW 39k. 11,600.0 11,600.0 13:30 13:45 7/6/2016 7/6/2016 0.75 PROD3 DRILL DRLG P 11,600'BOBD. 1.69 BPM @ 3888 psi 11,600.0 11,609.0 13:45 14:30 FS,BHP 4395 psi,WOB-4.5k,ROP 25 FPH.Purposely cross cut A5 up into the A6,TD called at 11,609'.PUH while mixing&pumping 15 x 20 sweep. 7/6/2016 7/6/2016 1.00 PROD3 DRILL WPRT P Sweep out of bit,POOH chasing 11,609.0 9,306.0 14:30 15:30 sweep to swab(wiper trip). 1.77 BPM. 7/6/2016 7/6/2016 0.10 PROD3 DRILL WPRT P Jog in open hole to clean-up prior to 9,306.0 9,504.0 15:30 15:36 entering build area. 1.78 BPM. 7/6/2016 7/6/2016 1.90 PROD3 DRILL WPRT P Cont POOH for swab wiper trip,WOB 9,504.0 72.0 15:36 17:30 negative 0.7 pull @ billet(8,973'). 7/6/2016 7/6/2016 1.50 PROD3 DRILL TRIP P Bump up,reset counters,RBIH 72.0 8,340.0 17:30 19:00 7/6/2016 7/6/2016 0.25 PROD3 DRILL DLOG P Tie at HRZ for plus 15 ft correction, 8,360.0 8,410.0 19:00 19:15 PUW 29k. 7/6/2016 7/6/2016 1.65 PROD3 DRILL TRIP P RBIH,clean thru pilot hole,window 8,410.0 11,580.0 19:15 20:54 and past billet. 7/6/2016 7/6/2016 2.85 PROD3 DRILL DISP P POOH laying in 11.8 ppg beaded liner 11,580.0 72.0 20:54 23:45 pill/completion fluid to surface.EOP flags at 8,500 ft and 5,800 ft. 7/6/2016 7/7/2016 0.25 PROD3 DRILL OWFF P On surface,monitor well for flow. 72.0 72.0 23:45 00:00 Discrepency in MW out 11.3 ppg measured, 11.8 ppg MW in measured. 7/7/2016 7/7/2016 0.65 PROD3 DRILL OWFF P Monitor well for flow,well appears 72.0 72.0 00:00 00:39 dead,concerns of low weight of mud out.Confer with town. Page 25/27 Report Printed: 7/11/2016 Operations Summary (with Timelog Depths) 1 L-24 conoccehmips 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) 7/7/2016 7/7/2016 1.10 PROD3 DRILL TRIP T RIH to 5,000 ft.MW in 11.8/MW out 72.0 5,000.0 00:39 01:45 11.4 at 500 ft measured, 11.8/11.6 at 1,000 ft, 11.8 in/11.7 out at 2,000 ft, 11.8 in/11.7 out at 3,000 ft,11.8 in/ 11.8 out at 4,500 ft all measured weights. 7/7/2016 7/7/2016 0.75 PROD3 DRILL CIRC T 5,000 ft.MW 11.8 ppg in/ MW 11.8 5,000.0 72.2 01:45 02:30 ppg out measured,POOH. 7/7/2016 7/7/2016 0.50 PROD3 DRILL OWFF T On surface,monitor well for flow, 11.8 72.2 72.2 02:30 03:00 ppg in/11.8 ppg out. PJSM-LD BHA over dead well. 7/7/2016 7/7/2016 0.85 PROD3 DRILL PULD P LD BHA#23,check pipe above CTC, 72.2 0.0 03:00 03:51 mild gouging 20 ft above CTC, bit condition:1-1-PN-N-X-I-NO-TD 7/7/2016 7/7/2016 0.40 COMPZ3 CASING PUTB P Prep floors to run liner.PJSM-MU 0.0 0.0 03:51 04:15 liner 7/7/2016 7/7/2016 1.75 COMPZ3 CASING PUTB P MU 33 jts slotted liner 0.0 1,010.6 04:15 06:00 7/7/2016 7/7/2016 0.50 COMPZ3 CASING PUTB P Crew change,valve check,check liner 1,010.6 1,010.6 06:00 06:30 in pipe shed, PJSM-MU liner 7/7/2016 7/7/2016 2.50 COMPZ3 CASING PUTB P MU remaining 53 jts slotted liner(86 1,010.6 2,974.1 06:30 09:00 total)followed by 11 jts of solid liner. Clean rig floor. 7/7/2016 7/7/2016 1.00 COMPZ3 CASING PUTB P PJSM.PU&MU MWD&SBR.Test 2,974.1 2,974.1 09:00 10:00 MWD. 7/7/2016 7/7/2016 2.50 COMPZ3 CASING RUNL P RIH BHA#24(liner+SBR).Stop© 2,974.1 11,320.0 10:00 12:30 painted flag(8818.3'),BHA just above window(+3.89 ft correction). 7/7/2016 7/7/2016 0.50 COMPZ3 CASING RUNL P Attempt to tie-in to HRZ,stacking out. 11,320.0 11,579.0 12:30 13:00 Work pipe down hole.PUH to second painted flag,BHA-66'off bottom (missed it while RIH).+1.76 ft ' correction 7/7/2016 7/7/2016 0.25 COMPZ3 CASING RUNL P RBIH,work pipe down to set depth. 11,579.0 11,588.0 13:00 13:15 7/7/2016 7/7/2016 0.25 COMPZ3 CASING RUNL P PU 40k to neutral weight.Pump 1.5 11,588.0 11,588.0 13:15 13:30 BPM to release off liner. PU,still pulling heavy,RBIH,PU. Released from liner.RBIH while pumping to push liner back down to required set depth. 7/7/2016 7/7/2016 0.50 COMPZ3 CASING TRIP P Release off liner,PUH to tie-in @ HRZ 11,588.0 8,345.0 13:30 14:00 (+3 ft correction). 7/7/2016 7/7/2016 0.75 COMPZ3 CASING DISP P RBIH&swap well to seawater. 8,345.0 8,571.0 14:00 14:45 7/7/2016 7/7/2016 1.25 COMPZ3 CASING TRIP P POOH while pumping seawater. 8,571.0 2,500.0 14:45 16:00 7/7/2016 7/7/2016 1.10 DEMOB WHDBOP FRZP P Pump freeze protect from 2,500'to 2,500.0 44.2 16:00 17:06 surface.POOH 7/7/2016 7/7/2016 1.90 DEMOB WHDBOP PULD P PJSM-PUD BHA#24,LD liner 44.2 0.0 17:06 19:00 running tools,pull checks. 7/7/2016 7/7/2016 1.50 DEMOB WHDBOP MPSP P Bring in BPV equipment,PJSM,RU 0.0 0.0 19:00 20:30 BPV equipment,lubricate in BPV,test from below good,RDMO BPV equipment. Page 26/27 Report Printed: 7/11/2016 • • Operations Summary (with Timelog Depths) &Wells 1 L-24 ConocoPhillips rtS:rks 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) 7/7/2016 7/7/2016 3.00 DEMOB WHDBOP RURD P PJSM-Install nozzle,jet stack,flush 0.0 0.0 20:30 23:30 surafce lines,blow down steam heaters,blow down surface lines,coil and TT lines,freeze protect tree, begine RD check list,complete off loading fluids from rig. 7/7/2016 7/8/2016 0.50 DEMOB WHDBOP NUND P PJSM-ND BOPE,torque checked,2 0.0 23:30 00:00 bolts loose around SSV flange(30 min) Rig released at 00:00 on 07/08/2016 Page 27/27 Report Printed: 7/11/2016 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad 1 L-24AL1 50-029-22170-60 Baker Hughes INTEQ 1 BAKER Definitive Survey Report HUGHES 21 July,2016 • . ConocoPhillips MI CBAICER onocoPhillips _ft O lir .> IIUGHIS „ � (Gampany: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-24 Preject: Kuparuk River Unit TVD Reference: 1 L-24 @ 130.00usft(1 L-24) Site:. Kuparuk 1L Pad MD Reference: 1 L-24 @ 130.00usft(1 L-24) Well: 1 L-24 North Reference: True Well ore: 1 L-24AL1 Survey Calculation Method Minimum Curvature 1 I Design: 1 L-24AL1 Database: EDM Alaska NSK Sandbox 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 Well Position +N/-S 0.00 usft Northing: 5,948,401.14usft Latitude: 70°16'11.882 N +E/-W 0.00 usft Easting: 539,924.95usft Longitude: 149°40'37.648 W f q Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 soft i Nfldlbete 1L-24AL1 a Magnetics Model Name Sample Date Declination �' DipA/iple � /�/// y� // (0) (0) ! ��=` BGGM2015 6/1/2016 18.44 80.93 57493 Design 1 L 24AL1 ,, .............. ..,°,W:d. Audit Notes: Version: 1.0 Phase: ACTUAL Tle On Depth: 8,965.21 1 1 Verb+, ct,,,, , Depth(%mj('l "',4,;;-% ' tom) ,..??'„%-'''''',6- ',';',' a" 130.00 0.00 0.00 330.00 SurveyPr ��/ From To Survey y (usrt)', (tart) Surveyf*ii‘tr,gire) Tool Name Deacrlptlon Start Data End Date a 200.00 8,800.00 1L-24(1L-24) GCT-MS Schlumberger GCT multishot 1/8/2001 8,874.00 8,965.21 1L-24APB1(1L-24AP81) MWD MWD-Standard 6/9/2016 6/17/2016 8,973.00 11,580.81 1L-24AL1(1L-24AL1) MWD MWD-Standard 7/2/2016 7/7/2016 7./2d O#E'i:33:99PIN Plage8 i i • CoesocaPhftx% 11111011 ConocoPhillips 13aftriiirve spy,Repciet BAKER Company: ConocoPhillips(Alaska)Inc.-Kup2 LoCatCa-4rdibat4ReferenGa:" Well 1L-24 Project: Kuparuk River Unit WD Reference: 1L-24©130.00usft(1L-24) Site: Kuparuk 1 L Pad MD Referencia: 1L-24 130.00usft(1 L-24) Well: 1 L-24 North Reference: True Wellbore: 1L-24AL1 Survey Calculation Method: Minimum Curvature Design: 1 L-24AL1 Database: EDM Alaska NSK Sandbox Survey MD: trio At , 'TVDSs *11,183 *E!-W =>Ea 9 DLS (usft) (usft) rthina (flOO) Survey Teal Name Annotation 8965.21 80.76 188.21 6,09342 5,96342 621041 -1,005.21 5,942,186.09 538,952.79 36.54 -4,875.77 MWD(2) TIP 8,973.00 82.92 186.93 6,094.53 5,964.53 -,218.06 -1,006.23 5,942,178.45 538,951.81 3214 -4,881.88 MWD(3) KOP j8 6000.95 90.83 196.50 6,096.06 5,966.06 -6,245.33 -1,011.89 5,942,151.15 538,946.30 44.38 -4,90267 MWD(3) 9,030.75 9160 209.42 6,095.42 5,965.42 -6,272.70 -1,023.49 5,942,123.71 538,934.85 4342 -0,920.57 MWD(3) • 9,060.84 90.98 222.47 6,094.74 5,964.74 -,297.00 -1,041.11 5,942,099.32 538,917.36 43.41 -4932.81 MWD(3) 9,091.12 90.31 234.78 6,094.40 5,964.40 -6,31698 -1,063.79 5,942,079.23 538,894.79 40.71 -4,938.77 MWD(3) 9,120.86 88.19 245.32 6,094.79 5,964.79 -6,331.80 -1,089.52 5,942,064.27 538,869.14 36.15 -4938.74 MWD(3) 9,151.03 88.40 257.39 6,095.69 5,965 69 -6,341.43 -1,118.04 5,942,054.50 538,840.67 39.99 -4,932.82 MWD(3) 9,180.88 88.59 267.78 6,096.48 5,966.48 -6,345.27 -1,147.59 5,942,050.49 538,811.15 34.80 -0,921.37 MWD(3) 9,210.96 87.39 279.70 6,097.54 5,967.54 -6,343.32 -1,177.53 5,942,052.29 538,781.20 39.80 -0,904.71 MWD(3) 9,241.13 90.52 290.20 6,098.09 5,968.09 -6,335.54 -1,206.63 5,942,059.91 538,752.06 36.31 -4,88343 MWD(3) 9,270.68 90.43 301.24 6,097.84 5,967.84 -6,32274 -1,233.21 5,942,072.57 538,725.42 37.36 -4,859.05 MWD(3) 9,300.79 90.09 303.92 6,097.70 5,96770 -6,306.53 -1,258.58 5,942,088.64 538,699.96 8.97 -4,832.32 MWD(3) 9,330.94 91.66 306.30 6,097.24 5,967.24 -6,289.19 -1,283.24 5,942,105.85 538,675.22 9.46 -4,804.98 MWD(3) 9,360.93 92.18 309.15 6,096.24 5,96624 -6,270.85 -1,306.94 5,942,124.06 538,651.42 9.65 -4,777.25 MWD(3) 9,390.77 9178 311.90 6,095.21 5,96521 -6,251.48 -1,329.61 5,942,143.31 538,628.65 9.31 -4,749.13 MWD(3) 9,416.09 91.32 314.55 6,094.52 5,964.52 -6,234.14 -1,348.05 5,942,160.54 538,610.12 10.62 -4,724.90 MWD(3) 9,451.11 91.26 317.14 6,093.73 5,963.73 -6,209.03 -1,372.44 5,942,185.53 538,585.60 7.40 -4,690.96 MWD(3) 9,480.82 90.12 318.89 6,093.38 5,963.38 -6,186.95 -1,392.31 5,942,207.50 538,565.61 7.03 -4,661.90 MWD(3) 9,510.43 90.28 321.85 6,093.27 5,96327 -6,164.14 -1,411.19 5,942,230.20 538,546.61 10.01 -0,632.71 MWD(3) 9,540.77 90.28 324.71 6,093.12 5,963.13 -6,139.83 -1,429.33 5,942,254.42 538,528.35 9.43 -4,602.58 MWD(3) 9,570.59 89.42 326.74 6,093.20 5,963.20 -6,115.19 -1,446.12 5,942,278.97 538,511.43 7.39 -4,57285 MWD(3) 9,600.76 87.08 324.60 6,094.12 5,964.12 -6,090.29 -1,463.13 5,942,303.78 538,494.29 10.51 -4,542.78 MWD(3) 9,630.78 86.56 321.87 6,095.79 5,965.79 -6,066.28 -1,481.06 5,942,327.69 538,476.23 9.24 -4,513.02 MWD(3) 9,660.69 86.68 319.37 6,097.55 5,967.55 -6,043.20 -1,500.01 5,942,350.66 538,457.16 8.35 4,483.56 MWD(3) F 9,690.71 86.90 316.85 6,099 23 5,969.24 -6,020.89 -1,520.02 5,942,372.86 538,437.04 8.41 -4,454.23 MWD(3) 9,720.50 86.50 319.40 6,100.95 5,970.95 -5,998.75 -1,539.87 5,942,394.90 538,417.07 8.65 -4,425.13 MWD(3) 9,750.57 87.42 322.30 6,10255 5,972.55 -5,975.46 -1,558.82 5,942,418.08 538,397.99 10.10 -4,395.49 MWD(3) € 9,780.78 88.53 325.48 6,103.61 5,973.61 -5,951.08 -1,576.61 5,942,442.37 538,380.08 11.14 -4,365.48 MWD(3) 9,81060 8727 327.48 6,104.71 5,974.71 -5,926.23 -1,593.07 5,942,467.12 538,363.49 7.92 -4,335.73 MWD(3) 7Z4^T. t5''9i55 S .7 wild • i ConocoPiill iti :'. ConocoPh)II(ps :SarverHUGHES Company: ConocoPhilips(Alaska)Inc.-Ku p2 Local Co-ordinate Reference: Well 1L-24 Project::+.. Kuparuk River Unit ND Reference: 1 L-24 ig 130.00usft(1L-24) Site: Kuparuk 1 L Pad MO Reference: 1 L-24©130.00usft(1 L-24) Well: 1L-24 North Reference: True Wellbore:. 1L-24AL1 Survey Calculation Method: Minimum Curvature Design: :. 1 L-24AL1 Database: EDM Alaska NSK Sandbox Survey Map L MD' Incnc Azi TVD TVDSS +kli•M +EJWNorthing -Nng °DLS' t ':".0.,,,,4-:),',..,SectonSurvey Toot: i ation(u -fl (° (usft) (usft) (01CNat) I tit) (1100) (ft) Oa. 9,840.93 86.59 329.64 1106.33 1976.33 5,800.40 -1,608.87 1942,492.87 531347.56 7.46 -4305.46 MWD(3) 1 9,870.85 86.59 332.13 6,108.11 6978.11 -5874.30 -1623.40 1942,518.88 531332.89 8.31 -4275.60 MWD(3) j 9,900.85 8733 33479 6,109.70 1979.70 5,847.51 -1636.78 1942646.61 530319.37 9.19 -4245.70 MWD(3) g 9,930.69 87.94 336.53 6,110.93 5,980.93 5,820.34 -1,649.07 5,942,572.70 538,306.94 6.17 -4,216.03 MWD(3) 111{ 9,960.79 9021 338.36 6,111.42 1981.42 -5,792.55 -1,660.61 5,942,600.43 538,295.25 9.69 -4,186.19 MWD(3) 9,990.83 89.85 34099 6,111.40 5,98140 5,764.38 -1,671.04 5,942,628.54 538,284.67 8.84 -4,156.58 MWD(3) 10,020.56 90.58 343.33 6,111.29 6981.29 -5,736.09 -1,680.15 5,942,656.79 538,275.41 8.24 -4,127.52 MWD(3) 10,050.81 90.12 345.59 6111.11 1981.11 -5,706.94 -1,688.26 5,942,685.88 538,267.15 762 -4,098.23 MWD(3) 10,080.59 91.01 347.43 6,110.81 6980.81 -5,677.99 -1,695.20 5,942,714.80 538,260.05 6.86 -4,069.68 MWD(3) I 10,110.69 90.95 349.18 6,110.30 1980.30 -5,648.52 -1,701.30 5,942,744.23 538,253.80 5.82 4,041.11 MWD(3) S 10,140.49 92.55 351.39 6,109.39 6979.39 -5,619.16 -1,706.33 5,942,773.56 538,248.62 9.15 -4,013.17 MWD(3) 10,170.81 9264 354.32 6,108.01 5,978.02 -5,589.11 -1,710.10 5,942,803.58 538,244.69 9.66 -3,985.27 MWD(3) 1 10,200.89 91.90 356.56 6,106.82 5,976.82 -5,559.15 -1,71248 5,942,833.53 538,242.14 7.84 3,958.13 MWD(3) 10,230.77 9095 358.71 6,106.08 6976.08 -5,529.31 -1,713.72 5,942,863.36 538,240.75 7.86 3,931.66 MWD(3) 10,260.69 90.21 0.46 6,105.78 5,975.78 -5,499.39 -1,713.93 5,942,893.27 538,240.38 6.35 -3,905.65 MWD(3) 1 10,290.83 90.40 2.98 6,105.62 5,975.62 -5,469,27 -1,713.03 5,942,923.40 538,241.12 8.38 3,880.01 MWD(3) 1 E110,320.70 90.31 2.75 6,105.43 5,975.43 -5,439.44 -1,711.54 5,942,953.23 538,242.46 0.83 3,854.92 MWD(3) 1 10,350.59 90.55 0.62 6,105.21 5,975.21 -5,409.56 -1,710.66 5,942,983.11 538,243.18 7.17 3,829.49 MWD(3) 10,380.69 90.21 358.82 6,105.01 5,975.01 -5,379.47 -1,710.80 5,943,013.20 538,242.87 6.09 3,803.35 MWD(3) 10,410.68 90.64 356.86 6,104.79 5,974.79 -5,349.50 -1,711.93 5,943,043.16 538,241.58 6.69 -3,776.84 MWD(3) 10,440.69 91.72 355.28 6,104.17 1974.17 -5,319.57 -1,713.99 5,943,073.08 538,239.37 6.38 3,748.89 MWD(3) 10,470.84 92.15 353.65 6,103.15 5,973.15 5,289.58 -1,716.90 5,943,103.05 538,236.30 5.59 3,722.46 MWD(3) .10,500.80 92.92 351.79 6,101.82 1971.82 5,259.89 -1,720.69 5,943,132.71 538,232.35 6.71 -3,694.85 MWD(3) 10,530.69 91.26 349.50 6,100.73 1970.73 5,230.42 -1,725.54 5,943,162.16 538,227.34 9.46 -3,666.90 MWD(3) 10,560.65 91.78 347.46 6,099.94 1969.94 5,201.08 -1,731.53 5,943,191.46 538,221.21 7.02 -3,638.50M WD(3) '¢ 10,590.82 91.53 345.86 6,099.07 1969.07 5,171.73 -1,738.48 5,943,220.77 538,214.09 5.37 3,609.61 MWD(3) 1 10,620.93 91.17 344.05 6,098.36 1968.36 -5,142.66 -1,746.30 5,943,249.79 538,206.13 6.13 3,580.53 MWD(3) I. 10,650.99 90.00 341.96 6,098.05 1968.05 -5,113.92 -1,755.08 5,943,278.48 538,197.19 7.97 -3,551.24 MWD(3) r 10,680.84 89.51 340.92 6,098.18 5,968.18 5,085.62 -1,764.58 5,943,306.73 538,187.54 3.85 3,521.99 MWD(3) 10,710.73 90.00 338.28 6,098.31 1968.31 -5,057.61 -1,775.00 5,943,334.68 538,176.97 8.98 -3,492.52 MWD(3) . 3 10740.85 89.69 337.65 6,09839 196839 -1029.69 178630 5,943,362.54 538,165.53 2.33 3,462.69 MWD(3) .7118 a fliVegicrl f ' 4f COMPASSPD091.iif/Ad W • • ConocoPhillipS Will ConocoPhillips ,eapartAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-24 r Project: Kuparuk River Unit TVD Reference: 1L-24 icit 130.00usft(1 L-24) Site: Kuparuk 1L Pad MD Reference: 1L-24/130.00usft(1 L-24) Well: . _1L-24 North Reference; True Wellbore: -1L-24AL1 Survey Calculation Method: Minimum Curvature Design: 1 L-24AL I Database: EDM Alaska NSK Sandbox Survey ,a __ Map Vertical MD Inc Azi ND TVDSS +NI-S #E.W North" OLS sectionbapj� Survey Tool Name Annotation ,(usft) (° °I utrifw. 10,770.75 89.45 336.33 6,09861 5,968.61 -5002.17 1,797.99 5,943,389.99 538,153.70 4.49 -3,433.01 MWD(3) 10,800 83 90.49 333.69 6,098.63 5,968.63 -0,974.91 -1,810.69 5,943417 18 538,140.85 9.43 -3,403.05 MWD(3) 10,830.92 88.99 333.04 6,098.76 5,968.77 -4,948.01 -1,824.18 5,943,444.01 538,127.22 5.43 -3,373.01 MWD(3) t 10,860.78 88.40 331.43 6,099.44 5,969.45 -4921.60 -1,838.09 5,943,470.34 538,113.17 5.74 -3,343.19 MWD(3) a 10,890.93 88.77 333.40 6,100.19 5,970.19 -4,894.89 -1,852.05 5,943,496.98 538,099.07 6.65 -3,313.07 MWD(3) 10,920.91 89.20 336.80 6,100.72 5,970.72 -4,867.70 -1,864.66 5,943,52A 09 538,086.31 11.43 3,283.22 MWD(3) 10,950.95 89.20 339.00 6,101.14 5,971.14 -0,839.87 -1,875.96 5,943,551.86 538,074.87 7.32 3,253.47 MWD(3) 10,980.75 8831 340.07 6,101.79 5,971.79 d -4,811.96 -1,886.38 5,943,57a 71 538,064.30 4.67 3,724.09 MWD(3) 11,010.85 88.16 341.74 6,102.71 5,972.72 x,783.53 -1,896.22 5,943,608.09 538,054.31 5.57 3,194.55 MWD(3) gig 11,041.12 87.85 344.38 6,103.77 5,973.77 -4,754.60 -1,905.04 5,943,636.97 538,045.35 8.78 -3,165.08 MWD(3) @ 11,070.85 87.24 346.92 6,105.04 5,975.04 -4,725.82 -1,912.40 5,943,665.70 538,037.83 8.78 -3,136.48 MWD(3) £ 11,100.63 87.14 348.96 6,106.50 5,976.50 -4696.74 -1,918.61 5,943,69A 75 538,031.46 6.85 -3,108.19 MWD(3) i 11,130.75 87.30 350.63 6,107.96 5,977.96 -4,667.13 -1,923.94 5,943,72A 33 538,025.98 5.56 -3079,88 MWD(3) 11,160.69 90.28 352.95 6,108.60 5,978.60 -4637.51 -1,928.22 5,943,753.93 538,021.55 12.61 -3,052.09 MWD(3) 1. 11,190.76 90.52 350.11 6,108.39 5,978.39 -4,607.77 -1,932.64 5,943,783.64 538,016.96 9.48 -3,024.12 MWD(3) 11,220.7.3 80.89 347.33 6,108.02 5,978.02 -4,578.38 -1,938.50 5,943,81299 538,010.95 9.36 -2,995.74 MWD(3) 11,250.66 91.29 345.86 6,107.45 5,977.45 -4,549.28 -1,945.44 5,943,84206 538,003.86 5.09 -2,967.07 MWD(3) 11,280.53 91.60 344.65 6,106.69 5,976.69 -4,520.40 -1,953.04 5,943,87a 89 537,996.10 4.18 -2,938.26 MWD(3) 11,310.96 90.95 344.13 6,106.02 5,976.02 -4,491.10 -1,961.23 5,943,90a 14 537,987.76 2.74 -2,908.79 MWD(3) 1 11,340.83 90.34 341.84 6,105.68 5,975.68 -4,462.54 -1,969.97 5,843,928.65 537,978.87 7,93 -2,879.69 MWD(3) 11,370.62 90.49 339.11 6,105.47 5,975.47 -4,434.47 -1,979.92 5,943,956.67 537,968.77 9.18 -2,850.40 MWD(3) 11,400.81 89.36 337.45 6,105.50 5,975.50 -4,406.42 -1,991.09 5,943,984.65 537,957.45 6.65 -2,820.53 MWD(3) 11,430.67 90.09 334.87 6,105.65 5,975.65 -4,379.11 -2,003.16 5,944,011.90 537145.24 8.98 -2,790.84 MWD(3) 11,460.67 89.66 337.05 6,105.71 5,975.71 4,351.72 -2,015.38 5,944,039.22 537,932.87 7.41 -2,761.0 MWD(3) 11,490.76 89.88 339.29 6,105.83 5,975.83 4,323.79 -2,026.57 5,944,067.09 537,921.54 7.48 -2,73122 MWD(3) ggg 11,520.63 90.18 342.75 6,105.82 5,975.82 -4,295.54 -2,036.28 5,944,095.28 537,911.68 11.63 -2,701.91 MWD(3) 11,550.81 90.95 344.84 6,105.52 5,975.52 -4,266.57 -2,044.71 5,944,124.21 537,90.10 7.38 -2,672.0 MWD(3) 11,580.61 90.40 347.07 6,105.17 5,975.17 -4,237.66 -2,051.94 5,944,153.07 537,895.72 7.71 -2,643.95 MWD(3) 11,609.00 90.40 347.07 6,104.97 5,974.97 -4,209.99 -2,058.29 5,944,180.70 537,889.22 0.00 -2,616.81 PROJECTED to TD , 7i29-35 IIVI4taPkg Aftge5 COMI44.1.S WW1 Bad:7-4 DECEIVED • AUG0 2 2016 Letter of Transmittal AOGCC vu BAKER Date: DATA LOGGED August 1, 2016 1i 4201 R 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): 1L-24APB1 2 1 6 0 4 9 2 7 4 3 9 1L-24A 2 1 60 49 27 440 1L-24AL1-02PB1 2 1 6 0 8 0 7 4 4 1 1L-24AL1-02 2 1 6 0 8 0 1L-24AL1 2 1 60 50 3 44 1L-18APB1 2 1 6 0 5 6 3 4 4 11L-18Ak 1L-18APB2 2160 567446 1L-18AL1 2 1 6 0 4 2 7 4 4 7 (9) 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. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh • BakerHughes.com ®.. N, • • in, * au iA 1i�_ mum sz N a Liu :.. I C.? . ill o C. _ 41 a ' cc L cr iJi a ca 0 0 Qce 0. L z o o o > a o = p v 0C 2 2 0 J Na) N � La � •— U o c N O as 0 -'2 00 0 N • • • • v CO Lill X howl - ci co o c aC. v m'I `, a ''.O O k7. O r V O T N co co 0 0 0 0 1 ":',ami m o � 't' N N N 3 0 o m rn N F p s yea i:111,,,;; � r O f` 0 J ,,fi, ibl igau rim, J J 0 py CC ` 76)IGS d v v o e T ,I it N N J J a 7 Y NIIn7$�e 4, e .LN-. 0 o m U 3l'''; ' z 1 ca 0 0 §� -Z5 H U �c N o oo -o a a N N N E 0 a+ Cl) Y � k�� � w � O o N N w v co 112 'a in . E Q) U N =41 N = a G1 F J K 0) �s. 01 U 0 U Y > z O Nvrn m Qacc CO-a c E an 1 y4 L d Oi 1. 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M oCo Co Co Co Co MM Co Co Co MM Co Co co co co co co co co co n > a . e cc a VI a - Q Q 00 2 0 N Co Co O r` O O m (0 V O m N m m O '23422) 22c° 84 V m m m (p m m (0 O O 0 Q Q N N N V V m V r- N N M m N M N (0 m N m m M V M O (0 m m V V 1 of o oo Co co 0 of co 06 r N: N: N: 0 0 0 0 0 0 of ci ai of 0 0 0 0 S U Y Y J J J c m m m (Ca, m m m woo m m m m m m Co m m m m m m 03030010 Co 0- 0- O 7 U (0 Co N CO CO N N (0 CV CO Co (0 m co Co CO co co co N N- N- CO CO O O r CO m N- m Com N- m CO CO N- m r` N. m m m m m m CO CO r` m ao (o o Co 0 ci d 0 0 0 0 0 0 ci 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ai r O Co CO m Co CO aJ V N. O CO CO m N (0 m V N- O CO CO m Co (0 m 0 C C d N CO .d 7 r. CO CO co CO m m m O O O 7. N N N CO CO co V V V V 0 (0 (0 (O (0 LI _ a co 0 a in 75 71.7 o 0) N. 0 • OFT • • 111/79 THE STATE Alaska Oil and Gas 'F."; Of Conservation Commission €e =_`_ E. . 'ise STATE OF ALASKA klAy 10 2016 ASA OIL AND GAS CONSERVATION COMMON PERMIT TO DRILL A OG,GC 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if well is proposed for: Drill ❑ Lateral 0 Stratigraphic Test ❑ Development-Oil Q Service- Winj ❑ Single Zone LI Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket D Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 5952180 KRU 1 L-24AL1 3.Address: 6. Proposed Depth: .ry P95 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11750' TVD: 5978' Kuparuk River Field/ 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk River Oil Pool Surface: 567'FNL,143'FEL,Sec 31,T11 N,R10E, UM ADL 25664 )495\c 6q Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1502'FNL, 1168'FEL,Sec 6,T10N,R10E,UM ALK 473 6/1/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4646'FNL,2230'FEL,Sec 31,T11 N,R10E,UM 1561 1-46111 g.. 11100' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 130' 15.Distance to Nearest Well Open Surface: x- 539924 Y- 5948401 Zone- 4 GL Elevation above MSL(ft): 43' to Same Pool: 730', 1L-13 16.Deviated wells: Kickoff depth: 8970 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93 degrees Downhole: 4266 Surface: 3661 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 3" 2-3/8" 4.6# L-80 STL 3110' 8640' 5775' 11750' 5978' 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): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): 9241' 6287' None 9155' 6232' None Casing Length Size Cement Volume MD TVD Conductor 78' 16" 235 sx AS 1 122' 122' Surface 5038' 9-5/8" 750 sx Type E,550 sx Class G 5081' 3610' Production 9213' 7" 250 sx Class G Prem 9241' 6287' Perforation Depth MD(ft): 8735'-8782'/8920'-8949'/9010'-9029' Perforation Depth ND(ft): 5966'-5996'/6084'-6102'/6141'-6153' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 require nts Q 21. Verbal Approval: Commission Representative: Date 006 4L-- 22. C22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Keith Herring @ 263-4321 Email Keith.E.Herrinq@cop.com Printed Name J. Burke Title Senior CTD Engineer Signature �/ Phone 265-6097 Date 3 -to---f,6 `ap.-- Commission Use Only Permit to Drill "' 1 API Number: Permit Approval See cover letter for other Number: ala'QSO Mu( 50- Oaq -494900 -(p0 -(,c Date: 411411t requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shales: 2" Other: ocp fry 7L to ,¢f ot, I" Sig L 4_. t— Samples req'd: Yes❑ No ' Mud log req'd:Yes❑ No iV ,i 41 j.„1 .jar- p`z-t, /�f-t t' 1--i•--S/ / P 2 C2/25 2 H2S measures: Yes["No❑ Directional svy req'd:Yes❑✓/No❑ Spacirf exception req'd: Yes❑ No L Inclination-only svy req'd:Yes❑ No Ire' Post initial injection MIT req'd:Yes❑ No❑ 2ext,t,...14„....Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date:S–Zy-/,‘ Submit Form and Form 10-401 Revised 11/2015) ' � OITVR Nc ( if.1 K^�" from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate Revise d • • Kuparuk CTD Laterals NA®OAS ALASKA 1L-24A & 1 L-24AL1 CDA ConocoPhillipsApplication for Permit to Drill Document 211C 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 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 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 6 Attachment 1: Directional Plans for 1 L-24A& 1 L-24AL1 6 Attachment 2: Current Well Schematic for 1 L-24 6 Attachment 3: Proposed Well Schematic for 1 L-24A& 1 L-24AL1 6 Page 1 of 6 May 10, 2016 • • PTD Application: 1L-24A & 1 L-24AL1 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 1 L-24A& 1 L-24AL1. 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 1 L-24A& 1 L-24AL1. 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 4,000 psi. Using the maximum formation pressure in the area of 4,266 psi in 2E-05 (i.e. 13,4 ppg EMW), the maximum potential surface pressure in 1 L-24, assuming a gas gradient of 0.1 psi/ft, would be 3,661 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AA C 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1L-24 was measured to be 2.743 psi (3.7 ppg EMW) on 3/31/2016. The maximum downhole pressure in the 1 L-24 vicinity is to the south in the 2E-05 injector at 4,266 psi (13.4 ppg EMW)from May of 2016. The 1 L-24A sidetrack will be drilled southeast across a N-S fault that could encounter formation pressure as high as 10.6 ppg, which is what was measured in 1L-26A in June of 2012. The 1L-24AL1 lateral will be drilled to the northwest towards a formation pressure of 9.4 ppg, which is what was measured in 1L-15 in April of 2015. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) Wells on 1L pad have injected gas, so there is a chance of encountering free gas while drilling the 1 L-24 laterals. 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 in the 1 L-24 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AA C 25.005(c)(5)) The 1 L-24 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 6 May 10, 2016 • • PTD Application: 1L-24A & 1 L-24AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Top Liner Btm Liner Top Liner Btm Lateral Name MD MD TVDSS TVDSS Liner Details 2 3/8", 4.7#, L-80, ST-L slotted liner; 1L-24A 8970' 13400' 5964' 6014' aluminum billet on top 2-3/8", 4.7#, L-80, ST-L slotted liner; 1 L-24AL1 8640' 11750' 5775' 5978' deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (ppf) TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 122' 0' 122' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 5081' 0' 3610' 3520 2220 Production 7" 26.0 J-55 BTC-MOD 0' 9241' 0' 6287' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 0 8655' 0 5914' 10160 10530 7. Diverter System Information (Requirements of 20 AA C 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 (8.6 ppg) — Drilling operations: Chloride-based FloVis mud (8.6 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 5,000 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". In the 1 L-24 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. Page 3 of 6 May 10, 2016 • 4110 PTD Application: 1L-24A & 1 L-24AL1 Pressure at the 1L-24 Window(8875' MD, 6055' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (8.7 ppg) 2743 psi 2743 psi Mud Hydrostatic (8.6 ppg) 2708 psi 2708 psi Annular friction (i.e. ECD, 0.090 psi/ft) 799 psi 0 psi Mud + ECD Combined 3507 psi 2708 psi (no choke pressure) (overbalanced —764 psi) (underbalanced —35 psi) Target BHP at Window(11.8 ppg) 3716 psi 3716 psi Choke Pressure Required to Maintain 209 psi 1008 psi Target BHP 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 AA C 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 AA C 25.005(c)(13)) Summary of Operations Background KRU well 1L-24 is a Kuparuk A-sand and C-sand producer equipped with 3-1/2"tubing and 7"production casing. The CTD sidetrack will utilize two laterals to target the A5 sand to the southeast and northwest of 1L-24. The laterals will be supported by injectors 1L-18 and 2E-05. Prior to CTD operations,E-line will punch 2' of holes in the 3-1/2"tubing tail and the D nipple at 8621' MD will be milled out to a 2.80"ID. The existing A-sand and C-sand perforations will be squeezed with cement and the 3-1/2"tubing tail will be cemented in place to provide a means to kick out of the 7"casing. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 8905' MD and set a mechanical whipstock in the 2.80"pilot hole to kick off at 8875' MD. The window will be milled at 8875' MD to drill and complete the 1L-24A and 1L-24AL1 laterals. The 1L-24A southeastern lateral will exit the cement pilot hole at 8875' MD and TD at 13400' MD, targeting the A5 sand. It will be completed with 2-3/8" slotted liner from TD up to 8970'MD with an aluminum billet for kicking off the 1L-24AL1. The 1L-24AL1 lateral will drill to the northwest to a TD of 11750' MD targeting the A5 sand. It will be completed with 2-3/8" slotted liner from TD up to 8640' MD, back into the 3-1/2"tubing tail with a deployment sleeve. Page 4 of 6 May 10, 2016 • • PTD Application: 1L-24A & 1 L-24AL1 Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 3-1/2"tubing tail at 8626' MD. 3. RU Pumping Unit: Perform injectivity test down the tubing. 4. RU Service Coil: Mill out"D"nipple and cement squeeze the A-sand and C-sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE, test. 2. 1L-24A Sidetrack(AS sand- Southeast) a. Drill 2.80"high-side pilot hole through cement to 8905' MD b. Caliper pilot hole c. Set top of whipstock at 8875' MD d. Mill 2.80"window at 8875' MD. e. Drill 3"bi-center lateral to TD of 13400' MD. f. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8970' MD. 3. 1L-24AL1 Lateral (A5 sand-Northwest) a. Kick off of the aluminum billet at 8970' MD. b. Drill 3"bi-center lateral to TD of 11750' MD. c. Run 2-3/8" slotted liner with a deployment sleeve from TD up to 8640' MD. 4. Freeze protect, set BPV,ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Obtain SBHP. 3. Install gas lift design. 4. 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. 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 can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. Page 5 of 6 May 10, 2016 PTD A.plication: 1L-24A & 1 L-24AL1 — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1 L-24 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 2-3/8" slotted liner, a joint of 2-3/8" 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 2-3/8" rams will provide secondary well control while running 2-3/8" 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). 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 Plans — 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 open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1L-24A 7440' 1 L-24AL1 11100' — Distance to Nearest Well within Pool Lateral Name Distance Well 1L-24A 96' 1 L-25A 1 L-24AL1 730' 1L-13 16. Attachments Attachment 1: Directional Plans for 1L-24A & 1L-24AL1 laterals Attachment 2: Current Well Schematic for 1L-24 Attachment 3: Proposed Well Schematic for 1L-24A & 1L-24AL1 laterals Page 6 of 6 May 10, 2016 RFC:FIVE° /epp Gvisa(,)l vim( 1 6 Z016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGGC PERMIT TO DRILL 20 AAC 25.005 1a.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if well is pro,.sed for: Drill ❑ Lateral 11:1 Stratigraphic Test ❑ Development-Oil jil Service- Winj ❑ Single Zone 0 Coalbed Gas ❑ • Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ hale Gas ❑ 2.Operator Name: 5. Bond: Blanket El Single Well ❑ 11.Well Name- • Number. ConocoPhillips Alaska,Inc. Bond No. 5952180 'U 1L-24AL1 3.Address: 6.Proposed Depth: 12.Field/P•.1(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11750' TVD: 5978' uparuk River Field! 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk River Oil Pool Surface: 567'FNL,143'FEL,Sec 31,T11N,R10E,UM ADL 25664 Top of Productive Horizon: 8.Land Use Permit: 1 Approximate Spud Date: 1502'FNL,1168'FEL,Sec 6,T1ON,R10E,UM ALK 473 6/1/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4646'FNL,2230'FEL,Sec 31,T11 N,R10E,UM 2501 11100' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 0' 15.Distance to Nearest Well Open Surface: x- 539924 Y- 5948401 Zone- 4 GL Elevation above MSL(ft): 43' to Same Pool: 730',1L-13 16.Deviated wells: Kickoff depth: 8970 feet 17.Maximum Potential Pressures in •• .(see 20 AAC 25.035) Maximum Hole Angle: 93 degrees Downhole: 4266 Surface: 3661 18.Casing Program: Specifications Top - Selling Depth - =ottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND 1 TVD (including stage data) 3" 2-3/8" 4.6# L-80 STL 3110' 8640' 5775' 11750' 5978' Slotted Liner i 19. PRESENT WELL CONDITION SUMMARY(To be complet-•fo 4:. :•d Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): E .D-. • D(ft): Effect Depth TVD(ft): Junk(measured): 9241' 6287' None f\ 6232' None Casing Length Size Cemt Volume MD ND Conductor 78' 16" 235 sx AS 1 122' 122' Surface 5038' 9-518" 50 sx Type E,550 sx Class G 5081' 3610' Production 9213' 7" \A'r 250 sx Class G Prem 9241' 6287' Perforation Depth MD(ft): 8735'-8782'!8920'-8949'!9010'-90-•'' Perforation Depth ND(ft): 5966'-5996'I 6084'-6102'!6141'-6153' 20. Attachments: Property Plat ❑ BOIt'Ske .• \� Drilling Program [] Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Skei ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 require nts2 21. Verbal Approval: Commission Representative: Date 7/0(s 22.I hereby certify that the foregoing is true and the pr. -.ure approved herein will not be deviated from without prior written approval. Contact Keith Hefting'e 263-432/ Email Keith.E.Herrinaacop.com Printed Name J.Burke Title Senior CTD Engineer Signature A#4111111: --- Phone 265-6097 Date 5 -10-1.6 4.-r Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number:2_14.-U t7 ( k5 . 50- 0 2.1- 2.2-11 0 -too^UO Date:c.(- L( - I L& requirements. Conditions of approval: f box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 0 Other: Samples req'd: Yes El No Mud log req'd:Yes No H2S measures: Yes❑ No❑ Directional svy req'd:Yes❑ No❑ Spacing exception req'd: Yes❑ No❑ Inclination-only svy req'd:Yes❑ No❑ Post initial injection MIT req'd:Yes El No APPROVED BY Approved by: RCOMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401(Revised 1112015) s it"s a"d r months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • Rity €d Kuparuk CTD Laterals NABORS ALASKA Driving 1L-24A & 1 L-24AL 1 Application for Permit to Drill Document RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(6)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 MC 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 6 (Requirements of 20 AAC 25 050(b)) 6 16. Attachments 6 Attachment 1: Directional Plans for 1L-24A& 1 L-24AL1 6 Attachment 2: Current Well Schematic for 1L-24 6 Attachment 3: Proposed Well Schematic for 1L-24A&1 L-24AL1 6 Page 1 of 6 May 10,2016 • • PTD Application: IL-24A & 1L-24AL1 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 1L-24A& 1L-24AL1. 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 1 L-24A& 1 L-24AL1. 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 4,000 psi. Using the maximum formation pressure in the area of 4,266 psi in 2E-05 (i.e. 13.4 ppg EMW), the maximum potential surface pressure in 1L-24, assuming a gas gradient of 0.1 psi/ft, would be 3,661 psi. See the"Drilling Hazards Information and Reservoir Pressure"section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AA C 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure(Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 1L-24 was measured to be 2,743 psi(8.7 ppg EMW)on 3/31/2016. The maximum downhole pressure in the 1L-24 vicinity is to the south in the 2E-05 injector at 4,266 psi (13.4 ppg EMW)from May of 2016. The 1 L-24A sidetrack will be drilled southeast across a N-S fault that could encounter formation pressure as high as 10.6 ppg, which is what was measured in 1 L-26A in June of 2012. The 1 L-24AL1 lateral will be drilled to the northwest towards a formation pressure of 9.4 ppg, which is what was measured in 1L-15 in April of 2015. Potential Gas Zones (Requirements of 20 AA C 25.005(c)(4)(b)) Wells on 1L pad have injected gas, so there is a chance of encountering free gas while drilling the 1 L-24 laterals. 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 AA C 25.005(c)(4)(c)) The major expected risk of hole problems in the 1L-24 laterals will be shale instability across faults. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AA C 25.005(c)(5)) The 1 L-24 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 6 May 10,2016 I • PTD Application: 1L-24A & 1 L-24AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details MD MD TVDSS TVDSS 1 L-24A 8970' 13400' 5964' 6014' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 1L-24AL1 8640' 11750' 5775' 5978' 2-3/8", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (PO ND TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 122' 0' 122' 1640 670 Surface 9-518" 36.0 J-55 BTC 0' 5081' 0' 3610' 3520 2220 Production 7" 26.0 J-55 BTC-MOD 0' 9241' 0' 6287' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 0 8655' 0 5914' 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 MC 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 (8.6 ppg) — Drilling operations: Chloride-based FloVis mud (8.6 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 5,000 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". in the 1L-24 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. Page 3 of 6 May 10,2016 • • PTD Application: 1L-24A& 1 L-24AL1 Pressure at the IL-24 Window(8875' MD,6055'TVD)Using MPD Pumps On(1.5 bpm) Pumps Off A-sand Formation Pressure(8.7 ppg) 2743 psi 2743 psi Mud Hydrostatic(8.6 ppg) _ 2708 psi 2708 psi Annular friction(i.e. ECD, 0.090 psi/ft) 799 psi 0 psi Mud + ECD Combined 3507 psi 2708 psi (no choke pressure) (overbalanced—764 psi) _ (underbalanced—35 psi) Target BHP at Window(11.8 ppg) 3716 psi 3716 psi Choke Pressure Required to Maintain 209 psi 1008 psi Target BHP 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)(1 1)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AA C 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AA C 25.005(c)(13)) Summary of Operations Background KRU well I L-24 is a Kuparuk A-sand and C-sand producer equipped with 3-1/2"tubing and 7"production casing. The CTD sidetrack will utilize two laterals to target the A5 sand to the southeast and northwest of 1L-24. The laterals will be supported by injectors 1L-18 and 2E-05. Prior to CTD operations, E-line will punch 2' of holes in the 3-1/2"tubing tail and the D nipple at 8621' MD will be milled out to a 2.80"ID.The existing A-sand and C-sand perforations will be squeezed with cement and the 3-1/2"tubing tail will be cemented in place to provide a means to kick out of the 7"casing. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 8905' MD and set a mechanical whipstock in the 2.80"pilot hole to kick off at 8875' MD. The window will be milled at 8875'MD to drill and complete the IL-24A and 1L-24AL1 laterals. The 1L-24A southeastern lateral will exit the cement pilot hole at 8875' MD and TD at 13400'MD, targeting the A5 sand. It will be completed with 2-3/8"slotted liner from TD up to 8970'MD with an aluminum billet for kicking off the 1L-24AL1. The 1L-24AL1 lateral will drill to the northwest to a TD of 11750' MD targeting the A5 sand. It will be completed with 2-3/8"slotted liner from TD up to 8640' MD,back into the 3-1/2"tubing tail with a deployment sleeve. Page 4 of 6 May 10,2016 • • PTD Application: 1L-24A& 1 L-24AL1 Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas Lift mandrels,and pressure test. 2. RU E-line:Punch 2' of holes in the 3-1/2"tubing tail at 8626' MD. 3. RU Pumping Unit: Perform injectivity test down the tubing. 4. RU Service Coil: Mill out"D"nipple and cement squeeze the A-sand and C-sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1L-24A Sidetrack(A5 sand- Southeast) a. Drill 2.80"high-side pilot hole through cement to 8905' MD b. Caliper pilot hole c. Set top of whipstock at 8875' MD d. Mill 2.80"window at 8875' MD. e. Drill 3"bi-center lateral to TD of 13400' MD. f. Run 2-3/8"slotted liner with an aluminum billet from TD up to 8970' MD. 3. 1 L-24AL 1 Lateral(A5 sand-Northwest) a. Kick off of the aluminum billet at 8970' MD. b. Drill 3"bi-center lateral to TD of 11750' MD. c. Run 2-3/8"slotted liner with a deployment sleeve from TD up to 8640' MD. 4. Freeze protect,set BPV,ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Obtain SBHP. 3. Install gas lift design. 4. 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. 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 can be used.This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment,the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via Slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. Page 5 of 6 May 10,2016 • • Bettis, Patricia K (DOA) From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Tuesday, May 17, 2016 11:07 AM To: Bettis, Patricia K(DOA) Subject: RE: KRU 1L-24AL1: Revised Permit to Drill Application (Form 10-401) Attachments: 1L-24A, 1L-24AL1 Revised 10-401 PTD.pdf Good morning Patricia, Attached is the revised PTD for KRU 1L-24A and KRU 1L-24AL1. The original copies were scanned using black and white so the changes that have been highlighted in yellow. If you have questions or concerns please let me know. Thanks, Keith Herring CTD Engineer ConocoPhillips Alaska, Inc. 700 G Street,ATO—664 907.263.4321 Office 907.570.2410 Cell From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Tuesday, May 17, 2016 10:53 AM To: Herring, Keith E<Keith.E.Herring@conocophillips.com> Subject: [EXTERNAL]KRU 1L-24AL1: Revised Permit to Drill Application (Form 10-401) Good morning Keith, Please send a copy of the revised permit to drill application for KRU 1L-24AL1 showing all changes in red. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • TRANSMITTAL LETTER CHECKLIST WELL NAME: K ft( _ 1 L- 24 AL. PTD: c)C 1 to —0.50 /Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: kurft,,A �f�� POOL: `<t y &ft.&. ,Iv�r, (� "Y' /�.1 i( -( / uy' 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 IV/ LATERAL No. a m(o-04.15 , API No. 50-O2q - ;Z J .O -0/ - Od. (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 III III J H @ > O Q. 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J O m U W ole a s (c a > 0 a s 5y a a •a V OF T� • ssIv7,* THE STATE Alaska Oil and Gas _ —dam — �, of/\ T /\ SKA Conservation Commission 333 West Seventh Avenue / GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *M_ Main: 907.279.1433 OF ALAB1P Fax: 907.276.7542 www.aogcc.alaska.gov J. Burke Senior CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 L-24AL 1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-050 Surface Location: 567' FNL, 143' FEL, SEC. 31, T11N, R10E, UM Bottomhole Location: 4646' FNL, 2230' FEL, SEC. 31, T11N, R10E, UM Dear Mr. Burke: 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. 216-049, API No. 50-029- 22170-01-00. 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, /4°44414_ Cathy P. oerster Chair DATED this 1 day of April, 2016. RECENTED STATE OF ALASKA A CA OIL AND GAS CONSERVATION COMSON MAR 1 0 2016 PERMIT TO DRILL 20 AAC 25.005 AOGCC la.Type of Work: 1b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Specify if well is proposed for: Drill ❑ .Lateral El Stratigraphic Test ❑ Development-Oil ❑✓ . Service- Winj ❑ Single Zone 0 Coalbed Gas ❑ Gas Hydrates ❑ Redril El Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal Cl Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q - Single Well Cl 11.Well Name and Number: ConocoPhillips Alaska, Inc. , Bond No. 5952180 . KRU 1L-24AL1 3.Address: 6.Proposed Depth: -N SS 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11750' „ T : 5978' Kuparuk River Field/ , 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): A Kuparuk River Oil Pool Surface: 567'FNL, 143'FEL,Sec 31,T11N,R10E,UM ' ADL 256641 as 6,Sq Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1502'FNL, 1168'FEL,Sec 6,T1 ON,R10E,UM ALK 473 6/1/2016 Total Depth: 9.Acres in Property: tt1C) 14.Distance to Nearest Property: 4646'FNL,2230'FEL,Sec 31,T11N,R10E,UM 24e y59), 11100' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 130'• 15.Distance to Nearest Well Open Surface: x- 539924 Y- 5948401 Zone- 4 - GL Elevation above MSL(ft): 43' to Same Pool: 730', 1L-13 16.Deviated wells: Kickoff depth: 8970 feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93 degrees' Downhole: 3619 . Surface: 3014. 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" 2-3/8" 4.6# L-80 STL 3110' 8640' 5775' 11750' 5978' 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): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 9241' 6287' None 9155' 6232' None Casing Length Size Cement Volume MD TVD Conductor 78' 16" 235 sx AS 1 122' 122' Surface 5038' 9-5/8" 750 sx Type E,550 sx Class G 5081' 3610' Production 9213' 7" 250 sx Class G Prem 9241' 6287' Perforation Depth MD(ft): 8735'-8782'/8920'-8949'/9010'-9029' Perforation Depth TVD(ft): 5966'-5996'/6084'-6102'/6141'-6153' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot El Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 re uir ents❑✓ 21. Verbal Approval: Commission Representative: Date044e 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Keith Herring @ 263-4321 Email Keith.E.Herringcop.com Printed Name J.Burke Title Senior CTD Engineer Signature '-'7e__________ Phone 265-6097 Date /�/I(Q Commission Use Only Permit to Drill API Number: Permit Approvalr See cover letter for other Number: Q 162.. -0S0 50- O 9 -02p�I�.0 -(�-i; Date: �y(I`p requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: u Other: P re-.5 t 1-.2 3 j v v n S,` Samples req'd: Yes❑ Nog Mud log req'd:Yes❑ No A-1-1,r- vias-pre v-z'vi tri } r.t Z5-Po p5 t g H2S measures: Yes[►/r No❑ Directional svy req'd:Yes[' No❑ Spacing exception req'd: Yes❑ No 21 Inclination-only svy req'd:Yes❑ No Z Post initial injection MIT req'd:Yes❑ No a Approved by: COMMISSIONER P APPROVED BY a., ,?p THE C MMISSION Date: VTL 4 4/14. r^, 3)I(#�)4 Submit Form and GReiriGiallot Form 10-401(Revised 11/2015) months from the date of approva (20 AAC 25.005(g)) Attachments in Duplicate • • IIPV ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 8, 2016 RECEIVED MAR 10 2016 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission AOGCC 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permit to drill a dual lateral out of the Kuparuk Well 1 L-24 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin as early as April 1, 2016. The CTD objective will be to drill the 1 L-24A sidetrack and 1 L-24AL1 lateral, targeting the Kuparuk A5- sand interval. A separate application for sundry approval (10-403) has been submitted with this document to plug the KRU 1 L-24 (191-066) perforations to allow for the laterals to be drilled. As detailed in the summary for plugging sundry, ConocoPhillips requests a variance from the requirements of 20 ACC 25.112(c)(1) to plug the A-sand and C-sand perforations in this manner. Attached to this application are the following documents: - Permit to Drill Application Form (10-401) for 1 L-24A& 1 L-24AL1 - Detailed Summary of Operations - Directional Plans for 1 L-24A& 1 L-24AL1 - Current Wellbore Schematic - Proposed Wellbore Schematic If you have any questions or require additional information please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer • „{ Kuparuk CTD Laterals NABORS ALASKA 1L-24A & 1 L-24AL1 CDA °`°p"'PS Application for Permit to Drill Document AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 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 6 (Requirements of 20 AAC 25.050(b)) 6 16. Attachments 6 Attachment 1: Directional Plans for 1 L-24A& 1 L-24AL1 6 Attachment 2: Current Well Schematic for 1 L-24 6 Attachment 3: Proposed Well Schematic for 1 L-24A& 1 L-24AL1 6 Page 1 of 6 March 8, 2016 PTDp plication: 1L-24A & 1 L-24AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 L-24A& 1 L-24AL1. 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 1 L-24A& 1 L-24AL1. 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 3,500 psi. Using the maximum formation pressure in the area of 3619 psi in 2E-05 (i.e. 11.4 ppg EMW), the maximum potential surface pressure in 1L-24, assuming a gas gradient of 0.1 psi/ft, would be 3014 psi.' See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 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 1L-24 was measured to be 3,092 psi (9.9 ppg EMW) on 1/9/2014. The maximum downhole pressure in the 1 L-24 vicinity is to the south in the 2E-05 injector at 3,619 psi (11.4 ppg EMW) from November of 2014. The 1 L-24A sidetrack will be drilled southeast across a N-S fault that could encounter formation pressure as high as 10.6 ppg, which is what was measured in 1L-26A in June of 2012. The 1 L-24AL1 lateral will be drilled to the northwest towards a formation pressure of 9.4 ppg, which is what was measured in 1L-15 in April of 2015. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) Wells on 1L pad have injected gas, so there is a chance of encountering free gas while drilling the 1 L-24 laterals. 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 in the 1 L-24 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 L-24 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 6 March 8, 2016 • PTDpplication: 1L-24A & 1 L-24AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Top Liner Btm Liner Top Liner Btm Lateral Name Liner Details MD MD TVDSS TVDSS 1L-24A 8970' 13400' 5964' 6014' 2-3/8", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 1L-24AL1 8640' 11750' 5775' 5978' 2 3/8", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse (ppf) TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 122' 0' 122' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 0' 5081' 0' 3610' 3520 2220 Production 7" 26.0 J-55 BTC-MOD 0' 9241' 0' 6287' 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE 0 8655' 0 5914' 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 (8.6 ppg) — Drilling operations: Chloride-based FloVis mud (8.6 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 5,000 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". In the 1 L-24 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. Page 3 of 6 March 8, 2016 • PTDpplication: 1L-24A & 1L-24AL1 Pressure at the 1L-24 Window(8875' MD, 6055' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (9.9 ppg) 3117 psi 3117 psi Mud Hydrostatic(8.6 ppg) 2708 psi 2708 psi Annular friction (i.e. ECD, 0.090 psi/ft) 799 psi 0 psi Mud + ECD Combined 3507 psi 2708 psi (no choke pressure) (overbalanced -390 psi) (underbalanced -409 psi) Target BHP at Window(11.8 ppg) 3716 psi 3716 psi Choke Pressure Required to Maintain 209 psi 1008 psi Target BHP 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 AA C 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 KRU well 1L-24 is a Kuparuk A-sand and C-sand producer equipped with 3-1/2"tubing and 7"production casing. The CTD sidetrack will utilize two laterals to target the A5 sand to the southeast and northwest of 1L-24. The laterals will be supported by injectors 1L-18 and 2E-05. Prior to CTD operations,E-line will punch 2' of holes in the 3-1/2"tubing tail and the D nipple at 8621' MD will be milled out to a 2.80" ID. The existing A-sand and C-sand perforations will be squeezed with cement and the 3-1/2"tubing tail will be cemented in place to provide a means to kick out of the 7"casing. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 8905' MD and set a mechanical whipstock in the 2.80"pilot hole to kick off at 8875' MD. The window will be milled at 8875' MD to drill and complete the 1L-24A and 1L-24AL1 laterals. The 1L-24A southeastern lateral will exit the cement pilot hole at 8875' MD and TD at 13400' MD, targeting the A5 sand. It will be completed with 2-3/8" slotted liner from TD up to 8970'MD with an aluminum billet for kicking off the 1 L-24AL1. The 1L-24AL1 lateral will drill to the northwest to a TD of 11750' MD targeting the A5 sand. It will be completed with 2-3/8" slotted liner from TD up to 8640' MD,back into the 3-1/2"tubing tail with a deployment sleeve. Page 4 of 6 March 8, 2016 • PTDpp lication: 1L-24A & 1 L-24AL1 Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 3-1/2"tubing tail at 8626' MD. 3. RU Pumping Unit: Perform injectivity test down the tubing. 4. RU Service Coil: Mill out"D"nipple and cement squeeze the A-sand and C-sand perforations up to the holes in the tubing tail. 5. RU Slickline: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE,test. 2. 1L-24A Sidetrack(A5 sand- Southeast) a. Drill 2.80"high-side pilot hole through cement to 8905' MD b. Caliper pilot hole c. Set top of whipstock at 8875' MD d. Mill 2.80"window at 8875' MD. e. Drill 3"bi-center lateral to TD of 13400' MD. f. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8970' MD. 3. 1 L-24AL1 Lateral(A5 sand-Northwest) '/ a. Kick off of the aluminum billet at 8970' MD. b. Drill 3"bi-center lateral to TD of 11750' MD. c. Run 2-3/8" slotted liner with a deployment sleeve from TD up to 8640' MD. 4. Freeze protect, set BPV,ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pu11 BPV. 2. Obtain SBHP. 3. Install gas lift design. 4. 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. 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 can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. Page 5 of 6 March 8, 2016 • PTDpplication: 1L-24A & 1 L-24AL1 — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1 L-24 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 2-3/8" slotted liner, a joint of 2-3/8" 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 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. / • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — 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 open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Latera[Name' Dis*ance 1 L-24A 7440' 1 L-24AL1 11100' — Distance to Nearest Well within Pool 1L-24A 96' 1 L-25A 1 L-24AL1 730' 1L-13 16. Attachments Attachment 1: Directional Plans for 1L-24A & 1 L-24AL 1 laterals Attachment 2: Current Well Schematic for 1L-24 Attachment 3: Proposed Well Schematic for 1L-24A & 1L-24AL1 laterals Page 6 of 6 March 8, 2016 0W • i `I I1 hg 2 IG � SI _. - 0 0 M O 944, 00 _._ :__. .� ____ - __ _ __— ri O zjwm a„* o 9 meg- - .,r Z �i4w�� , ,4. r O WE',-,5-s , ....._I SII . Cg3=. i{ _ _a ' m a WI T - A _ i , . > m 1. :1 t936 4 o0 o Q v r, r. o Liii • a - - �*4 - r` a:i .o' - - . z- LLog?-riUr y -- 4. L :. y C .+ .. -. - y _ ` G - N N �J J a 4--4----1--, _ , ,- . . - ,_---V N V V J O / i Og 0 0 _m oN3a¢ a J o d / ” N v -_ 7 _� .1 _ o0 m vi O = _, -11- r i N N... Z CL O o m 0 o — - ,r : 7 0 0 0 0 0 0 0 0 0 0 0 0 0 O o O o O o O C . o o o O O o o O o a o O a o 0 0 0 a 0 0 o a 2� V V V V V V O N V 2 8 b 8 8 8 O N 3 ' ' O N V ' �N V U (uijjsn OO ) (+)gJoN/(-)u;nos A i ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 1L Pad 1L-24 1 L-24AL1 Plan: 1 L-24AL1 wp01 Standard Planning Report 04 March, 2016 BAKER HUGHES ✓ • ConocoPhillips Ira.. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 L-24 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-24 @ 130.00usft(1L-24) Site: Kuparuk 1L Pad North Reference: True Well: 1L-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 L-24AL1 Design: 1 L-24AL1_wp01 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1L Pad Site Position: Northing: 5,949,190.90 usft Latitude: 70°16'19.650 N From: Map Easting: 539,916.78 usft Longitude: 149°40'37.763 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.30 ° Well 1 L-24 Well Position +N/-S 0.00 usft Northing: 5,948,401.14 usft Latitude: 70°16'11.882 N +E/-W 0.00 usft Easting: 539,924.95 usft Longitude: 149°40'37.648 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1L-24AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2015 6/1/2016 18.44 80.93 57,493 Design 1L-24AL1_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,970.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 330.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (0) (0) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 8,970.00 84.34 184.98 5,963.58 -6,215.37 -1,003.34 0.00 0.00 0.00 0.00 9,070.00 89.91 224.66 5,968.58 -6,304.16 -1,044.46 40.00 5.57 39.61 82.00 9,250.00 89.91 296.66 5,968.85 -6,331.50 -1,210.61 40.00 0.00 40.00 90.00 9,550.00 89.91 317.66 5,969.30 -6,151.32 -1,448.38 7.00 0.00 7.00 90.00 9,710.00 87.02 328.48 5,973.59 -6,023.68 -1,544.34 7.00 -1.81 6.77 105.00 9,870.00 89.91 339.30 5,977.87 -5,880.28 -1,614.61 7.00 1.81 6.76 75.00 10,170.00 89.91 0.30 5,978.32 -5,586.67 -1,667.42 7.00 0.00 7.00 90.00 10,350.00 89.91 347.70 5,978.59 -5,408.02 -1,686.19 7.00 0.00 -7.00 -90.00 10,550.00 88.94 333.74 5,980.59 -5,219.72 -1,752.07 7.00 -0.49 -6.98 -94.00 10,850.00 88.21 354.73 5,988.07 -4,932.71 -1,833.11 7.00 -0.24 7.00 92.00 11,050.00 89.43 340.78 5,992.20 -4,737.79 -1,875.42 7.00 0.61 -6.97 -85.00 11,230.00 90.09 328.20 5,992.97 -4,575.67 -1,952.79 7.00 0.37 -6.99 -87.00 11,750.00 93.26 4.48 5,977.81 -4,079.08 -2,073.59 7.00 0.61 6.98 85.00 3/4/2016 4:12:29PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ..'� - ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 L-24 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-24 @ I30.00usft(1 L-24) Site: Kuparuk 1L Pad North Reference: True Well: 1L-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 L-24AL1 Design: 1 L-24AL1_wp01 Planned Survey Measured TVD Below Vertical Dogleg ToolfaceMap Map Depth Inclination Azimuth System +NI-S +El-W Section Rate Azimuth Northing Easting (usft) (°) r) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 8,970.00 84.34 184.98 5,963.58 -6,215.37 -1,003.34 -4,881.00 0.00 0.00 5,942,181.15 538,954.69 TIP/KOP 9,000.00 86.01 196.91 5,966.10 -6,244.66 -1,009.01 -4,903.53 40.00 82.52 5,942,151.83 538,949.18 9,070.00 89.91 224.66 5,968.58 -6,304.16 -1,044.46 -4,937.33 40.00 82.65 5,942,092.15 538,914.04 Start 40 dls 9,100.00 89.91 236.66 5,968.63 -6,323.14 -1,067.62 -4,942.19 40.00 90.01 5,942,073.04 538,890.99 9,200.00 89.91 276.66 5,968.78 -6,345.76 -1,162.96 -4,914.11 40.00 90.03 5,942,049.92 538,795.78 9,250.00 89.91 296.66 5,968.85 -6,331.50 -1,210.61 -4,877.93 40.00 90.01 5,942,063.93 538,748.05 End 40 dls,Start 7 dls 9,300.00 89.91 300.16 5,968.93 -6,307.72 -1,254.59 -4,835.35 7.00 90.00 5,942,087.47 538,703.96 9,400.00 89.91 307.16 5,969.08 -6,252.33 -1,337.77 -4,745.79 7.00 90.01 5,942,142.41 538,620.49 9,500.00 89.91 314.16 5,969.23 -6,187.22 -1,413.59 -4,651.50 7.00 90.01 5,942,207.11 538,544.33 9,550.00 89.91 317.66 5,969.30 -6,151.32 -1,448.38 -4,603.01 7.00 90.00 5,942,242.83 538,509.36 4 9,600.00 89.01 321.04 5,969.77 -6,113.40 -1,480.95 -4,553.88 7.00 105.01 5,942,280.58 538,476.60 9,700.00 87.20 327.80 5,973.08 -6,032.16 -1,539.06 -4,454.47 7.00 105.09 5,942,361.49 538,418.05 9,710.00 87.02 328.48 5,973.59 -6,023.68 -1,544.34 -4,444.49 7.00 105.02 5,942,369.94 538,412.74 5 9,800.00 88.65 334.57 5,977.00 -5,944.66 -1,587.19 -4,354.63 7.00 75.13 5,942,448.72 538,369.46 9,870.00 89.91 339.30 5,977.87 -5,880.28 -1,614.61 -4,285.17 7.00 75.04 5,942,512.95 538,341.71 6 - 9,900.00 89.91 341.40 5,977.92 -5,852.03 -1,624.69 -4,255.66 7.00 90.00 5,942,541.15 538,331.48 10,000.00 89.91 348.40 5,978.07 -5,755.55 -1,650.72 -4,159.09 7.00 90.01 5,942,637.49 538,304.94 10,100.00 89.91 355.40 5,978.22 -5,656.60 -1,664.80 -4,066.36 7.00 90.01 5,942,736.34 538,290.34 10,170.00 89.91 0.30 5,978.32 -5,586.67 -1,667.42 -4,004.49 7.00 90.00 5,942,806.25 538,287.34 7 10,200.00 89.91 358.20 5,978.37 -5,556.68 -1,667.82 -3,978.32 7.00 -90.00 5,942,836.24 538,286.79 10,300.00 89.91 351.20 5,978.52 -5,457.17 -1,677.04 -3,887.53 7.00 -90.01 5,942,935.69 538,277.04 10,350.00 89.91 347.70 5,978.59 -5,408.02 -1,686.19 -3,840.39 7.00 -90.00 5,942,984.78 538,267.63 8 10,400.00 89.67 344.21 5,978.77 -5,359.52 -1,698.33 -3,792.32 7.00 -94.00 5,943,033.21 538,255.24 10,500.00 89.18 337.23 5,979.77 -5,265.20 -1,731.32 -3,694.13 7.00 -94.03 5,943,127.35 538,221.75 10,550.00 88.94 333.74 5,980.59 -5,219.72 -1,752.07 -3,644.38 7.00 -94.03 5,943,172.71 538,200.77 9 10,600.00 88.82 337.23 5,981.57 -5,174.24 -1,772.81 -3,594.62 7.00 92.03 5,943,218.08 538,179.79 10,700.00 88.57 344.23 5,983.85 -5,079.93 -1,805.77 -3,496.46 7.00 92.08 5,943,312.21 538,146.32 10,800.00 88.33 351.23 5,986.56 -4,982.31 -1,827.00 -3,401.30 7.00 92.09 5,943,409.70 538,124.58 10,850.00 88.21 354.73 5,988.07 -4,932.71 -1,833.11 -3,355.30 7.00 92.05 5,943,459.26 538,118.21 10 10,900.00 88.51 351.24 5,989.50 -4,883.11 -1,839.21 -3,309.29 7.00 -85.05 5,943,508.82 538,111.84 11,000.00 89.12 344.27 5,991.57 -4,785.47 -1,860.41 -3,214.14 7.00 -85.08 5,943,606.34 538,090.13 11,050.00 89.43 340.78 5,992.20 -4,737.79 -1,875.42 -3,165.34 7.00 -85.02 5,943,653.93 538,074.87 11 11,100.00 89.61 337.28 5,992.62 -4,691.11 -1,893.31 -3,115.97 7.00 -87.02 5,943,700.51 538,056.73 11,200.00 89.98 330.29 5,992.99 -4,601.45 -1,937.45 -3,016.25 7.00 -87.02 5,943,789.93 538,012.12 11,230.00 90.09 328.20 5,992.97 -4,575.67 -1,952.79 -2,986.25 7.00 -87.00 5,943,815.62 537,996.65 12 11,300.00 90.51 333.08 5,992.61 -4,514.68 -1,987.10 -2,916.28 7.00 84.99 5,943,876.42 537,962.02 11,400.00 91.12 340.05 5,991.18 -4,423.00 -2,026.85 -2,817.01 7.00 84.96 5,943,967.89 537,921.79 11,500.00 91.73 347.03 5,988.69 -4,327.19 -2,055.15 -2,719.88 7.00 84.92 5,944,063.54 537,892.98 11,600.00 92.34 354.01 5,985.13 -4,228.68 -2,071.61 -2,626.34 7.00 84.88 5,944,161.95 537,876.00 11,700.00 92.95 0.99 5,980.51 -4,128.94 -2,075.97 -2,537.78 7.00 84.85 5,944,261.65 537,871.11 3/4/2016 4:12:29PM Page 3 COMPASS 5000.1 Build 74 • `-- ConocoPhillips • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 L-24 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-24 @ 130.00usft(1 L-24) Site: Kuparuk 1L Pad North Reference: True Well: 1 L-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 L-24AL1 Design: 1 L-24AL1_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-5 +E/-W Section Rate Azimuth Northing Easting (usft) (0) (a) (usft) (usft) (usft) (usft) (%100ft) (0) (usft) (usft) 11,750.00 93.26 4.48 5,977.81 -4,079.08 -2,073.59 -2,495.79 7.00 84.91 5,944,311.52 537,873.22 Planned TD at 11750.00 3/4/2016 4:12:29PM Page 4 COMPASS 5000.1 Build 74 • ConocoPhillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 L-24 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 L-24 @ 130.00usft(1 L-24) Site: Kuparuk 1L Pad North Reference: True Well: 1L-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 L-24AL1 Design: 1 L-24AL1_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1L-24AL1_T07 0.00 0.00 5,993.00 -10,891.231,138,177.05 5,943,548.00 1,678,032.00 70°0'25.704 N 140°33'38.035 W -plan misses target center by 1139189.99usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Point 1 L-24AL1_T08 0.00 0.00 5,979.00 -10,393.401,138,031.68 5,944,045.00 1,677,884.00 70°0'30.750 N 140°33'40.030 W -plan misses target center by 1139042.68usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Point 1L-24AL1_T03 0.00 0.00 5,970.00 -12,472.151,138,695.72 5,941,970.00 1,678,559.00 70°0'9.593 N 140°33'30.084 W -plan misses target center by 1139716.24usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Point 1L-24AL1_T06 0.00 0.00 5,988.00 -11,261.801,138,277.10 5,943,178.00 1,678,134.00 70°0'21.959 N 140°33'36.782 W -plan misses target center by 1139291.61 usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Point 1 L-24AL1_T01 0.00 0.00 5,970.00 -12,564.241,139,086.28 5,941,880.00 1,678,950.00 70°0'8.127 N 140°33'19.398 W -plan misses target center by 1140107.30usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Point 1L-24AL1_T05 0.00 0.00 5,978.00 -11,708.621,138,422.74 5,942,732.00 1,678,282.00 70°0'17.407 N 140°33'34.561 W -plan misses target center by 1139439.32usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Point 1L-24AL1_T04 0.00 0.00 5,977.00 -12,164.471,138,573.34 5,942,277.00 1,678,435.00 70°0'12.760 N 140°33'32.239 W -plan misses target center by 1139592.21 usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Point 1L-24 CTD Polygon Sou 0.00 0.00 0.00 -12,380.441,138,940.24 5,942,063.00 1,678,803.00 70°0'10.126 N 140°33'22.754 W -plan misses target center by 1139975.85usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Polygon Point 1 0.00 0.00 0.00 5,942,063.00 1,678,803.00 Point2 0.00 -44.05 388.81 5,942,021.02 1,679,192.00 Point3 0.00 -183.24 423.08 5,941,882.02 1,679,227.00 Point4 0.00 -406.86 726.94 5,941,660.04 1,679,532.02 Point 5 0.00 -646.46 1,406.76 5,941,424.07 1,680,213.03 Point6 0.00 -816.03 1,891.93 5,941,257.10 1,680,699.05 Point 7 0.00 -1,439.41 2,902.76 5,940,639.15 1,681,713.07 Point8 0.00 -2,063.52 4,052.61 5,940,021.21 1,682,866.10 Point9 0.00 -2,182.62 4,260.01 5,939,903.22 1,683,074.11 Point 10 0.00 -2,514.67 4,071.25 5,939,570.21 1,682,887.13 Point 11 0.00 -2,437.67 3,883.63 5,939,646.20 1,682,699.12 Point12 0.00 -1,813.64 2,747.78 5,940,264.14 1,681,560.09 Point 13 0.00 -1,176.37 1,758.02 5,940,896.09 1,680,567.06 Point 14 0.00 -1,020.98 1,307.78 5,941,049.07 1,680,116.05 Point 15 0.00 -745.87 531.14 5,941,320.03 1,679,338.04 Point 16 0.00 -533.34 244.23 5,941,531.02 1,679,050.03 Point 17 0.00 -292.06 5.47 5,941,771.00 1,678,810.02 Point 18 0.00 0.00 0.00 5,942,063.00 1,678,803.00 1L-24 CTD Polygon Nor 0.00 0.00 0.00 -12,380.441,138,940.24 5,942,063.00 1,678,803.00 70°0'10.126 N 140°33'22.754 W -plan misses target center by 1139975.85usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Polygon Point 1 0.00 0.00 0.00 5,942,063.00 1,678,803.00 Point2 0.00 -37.01 381.85 5,942,028.02 1,679,185.00 Point 3 0.00 -244.81 339.75 5,941,820.02 1,679,144.01 Point4 0.00 -404.20 219.90 5,941,660.01 1,679,025.02 Point5 0.00 -459.15 18.59 5,941,604.00 1,678,824.02 Point 6 0.00 -346.75 -244.85 5,941,714.99 1,678,560.02 Point7 0.00 9.92 -555.01 5,942,069.98 1,678,248.00 Point8 0.00 1,191.70 -868.84 5,943,249.96 1,677,927.94 Point 9 0.00 2,005.90 -1,079.58 5,944,062.95 1,677,712.90 3/4/2016 4:12:29PM Page 5 COMPASS 5000.1 Build 74 • • ConocoPhillips «L ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1 L-24 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1L-24 @ 130.00usft(1L-24) Site: Kuparuk 1LPad North Reference: True Well: 1L-24 Survey Calculation Method: Minimum Curvature Wellbore: 1L-24AL1 Design: 1 L-24AL1_wp01 Point 10 0.00 2,199.88 -1,071.56 5,944,256.95 1,677,719.89 Point 11 0.00 2,169.76 -668.68 5,944,228.97 1,678,122.89 Point 12 0.00 1,982.81 -683.66 5,944,041.96 1,678,108.90 Point 13 0.00 1,272.55 -458.37 5,943,332.98 1,678,337.93 Point 14 0.00 271.08 -199.60 5,942,332.99 1,678,601.98 Point 15 0.00 34.44 -82.83 5,942,097.00 1,678,720.00 Point 16 0.00 0.00 0.00 5,942,063.00 1,678,803.00 1L-24AL1_T02 0.00 0.00 5,964.00 -12,647.171,138,883.82 5,941,796.00 1,678,748.00 70°0'7.618 N 140°33'25.497 W -plan misses target center by 1139905.30usft at 8970.00usft MD(5963.58 TVD,-6215.37 N,-1003.34 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,750.00 5,977.81 23/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,970.00 5,963.58 -6,215.37 -1,003.34 TIP/KOP 9,070.00 5,968.58 -6,304.16 -1,044.46 Start 40 dls 9,250.00 5,968.85 -6,331.50 -1,210.61 End 40 dls,Start 7 dls 9,550.00 5,969.30 -6,151.32 -1,448.38 4 9,710.00 5,973.59 -6,023.68 -1,544.34 5 9,870.00 5,977.87 -5,880.28 -1,614.61 6 10,170.00 5,978.32 -5,586.67 -1,667.42 7 10,350.00 5,978.59 -5,408.02 -1,686.19 8 10,550.00 5,980.59 -5,219.72 -1,752.07 9 10,850.00 5,988.07 -4,932.71 -1,833.11 10 11,050.00 5,992.20 -4,737.79 -1,875.42 11 11,230.00 5,992.97 -4,575.67 -1,952.79 12 11,750.00 5,977.81 -4,079.08 -2,073.59 Planned TD at 11750.00 3/4/2016 4:12:29PM Page 6 COMPASS 5000.1 Build 74 `-- • Baker Hughes INTEQ • Fail ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 1L-24 Project: Kuparuk River Unit TVD Reference: 1L-24 @ 130.00usft(1L-24) Reference Site: Kuparuk 1L Pad MD Reference: 1L-24 @ 130.00usft(1L-24) Site Error: 0.00 usft North Reference: True Reference Well: 1 L-24 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1 L-24AL1 Database: OAKEDMP2 Reference Design: 1 L-24AL1_wp01 Offset TVD Reference: Offset Datum Reference 1L-24AL1_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,970.00 to 11,750.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,362.00 usft Error Surface: Elliptical Conic Survey Tool Program Date 3/3/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 200.00 8,800.00 1L-24(1L-24) GCT-MS Schlumberger GCT multishot 8,800.00 8,970.00 1L-24A_wp03(1L-24A) MWD MWD-Standard 8,970.00 11,750.00 1L-24AL1_wp01 (1L-24AL1) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 11,750.00 6,107.81 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 1L Pad 1L-13-1L-13AL1-1 L-13AL1_wp04 Out of range 1L 18 1 L 18 1L 18 Out of range 1 L-23-1 L-23-1 L-23 Out of range 1L 24 1L 24 1L 24 8,984.69 9,000.00 39.88 9.02 30.97 Pass-Major Risk 1L-24-1L-24A-1 L-24A_wp03 8,975.00 8,975.00 0.11 0.33 -0.13 FAIL-Minor 1/10 1L 25 1L 25 1L 25 Out of range 1 L-25-1 L-25A-1 L-25A 9,140.00 11,850.00 736.08 318.36 448.13 Pass-Major Risk 1 L-25-1 L-25AL1-01-1 L-25AL1-01 Out of range 1 L-25-1 L-25AL1-01 PB1-1 L-25AL1-01 PB1 Out of range 1 L-25-1 L-25AL1-02-1 L-25AL1-02 Out of range 1 L-25-1 L-25AL1-02PB2-1 L-25AL1-02PB2 Out of range 1L-25-1L-25APB1-1L-25APB1 Out of range Offset Design Kuparuk 1L Pad- 1 L-24-1 L-24-1 L-24 Offset Site Error: 0.00 usft Survey Program: 200-GCT-MS Rule Assigned:Major Risk 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 +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (") (usft). (usft) (") (usft) (usft) (usft) 8,984.69 6,094.92 9,000.00 6,134.65 0.30 1.46 11.46 -6,226.62 -1,004.28 2-11/16 39.88 9.02 30.97 Pass-Major Risk,CC,ES,SF 9,003.76 6,096.35 9,025.00 6,150.52 0.31 1.64 21.82 -6,245.87 -1,005.94 2-11/16 54.39 9.92 44.89 Pass-Major Risk 9,021.37 6,097.36 9,050.00 6,166.37 0.32 1.83 32.37 -6,265.13 -1,007.60 2-11/16 69.61 10.79 59.50 Pass-Major Risk 9,037.23 6,098.01 9,075.00 6,182.20 0.33 2.01 42.36 -6,284.41 -1,009.26 2-11/16 85.72 11.55 75.01 Pass-Major Risk 9,051.27 6,098.39 9,100.00 6,198.00 0.33 2.19 51.43 -6,303.71 -1,010.94 2-11/16 102.77 12.24 91.51 Pass-Major Risk 9,063.54 6,098.55 9,125.00 6,213.79 0.34 2.38 59.51 -6,323.02 -1,012.62 2-11/16 120.77 12.80 109.01 Pass-Major Risk 9,074.61 6,098.59 9,150.00 6,229.56 0.35 2.56 66.77 -6,342.35 -1,014.31 2-11/16 139.62 13.29 127.42 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 3/3/2016 2:06:52PM Page 2 COMPASS 5000.1 Build 74 III N ` N O O • p ,. q rel. _... -N n N .. 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N O 11 0 O o 0 0 0 0 0 0 o O o 0 0 �� 1 + 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O vl O O J O 00 0 0 LO_O 0 0 0 0 0 0 0 0 h N N N ore N N N O - N N n N O O N(f)N-00 In 1`M v)00 0 N r b b U1 U 00000000000 O O N d O z0 � (ui/}Fsn c8)u3daQ I�aivan aru,j, V KUP PROD • 1L-24 prii._ ConocoPhillips ' Well Attributes Max Angle&MD TD Alaska,he. Wellbore APIIU WI Field Name Wellbore Status ncl() MO(ftKB) Act Btm(ftKB) Cc.rrr"7.illipn 500292217000 KUPARUK RIVER UNIT PROD 53.31 4,700.00 9241.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date 1L-24,4/2420154:4126 PM SSSV:NONE 75 11/82014 Last WO: 12/17/2013 42.99 5/23/1991 Vertical schematic(actual) Annotation Depth(MKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,928.0 4/23/2015 Rev Reason:TAG lehallf 4/24/2015 HANGER:39.2TRW asL ing Strings Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread - CONDUCTOR 16 15.062 44.0 122.0 122.0 62.50 H-40 WELDED • • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread • ,SURFACE 9518 8.921 43.0 5,081.2 3,6102 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB( Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread ' PRODUCTION 7 6276 28.3 9,240.9 6,286.8 26.00 J-55 BTC-MOD Tubing Strings I Tubing Description I String Ma...I ID(in) I Top(ftKB) I SetDepth(ft../Set Depth(ND)(...I Wt(11c/ft) I Grade I Top Connection TUBING WO-2013 31/2 2.992 392 8,46441 5,7919 930 L-80 EUE-m .M/CONDUCTOR;440-122.0• ."M.1^Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;3,338.6 39.2 39.2 0.08 HANGER FMC Gen IV TUBING HANGER 2.992 8,355.3 5,721.4 49.72 LOCATOR BAKER LOCATOR SUB 2.990 8,356.3 5,722.0 49.72 SEAL ASSY BAKER SEAL ASSY-Space out above PBR locator sub 2.990 "Actual space out" 7.08'locator above PBR 8,363.4 5,726.6 49.72 PBR BAKER 80-40 POLISH BORE RECEPTACLE 40,000 4.000 GAS LIFT,4,994.3 - Shear force 2 8,385.8 5,741.1 49.72 PACKER BAKER FHL RETRIEVABLE PACKER 60,000 PSI Shear 2.930 Release 8,438.5 5,775.2 49.75 NIPPLE CAMCO"DS"NIPPLE 2.875" 2.875 SURFACE;43.05,081.2- H A 8,456.1 5,786.6 49.76 OVERSHOT BAKER POORBOY OVERSHOT 6"OD x 3.62"ID 3.000 Swallowed 6.84'of tbg stub. • Tubing Description I String Me...I ID(in) (Top(ftKB)8,457.6 8,get Depth(ft.602.3.l Set Depth(ND)(...I Wt(Ilvk) (Grade (Top Connection TUBING WO-2004 31/2 2.992 5,880.9 9.30 J-55 EUE AB MOD GAS LIFT;6,219.9 Completion Details 1111 in Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 8,476.0 5,799.4 49.78 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.980 GAS LFT;7,1994 - 8,477.3 5,800.2 49.78 PBR BAKER 80-40 PBR 2.980 8,491.0 5,809.1 49.79 PACKER BAKER FHL PACKER 2.930 I 8,572.5 5,861.6 49.89 NIPPLE CAMCO DS NIPPLE WITH 2.72"NO-GO 2.812 GAS LIFT;7,870.9 8,589.6 5,872.6 49.92 SEAL ASSY TIW SEAL ASSEMBLY/PBR,STABBED INTO EXISTING PBR 3.000 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-Original 3 1/2 2.992 8,590.9 8,654.6 5,914.4 9.30 J-55 EUE8rdABMOD Completion Details GAS LIFT;8,299.3 E Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) - 8,590.9 5,873.5 49.92 PBR TIW PBR w/10'STROKE 3.000 8,603.7 5,881.7• 49.94 PACKER TIW HM-1 RETRIEVABLE PACKER 3.500 LOCATOR;8.355.3 - 1 8,621.0 5,892.9 49.98 NIPPLE CAMCO D NIPPLE NO GO 2.750 SEAL ASSY;8,356.3 s 8,653.6 5.913.8 50.06 SOS TIW SHEAR OUT SUB 3.015 PBR;8,363.4 lPerforations&Slots PACKER;8,385.8 Shot Dens Top(ND) Btm(ND) (shotslf L- Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,735.0 8,782.0 5,966.0 5,996.0 C-4,1L-24 8/20/1991 6.0 (PERF 2 1/8"Flow Jet Stri;0 NIPPLE;8.4385 deg.ph 8,920.0 8,949.0 6,083.8 6,102.2 A-5,1L-24 6/18/1991 4.0 (PERF 4.5"Carrier;180 deg.ph OVERSHOT;8,456.1 9,010.0 9,029.0 6,141.0 6,153.0 A-4,1L-24 6/18/1991 4.0 (PERF 4.5"Carrier;180 deg.ph Mandrel Inserts SEAL ASSY;9.476.0 - St 000i PBR;8,477.3 Top(ND) Valve Latch Port Size TRO Run PACKER;8.491.0 _--.." N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com -"` 1' 3,338.6 2,496.9 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,264.0 1/6/2014 I 2 4,994.3 3,549.7 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,253.0 1/6/2014 3 6,219.9 4,344.4 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,241.0 1/6/2014 11 4 7,199.5 4,959.4 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,228.0 1/6/2014 NIPPLE;8,572.5 5 7,870.9 5,403.2 CAMCO MMG 11/2 GAS LIFT OV RK 0.250 0.0 1/7/2014 a6 8,299.3 5,685.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/22/2013 SEAL ASSY;8,589.6, Notes:General&Safety PBR;8,590.9 TEnd Date Annotation 6/12/2004 NOTE WORKOVER PACKER;8,603.7 6/12/2004 NOTE:TREE CAP CONNECTION:3" al 6/12/2004 NOTE:TREE:CAMERON/GEN 5/3-1/8"/5000 psi NIPPLE;8,621.0 " 10/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 al SOS;8,653.6 -ill . -- PERE;8,735.0-8782.0--.. !PERE;8.920.0.8,940.0------- (PERF;9,010.0.9,029.0-~ PRODUCTION;28.3.9,240.9 • • 1 L-24 Proposed CTD Schematic Modified by KEH 3/2/16 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 16"62#H-40 shoe @ 122'MD „ 3-1/2"Camco MMG gas lift mandrel @ 3339',4994',6220', 7200',7871',8299'MD 9-5/8"36#J-55 shoe @ 5081'MD ' ' Baker 80-40 PBR @ 8363'MD(4.0"ID) Baker FHL packer @ 8386'MD(2.93"ID) 3-1/2"Camco DS nipple @ 8573"MD(2.875"min ID) a=te Baker Poorboy Overshot @ 8456'MD(3.00"min ID) Baker 80-40 PBR @ 8477'MD(2.98"ID) Baker FHL packer @ 8491'MD(2.93"ID) 1 3-1/2"Camco DS nipple @ 8573"MD(2.812"min ID) ,i[ TIW Seal Assy @ 8590'MD(3.00"ID) -- TIW PBR @ 8591'MD(3.00"ID) TIW HM-1 Retrievable Packer @ 8604'MD(3.5"ID) illimiri 3-1/2"Camco D landing nipple @ 8621"MD(2.75"min ID) 3-1/2"SOS @ 8654'MD(8649'PDC) C-sand perfs 8735'-8782'MD no KOP @ 8875 PDC 1 L-24AL1 w5p0 (A5 sand-Northwest) Top of liner @ 8640 MD A-sand perfs 8920'-8949'MD —ss ____________________---- 9010'-9029'MD =___ 7"26#J-55 shoe @ 9241'MD - 1L-24A wp03(A5 sand-Southeast) TD @ 13,400'MD Liner Billet @ 8970'MD • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • TRANSMITTAL LETTER CHECKLIST WELL NAME: / Rlx.. IL- AL PTD: a)(o -Q O ✓Development _Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: Ap /( Vi POOL: JCC ?t`/E J^ /'` J�t V/f Or l I t,yCk�/L./� Check Box for Appropriate Letter/Paragraphs to be Incccluded in Transmittal Letter CHEC OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. 06-049 , API No. 50-O 9 - ?O -01 -04 . (If last two digits Production should g 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 • o 0❑ To O) O o 0. 0 N . o a) ai. Q@ aS0. 0 cTu E m. a. �: t, s p a' a' , c0 3 >. o: c o O z oo > O a 4 u) @ C. •C CO, 3. C CA Co EO tea' 0 a co . 3. ami o a) o: :)•-• a 6o w w 3 J S O, _, c U. Op� O' w. H. •3 c'. d a 4 ai n E a Q � •Y. Op U, � �� U' �� �: cps 2 p, D� Ci O! l0 �: O• w17; 0 m CD aa) N O U Q)• , :, C• C (p. y 7, =,,,_ . P2, S. O. C 0_ 000 , -J. Y• 0 aa) a m. 3. y N '9: 2, Z. a). 't. a' O,. G �� Y' N' TY (a' y' >a a) .N N co y' a Y co 3, . w. 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