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217-163
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I' N Z H m 0z 0 C a) p ev Q O 0 O O al « C C U ,"�, U U U U U O • 1.7. m J 'N N .Q' a) U t� D: a o a a m V E a UO E 0 O o O O o a) LL E 2 aa)) 0 o a3) d o E d a w J w w J 3 —• U a 0 0 0 ct 0 10 0 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0• Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: 1/4/2018 217-163 ' 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 12/20/2017 . 50-029-22948-62-00 r 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 224'FSL,594'FEL,Sec 14,T11N, R10E,UM 44/2 947 12/23/14 KRU 1D-12L3 . Top of Productive Interval: 9. Ref Elevations: KB:104.3 d 17. Field/Pool(s): 461'FSL,205'FEL,Sec 13,T11N,R10E, UM GL:61.1 h BF:43.2 Kuparuk River Field/Kuparuk Oil Pool ' Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 815'FSL, 1786'FWL,Sec 18,T11N,R11 E, UM N/A ADL 25650 ei&.2 y3 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. DNR ApprovAl Number: Surface: x- 560491 y- 5959889 Zone- 4 11148/6555 . LONS 79-016 TPI: x- 566157 y- 5960173 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 568145 y- 5960545 Zone- 4 N/A 1678/1649 5. Directional or Inclination Survey: Yes 2 , (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)I 9027/6539 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 RECEIVED GR/Res FEB 022018 AOGCC 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 62.58 H-40 35 121 35 121 42 Existing,cement to surface 9.625 40 L-80 35 5641 35 4327 13.5 974 sx 11.0 Lead,146 sx 12.0 Tail 7 26 L-80 31 8695 31 6323 9.875 644 sx 15.8 Class G 2 3/8 4.6 L-80 9901 11148 6587 6555 3 Slotted Liner 24.Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD; Size and Number; Date Perfd): 4 1/2 x 3 1/2 8572 8095/5929 SLOTTED @: 9911 -11148 MD and 6587-6555 ND 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. t lu I t$ Was hydraulic fracturing used during completion? Yes❑ No 0 l Per 20 AAC 25.283(i)(2)attach electronic and printed information I-tDEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 1/15/2018 GAS LIFT Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/18/2018 24hrs Test Period 2553 3024 7035 176 1185 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 99R 1101 24-Hour Rate - 2553 3024 7035 • Form 1$--40,7 Revised,..,5/2.A37//Ay7 1/71- Z 113/)5,00, INUED ON PAGE 2 RBDMS IA, FEB - 2 2018 Submit ORIGINIAL or i` • i 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 ND Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1678 1649 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 9027 6541 information, including reports, per 20 AAC 25.071. Formation @ TPI-Kuparuk C TD 11148 6555 1 D-12L3-01 PB1 Total Depth 9974 6588 Formation at total depth: Kuparuk D ' 31. List of Attachments: Daily Operations Summary,Definitive Survey,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlinger Contact Name: Mike Callahan Authorized Title: Staff CTD En ineer Contact Email: Mike.Callahana,cop.com Authorized Contact Phone: 263-4180 Signature: Date: 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 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • • Proposed 1D-12L3,-01,-02,-03 _ 4-1122"nippleGLM@TBD @TBD(3.813"min ID) 4-1/2"12.6#L-80 Tubing �� 4.4-11 8-5/8"40#L-80 �" 4-1/2"Baker Premier packer @ TBD -..wwilli _,------ 4-12"DB-nipple @ TBD(3.31"min ID) 4-1/2"x 3-1/2 cross-over@ TBD MD 3-12"Baker FHL packer @ TBD MD ir 3-12"X-nipple @TBD(2.813"min ID) Poor Boy Overshot @TBD MD ^ °^w+ '#tl°'�': 1 MIMI ;-3-12"cut tubing @ 8502"(11/19/03) �tme'#13 dirt, emrq, �kon13C'.EtAD Y61' 67 / 3-12"Camco DS nipple @ 8538'MD(2.75"min ID,Milled to 2.80"?) Baker 3-1/2"80-40 seal assembly @ 8546'MD(3"ID) BAKER 7"x 3.5"SLZXP LT PACKER&Hanger w/PBR @ 8542'MD sei --- - „-„ ! 10.12L3-03 TD=11993'MD T'26#L-80 shoe _ 2-3/8”liner w/sealbore deployment sleeve 1 Sealbore Deploynrent Sleeve @ Top of slotted liner BOL94831MD 993*MD —8984'MD 3-12”KB Packer Whipstock @ HES Swell Packer=9457'MD 9027'MD 10.12L3-02 TD=11707 MD KB packer straddle assembly ,.— ---- ,-' _ _____ _ 2-3/8'slotted liner w/liner top billet (1.83"min ID) ----w»..I ` __--,_------ -' - -- ------ _._ _.___ __- ' TOL=9904'MD BOL=11702'MD 9043'-9099'MO --� - ��.� 10-120-01 TD 11107 MD ir 23/8'slotted lner w/lner top billet Scueazed Perts � TOL 9554'MD BOL 11107'MD 9001-9031'MD(C4)9051-9089'MD(C4) 10-12L3-01 P01 TD=9974'MD 9136-9138'MD __00 -_-_-_-_ - _ =:___` ___ -,;__: Anchored billet=9885'MD(failed) 9171-9181'MD(C7) '-- "- _--' Anchored billet=9807 MD Snap-latch assembly at 9107'MD L2 KOP 9100'MD 1D-12L3 TD=11146'MD 3-1/2"KB Packer at 9110'MD �.=k N. off of 3-1/7'snap-latch tray(removed) 2-3/8'slotted liner w/liner top billet 1.71"R-nipple at 9123'MD • L2 Liner:2-3/8",4.68,L-80 ST-L liner 9108'-10935' TOL=9901'MD,BOL=11148'MD Muleshoe at 9128'MD solid liner 9108'-9129' L2 @ 10,955'MD slotted liner:9129'-10935' 3"borehole ---"" L1KOP @9135'MD off of 3-12"monobore whipstock , [anchor billet as L1 PB1 9340-10,251 MD NA no liner OM `:. 3-1/7'9.3#L-80 L1 TD @ 10,695'MD L1 Liner.2-3/8",4.6#,L-80 ST-L liner 9134'-10695' 3"borehole solid liner 9134'-9271',9334-9429',&10219-10346' . slotted liner 9271'-9334',9429'-10219',10346'-10662' •Operations Summary (with Timelog�epths) 1D-12 Cono ill Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time : Our(hr) Phase Op Code ACGvity Code Time P-T-X Operation (ftK6) End fepth(ftK13) 12/16/2017 12/16/2017 3.00 MIRU MOVE OTHR P Continue prepping for MOB to 1D-12. 0.0 0.0 15:00 18:00 Reconfigure BOPE stack for big tree operations,Swap out swab valve and three way in stack 12/16/2017 12/16/2017 3.00 MIRU MOVE OTHR P Crew change,continue BOPE stack 0.0 0.0 18:00 21:00 reconfiguration to 4-1/16" components, worsening weather conditions likely to delay move,TT hardline broken down 12/16/2017 12/17/2017 3.00 MIRU MOVE RURD P RD PUTZ,secure BOP stack,install 0.0 0.0 21:00 00:00 tree cap,work RD checklist Field wide phase 2 conditions on main roads&to CDR3 drill sites,phase 3 in all other locations 12/17/2017 12/17/2017 4.00 MIRU MOVE RURD P Continue RD checklist,call Peak truck 0.0 0.0 00:00 04:00 out for move when phase 1 conditions called,warm up generators, disconnect from hi-line,RD PUTZ, load&move product to 1D-Pad, orgainize snow removal on 2G-Pad& 1D-Pad,Peak trucks arrive at 04:00 hrs 12/17/2017 12/17/2017 6.00 MIRU MOVE MOB P Boiler#1 issues,trouble shoot no fuel 0.0 0.0 04:00 10:00 to boiler,sediment plugged off meter on flow-line,cleared&fixed,PJSM, hook up pits&sub to sows,pull off well,jack&hook up shop&1/2-way house 12/17/2017 12/17/2017 4.00 MIRU MOVE MOB P Move CDR3 from 2G-Pad to 1D-Pad 0.0 0.0 10:00 14:00 12/17/2017 12/17/2017 3.50 MIRU MOVE MOB P Unhook jeeps,spot sub&pits on 10- 0.0 0.0 14:00 17:30 12 12/17/2017 12/17/2017 4.50 MIRU MOVE RURD P Work RU checklist,get on hi-line,get 0.0 0.0 17:30 22:00 COMMS up,rework cellar scaffolding, MU TT hard-line&test,move&spot shop&1/2-way house,connect PUTZ 12/17/2017 12/18/2017 2.00 MIRU WHDBOP NUND P Continue RU checklist,bring on 0.0 0.0 22:00 00:00 seawater for flush&used drilling fluid for milling,NU BOPE,grease tree& CDR3 swab "Rig Accept 24:00 hrs 12/17/17 12/18/2017 12/18/2017 3.50 MIRU WHDBOP RURD P Continue prep for BOPE test,clear 0.0 0.0 00:00 03:30 floor,fluid pack lines,shell test 12/18/2017 12/18/2017 7.50 MIRU WHDBOP BOPE P BOPE test,Test witnes waived by 0.0 0.0 03:30 11:00 Brian Bixby,AOGCC.Fail Pass on lower 2"pipe slips.AIII other tests satisfactory 12/18/2017 12/18/2017 2.00 MIRU WHDBOP MPSP P PJSM W/Kuparuk valve crew to pull 0.0 0.0 11:00 13:00 BPV,R/U and Pull BPV.2106 PSI under plug,Bleed off BPV lubricator and blow down.Rig down valve crew 12/18/2017 12/18/2017 0.70 SLOT WELLPR CIRC P WHP 2106 PSI, Pump 100 BBIs 0.0 0.0 13:00 13:42 seawater downhole @ 3.5BPM.Knock WHP down to 1020 Page 1/24 Report Printed: 1/9/2018 x " � Operations Summary (with TimelogDepths) ;n,: 1D-12 ConoicoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tune End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/18/2017 12/18/2017 1.50 SLOT WELLPR PULD P PJSM, PD BHA#1,Clean out BHA 0.0 63.6 13:42 15:12 with 2.80 D-331 with Ridgeset side cutters and straight motor.Pressure increased from 1020 to 1500 PSI.Circ another 65 BBIs down well.WHP down to 930 PSI.Resume pressure deploying BHA#1.Make up to coil and surface test.Check packoffs 12/18/2017 12/18/2017 3.80 SLOT WELLPR TRIP P Trip in well,EDC open pumping.5 63.6 8,860.0 15:12 19:00 BPM seawater 12/18/2017 12/18/2017 0.10 SLOT WELLPR DLOG P Log K1 for+.5'correction,PUW=33K, 8,860.0 8,894.0 19:00 19:06 Close EDC 12/18/2017 12/18/2017 0.20 SLOT WELLPR TRIP P Continue in well,Dry tag straddle 8,894.0 9,043.0 19:06 19:18 packer @ 9043 12/18/2017 12/18/2017 0.90 SLOT WELLPR REAM P PUH,start reaming up from 9040, 9,043.0 8,990.0 19:18 20:12 1.84 BPM @ 4095 PSI FS. PUW=34.5K.Saw no motor work of over pulls. 12/18/2017 12/18/2017 2.90 SLOT WELLPR REAM P continue reaming passes perfs up& 8,990.0 9,043.0 20:12 23:06 down from 8990 to 9040', 1.84 BPM @ 4095 PSI FS,BHP=3314.Roll hole to used power pro,perform CCL, evaluation of log shows 9027'TOWS depth looks good with colloar at -9022'(5'above TOWS) 12/18/2017 12/19/2017 0.90 SLOT WELLPR TRIP P POOH 9,043.0 4,088.0 23:06 00:00 12/19/2017 12/19/2017 0.90 SLOT WELLPR TRIP P 'Complete POOH,tag up,PJSM 4,088.0 63.0 00:00 00:54 12/19/2017 12/19/2017 1.10 SLOT WELLPR PULD P PUD BHA#1,clear floor 63.0 0.0 00:54 02:00 12/19/2017 12/19/2017 1.30 PROD1 RPEQPT PULD P PJSM,PD BHA#2 WS setting 0.0 73.0 02:00 03:18 assembly(3.5"Monobore XL w/KB packer&solid bullnose).EDC open 12/19/2017 12/19/2017 2.20 PROD1 RPEQPT WPST P RIH with BHA#2 73.0 8,870.0 03:18 05:30 12/19/2017 12/19/2017 0.20 PROD1 RPEQPT DLOG P Tie into K1 for-3.5'correction 8,870.0 8,900.0 05:30 05:42 12/19/2017 12/19/2017 0.10 PROD1 RPEQPT WPST P Continue RIH,arrive at setting depth, 8,900.0 9,038.3 05:42 05:48 bring up pump and set WS,TOWS= 9027',oriented 330°ROHS 12/19/2017 12/19/2017 2.10 PROD1 RPEQPT TRIP P POOH,tag up,space out,bleed off 9,038.3 67.0 05:48 07:54 pump&choke,close choke,WHP increases,well is live requiring a PUD, bump back to 500 psi WHP,PJSM 12/19/2017 12/19/2017 1.10 PROD1 RPEQPT PULD P PUD BHA#2 67.0 0.0 07:54 09:00 12/19/2017 12/19/2017 1.30 PROD1 WHPST PULD P PD BHA#3 Window Milling Assembly 0.0 75.0 09:00 10:18 (DSM,string reamer,0.6°AKO X- Treme motor),slide in cart,MU to coil, tag up 12/19/2017 12/19/2017 1.70 PROD1 WHPST TRIP P RIH with BHA#3 75.0 8,870.0 10:18 12:00 12/19/2017 12/19/2017 0.20 PROD1 WHPST DLOG P Tie into K1 for-3'correction 8,870.0 8,896.0 12:00 12:12 12/19/2017 12/19/2017 0.10 PROD1 WHPST TRIP P Continue RIH,dry tag TOWS at 9028', 8,896.0 9,027.8 12:12 12:18 PUH,bring pumps up to 1.8 bpm, orient to 330°ROHS,RBIH to begin milling wiindow,zero WOB Page 2/24 Report Printed: 1/9/2018 Ak 4 Y ",... k: • operations Summary (with TimeloPepths) i4: tecii 4' 1 D-12 Phillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKFB) End Depth(ftKE) 12/19/2017 12/19/2017 1.80 PROD1 WHPST WPST P Begin milling window at 9027.8', 9,027.8 9,029.0 12:18 14:06 pumping 1.77 bpm,contact TOWS& tool face torqued past 330°ROHS, PU,orient around to other side of stops,RBIH&stall getting started at 9028.0',PUW=36K,RBIH, Milling window at 9027.7',FS=507 psi,CWT= 15K,WOB=.2K,annular =3663 psi,WHP=275 psi 12/19/2017 12/19/2017 2.50 PROD1 WHPST WPST P PU,reorient TF to other side of stops 9,029.0 9,030.2 14:06 16:36 at 330°ROHS,RBIH&continue milling window,CWT=14K,WOB= 1.3K,a couple PU's battling TF stops &torquing past 330°ROHS,stalled at 9030.2' 12/19/2017 12/19/2017 2.75 PROD1 WHPST WPST P PUW=38K,roll TF around stops 9,030.2 9,033.0 16:36 19:21 again,RBIH&continue milling,CWT =14K,WOB=1K,annular=3676 psi, WHP=294 psi 12/19/2017 12/19/2017 0.95 PROD1 WHPST WPST P Bottom of window called, CWT= 9,033.0 9,038.0 19:21 20:18 12.8K,WOB=2K,Annular=3,662 psi,WHP=294 psi. 12/19/2017 12/19/2017 0.90 PROD1 WHPST DRLG P Begin milling rathole,CWT=13K, 9,038.0 9,048.0 20:18 21:12 WOB=.5K to 1.4K,Annular=3,679 psi,WHP 316 psi.Preload DS PDL w build BHA. Formation in returns 12/19/2017 12/19/2017 1.55 PROD1 WHPST REAM P Back ream window area 30°L/R and 9,048.0 9,048.0 21:12 22:45 180°from milled TF at 1 fpm,PUW 35K, Annular=3,700 psi,WHP= 322 psi, 12/19/2017 12/19/2017 0.60 PROD1 WHPST SRVY P Dry drift window area at milled TF, 9,048.0 9,020.0 22:45 23:21 clean,PUH to 9,020'MD,survey at 8,980'MD(6,506'TVD)initial BHP 3,679 psi, 15 minutes 3,630 psi,Bleed down to 3,563 psi, 15 minutes 3,543 psi=10.47 ppg 12/19/2017 12/20/2017 0.65 PROD1 WHPST TRIP P Open EDC,pump 5x5 to/hi sweep, 9,020.0 7,320.0 23:21 00:00 POOH to 7,320'as of midnight. 12/20/2017 12/20/2017 1.10 PROD1 WHPST TRIP P Continue POOH,tag up,WHP 570 7,320.0 69.0 00:00 01:06 psi.. 12/20/2017 12/20/2017 1.30 PROD1 WHPST SVRG P Install nozzle,wash stack,blow-down 0.0 0.0 01:06 02:24 choke,remove and snake Micro Motion per WellWorc rep.Inspect injector,replace air boot,install MM. 12/20/2017 12/20/2017 1.00 PROD1 WHPST PULD P PJSM, PUD BHA#3,window mill 69.0 0.0 02:24 03:24 came out 2.80"no-go,string reamer came out 2.79"no-go,tools looked good,clean floor 12/20/2017 12/20/2017 1.05 PROD1 DRILL PULD P PJSM,PD BHA#4,L3 Build/Turn 0.0 72.2 03:24 04:27 Assembly(1.9-°AKO motor,HCC bit), slide in cart,MU to coil,tag up 12/20/2017 12/20/2017 1.65 PROD1 DRILL TRIP P RIH with BHA#4,EDC open 72.2 8,866.0 04:27 06:06 12/20/2017 12/20/2017 0.30 PROD1 DRILL DLOG P Tied into K1 for a-3.5'correction 8,866.0 8,880.0 06:06 06:24 12/20/2017 12/20/2017 0.20 PROD1 DRILL TRIP P Continue RIH 8,880.0 9,048.0 06:24 06:36 Page 3/24 Report Printed: 1/9/2018 F, Operations Summary (with Timelog Depths) rpt v 1D-12 ConocoPhillips taitiaps F.e Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth MKS)12/20/2017 12/20/2017 3.70 PROD1 DRILL DRLG P Drilling build/turn section at 9048. ,FS 9,048.0 9,159.0 06:36 10:18 =460 psi,CWT=14K,WOB=1K, Rate in=1.76 bpm,Rate out=1.75 bpm,annular=3664 psi,WHP=267 psi,stall at 9078,PUW=38K,rate out dropped at 9088'to.7 bpm,drop WHP to 125 psi&returns come back o 1.6 bpm out,pump sweeps,take a bit of gas cut mud to TT(while on losses), increased choke pressure. Confer with town,decision made to land build deeper than plan to accommodate swell pack on final liner run 12/20/2017 12/20/2017 0.50 PROD1 DRILL DRLG P Continue drilling build at 9159',in 9,159.0 9,165.0 10:18 10:48 harder formation with lower ROP, CWT=13.7K,WOB=2K,annular= 3634 psi,WHP=219 psi,rate in= 1.79 bpm,rate out= 1.62 bpm 12/20/2017 12/20/2017 0.40 PROD1 DRILL DLOG P PUH to tie into K1 &log RA while 9,165.0 9,044.0 10:48 11:12 awaiting updated targets for build.Tie into K1 for+1.5'correction,log RA tag at 9033',puts BOW at 9033'as well, TOWS=9027' 12/20/2017 12/20/2017 0.30 PROD1 DRILL WAIT T Circlating in cased hole awaiting 9,044.0 8,660.0 11:12 11:30 geological targets&subsequent well plan for build 12/20/2017 12/20/2017 1.50 PROD1 DRILL EQRP T Experience short issue to tools, 8,660.0 8,508.0 11:30 13:00 perform surface tests,unable to pinpoint the issue,lockout reel, perform surface test per Nabors checklist,unable to conclusively determine issue 12/20/2017 12/20/2017 1.50 PROD1 DRILL TRIP T Decision made to POOH both for Lat 8,508.0 72.0 13:00 14:30 BHA and to troubleshoot tool failure. 12/20/2017 12/20/2017 0.50 PROD1 DRILL PULD T PUD,to point of un stabing injector. 72.0 72.0 14:30 15:00 BHA hanging in BOP. 12/20/2017 12/20/2017 0.20 PROD1 DRILL RGRP T Continue troubleshooting,tests 72.0 72.0 15:00 15:12 indicate possibly pressure bulkhead, lockout reel, 12/20/2017 12/20/2017 1.00 PROD1 DRILL PULD T Continue ahead with PUD,at the 72.0 0.0 15:12 16:12 same time shorten inner reel iron,pull &replace pressure bulkhead,issue not resolved, load tools in PDL(by 16:45),pull Baker head to test bare wire to wire,test good from whip end to reel&reel to whip end,decision made to rehead 12/20/2017 12/20/2017 0.80 PROD1 DRILL RGRP T Rehead, Tested wire to wire-good. 0.0 0.0 16:12 17:00 12/20/2017 12/20/2017 2.40 PROD1 DRILL RGRP T Reassemble Pressure bulkhead- 0.0 78.0 17:00 19:24 simultaniously PD Lat drilling assembly to point where BHA is hung in BOP's waiting to stab on. 12/20/2017 12/20/2017 0.30 PROD1 DRILL RGRP T PD Lat drilling assembly to point 0.0 78.0 19:24 19:42 where BHA is hung in BOP's waiting to stab on. 12/20/2017 12/20/2017 0.30 PROD1 DRILL RGRP T Fluid pack coil,PT inner reel iron/ 78.0 78.0 19:42 20:00 presure bulkhead to 4000 psi good. Page 4/24 Report Printed: 1/9/2018 0 S Operations Summary (with TimelogDepths) 1D-12 Cono imps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(Mr) Phase Op Code Activity Code Time P-T-X Operation - (ftKB) End Depth(ftKB) 12/20/2017 12/20/2017 1.30 PROD1 DRILL PULD T Skid cart,inspect pack offs,stab 78.0 78.0 20:00 21:18 injector,complete PD BHA#5 12/20/2017 12/20/2017 1.60 PROD1 DRILL TRIP T Bump up,set depth,RIH, Park at 417', 78.0 8,865.0 21:18 22:54 close EDC,Shallow test agitator to 1.8 bpm,-good,continue to RIH pumping min rate. 12/20/2017 12/20/2017 0.20 PROD1 DRILL DLOG T Tie into the K1 marker for a-4' 8,865.0 8,898.0 22:54 23:06 correction. 12/20/2017 12/20/2017 0.30 PROD1 DRILL TRIP T PU Wt 35 k lbs,contiune to RIH. 8,898.0 9,165.0 23:06 23:24 12/20/2017 12/21/2017 0.60 PROD1 DRILL DRLG P CT RIH Wt, 15 k lbs, 1.80 bpm in, 1.77 9,165.0 9,221.0 23:24 00:00 bpm out,CT 4504 psi,WH 160 psi, Annular 3580 psi-10.46 ppg free spin diff, 1380 psi. OBD,CT Wt 13.8 klbs,WOB 1.83 k lbs,ROP 100 ft/hr **Swap to pit#3, new flow pro, exporting returns outside to tiger tank- 22:33 Swap to pump#2,leaking packing New mud at the bit 9200' 12/21/2017 12/21/2017 1.00 PROD1 DRILL DRLG P CT Wt 12.7 k lbs,CT 5100 psi, 1.84 9,221.0 9,299.0 00:00 01:00 bpm in, 1.81 bpm out,annular 3547 psi WOB 1.8 k lbs, ROP 102 ft/hr ***12:58 brought new mud back inside PU 35 k lbs Average over interval 78 ft/hr 12/21/2017 12/21/2017 3.70 PROD1 DRILL DRLG P RIH Wt 15 k lbs,CT 4783 psi, 1.83 9,221.0 9,720.0 01:00 04:42 bpm in, 1.78 bpm out, Free spin diff 1409 psi.annular 3548, 10.3 ppg WOB 2.4-2.8 k lbs,ROP climbed to 140 then 250 ft hr PU Wt 37 k lbs-9428' Pumped 5x5 sweep, PU as sweep transits the back side PU 35 k lbs RBIH drill ahead PU 35 k lbs Pumped 5 x 5 sweep Average over interval 135 ft/hr 12/21/2017 12/21/2017 0.30 PROD1 DRILL WPRT P PU 35 k lbs-Wiper trip,#1 PUH 9,720.0 9,170.0 04:42 05:00 chasing sweeps 12/21/2017 12/21/2017 0.30 PROD1 DRILL WPRT P RBIH, RIH Wt 16 k lbs 9,170.0 9,720.0 05:00 05:18 12/21/2017 12/21/2017 3.20 PROD1 DRILL DRLG P CT 4880 psi, 1.80 bpm in, 1.7 bpm 9,720.0 9,997.0 05:18 08:30 out,free spin diff 1550 psi,annular 3571 psi, IA 47 psi,OA 394 psi OBD,CT Wt 14 k lbs,WOB 1.2 k lbs, ROP 200 ft/hr, PUW=38K from 9941',pulled heavy up to 9883'(50K), then fell off to-38K,sections of lower ROP with trace Siderite in samples over shakers,average ROP over interval=87 fph 12/21/2017 12/21/2017 1.50 PROD1 DRILL DRLG P Continue drilling ahead,CWT= 10.5K, 9,997.0 10,120.0 08:30 10:00 WOB=1.6K,returns=98%,annular= 3635 psi,WHP=214 psi, IA= 186 psi, pumps sweeps,average ROP over interval=82 fph Page 5/24 Report Printed: 1/9/2018 Operations Summary (with TimelogDepths) ,., 1D-12 ConocoPhiillips ur:ke , Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKS)'. 12/21/2017 12/21/2017 1.30 PROD1 DRILL WPRT P Wiper up to window, PUW=39 K, 10,120.0 6,522.0 10:00 11:18 pulled heavy though 9910'(60K CWT),open EDC in cased hole,PUH to 6525"into 4-1/2"tubing,change out leaking packing in MP#1 during trip, experience leaking packing on MP#2, lower rate.8 bpm,swap over to MP #1,tie into K1 for+6'correction 12/21/2017 12/21/2017 1.80 PROD1 DRILL WPRT P Wiper in-hole,close EDC,2.4K WOB 6,522.0 10,120.0 11:18 13:06 spike at 9410',geology observed RA tag depth was off by 5',PUH to verify good tie-in,PUW=37K,log RA tag for a+1.5'correction,RIW=12.5K 12/21/2017 12/21/2017 4.30 PROD1 DRILL DRLG P BOBD,rate in=1.72 bpm(to reduce 10,120.0 10,404.0 13:06 17:24 vibration),rate out=1.62 bpm,CWT= 9.5K,WOB=1.9K,annular=3668 psi,WHP=253 psi,variable ROP b/w 30-180 fph Average over interval-66 12/21/2017 12/21/2017 1.50 PROD1 DRILL DRLG P PU 40 k lbs,to catch missed survey 10,404.0 10,530.0 17:24 18:54 1.80 bpm in 1.72 bpm out free spin diff 1582 psi RIH wt 10.9 k OBD,WOB 1.8 k lbs,ROP 50-160 fUhr Average over interval-84 ft/hr 12/21/2017 12/21/2017 0.60 PROD1 DRILL WPRT P PU45 k lbs, Wiper trip chasing 10,530.0 9,020.0 18:54 19:30 sweeps out of hole, CT wt 33-40 k lbs send another 5x5 sweep 12/21/2017 12/21/2017 0.20 PROD1 DRILL DLOG P Park at 9020'md,6504.64 TVD 10,530.0 9,020.0 19:30 19:42 pressure sensor TVD,S/D pumps, trapping pressure. innital 3579 psi -10.58 EMW. @ 5 min 3491 psi-10.35 EMW @ 10 min 3457 psi 10.23 EMW 12/21/2017 12/21/2017 0.30 PROD1 DRILL WPRT P Online w pumps, PU Wt 36,down on 9,020.0 7,909.0 19:42 20:00 pumps, open EDC,on line pumping 1.88 bpm, send 5 x5 sweep. PUH jetting to 4.5 XO 12/21/2017 12/21/2017 0.40 PROD1 DRILL WPRT P RBIH closed EDC. 7,909.0 9,010.0 20:00 20:24 12/21/2017 12/21/2017 0.20 PROD1 DRILL DLOG P Tie into the RA tag for a+3.5' 9,010.0 9,068.5 20:24 20:36 12/21/2017 12/21/2017 0.60 PROD1 DRILL WPRT P Continue to RIH. 9,010.0 10,530.0 20:36 21:12 TF HS,WOB spike to 4.5 k lbs,@ 9848,PU,saw neg 2.6 k lbs WOB as we pulled past,RBIH TF 70 LOHS Same,WOB spike to 6.6k lbs, bounced through continue to bottom 12/21/2017 12/21/2017 0.90 PROD1 DRILL DRLG P RIH Wt 13 k lbs @ 23 ft/min. 1.80 10,530.0 10,556.0 21:12 22:06 bpm in 1.73 bpm out,CT 4900 psi, free spin diff 1390 psi. OBD CT Wt 10 k lbs,WOB 1.3 k lbs, ROP 100 Uhr Rann into siderite @ 10551' ROP slow... PU 42 klbs Average ROP 29 ft/hr Page 6/24 Report Printed: 1/9/2018 t operations Summary (with Timelog!epths) .- 1D-12 Conocc.Whillips 1. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur fir) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKB) 12/21/2017 12/22/2017 1.90 PROD1 DRILL DRLG P Broke out of siderite,drilling ahead 10,556.0 10,650.0 22:06 00:00 PU @ 10562 55k lbs PU @ 10582 55 k lbs PU @ 10625 58 k lbs 12/22/2017 12/22/2017 0.10 PROD1 DRILL WPRT P PU,60 k lbs-PUH to 10,500, 10,650.0 10,644.0 00:00 00:06 RBIH 12/22/2017 12/22/2017 0.60 PROD1 DRILL RGRP T MWD reports lost power to tools. 10,644.0 10,337.0 00:06 00:42 Meg'd lines from MWD shack to reel- good. Pump 5x5 sweep 12/22/2017 12/22/2017 0.60 PROD1 DRILL RGRP T Chase sweep out of hole,pull into 10,337.0 9,003.6 00:42 01:18 casing 12/22/2017 12/22/2017 0.60 PROD1 DRILL RGRP T Lock out reel,test leads from J box to 9,003.0 9,003.0 01:18 01:54 inlet of the bulkhead-good,unlock the reel. 12/22/2017 12/22/2017 1.60 PROD1 DRILL TRIP T POOH @ 120 ft/min, start swapping 9,003.0 78.0 01:54 03:30 the coil to water at 2000'. 12/22/2017 12/22/2017 1.50 PROD1 DRILL PULD T Bump up,PUD BHA#5 to stub,test 78.0 0.0 03:30 05:00 tools,good. Continue to PUD. Agitator has 82 hr,Cl bit came out a 1 -1 12/22/2017 12/22/2017 1.00 PROD1 DRILL CTOP T Stab on,finish loading coil w fresh 0.0 0.0 05:00 06:00 water,reverse circulate to push slack back. Unstab. 12/22/2017 12/22/2017 2.00 PROD1 DRILL CTOP T Pumped slack back,pulled apart 0.0 0.0 06:00 08:00 pressure bulkhead,identified a faulty crimp on ground wire,recrimped, buttoned up pressure bulkhead 12/22/2017 12/22/2017 0.80 PROD1 DRILL CIRC T MU nozzle,displace coil to FloPro 0.0 0.0 08:00 08:48 12/22/2017 12/22/2017 1.20 PROD1 DRILL PULD T PD BHA#6 L3 Lateral Assembly#2 0.0 78.0 08:48 10:00 (0.8-°AKO motor,agitator,RB HYC B8),change out checks,slide in cart, check pack-offs,MU to coil,test tools 12/22/2017 12/22/2017 1.60 PROD1 DRILL TRIP T RIH with BHA#6 78.0 8,865.0 10:00 11:36 12/22/2017 12/22/2017 0.20 PROD1 DRILL DLOG T Tie into K1 for-4.5'correction,PUW= 8,865.0 8,908.0 11:36 11:48 33K 12/22/2017 12/22/2017 0.70 PROD1 DRILL TRIP T Continue RIH,2.6K WOB spike at 8,908.0 10,652.0 11:48 12:30 9845',get by without issue,slow by 10,610'to shoot survey 12/22/2017 12/22/2017 2.70 PROD1 DRILL DRLG P OBD,rate in=1.8 bpm,rate out=1.6 10,652.0 10,855.0 12:30 15:12 bpm,FS= 1480 psi,CWT= 12.8K, WOB= 1.2K,annular=3692 psi, WHP= 164 psi, IA=0 psi,40K PUW from 10,705',55K PUW from 10,771', 52K PUW from 10,788',60K PUW from 10,805',pumped 5x5 sweep, average ROP over interval=75 fph 12/22/2017 12/22/2017 0.30 PROD1 DRILL WPRT P BHA wiper,PUW=62K,pump 5x5 10,855.0 10,855.0 15:12 15:30 sweep 12/22/2017 12/22/2017 0.70 PROD1 DRILL DRLG P BOBD,rate in= 1.78 bpm,rate out= 10,855.0 10,905.0 15:30 16:12 1.67 bpm,CWT=9K,WOB=1.8K, annular=3682 psi,WHP=150 psi,IA =242 psi 12/22/2017 12/22/2017 0.30 PROD1 DRILL WPRT P Wiper up-hole,PUW=61K 10,905.0 10,110.0 16:12 16:30 12/22/2017 12/22/2017 0.30 PROD1 DRILL WPRT P Wiper in-hole, RIW= 12.5K 10,110.0 10,905.0 16:30 16:48 Page 7/24 Report Printed: 1/9/2018 i Operations Summary (with Timelogllepths) 014 �.0 1D-12 PhiI!�ps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(itKB)' 12/22/2017 12/22/2017 1.70 PROD1 DRILL DRLG P BOBD,CWT=1.5 K,WOB=2.3K, 10,905.0 11,041.0 16:48 18:30 annular=3666 psi,WHP=106 psi Average ROP on bottom-80 ft/hr 12/22/2017 12/22/2017 2.70 PROD1 DRILL DRLG P 1.84 bpm in 1.78 bpm out,CT 5094 11,041.0 11,141.0 18:30 21:12 psi,free spin diff 1550 psi OBD,CT 5177 psi,CT Wt 9 klbs, WOB 1.2 k lbs, ROP-100 ft/hr PU 11067'36 k lbs PU 11092'57 k lbs PU 11119'45 k lbs Geo's called TD early,Pump 10 x 10 12/22/2017 12/22/2017 1.30 PROD1 DRILL WPRT P PU 50 k lbs,RBIH as sweeps exit, 11,141.0 9,007.0 21:12 22:30 PU,40 k lbs, POOH on swab wiper 1.81 bpm in 1.55 bpm out Pull up into the tubing. 12/22/2017 12/23/2017 1.50 PROD1 DRILL WPRT P S/D pumps,open EDC,pump to 2.23 9,007.0 2,663.0 22:30 00:00 bpm,CT 4325 psi Contiue on out of hole on swab wiper 80 ft/min 12/23/2017 12/23/2017 0.70 PROD1 DRILL WPRT P Contiue on out of hole on swab wiper 2,663.0 78.0 00:00 00:42 80 ft/min 12/23/2017 12/23/2017 1.60 PROD1 DRILL TRIP P Bump up,set counters,RBIH 78.0 8,860.0 00:42 02:18 Lost WITS data @ 0:50-687'back on @ 1:10-2605' 12/23/2017 12/23/2017 0.20 PROD1 DRILL DLOG P Tie into the K1 for a-5 correction 8,860.0 8,895.0 02:18 02:30 12/23/2017 12/23/2017 0.20 PROD1 DRILL DLOG P RIH and park at 9000 MD,6491 TVD, 8,895.0 9,000.0 02:30 02:42 trapped pressure Initial 3518 psi,-10.42 EMW 5 min 3450 psi-10.22 EMW 12/23/2017 12/23/2017 1.10 PROD1 DRILL TRIP P Continue to RIH 9,000.0 11,148.0 02:42 03:48 S/D @ 9831-9835,PU 35 k lbs _ RBIH,at HS and S/D @ 9837',PU 35 k lbs RBIH,at 280 ROHS(as drilled)and min rate,S/D 9837',PU 35 k lbs RBIH pumps off at 35 ft/min,slid right through Continue on to bottom 12/23/2017 12/23/2017 0.40 PROD1 DRILL DISP P PUH-40 k lbs 11,148.0 11,148.0 03:48 04:12 Displace coil to 10.8 ppg Kill weight RBIH 12/23/2017 12/23/2017 3.50 PROD1 DRILL DISP P Lay in liner running pill 48 bbls,while 11,148.0 78.0 04:12 07:42 pulling up hole. Paint Yellow TD flag @ 9838.74' Paint white window flag @ 7678 PJSM,flow check well,good 12/23/2017 12/23/2017 0.90 PROD1 DRILL PULD P LD BHA#6 over a dead well,check 78.0 0.0 07:42 08:36 for flats spots(only 10'up,will check higher up after liner run), -4.5 bph losses,bit came out a 2-1,agitator came out w/104 hrs 12/23/2017 12/23/2017 1.60 COMPZ1 CASING PUTB P PJSM,PU L3 liner(non-ported BN,30' 0.0 1,205.0 08:36 10:12 solid pup,30 jnts slotted liner,liner top billet),filling hole as required 12/23/2017 12/23/2017 0.90 COMPZ1 CASING PULD P PJSM, PU BHA#7 L3 Liner Running 1,205.0 1,290.0 10:12 11:06 Tools,check pack-offs,slide in cart, MU to coil,tag up,set counters Page 8/24 Report Printed: 1/9/2018 Operations Summary (with Timelogfepths) 0 0 1D-12 Conoccritiiiiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 12/23/2017 12/23/2017 2.40 COMPZ1 CASING RUNL P RIH with L3 liner,-tie into white flag for 1,290.0 11,148.0 11:06 13:30 -5'correction,PUW=34K at window, clean through window,slid right by 9848',arrive at TD, PUW=38K, RBIH,bring up pump,release off liner, PUW=34K,TOL-9902' 12/23/2017 12/23/2017 1.70 COMPZ1 CASING TRIP P POOH,flow check,good,tag up 11,148.0 50.0 13:30 15:12 12/23/2017 12/23/2017 0.50 COMPZ1 CASING PULD P PJSM,LD BHA#7,small flat spot at 50.0 0.0 15:12 15:42 -10'up from CTC,small gouge in pipe at same depth. 12/23/2017 12/23/2017 0.30 PROD2 STK BOPE P PU&lower test jnt,function test 0.0 0.0 15:42 16:00 BOPE's 12/23/2017 12/23/2017 1.00 PROD2 STK PULD P PJSM,PU BHA#8 L3-01 Drilling 0.0 75.0 16:00 17:00 Assembly(0.5°AKO motor,agitator, RB Hughes bit w/P104 cutters),slide in cart,tag up,set counters 12/23/2017 12/23/2017 0.40 PROD2 STK TRIP T Begin RIH,test agitator,experience 75.0 500.0 17:00 17:24 lost COMMS to tools 12/23/2017 12/23/2017 0.40 PROD2 STK CTOP T POOH,PJSM,un stab injector over a 500.0 75.0 17:24 17:48 dead well,test tools-good,test eline bad,find split in UQC boot,wire shorted. repair, 12/23/2017 12/23/2017 0.30 PROD2 STK CTOP T Make up,Stab on,bump up.,RIH to 75.0 500.0 17:48 18:06 500' 12/23/2017 12/23/2017 1.60 PROD2 STK TRIP P Continue to RIH,park @ 2620',open 500.0 8,865.0 18:06 19:42 EDC,continue to RIH,pumping min rate,0.25 bpm in,0.48 bpm out, 100 ft/min,-0.15 bpm losses 12/23/2017 12/23/2017 0.20 PROD2 STK DLOG P Tie into the K1 for a-2'correction, 8,865.0 8,894.4 19:42 19:54 12/23/2017 12/23/2017 1.10 PROD2 STK DISP P Continue to RIH,@ 8998'start turning 8,894.0 8,965.0 19:54 21:00 the hole over to drilling fluid. Took 4 min to get returns,worked rate up slowly to 2 bpm,losing-0.25 bpm while creeping up hole. Density fell off,S/D,close EDC, 12/23/2017 12/23/2017 0.50 PROD2 STK TRIP P RIH,no issues passing previous 8,965.0 9,863.0 21:00 21:30 trouble zone @ 9931-9948',smooth, no WOB bobble,TF 330°ROHS,35 ft/min min rate. dry tag TOB 9901' PU 35 k lbs 12/23/2017 12/24/2017 2.50 PROD2 STK KOST P 1.79 bpm in 1.76 bpm out,CT 4316 9,863.0 9,905.0 21:30 00:00 psi,free spin 1170 psi,RIH Wt 16 k lbs,WH 208 psi,Annular 3566 psi, 10.4 ppg EMW,IA 0 psi,OA 204 psi, OBD,tag @ 9900.6' start milling off billet 12/24/2017 12/24/2017 0.50 PROD2 DRILL DRLG P Drill ahead on L3-01 latteral,stall,PU 9,905.0 9,941.0 00:00 00:30 37k lbs,RBIH 1.77 bpm in, 1.77 bpm out CT 4320 psi,WH 126 psi,Annular 3463 psi OBD,CT Wt 14klbs,WOB 2.45 K lbs, ROP 53 ft/hr Stall 12/24/2017 12/24/2017 1.20 PROD2 DRILL DRLG P 'PU 38 k lbs, RBIH Dry drift-clean 9,941.0 9,950.0 00:30 01:42 1.80 bpm in, 1.80 bpm out,CT 4180 psi,WH 280 psi,Annular 3605 psi, 10 stalls from 9945-9950',low to no vibrations,low motor work until stall. Page 9/24 Report Printed: 1/9/2018 Operations Summary (with TimelogDepths) z ,;,w 00: .0000 1D-12 ConocoPhillips .° Rig: NABORS CDR3-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(ftKS); 12/24/2017 12/24/2017 1.60 PROD2 DRILL DRLG T Drill 4 feet,stall-PU 38 k lbs 9,950.0 9,974.0 01:42 03:18 RBIH, 1.77 bpm in, 1.72 bpm out,free spin 1127 psi,near bit inc continues to fall-89.4°@ 9955' Drill ahead 3 feet and stall w little motor work till point of stall 9958', PU 38 k lbs Drill ahead 3 feet and stall w little motor work-inclination now 89.1°, stall 9961'PU 38 k lbs 9964'stall-89.0°-call consult town, path forward to pull for anchored billet, suspect we're in L3 lat next to liner Finish building sweeps post liner running, pump 5x5,consult w town again 12/24/2017 12/24/2017 0.60 PROD2 DRILL CIRC T PU 37 k lbs, PUH slowly waiting for 9,974.0 9,039.0 03:18 03:54 sweeps to exit Saw slight neg WOB 9943'and a little motorwork. Another neg WOB spike at 9899' Continue to PUH 12/24/2017 12/24/2017 0.20 PROD2 DRILL DLOG T Tie into the RA flag for+2'correction. 9,039.0 9,071.0 03:54 04:06 12/24/2017 12/24/2017 0.30 PROD2 DRILL TRIP T 9435'3 k lbs WOB spike,reduced rate 9,071.0 9,953.0 04:06 04:24 slid through. 12/24/2017 12/24/2017 3.60 PROD2 DRILL WAIT T Pull uphole slowly waiting for KWF, 9,953.0 9,195.0 04:24 08:00 water KWF down from 10.9 ppg to 10.5 ppg 12/24/2017 12/24/2017 2.30 PROD2 DRILL DISP T POOH,displace well to KWF from 9,195.0 9,400.0 08:00 10:18 9400'to surface(deepest TVD of lateral),tag up,flow check,good, PJSM **DD proposed KO modification after reviewing well-plan,confer with town, agreed upon setting anchor oriented 350°ROHS,KO 20°ROHS 12/24/2017 12/24/2017 0.80 PROD2 DRILL PULD T LD BHA#8,swap out elevators, 78.0 0.0 10:18 11:06 losses—3.5 bph,bit came out a 1-1 (1 nose cutter chipped, 1 side cutter chipped) 12/24/2017 12/24/2017 1.00 PROD2 DRILL PULD T PJSM,PU BHA#9 Liner/Anchor 0.0 151.0 11:06 12:06 Assembly(ported BN,2 jnts slotted, OH anchor&billet),slide in cart, MU to coil,tag up,set counters,open EDC 12/24/2017 12/24/2017 1.60 PROD2 DRILL RUNL T RIH with BHA#9 151.0 8,955.0 12:06 13:42 12/24/2017 12/24/2017 0.20 PROD2 DRILL DLOG T Log K1 for a-4.5'correction,PUW= 8,955.0 8,975.0 13:42 13:54 34K,close EDC 12/24/2017 12/24/2017 0.60 PROD2 DRILL TRIP T Contine RIH with BHA#9,see WOB 8,975.0 9,941.0 13:54 14:30 passing 9848',confer with town, decision made to set TOB 5'higher at 9845',arrive at setting depth of 9935.57',bring up pump,shear off anchor,went to set down weight on billet/anchor,pushed down hole,bad anchor set,confer with town,decision made to push assembly to bottom at 9976',putting TOB—9885.4' Page 10/24 Report Printed: 1/9/2018 • Operations Summary (with TimelogTepths) 0, `:;sit 1D-12 Conoc tiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Cur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 12/24/2017 12/24/2017 2.10 PROD2 DRILL TRIP T POOH to grab another anchored billet 9,941.0 78.0 14:30 16:36 assembly,tag up,PJSM,flow check, good ""Confer with town.Plan to set next assembly with TOB at 9803'(right on top of last assmebly) 12/24/2017 12/24/2017 0.40 PROD2 DRILL PULD T LD BHA#9 78.0 0.0 16:36 17:00 12/24/2017 12/24/2017 0.50 PROD2 DRILL PULD T PU BHA#10(ported bull-nose,30' 0.0 144.0 17:00 17:30 slotted jnt,40'slotted jnt,OH anchor& billet) 12/24/2017 12/24/2017 2.00 PROD2 DRILL RUNL T RIH with BHA#10,losses-1/8 bpm 144.0 8,950.0 17:30 19:30 on the trip in while pumping min rate 12/24/2017 12/24/2017 0.20 PROD2 DRILL RUNL T Log the K1 for a-0.5'correction 8,950.0 8,967.0 19:30 19:42 12/24/2017 12/24/2017 0.50 PROD2 DRILL RUNL T Park,close the EDC,PU Wt 35 k lbs, 8,967.0 9,886.0 19:42 20:12 continue to RIH,S/D 4 k lbs 12/24/2017 12/24/2017 0.10 PROD2 DRILL RUNL T PU to neutral Wt 32 k lbs,9882, Slips 9,886.0 9,886.0 20:12 20:18 350°ROHS,online w the pumps,circ press broke back at 3100 psi,down on pumps,Set weih to 4.7 k lbs,@ 9886' -Anchored billet set W TOB @ 9803' 12/24/2017 12/24/2017 1.80 PROD2 DRILL RUNL T PU 35 k lbs,reset depth,dropping off 9,886.0 136.0 20:18 22:06 82.43'ft of assemby.lost 48 bbls on the trip 12/24/2017 12/24/2017 1.00 PROD2 DRILL PULD T PJSM,at surface,flood up to the 136.0 0.0 22:06 23:06 stack/half drum,no flow,unstab injector,LD tools,hole fill 3 bbls 12/24/2017 12/25/2017 0.90 PROD2 DRILL PULD T PJSM,PU BHA#11,fill hole-3 bbls. 0.0 72.0 23:06 00:00 12/25/2017 12/25/2017 0.20 PROD2 DRILL PULD T Stab on injector,inspect packoffs- 78.0 78.0 00:00 00:12 replace,bump up,set counters 12/25/2017 12/25/2017 1.80 PROD2 DRILL TRIP T RIH,shallow test agitator @ 500'to 78.0 8,870.0 00:12 02:00 1.5 bpm,strong vibrations,Park,open EDC,continue to RIH 12/25/2017 12/25/2017 0.20 PROD2 DRILL DLOG T Tie into the K1 for a+4.5'correction 8,870.0 8,894.4 02:00 02:12 12/25/2017 12/25/2017 1.10 PROD2 DRILL DISP T Continue to RIH while rolling coil over 8,894.0 8,999.0 02:12 03:18 to drilling fluid,Flow pro @ the bit 8992',02:15 creep up hole displacing KW fluid 2.0 bpm in, 1.91 bpm out, 10.5 EMW at the tool,Close EDC 12/25/2017 12/25/2017 0.40 PROD2 DRILL TRIP T Continue to RIH, 8,999.0 9,801.7 03:18 03:42 ""'dry tag TOB @ 9802' PU 36k lbs,RBIH Page 11/24 Report Printed: 1/9/2018 operations Summary (with Timelog�epths) 1D-12 snocra*hitrp+s" Rig: NABORS CDR3-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(ftKE) 12/25/2017 12/25/2017 1.50 PROD2 STK KOST T Contiune to PUH,Set rate,RBIH TF 9,801.7 9,809.0 03:42 05:12 set to 20°ROHS 1.78 bpm in, 1.70 bpm out,CT 4370 psi,WH 240,Annular 3581 psi, 1046 ppg EMW, IA 0 psi,OA 135 psi,RIH Wt14k OBD WOB 0.57 klbs,CT Wt 17.8 k lbs, Free Spin 1274 psi grab tenths WOB—.46 k lbs,engage auto driller @ 9802.23' cutting easy 1374 psi diff. @ 9802.67-start walking auto drill up to 2 ft/hr Having a hard time keeping WOB by 9805,increase ROP to 20 ft/hr-near bit inc climbing slowly ROP to 180 fUhr WOB 0.6 k lbs-stall 12/25/2017 12/25/2017 1.80 PROD2 STK KOST P PU 37 k lbs,mostly clean dry drift, 9,809.0 9,945.0 05:12 07:00 new parameters with mud weight stabilized 1.78 bpm in, 1. out,CT 4089 psi,WH 271 psi,Annular 3575 psi,Free spin 1014 psi CT Wt 13.8 k lbs,WOB 1 k lbs,ROP 140+ft/hr,PUH from 9871'to grab survey Average ROP over interval=76 fph **Off billet&off trouble time 12/25/2017 12/25/2017 1.70 PROD2 DRILL DRLG P Continue drilling from 9945',CWT= 9,945.0 10,250.0 07:00 08:42 9K,WOB=2K,rate in= 1.84 bpm, rate out=1.76 bpm,annular=3511 psi,WHP=159 psi,circ pressure= 4554 psi,PUH from 10,065'to grab survey,pump 5x5 sweep,PUW at 10,095=38K,RIW=12.5K, getting knocked North&up in TVD,average ROP over interval=179 fph **Approval given by engineer to extend MD by—50'to achieve XY geological goals if required 12/25/2017 12/25/2017 0.40 PROD2 DRILL WPRT P Wiper up-hole,PUW=38K 10,250.0 9,248.0 08:42 09:06 12/25/2017 12/25/2017 0.40 PROD2 DRILL WPRT P Wiper in-hole,RIW=12K 9,248.0 10,250.0 09:06 09:30 12/25/2017 12/25/2017 2.80 PROD2 DRILL DRLG P BOBD,FS=1140 psi,CWT=11K, 10,250.0 10,675.0 09:30 12:18 WOB=1.3K,annular=3545 psi,WHP = 154 psi,PUW=40K from 10,579', average ROP over interval=152 fph 12/25/2017 12/25/2017 0.50 PROD2 DRILL WPRT P Wiper up-hole,PUW=39K,clean 10,675.0 9,200.0 12:18 12:48 12/25/2017 12/25/2017 0.50 PROD2 DRILL WPRT P Wiper in-hole,RIW=12K 9,200.0 10,675.0 12:48 13:18 12/25/2017 12/25/2017 3.60 PROD2 DRILL DRLG P BOBD,CWT=11K,WOB=1.5K, 10,675.0 11,100.0 13:18 16:54 annular=3588 psi,WHP=116 psi, 98%returns,pump 10x10 sweep, reached planned TD of 11,100', average ROP over interval=118 fph Page 12/24 Report Printed: 1/9/2018 •Operations Summary (with Timelog!epths) ippo ►w ConocoPh aih 0%kmk:a Rig: NABORS CDR3-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 MKS) 12/25/2017 12/25/2017 3.10 PROD2 DRILL WPRT P Perform swab wiper trip,PUW=40K, 11,100.0 78.0 16:54 20:00 open EDC in cased hole,bring up rate up to 225 bpm,tag up,clean trip 12/25/2017 12/25/2017 1.80 PROD2 DRILL WPRT P RBIH hole 78.0 8,865.0 20:00 21:48 12/25/2017 12/25/2017 0.40 PROD2 DRILL DLOG P Tie into K1 for a-4'correction, 8,865.0 9,000.0 21:48 22:12 pumping 1.87 bpm to continue cleaning 4.5"tubing during tie-in,close EDC Obtain SBHP,bleed down,sensor TVD=6491',annular=3455 psi, EMW=10.24 ppg 12/25/2017 12/25/2017 0.80 PROD2 DRILL WPRT P Continue RIH,clean through window, 9,000.0 11,107.0 22:12 23:00 clean past billet,confirm TD at 11107. 12/25/2017 12/26/2017 1.00 PROD2 DRILL DISP P Lay in 50 bbl liner running pill(10.5 11,107.0 9,699.0 23:00 00:00 ppg)&10.6 ppg KWF to surface 12/26/2017 12/26/2017 0.10 PROD2 DRILL DISP P Lay in 50 bbl liner running pill(10.5 9,699.0 9,460.0 00:00 00:06 ppg)&10.6 ppg KWF to surface 12/26/2017 12/26/2017 0.20 PROD2 DRILL DISP P Found multiple gouges in coil,typical 9,460.0 9,460.0 00:06 00:18 gripper block damage that we've been seeing since start up. Three main areas 4-5 inches long. Smear pattern indicates pulling out of hole. Damaged area is at the horses head @ 9460'bit depth,with 78.25'BHA and current coil length is 15768'. Estimate damage is 6463'from the core. Damaged area is not on or near a weld and has-11.6%pipe life used. 12/26/2017 12/26/2017 2.30 PROD2 DRILL DISP P Paint Yellow TD flag @ 9478.33, 9,460.0 72.0 00:18 02:36 continue to POOH displacing well,lay in liner running pill to 7725',continue out of hole displacing to 10.57 ppg KWF,paint white window flag @ 7378.49,continue out of hole 12/26/2017 12/26/2017 0.90 PROD2 DRILL PULD P PJSM,Flow check,pop off,inspect 72.0 0.0 02:36 03:30 pipe to coil connector. LD BHA#11 over a dead well,<1 bph losses,bit came out a 1-1,agitator came out w/ 42.6 hrs 12/26/2017 12/26/2017 0.40 COMPZ2 CASING PUTB P Prep floor for running liner 0.0 1,550.4 03:30 03:54 12/26/2017 12/26/2017 2.40 COMPZ2 CASING PUTB P PJSM,PU L3-01 liner(non-ported BN, 0.0 1,550.4 03:54 06:18 39'jnts slotted liner,liner top billet), filling hole as required,crew change out at Joint 32,(safet joint drill pre C/O)PJSM 12/26/2017 12/26/2017 1.00 COMPZ2 CASING PULD P PJSM,PU BHA#12 L3-01 Liner 1,550.4 1,594.6 06:18 07:18 Running Tools,check pack-offs,slide in cart,MU to coil,tag up,set counters,EDC is closed 12/26/2017 12/26/2017 2.30 COMPZ2 CASING RUNL P RIH with L3-01 liner,-tie into white flag 1,594.6 11,105.0 07:18 09:36 for-7.6'correction,PUW=40K at window,arrive at TD,PUW=46 k, WOB-3.9 k lbs RBIH,bring up pump 1.6 bpm,release off liner, PUW=40k lbs, WOB 0.77 klbs,TOL 9556.6, reset counters, Page 13/24 Report Printed: 1/9/2018 Operations Summary (with Timelog�epth s) 1D-12 titfr ConocciPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-TX Operation (ftKB) End Depth(ftKB) 12/26/2017 12/26/2017 1.50 COMPZ2 CASING TRIP P POOH,PJSM,flood up to the stack, 11,105.0 60.0 09:36 11:06 flow check-good, 12/26/2017 12/26/2017 0.60 COMPZ2 CASING PULD P LD BHA#12, 60.0 0.0 11:06 11:42 12/26/2017 12/26/2017 0.70 PROD3 STK PULD P PU and run BHA#13,inspect pack 0.0 78.3 11:42 12:24 offs.bump up,set counters 12/26/2017 12/26/2017 1.50 PROD3 STK TRIP P RIH,shallow test agitator @ 500'to 78.3 8,870.0 12:24 13:54 1.4 bpm,strong vibrations,park,open EDC,continue to RIH 12/26/2017 12/26/2017 0.20 PROD3 STK DLOG P Tie into the K1 fora+0.5'correction 8,870.0 8,896.0 13:54 14:06 12/26/2017 12/26/2017 1.10 PROD3 STK DISP P Continue to RIH while rolling coil over 8,896.0 8,975.0 14:06 15:12 to drilling fluid,creep up hole displacing KW fluid working rate up to 2.24 bpm in,2.24 bpm out,Close EDC 12/26/2017 12/26/2017 0.30 PROD3 STK TRIP P Continue to RIH, ***dry tag TOB @ 8,975.0 9,553.8 15:12 15:30 9555' PU 37k lbs,RBIH 12/26/2017 12/26/2017 1.50 PROD3 STK KOST P Contiune to PUH,Set rate,RBIH TF 9,553.8 9,565.0 15:30 17:00 set to 340°ROHS 1.81 bpm in, 1.77 out,CT 4168 psi, free spin 950 psi,annular 3508 psi, 10.2 ppg,WH 94 psi, IA 0 psi,OA 238 psi RIH Wt16kIbs.OBD,CtWt18.19k lbs, Pinch choke,Annular 3529, 10.26 ppg EMW,WH 118 psi. feeding tenths,then auto,Stall @ 9554.36'PU 38 k lbs Chasing it to maintain WOB by 9556', 20+ft/hr 12/26/2017 12/26/2017 0.20 PROD3 DRILL WPRT P PUH,PUW 38 k,RBIH clean past 9,565.0 9,565.0 17:00 17:12 billet area(kickoff point) 12/26/2017 12/26/2017 1.50 PROD3 DRILL DRLG P Drill ahead,Ct Wt 11.8 k lbs,WOB 2 k 9,565.0 9,660.0 17:12 18:42 lbs,ROP 80-105 ft/hr 12/26/2017 12/26/2017 0.20 PROD3 DRILL WPRT P BHA wiper up hole,PUW 37 k 9,660.0 9,660.0 18:42 18:54 12/26/2017 12/26/2017 1.70 PROD3 DRILL DRLG P BOBD, 1.78 bpm at 4,233 psi,Diff= 9,660.0 9,775.0 18:54 20:36 1,077 psi, BHP 3585,WHP 131, IA 264,OA 564,CTSW=14 k, DHWOB=1.3 k 12/26/2017 12/26/2017 0.20 PROD3 DRILL WPRT P BHA wiper up hole,PUW 38 k 9,775.0 9,775.0 20:36 20:48 12/26/2017 12/27/2017 3.20 PROD3 DRILL DRLG P BOBD, 1.81 bpm at 4,385 psi,Diff= 9,775.0 9,915.0 20:48 00:00 985 psi,BHP 3,589,WHP 131, CTSW=10.9 k,DHWOB=2.9 k,ROP 50-70 fph 12/27/2017 12/27/2017 0.65 PROD3 DRILL DRLG P OBD hard spot, 1.8 bpm at 4,383 psi, 9,915.0 9,915.0 00:00 00:39 Diff=1,077 psi,BHP 3,609,WHP 125, IA 268,OA 569,CTSW=7.5 k, DHWOB=3.0 k,ROP 10 fph 12/27/2017 12/27/2017 0.20 PROD3 DRILL DRLG P Broke thru hard spot,ROP 300 fph,no 9,915.0 9,942.0 00:39 00:51 diff,no DHWOB 12/27/2017 12/27/2017 0.20 PROD3 DRILL DRLG P PUH,PUW 40 k,RBIH,BOBD, 1.78 9,942.0 9,955.0 00:51 01:03 bpm at 4,400 psi,BHP 3,598, WHP=141,CTSW=11 k,DHWOB=2.2 k,ROP 100-250 fph 12/27/2017 12/27/2017 0.50 PROD3 DRILL WPRT P Wiper up hole PUW 41 k 9,955.0 9,170.0 01:03 01:33 Page 14/24 Report Printed: 1/9/2018 V4501 Operations Summary (with TimeloRepths) r 1D-12 Conoco#'"hifttps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS) 12/27/2017 12/27/2017 0.50 PROD3 DRILL WPRT P Wiper back in hole,RIW 14 k 9,170.0 9,955.0 01:33 02:03 12/27/2017 12/27/2017 4.20 PROD3 DRILL DRLG P BOBD, 1.79 bpm at 4,368 psi, 9,955.0 10,080.0 02:03 06:15 Diff=965,BPH 3,604,WHP 148, IA 281,OA 585,CTSW=10 k, DHWOB=2.2 k,average ROP over interval drilled 26 ft/hr 12/27/2017 12/27/2017 0.10 PROD3 DRILL WPRT P Wiper up hole PUW 43 k 10,080.0 9,922.0 06:15 06:21 12/27/2017 12/27/2017 0.10 PROD3 DRILL WPRT P RBIH 9,922.0 10,080.0 06:21 06:27 12/27/2017 12/27/2017 1.50 PROD3 DRILL DRLG P 1.85 bpm in, 1.85 bpm out,RIH Wt 10,080.0 10,181.0 06:27 07:57 12.5 k lbs,free spin diff 1,120 psi,WH 108 psi,IA 421,OA 681 psi, OBD,CT Wt 8 k lbs,WOB 2-3 k lbs, ROP 40-100 ft/hr average ROP 67 ft/hr 12/27/2017 12/27/2017 3.60 PROD3 DRILL DRLG P Ran into something hard @ 10181', 10,080.0 10,435.0 07:57 11:33 WOB 2-3 k lbs, ROP 25 ft/hr 10 1084 broke through 1.85 bpm in, 1.77 bpm out,Annular 3623 psi, 10.58 ECD CTWt10klbs,WOB 1.5klbs ROP 100 ft/hr pump 5x5,pull BHA wiper as sweeps exit bit @ 10,343',PU 37K lbs. 10284'PU 40 k lbs 10420'PU 44 k lbs Coil weight falling off. Average rop over interval-98.6 ft/hr 12/27/2017 12/27/2017 1.30 PROD3 DRILL WPRT P Wiper up hole PUW 58 k,Drive by RA 10,435.0 8,375.0 11:33 12:51 tag+10'correction.Open EDC& pumnp 5x5,chase sweep out of hole. 12/27/2017 12/27/2017 0.20 PROD3 DRILL DLOG P Tie into K1 marker+8'correction 8,375.0 9,006.0 12:51 13:03 12/27/2017 12/27/2017 0.60 PROD3 DRILL WPRT P RBIH CTSW=15k, 9,006.0 10,435.0 13:03 13:39 12/27/2017 12/27/2017 0.40 PROD3 DRILL DRLG P 1.83 bpm in 1.79 bpm out,Ct 4608 10,435.0 10,488.0 13:39 14:03 psi,Annular 3640 psi, 10.6 ppg EMW, RIH wt 13.6 k lbs,free spin diff 1130 psi,WH 112 psi, IA 482 psi,OA 757 psi OBD,CTWt10.33klbs,WOB 1.15k lbs,70 ft/hr Start pumping new mud to the bit- 1:39 system#3 Drilling break 10446'-ROP up to 150- 200 ft/hr New mud at the bit 10485' average over interval 132 ft/hr 12/27/2017 12/27/2017 1.00 PROD3 DRILL DRLG P PU 44 k lbs 10,488.0 10,543.0 14:03 15:03 1.82 bpm in 1.81 bpm out,Ct 4608 psi,annular 3557 psi, 10.36 ppg EMW,free spin diff 1135 psi, OBD,CT Wt 9.8 k lbs,WOB 1.6 k lbs, 144 ft/hr average ROP 55 fUhr Page 15/24 Report Printed: 1/9/2018 } • • Operations Summary (with TimelogDepths) f r 1D-12 tConochitiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Cade Time P-T-X Operation MKS) End Depth(ftKra); 12/27/2017 12/27/2017 1.90 PROD3 DRILL DRLG P New mud all the way around PU-45 k 10,543.0 10,641.0 15:03 16:57 lbs-slight overpull 55 k Ct Wt and WOB-2.6 k lbs. RBIH,SD 10526 two times,Stacked out coil W 2.8 k lbs WOB Run through at rate,TF as drilled, good 1.85 bpm in, 1.80 bpm out,CT 4041 psi,WH 160 psi,free spin 1087 psi OBD,CT Wt 10 k lbs,WOB 1 k lbs, ROP 100 ft/hr PU 10615',49 k lbs average ROP 52 ft/hr 12/27/2017 12/27/2017 5.00 PROD3 DRILL DRLG P 1.85 bpm in, 1.82 bpm out,CT 4360 10,641.0 10,850.0 16:57 21:57 psi,Annular 3595,WH 154 psi,IA 338 psi,OA 645 psi.free spin 1231 psi. OBD CT Wt 12 k lbs,WOB 1 klbs, ROP 70 ft/hr,short BHA wiper at 10,768' 12/27/2017 12/27/2017 0.60 PROD3 DRILL WPRT P Wiper up hole PUW 39 k 10,850.0 9,570.0 21:57 22:33 12/27/2017 12/27/2017 0.60 PROD3 DRILL WPRT P Wiper back in hole,RIW 10 k 9,570.0 10,850.0 22:33 23:09 12/27/2017 12/28/2017 0.85 PROD3 DRILL DRLG P Tagged up on bottom 2.0'ft high 10,850.0 10,886.0 23:09 00:00 10,848',OBD 1.78 bpm at 4,146 psi, Diff=976 psi,BHP 3,677,WHP 208, IA 384,OA 676,CTSW=O k, DHWOB=1.6 k,ROP 45 fph 12/28/2017 12/28/2017 2.50 PROD3 DRILL DRLG P OBD, 1.79 bpm at 4,390 psi, Diff=976 10,886.0 11,040.0 00:00 02:30 psi,BHP 3,629, IA 413,OA 697, CTSW=2.0 k, DHWOB=1.3 k, ROP 13 fph-45 fph 12/28/2017 12/28/2017 0.20 PROD3 DRILL WPRT P 200'wiper up hole,PUW 39 k 11,040.0 11,040.0 02:30 02:42 12/28/2017 12/28/2017 3.30 PROD3 DRILL DRLG P BOBD, 1.78 bpm at 4,461 psi,BHP 11,040.0 11,179.0 02:42 06:00 3,662,WHP 132, IA 537,OA 798, CTSW=3.0 k,DHWOB=1.2 k,ROP 45 -80 fph 12/28/2017 12/28/2017 0.10 PROD3 DRILL WPRT P Wiper up 178',PU 37k 11,179.0 11,001.0 06:00 06:06 12/28/2017 12/28/2017 0.10 PROD3 DRILL WPRT P Wiper down 11,001.0 11,179.0 06:06 06:12 12/28/2017 12/28/2017 1.20 PROD3 DRILL DRLG P BOBD, 1.72 bpm @ 4,361 psi,BHP 11,179.0 11,224.0 06:12 07:24 3,648 psi,WHP 159 psi,IA 569,OA, 814,CTSW=0.8k,DHWOB=1.3k, Avg ROP 38 fph PU 35k @ 11,187' 12/28/2017 12/28/2017 2.20 PROD3 DRILL WPRT P Wiper into 4-1/2"PU 35k,open EDC 11,224.0 5,999.0 07:24 09:36 @ 9,020'2.25 bpm @ 4810 psi, 12/28/2017 12/28/2017 0.10 PROD3 DRILL DLOG P Tie into K1 for+9'correction 5,999.0 8,865.0 09:36 09:42 12/28/2017 12/28/2017 0.90 PROD3 DRILL WPRT P RBIH CTSW=16k,weight check PU 8,865.0 11,224.0 09:42 10:36 32k @ 8,960', 12/28/2017 12/28/2017 0.70 PROD3 DRILL DRLG P BOBD, 1.82 bpm @ 4,462 psi,BHP 11,224.0 11,265.0 10:36 11:18 3,640 psi,WHP 105 psi, IA 498 psi, OA 795 psi,CTSW=8 k, DHWOB=1.7k, avg ROP PU 42k @ 11,271' PU 37k @ 11,279' Page 16/24 Report Printed: 1/9/2018 • , Operations Summary (with TimeloRepths) '► 4 . 1D-12 Conocchiiltips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/28/2017 12/28/2017 5.30 PROD3 DRILL DRLG P Encounter Ankorite,slow drilling.Avg 11,265.0 11,390.0 11:18 16:36 ROP 23 fph PU 43k @ 11,352' PU 48k @ 11,361' PU 50k @ 11,364' 12/28/2017 12/28/2017 2.50 PROD3 DRILL DRLG P OBD, 1.83 bpm at 4,350 psi,Diff= 11,390.0 11,440.0 16:36 19:06 1,050 psi,BHP 3,655,WHP 74 psi, CTSW=-2.0--6.0 k,DHWOB=.0.5-1.2 k,ROP=30 fph,with frequent PU's, weight transfer issues 12/28/2017 12/28/2017 0.20 PROD3 DRILL WPRT P 500'wiper up hole,PUW 39.0 k, 11,440.0 10,640.0 19:06 19:18 12/28/2017 12/28/2017 0.20 PROD3 DRILL WPRT P Wiper back in hole,RIW 2.0 k 10,640.0 11,440.0 19:18 19:30 12/28/2017 12/28/2017 0.35 PROD3 DRILL DRLG P BOBD, 1.79 bpm at 4,300 psi, 11,440.0 11,449.0 19:30 19:51 Diff=1,050 psi,BHP 3,680,WHP 70, IA 682 psi,OA 902 psi,CTSW=1.0 k, DHWOB=2.1 k,ROP=26 fph 12/28/2017 12/28/2017 0.20 PROD3 DRILL WPRT P BHA wiper up hole,PUW 60.0 k 11,449.0 11,449.0 19:51 20:03 12/28/2017 12/28/2017 2.00 PROD3 DRILL DRLG P BOBD, 1.79 bpm at 4,300 psi, 11,449.0 11,534.0 20:03 22:03 Diff=1,050 psi,BHP 3,645,WHP 77, IA 688 psi,OA 902 psi,CTSW=-7.0 k, DHWOB=0.7 k,ROP=44 fph 12/28/2017 12/28/2017 0.20 PROD3 DRILL WPRT P BHA wiper up hole,PUW 41.0 k, 11,534.0 11,534.0 22:03 22:15 12/28/2017 12/29/2017 1.75 PROD3 DRILL DRLG P BOBD, 1.79 bpm at 4,300 psi, 11,534.0 11,697.0 22:15 00:00 Diff=1,050 psi,BHP 3,655,WHP 79, IA 686 psi,OA 903 psi,CTSW=-7.0 k, DHWOB=0.8 k,ROP 53 fph 12/29/2017 12/29/2017 PROD3 DRILL WPRT P 11,611.0 00:00 00:00 12/29/2017 12/29/2017 2.35 PROD3 DRILL DRLG P OBD, 1.79 bpm at4,300 psi, 11,611.0 11,666.0 00:00 02:21 Diff=1,050 psi,BHP 3,680,WHP 66, IA 687 psi,OA 904 psi,CTSW=-4.4 k,DHWOB=0.9 k,ROP=44 fph 12/29/2017 12/29/2017 2.00 PROD3 DRILL DRLG P Gamma 158 api continue drililng 11,666.0 11,688.0 02:21 04:21 ahead looking for res confirmation of top(C4)pay. 1.80 bpm at 4,684 psi, BHP 3,652,WHP 86, IA 684 psi,OA 897 psi,CTSW=-8.0 k,DHWOB=1.0 k,ROP=10-15 fph 12/29/2017 12/29/2017 1.30 PROD3 DRILL DRLG P Continue Drilling Ahead confirming 11,688.0 11,697.0 04:21 05:39 Top of the C4, 1.79 bpm at 4,300 psi, Diff=1,050 psi,BHP 3,667,WHP 81, IA 691 psi,OA 905 psi,CTSW=-5.3 k,DHWOB= 1.4 k, ROP= 15 fph **' TD Called by Geo's 12/29/2017 12/29/2017 3.60 PROD3 DRILL WPRT P Swab wiper,PU 44k 11,697.0 60.0 05:39 09:15 12/29/2017 12/29/2017 1.50 PROD3 DRILL TRIP P RBIH @ 100 fph 60.0 8,891.0 09:15 10:45 12/29/2017 12/29/2017 0.50 PROD3 DRILL DLOG P Tie into K1 for-4'correction,collect 8,891.0 8,891.0 10:45 11:15 static BHP of 3,314 psi @ 6,419'TVD, 8,891'MD. intial pressure 3,489 psi 5 min 3,430 psi 10 min 3,389 psi bleed to 3,309 psi and shut in 15 min 3,314 psi Page 17/24 Report Printed: 1/9/2018 At ' ,. Operations Summary (with TimeloRepths) bks .; 1D-12 ConocaPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/29/2017 12/29/2017 1.10 PROD3 DRILL TRIP P PU 35k,RIH to TD 8,891.0 11,702.0 11:15 12:21 Stack weight @ 11,550', 11,560, 11,640', 11,670' 12/29/2017 12/29/2017 3.50 PROD3 DRILL TRIP P Lay in 50 bbl liner running pill,paint 11,702.0 0.0 12:21 15:51 yellow flag @ 7,378',white flag @ 4,678',lay in 10.4ppg KW fulid to surface. 12/29/2017 12/29/2017 0.90 PROD3 DRILL PULD P Flow check good,lay down BHA#13. 0.0 0.0 15:51 16:45 12/29/2017 12/29/2017 0.50 COMPZ3 DRILL CTOP T Skid cart forward,remove BHI upper 0.0 0.0 16:45 17:15 quick,prep end of a-line,install nozzle,stab INJH 12/29/2017 12/29/2017 1.00 COMPZ3 DRILL CTOP T Perform slack management,displace 0.0 0.0 17:15 18:15 reel to fresh water,pump 2.2 bpm,e- line moving,unstab INJH 12/29/2017 12/29/2017 0.75 COMPZ3 DRILL CTOP T Crew change,PJSM,prep to cut coil, 0.0 0.0 18:15 19:00 install hydraulic tubing cutter 12/29/2017 12/30/2017 5.00 COMPZ3 DRILL CTOP T Trim Coil,found e-line at 134',@ 0.0 0.0 19:00 00:00 1,984'foot cut as of midnight 12/30/2017 12/30/2017 1.25 COMPZ3 DRILL CTOP T Continue Trimming Coil with hydraulic 0.0 0.0 00:00 01:15 cutter 1,984'to 2,500' 12/30/2017 12/30/2017 0.50 COMPZ3 DRILL CTOP T RD cutting Equipment,test e-line good 0.0 0.0 01:15 01:45 test(>550 m-ohms,61 ohms) 12/30/2017 12/30/2017 1.50 COMPZ3 DRILL CTOP T Dress,and install CTC,Pull Test CTC 0.0 0.0 01:45 03:15 35 k,re-head BHI upper quick.re-test e-line(>550 mohms.59 ohms) 12/30/2017 12/30/2017 0.75 COMPZ3 DRILL CTOP T Stab INJH,circulate 1 coil volume 0.0 0.0 03:15 04:00 forward,unstab INJH 12/30/2017 12/30/2017 0.50 COMPZ3 CASING PUTB P Prep RF for running liner. 0.0 0.0 04:00 04:30 12/30/2017 12/30/2017 2.90 COMPZ3 CASING PUTB P PJSM,PU/MU liner assembly 0.0 1,793.0 04:30 07:24 12/30/2017 12/30/2017 0.50 COMPZ3 CASING PULD P MU BHA#14 1,793.0 1,837.0 07:24 07:54 12/30/2017 12/30/2017 2.20 COMPZ3 CASING RUNL P RIH w/BHA#14 liner assembly 1,837.0 10,640.0 07:54 10:06 PU Wt 35k-@ 8958' 12/30/2017 12/30/2017 0.10 COMPZ3 CASING RUNL P Tie into K1 marker for-7' 10,640.0 10,658.0 10:06 10:12 12/30/2017 12/30/2017 1.30 COMPZ3 CASING RUNL P Continue RIH w/BHA#14 to TD 10,658.0 11,700.0 10:12 11:30 PU 40k @ 10,824' PU 40k @ 10,864' PU 42k @ 11,442' Set liner on depth 12/30/2017 12/30/2017 0.40 COMPZ3 CASING TRIP P POOH 11,700.0 8,845.0 11:30 11:54 PU 32k @ 11,700' 12/30/2017 12/30/2017 0.20 COMPZ3 CASING DLOG P Gamma Ray tie in for+3'correction 8,845.0 8,868.0 11:54 12:06 12/30/2017 12/30/2017 1.50 COMPZ3 CASING TRIP P Continue POOH to surface 8,868.0 38.0 12:06 13:36 12/30/2017 12/30/2017 1.10 COMPZ3 CASING PULD P Bumped up,flow check,PJSM,LD 38.0 0.0 13:36 14:42 BHA#14 12/30/2017 12/30/2017 1.30 PROD4 STK CIRC P Prep for BOPE tests,greasing stack& 0.0 0.0 14:42 16:00 vlaves. 12/30/2017 12/30/2017 6.00 PROD4 WHDBOP BOPE P Test BOPE,Test witnessed by State 0.0 0.0 16:00 22:00 AOGCC Rep.Lau Benstein,250 Low/2,500 Annular/3,800 High Page 18/24 Report Printed: 1/9/2018 F Operations Summary (with Timelog Depths) 1D-12 v IP ConocaPtvftlips 11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Opera€on MKS) End Depth(ftKS), 12/30/2017 12/30/2017 1.00 PROD4 STK CTOP P RD testing equipment,secure test 0.0 0.0 22:00 23:00 pump,blow down choke line,LD test joint 12/30/2017 12/31/2017 1.00 PROD4 STK PULD P PJSM,PU/MU drilling BHA#15 0.0 78.3 23:00 00:00 12/31/2017 12/31/2017 0.25 PROD4 STK TRIP P Surface test drilling BHA#15(good- 78.3 498.0 00:00 00:15 test),stab INJH 12/31/2017 12/31/2017 1.75 PROD4 STK TRIP P Surface test agitatorw/KWF 1.75 bpm 498.0 8,865.0 00:15 02:00 at 5,180 psi, Diff=1,967 psi,continue RIH,line up and time out displacing coil to drililng fliud 12/31/2017 12/31/2017 0.15 PROD4 STK DLOG T Log K1 marker,e-line communication 8,865.0 8,881.0 02:00 02:09 error,20 bbls of drilling fliud inside reel. 12/31/2017 12/31/2017 0.72 PROD4 STK CTOP T No communication with DHT,unplug 8,881.0 7,959.0 02:09 02:52 BHI cable from collector(good-test), mobilize Nabor's Electrician,pull up hole into the 4.5",circulate completion fluid behind drilling fluid 20 bbls at 0.78 bpm at 1,107 psi,to keep well dead. 12/31/2017 12/31/2017 1.50 PROD4 STK CTOP T Circulate completion fluid behind 7,959.0 7,959.0 02:52 04:22 drilling fluid 20 bbls at 0.78 bpm at 1,107 psi,to keep well dead.lockout INJH and storage reel,Nabor's electrician on location,PJSM,inspect CT bulkhead. 12/31/2017 12/31/2017 2.50 PROD4 STK TRIP T POOH,while circulating completion 7,959.0 79.0 04:22 06:52 fluid around 12/31/2017 12/31/2017 0.30 PROD4 STK PULD T Unstab injector 79.0 79.0 06:52 07:10 12/31/2017 12/31/2017 0.20 PROD4 STK CTOP T Trouble shoot comms issue on BHA 79.0 79.0 07:10 07:22 #15,good test from MWD shack to Upper Quick. Bad test,logging tools. 12/31/2017 12/31/2017 0.30 PROD4 STK PULD T Lay down upper section coil trak 79.0 63.0 07:22 07:40 12/31/2017 12/31/2017 0.70 PROD4 STK PULD T MU/PU BHA#16.Stab INJH,open 63.0 78.0 07:40 08:22 EDC. 12/31/2017 12/31/2017 1.70 PROD4 STK TRIP T RBIH w/BHA#16,circ.well to drilling 78.0 8,865.0 08:22 10:04 fluids while tripping in. 12/31/2017 12/31/2017 0.20 PROD4 STK DLOG P Tie into K1 marker,-4'correction 8,865.0 8,878.0 10:04 10:16 12/31/2017 12/31/2017 0.80 PROD4 STK DISP P Displace to drilling fluid,close EDC 8,878.0 8,796.0 10:16 11:04 PU 32k @ 8,800' 12/31/2017 12/31/2017 0.50 PROD4 STK TRIP P Continue RIH to TOB.Dry tag billet @ 8,796.0 9,904.0 11:04 11:34 9,904' PU 34k 12/31/2017 12/31/2017 1.80 PROD4 STK KOST P Milling off billet @ 9,902'. 1.81 bpm @ 9,904.0 9,910.0 11:34 13:22 4,905psi.CTSW=14.5k,WOB=.8k BHP 3,592 psi,WHP 184 psi, IA=0, OA=77 12/31/2017 12/31/2017 0.50 PROD4 DRILL DRLG P Off billet driling ahead 9,910.0 9,950.0 13:22 13:52 CT Wt 12.6 k lbs,CT 4500 psi, 1.83 bpm in 1.83 bpm out, WOB 2 k lbs ROP 30-200 ft/hr Page 19/24 Report Printed: 1/9/2018 •Operations Summary (with Timelo o the pt 9 p ) 1D-12 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code. Activity Code Time':P T-x Operation (MO) End Depth(ftKY) 12/31/2017 12/31/2017 2.70 PROD4 DRILL DRLG P PU Wt 35 k lbs 9,950.0 10,212.0 13:52 16:34 RBIH,S/D 9913',PU 37k,RBIH PU 34k @ 10,130' PU 45K @ 10,212',thre times,on something hard Average over the interval 97 ft/hr 12/31/2017 12/31/2017 2.00 PROD4 DRILL DRLG P Broke through 10,212.0 10,432.0 16:34 18:34 1.82 bpm in, 1.80 bpm out,CT 4400 psi,Annular 3657 psi,free spin diff 1480 psi OBD CT Wt 11 k lbs,WOB 1.2 k lbs, ROP 70 ft/hr 12/31/2017 12/31/2017 0.20 PROD4 DRILL WPRT P Wiper up hole,PUW 40 k 10,432.0 9,941.0 18:34 18:46 12/31/2017 12/31/2017 0.20 PROD4 DRILL WPRT P Wiper back in hole,RIW 11.2 k 9,941.0 10,432.0 18:46 18:58 12/31/2017 12/31/2017 3.00 PROD4 DRILL DRLG P BOBD, 1.81 bpm at 4,339 psi,Diff= 10,432.0 10,735.0 18:58 21:58 1,536 psi,BHP 3,552,WHP 173,IA 146,OA 310,CTSW=10.4 k, DHWOB=0.7 k, ROP=124 fph "'Note: 1 bpm losses encountered at 10,462',quickly healed up 12/31/2017 12/31/2017 1.00 PROD4 DRILL WPRT P Wiper up hole, PUW 39.0 k,chasing 10,735.0 8,098.0 21:58 22:58 5x5 sweep 12/31/2017 12/31/2017 0.20 PROD4 DRILL WPRT P Shut down pump,open EDC,bring 8,098.0 6,000.0 22:58 23:10 pump up to 2.54 bpm at 4,323 psi, PUH to 6,000' 12/31/2017 1/1/2018 0.84 PROD4 DRILL WPRT P RBIH,8,098'close EDC 6,000.0 8,086.0 23:10 00:00 1/1/2018 1/1/2018 0.25 PROD4 DRILL WPRT P Continue RIH 8,086.0 8,865.0 00:00 00:15 1/1/2018 1/1/2018 0.20 PROD4 DRILL DLOG P Log the K1 marker correction of plus 8,865.0 8,901.0 00:15 00:27 9.5' 1/1/2018 1/1/2018 0.60 PROD4 DRILL WPRT P Continue wiper in hole,RIW 14 k 8,901.0 10,734.0 00:27 01:03 1/1/2018 1/1/2018 4.20 PROD4 DRILL DRLG P BOBD, 1.8 bpm at 4,604 psi, 10,734.0 11,130.0 01:03 05:15 Diff=1,670 psi,BHP 3,576,WHP 67, IA 160,OA 339,CTSW=2.0 k, DHWOB=2.0 k,ROP=150 fph 1/1/2018 1/1/2018 0.40 PROD4 DRILL WPRT P 1,000'wiper,PU 36K 11,130.0 10,131.0 05:15 05:39 1/1/2018 1/1/2018 0.50 PROD4 DRILL WPRT P RBIH to bottom 10,131.0 11,130.0 05:39 06:09 1/1/2018 1/1/2018 1.20 PROD4 DRILL DRLG P BOBD, 1.81 bpm 4,961 psi,BHP 11,130.0 11,180.0 06:09 07:21 3,650 psi,WHP 78, IA 373,OA 463, CTSW=10.8k,WOB=.6k,ROP 108 fph Strange pressures being seen 5,376 psi @ 1.81 bpm,seeing axial stress on tools up to 5.lateral 2 Bypass high pressure screens,check pressures,smove higher,line back up to high pressure screens. 1/1/2018 1/1/2018 0.10 PROD4 DRILL WPRT P 500'wiper,PU 67k 11,180.0 10,687.0 07:21 07:27 1/1/2018 1/1/2018 0.30 PROD4 DRILL WPRT P RBIH to Bottom,Diff: 1,507 psi 10,687.0 11,195.0 07:27 07:45 Page 20/24 Report Printed: 1/9/2018 ='01.3 operations Summary (with Timelog Depths) 0 1D-12 • coPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 1/1/2018 1/1/2018 6.20 PROD4 DRILL DRLG P BOBD, 1.76 bpm @ 4,610 psi,WHP 11,195.0 11,598.0 07:45 13:57 57, IA 370,OA 468,CTSW=5.83k, WOB=2.89K, ROP 55, Diff:2,057 psi Pressures and Axial stress looking better PU 38k @ 11,366' AVG ROP 62 fph 1/1/2018 1/1/2018 0.30 PROD4 DRILL WPRT P 500' wiper 11,598.0 10,997.0 13:57 14:15 PU 45K @ 11,598 1/1/2018 1/1/2018 0.40 PROD4 DRILL WPRT P RBIH,stacking weight while RBIH 10,997.0 11,439.0 14:15 14:39 1/1/2018 1/1/2018 1.70 PROD4 DRILL WPRT P Perform wiper to window,open EDC 11,439.0 5,997.0 14:39 16:21 continue up hole 6,000' 1/1/2018 1/1/2018 0.50 PROD4 DRILL WPRT P RBIH to K1 marker 5,997.0 8,869.0 16:21 16:51 1/1/2018 1/1/2018 0.10 PROD4 DRILL DLOG P Tie into K1 for+12'correction,close 8,869.0 8,892.0 16:51 16:57 EDC,obtian static @ 6420'TVD BHP=3,260 psi=9.76 ppg 1/1/2018 1/1/2018 1.50 PROD4 DRILL WPRT P Continue RIH to bottom and turn well 11,439.0 11,606.0 16:57 18:27 over to new mud system 4,new mud at the bit 11,606' 1/1/2018 1/1/2018 2.10 PROD4 DRILL DRLG P BOBD 1.77 bpm @ 4,677 psi,WHP 11,606.0 11,708.0 18:27 20:33 110 psi, IA 343,OA 478,CTSW=9.3k, WOB=.99K Diff: 1,677psi. avg ROP=49 fpm PU 36k @ 11,664' 1/1/2018 1/1/2018 0.10 PROD4 DRILL WPRT P 100'wiper PU 51k 11,708.0 11,617.0 20:33 20:39 1/1/2018 1/1/2018 0.40 PROD4 DRILL WPRT P RBIH to bottom,difficulty getting back 11,617.0 11,707.0 20:39 21:03 down, PU 35k @ 11,563' PU 30K @ 11,637' 1/1/2018 1/2/2018 2.95 PROD4 DRILL DRLG P BOBD, 1.80 bpm @ 4,466 psi,WHP 11,707.0 11,803.0 21:03 00:00 235, IA 204,OA 377,CTSW=-5.K, WOB 2,6K Diff: 1,514 psi. PU 37K @ 11,740' PU 35k @ 11,755' 1/2/2018 1/2/2018 2.00 PROD4 DRILL DRLG P OBD, 1.83 bpm at 4,773 psi, 11,803.0 11,863.0 00:00 02:00 Diff=1,487 psi,BHP 3,640,WHP 181, IA 336,OA 442,CTWS=-6.4 k, DHWOB=2.2 k,ROP 30-40 fph 1/2/2018 1/2/2018 4.00 PROD4 DRILL DRLG P Continued drilling ahead toTD well at 11,863.0 11,990.0 02:00 06:00 11,990' 1/2/2018 1/2/2018 1.25 PROD4 DRILL WPRT P Pumped 10x10 sweep,started swab 11,990.0 9,000.0 06:00 07:15 wiper up hole to the window,chasing sweeps. 1/2/2018 1/2/2018 1.25 PROD4 DRILL WPRT P At the window increase pump rate, 9,000.0 2,654.0 07:15 08:30 continue POOH pumping 1.8 bpm at 3,261 psi,bore pressure around 6,000 psi 1/2/2018 1/2/2018 1.10 PROD4 DRILL WPRT T Bore pressure spiked from 4,200 psi 2,654.0 78.3 08:30 09:36 to 5,814 psi,shut down pump,RBIH, start pumping 1 bpm,stop and open EDC,continue POOH,pumping 2.00 bpm at 3,286 psi pump pressure,bore pressure 1,135 psi, 1/2/2018 1/2/2018 0.25 PROD4 DRILL SFTY T Tag up,space out,close the upper 2- 78.3 78.3 09:36 09:51 3/8 rams,PJMS for PUD 1/2/2018 1/2/2018 1.00 PROD4 DRILL PULD T PUD,drilling BHA#16 78.3 0.0 09:51 10:51 Page 21/24 Report Printed: 1/9/2018 • • 4,,,.,,,-,-,‘,,,,,4,17::,...,-;; Operations Summary (with Timelog Depths) 1D-12 446, Conoc hltfipsP. i. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftKD); 1/2/2018 1/2/2018 0.50 PROD4 DRILL PULD T Blow down tools,check motor,check 0.0 0.0 10:51 11:21 agitator by blowing air thru it, everything looks okay. 1/2/2018 1/2/2018 1.20 PROD4 DRILL PULD T PD,wiper BHA#17,surface test BHI 0.0 68.7 11:21 12:33 Coiltrak(good-test),stab INJH,check pac-off 1/2/2018 1/2/2018 1.50 PROD4 DRILL TRIP T Open rams,tag up,reset counters, 68.7 8,870.0 12:33 14:03 RIH,surface test agitator at 495'(good -test) 1/2/2018 1/2/2018 0.10 PROD4 DRILL DLOG T Log the K1 marker correction of minus 8,870.0 8,893.0 14:03 14:09 4.5'correction 1/2/2018 1/2/2018 0.20 PROD4 DRILL TRIP T Continue IH 8,893.0 8,997.0 14:09 14:21 1/2/2018 1/2/2018 0.50 PROD4 DRILL TRIP T Perform static BHP Sensor Depth 8,997.0 8,997.0 14:21 14:51 TVD 6495.71', 1/2/2018 1/2/2018 0.75 PROD4 DRILL TRIP T Continue IH,Pump 10x10 sweep 8,997.0 9,500.0 14:51 15:36 1/2/2018 1/2/2018 2.50 PROD4 DRILL TRIP T POOH,pumping 1.82 bpm at 4,431 9,500.0 69.0 15:36 18:06 psi,BHP 3,444,WHP 181,IA 106,OA 252 1/2/2018 1/2/2018 1.70 PROD4 DRILL TRIP P Tag up and set depths,Trip in hole to 69.0 8,870.0 18:06 19:48 confirm TD 1/2/2018 1/2/2018 0.10 PROD4 DRILL DLOG P Log K1 for-5'correction 8,870.0 8,896.0 19:48 19:54 1/2/2018 1/2/2018 0.10 PROD4 DRILL TRIP P Continue trip in 8,896.0 8,997.0 19:54 20:00 1/2/2018 1/2/2018 0.20 PROD4 DRILL PRTS P Stop and perform pressure survey, 8,997.0 8,997.0 20:00 20:12 Sensor TVD @ 6505',Ann Press=3301 PSI 1/2/2018 1/2/2018 2.10 PROD4 DRILL TRIP P Continue in,encounter hard area 8,997.0 11,993.0 20:12 22:18 -11885',Work pipe down,Continue to corrected TD @ 11993' 1/2/2018 1/3/2018 1.70 PROD4 DRILL TRIP P POOH pumping 9.9 PPG liner running 11,993.0 6,515.0 22:18 00:00 pill followed by 9.9 completion fluid. Paint EOP flags @ 9550'&6600' 1/3/2018 1/3/2018 1.30 PROD4 DRILL WPRT P Continue wiper trip OOH,Completion 6,515.0 58.0 00:00 01:18 fluild all around stop at 3000'for flow check.Good test continue out 1/3/2018 1/3/2018 0.30 PROD4 DRILL OWFF P On surface,flow check well,PJSM lay 58.0 58.0 01:18 01:36 down BHA on dead well 1/3/2018 1/3/2018 0.90 PROD4 DRILL PULD P Lay down BHA#17,Blow down 58.0 0.0 01:36 02:30 1/3/2018 1/3/2018 0.50 COMPZ4 CASING PULD P Prep floor to run liner,R/U tongs, 0.0 0.0 02:30 03:00 PJSM 1/3/2018 1/3/2018 3.00 COMPZ4 CASING PUTB P P/U AL3-03 lower liner segment,BHA 0.0 2,270.2 03:00 06:00 #18 with non ported bullnose, 1 - 30.99'Jt slotted liner,56 Jts-40' joints,and shorty deployment sleeve 1/3/2018 1/3/2018 1.00 COMPZ4 CASING PULD P PU/MU CoilTrac tools,surface test 2,270.2 2,314.4 06:00 07:00 (good-test),stab INJH,open 2-3/8" combi ram's,tag up,re-set counters 1/3/2018 1/3/2018 1.50 COMPZ4 CASING RUNL P RIH,w/L3-03 lower liner assembly 2,314.4 11,115.0 07:00 08:30 1/3/2018 1/3/2018 0.10 COMPZ4 CASING RUNL P RIH past flag, PUW 38 k(DHWOB=- 11,115.0 11,115.0 08:30 08:36 11.6 k),PUH to flag,correct to EOP flag(6,600'),correction of minus 11.33' Page 22/24 Report Printed: 1/9/2018 .; _ �-, . • 1 46, ' Operations Summary (with Timelog Depths) ,,lifr 1D-12 Conooz"iihps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/3/2018 1/3/2018 0.50 COMPZ4 CASING DLOG P Continue IH,no pumping 11,115.0 10,450.0 08:36 09:06 1/3/2018 1/3/2018 2.00 COMPZ4 CASING RUNL P Set down,work pipe,discussed plan 10,450.0 11,414.0 09:06 11:06 forward with TT,decision was made to line up down the backside bring pump up to 0.5 bpm WHP 148,continue working pipe down hole,line back up down the coil 1/3/2018 1/3/2018 2.00 COMPZ4 CASING RUNL P Set down again,continue to work pipe 11,414.0 11,414.0 11:06 13:06 further in hole,PUW 46 k, DHWOB=2.75 k/-12 k 1/3/2018 1/3/2018 0.50 COMPZ4 CASING RUNL P Liner is on bottom, PUW 48 k,set 11,414.0 11,993.0 13:06 13:36 back down,bring pump up to 1.5 bpm at 4,212 psi, 1.1 bpm returns,PUW 34 k,PUH and remove liner segment length from counters. 1/3/2018 1/3/2018 0.40 COMPZ4 CASING TRIP P POOH,pumping bottoms up from 11,993.0 8,983.0 13:36 14:00 EOB 1/3/2018 1/3/2018 1.00 COMPZ4 CASING CIRC P Slowly move up hole,above window, 8,983.0 8,850.0 14:00 15:00 finish circulating a bottoms up,while mixing a 10x10 beaded pill 1 1/3/2018 1/3/2018 0.10 COMPZ4 CASING DLOG P Log the K1 marker correction of+9.5' 8,850.0 8,868.2 15:00 15:06 1/3/2018 1/3/2018 1.90 COMPZ4 CASING TRIP P POOH,circulating beaded pill down 8,868.2 40.0 15:06 17:00 the coil. 1/3/2018 1/3/2018 0.60 COMPZ4 CASING PULD P At surface,PJSM to lay down BHA on 40.0 0.0 17:00 17:36 dead well,Flow check well,Lay down BHA#18 1/3/2018 1/3/2018 1.00 COMPZ4 CASING RURD P Rig up floor to run liner,Crew change, 0.0 0.0 17:36 18:36 PJSM to pick up liner 1/3/2018 1/3/2018 1.40 COMPZ4 CASING PUTB P M/U BHA#19 with ported bull nose,6 0.0 739.1 18:36 20:00 Jts 2 3/8"slotted liner,HES swell packer, 15 Jts 2 3/8"blank liner,and seal bore deployment sleeve 1/3/2018 1/3/2018 1.30 COMPZ4 CASING PULD P M/U coiltrak to liner,set in slips. 739.1 783.4 20:00 21:18 Change floats in UQC. M/U coil to tools and surface test,Change out pack offs 1/3/2018 1/3/2018 1.60 COMPZ4 CASING RUNL P Trip in hole BHA#19,EDC shut 783.4 9,585.0 21:18 22:54 1/3/2018 1/3/2018 0.10 COMPZ4 CASING DLOG P Log K1 for+4',do not stop to correct, 9,585.0 9,610.0 22:54 23:00 continue in well 1/3/2018 1/4/2018 1.00 COMPZ4 CASING RUNL P Run in well,clean trip to 9719(9723 9,610.0 9,719.0 23:00 00:00 corrected).Circulate 45 BBIs seawater while stabbed into deployment sleeve to place water around packer 1/4/2018 1/4/2018 0.70 COMPZ4 CASING TRIP P Bring pumps online and release from 9,719.0 8,979.9 00:00 00:42 liner.Weights seem the same.Set back down and increase pump rate. Release from liner,Remove liner length from counters. 1/4/2018 1/4/2018 2.00 DEMOB MOVE TRIP P Roll well to seawater,Trip out,stop 8,979.0 31.0 00:42 02:42 and obtain static BHP of 3301 PSI @ 6312'TVD,Continue out,Freeze .. protect from 3000' 1/4/2018 1/4/2018 1.70 DEMOB MOVE PULD P PJSM,PUD BHA#19 Liner running 31.0 0.0 02:42 04:24 tools.Blow down tools, 1/4/2018 1/4/2018 1.50 DEMOB MOVE OTHR P Install nozzle,stab back on well.Flush 0.0 0.0 04:24 05:54 stack,tree,and rig lines Page 23/24 Report Printed: 1/9/2018 • • Operations Summary (with Timelog Depths) &W+ 1D-12 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/4/2018 1/4/2018 1.50 DEMOB MOVE MPSP P PJSM, Load BPV lubricator, PU/MU 0.0 0.0 05:54 07:24 lubricator to stump,PT,Set BPV 1/4/2018 1/4/2018 4.00 DEMOB MOVE RURD P Continue with RD checklist,Blow down 0.0 0.0 07:24 11:24 surface lines to tiger tank,clean pits, MT sumps,and mouse holes,retrieve methonal for wellhead freeze protect, disconnect IA/OA sensors,remove fuseable cap.Highline on location, PJSM,go on gen power, 1/4/2018 1/4/2018 0.60 DEMOB MOVE RURD P NES trucks on location,load up shop 0.0 0.0 11:24 12:00 and halfway house,load rig mats that were under out buildings. DTH dispatched to haul rig mats and rig equipment,Pilot modules over to 1A- pad and stage,Secure rig for jacking up,lift stairs,disconnect all lines and slide PUTZ back,retrieve remotes for steering modules,flip up bottom of beaver slide '""""RIG RELEASE 12:00 noon Page 24/24 Report Printed: 1/9/2018 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1D Pad 1D-12L3 50-029-22948-62 Baker Hughes INTEQ sAtu+ Es Definitive Survey Report 12 January,2018 • 0 ConocoPhillipsBV SEs• ConocoPhillips p Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-12 Project:.. Kuparuk River Unit TVD Reference: 1D-12©104.30usft Site: Kuparuk 1D Pad MD Reference: 1D-12(d 104.30usft i. Well 1D-12 North Reference: True Wellbore:, 1D-12 Survey Calculation Method: Minimum Curvature y. Design: 1D-12 Database: EDT Alaska Sandbox Project Kuparuk River Unit,North Slope Alaska,United States 11 Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 D-12 1 Well Position 1-NI-S 0.00 usft Northing: 5 959,888.87usft Latitude: 70'18'3.521 N 1 +E/-W 0.00 usft Easting: 560,490.53usft Longitude: 149"30'36.243 W 1g Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 1 0.00 usft Wellbore. 1D-12L3 Magnetics Model Name Sample Date DeclinationGip Angle ' Field�l (°) (1 St gBg BGGM2017 12/1/2017 17.37 80.91 57,481 Design 1D-12 L3 Audit Notes: Version: 1.0 Phase: ACTUAL lie On Depth: 8,979.79 Vertical Section: Depth Fram ) TVD .. ".._ �.. 411-0411-0 ' "I £""" Direction: - - ( 104.30 0.00 0.00 - 90.00 _ Survey Program Date 12/2412017, - = ` From To Survey r: ey (usft)_ (usft) Survey)Welbmre) Teel Name Deecripfton „ """ t Date 115.00 8,979.79 1D-12(10.12) MWD MWD-Standard 2/23/2000 1 9,027.00 9,090.72 1D-12L3 MWD-INC(1 D-12L3) 11,107.17 1D-12L3 MIND(10.12L3) MWD-INC_ONLY MWD-INC_ONLY FILLER 12/20/2017 12/20/2017 912083MWD MWD-Standard 1212012017 12/23/2017 i 7/1212018 2 26 30P Page 2 COMPASS 5000.14 Build 85 • • ConocoPhillips aAliir ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-12 Project: Kuparuk River Unit IVO Reference:. 1 D-t2 @104.30usft Site: Kuparuk 1D Pad MD Reference: 1D-12©104.30usft ( Welk 1D-12 North Reference: True Wellbore: 1 D-12 Survey Calculation Method: Minimum Curvature Design: 1D-12 Database: EDT Alaska Sandbox Survey .>. .. ' Map ,„ Map Vertical MD Inc Azl TWD TVDSS +N1-S `�-W Northing Casting OLS Section Survey Tool Name Annotation (ustn (1 (") tusft) (usft) (deet) (usft) (ft) (ft} r111:191 (ft):a 8979.79 49.45 87.22 6509.63 6,405.33 236.87 5,633 19 5960171.06 566,121 09 1.26 5,633 19 MWD-INC_ONLY(2) TIP 9,027.00 48.76 87.86 6,540.53 6,436.23 238.41 5668.84 5960,172.88 566,156.73 1.78 5,668 84 MWD-INC_ONLY(2) KOP 9,060.44 56.96 80.50 6,560.72 6,456.42 241.20 5,695.30 5,960,175.88 566,183.16 30.13 5,695.30 MWD-INC_ONLY(2) Interpolated Azimuth 9,090.72 64.81 73.40 6,575.46 6,471.16 247.22 5,721.01 5,960,182.11 566,208.82 33.02 5,721.01 MWD-INC_ONLY(2) Interpolated Azimuth 9,120.93 71.47 65.41 6,586.72 6,482.42 257.11 5,747.20 5,960,192.21 566,234.92 32.98 5,747.20 MWD(3) 9,152.17 78.70 57.40 6,594.77 6,490.47 271.57 5,773.65 5,960,206.88 566,261.25 33.89 5,773.65 MWD(3) 9,180.63 79.54 54.06 6,600.14 6,495.84 287.30 5,796.74 5,960,222.80 566,284.21 11.90 5,796.74 MWD(3) 9,211.79 79.41 51.37 6,605.83 6,501.53 305.86 5,821.11 5,960,241.55 566,308.43 8.50 5,821.11 MWD(3) 9,241.11 80.05 49.72 6,611.06 6,506.76 324.19 5,843.39 5,960,260.06 566,330.56 5.95 5,843.39 MWD(3) 9,271.41 81.69 52.26 6,615.87 6,511.57 343.02 5,866.63 5,960,279.07 566,353.65 9.89 5,866.63 MWD(3) `( 9,302.17 86.10 52.40 6,619.14 6,514.84 361.71 5,890.83 5,960,297.95 566,377.70 14.34 5,890.83 MWD(3) 9,334.23 87.79 55.86 6,620.85 6,516.55 380.46 5,916.77 5,960,316.91 566,403.48 12.00 5,916.77 MWD(3) 9,362.23 87.57 60.13 6,621.98 6,517.68 395.29 5,940.49 5,960,331.92 566,427.08 15.26 5,940.49 MWD(3) 8,392.89 88.77 63.54 6,622.96 6,518.66 409.75 5,967.50 5,960,346.60 566,453.97 11.78 5,967.50 MWD(3) 9,421.13 90.55 65.30 6,623.13 6,518.83 421.94 5,992.97 5,960,359.00 566,479.34 8.86 5,992.97 MWD(3) 9,451.42 92.43 68.70 6,622.34 6,518.04 433.77 6,020.84 5,960,371.05 566,507.11 12.82 6,020.84 MWD(3) 9,481.31 95.04 71.65 6,620.39 6,516.09 443.88 6,048.89 5,960,381.39 566,535.07 13.16 6,048.89 MWD(3) tS € 9,510.95 97.24 74.49 6,617.22 6,512.92 452.47 6,077.08 5,960,390.20 566,563.19 12.08 6,077.08 MWD(3) ! $ 9,540.99 96.84 78.26 6,613.54 6,509.24 459.49 6,106.05 5,960,397.45 566,592.10 12.53 6,106.05 MWD(3) ( 9,573.29 95.82 81.19 6,609.98 6,505.68 465.21 6,137.63 5,960,403.43 566,623.63 9.55 6,137.63 MWD(3) 9,602.79 96.00 85.66 6,606.94 6,502.64 468.57 6,166.78 5,960,407.02 566,652.74 15.08 6,166.78 MWD(3) 9,630.71 96.16 90.04 6,603.98 6,499.68 469.61 6,194.51 5,960,408.29 566,680.47 15.61 6,194.51 MWD(3) 9,661.99 94.92 93.35 6,600.96 6,496.66 468.69 6,225.63 5,960,407.62 566,711.59 11.25 6,225.63 MWD(3) 9,694.62 94.55 96.63 6,598.27 6,493.97 465.86 6,258.02 5,960,405.05 566,744.00 10.08 6,258.02 MWD(3) 9,721.29 93.94 96.38 6,596.29 6,491.99 462.85 6,284.44 5,960,402.25 566,770.44 2.47 6,284.44 MWD(3) i 1 9,751.39 91.75 91.79 6,594.80 6,490.50 460.71 6,314.42 5,960,400.35 566,800.43 16.88 6,314.42 MWD(3) 1 9,782.77 92.83 88.73 6,593.54 6,489.24 460.57 6,345.77 5,960,400.46 566,831.78 10.33 6,345.77 MWD(3) 9,810.67 92.89 84.82 6,592.15 6,487.85 462.13 6,373.59 5,960,402.25 566,859.58 14.00 6,373.59 MWD(3) 9,831.02 92.98 81.45 6,591.11 6,486.81 464.56 6,393.76 5,960,404.84 566,879.73 16.54 6,393.76 MWD(3) 9,866.31 93.07 76.04 6,509.24 6,484.94 471.44 6,428.31 5,960,411.99 566,914.22 15.31 6,428.31 MWD(3) 1/12/2018 2:26:30PM Page 3 COMPASS 5000.14 Build 85 • • ConocoPhillipsu 4/ ConocoPhillips Definitive Survey Report �� Company: ConocoPhillips(Alaska)Inc.-Kupt Local Co-ordinate Reference: Well 1D-12 Project: Kuparuk River Unit TVD Reference: 10-12 @ 104.30usft Site: Kuparuk 1D Pad MD,Reference: 10-12©104.30usft Well: 10-12 North Reference: True Wellbore: 1D-12 Survey Calculation Method: Minimum Curvature Design: 1D-12 Database: MEDT Alaska Sandbox Survey MD Inc. Azi TVD TVDSS , '+NIS +F2-W Map Map DLS Vertical Northing Eaating ' Section Survey Tool Name Annotation (u ) (,) (I)` (usft) (ustt) (usft) (rift) (ft) (ft) (°n00•) (ft) 9.895.63 93.69 72.57 6,587.51 6,483.21 479.35 6,456.49 5,964420 14 566,942.33 12.00 6,456.49 MWD(3) s 9,925.75 91.75 68.96 6,586.08 6,481.78 489.26 6,484.89 5,96443427 566,970.64 13.59 6,484.89 MWD(3) I 9,954.79 9412 63.94 6,585.61 6,481.31 500.86 6,511.49 5,960,442.08 566,997.16 18.17 6,511.49 MWD(3) i§g 9,985.93 93.87 64.54 6,584.53 6,480.23 514.39 6,539.52 5,960,455.83 567,025.07 12.20 6,539.52 MWD(3) l 10,015.91 9212 60.17 6,582.96 6,478.66 528.27 6,566.03 5,960,469.93 567,051.47 15.68 6,566.03 MWD(3) 1 10,045.99 88.28 60.41 6,582.85 6,478.55 543.18 6,592.15 5,960,485.04 567,077.46 12.79 6,592.15 MWD(3) 11 1. 10,075.23 91.20 60.62 6,582.99 6,478.69 557.57 6,617.60 5,960,499.64 567,102.79 10.01 6,617.60 MWD(3) 10,103.50 91.01 63.05 6,582.44 6,478.14 570.91 6,642.52 5,960,513.18 567,127.60 8.62 6,642.52 MWD(3) 10,125.40 90.64 65.54 6,582.13 6,477.83 580.41 6,662.25 5,960,522.83 567,147.25 11.49 6,662.25 MWD(3) j 10,155.11 87.45 66.04 6,582.62 6,478.32 592.59 6,689.34 5,960,535.23 567,174.24 10.87 6,689.34 MWD(3) 10,186.31 88.13 70.39 6,583.83 6,479.53 604.15 6,718.28 5,960,547.03 567,203.08 14.10 6,718.28 MWD(3) 10,215.59 88.28 73.93 6,584.74 6,480.44 613.12 6,746.13 5,960,556.21 567,230.86 12.10 6,746.13 MWD(3) 10,245.24 85.09 76.61 6,586.46 6,482.16 620.64 6,774.75 5,960,563.97 567,259.42 14.04 6,774.75 MWD(3) 10,275.09 85.48 81.31 6,588.91 6,484.61 626.34 6,803.94 5,960,569.90 567,288.56 15.75 6,803.94 MWD(3) 11 ( 10,305.69 86.58 88.01 6,591.03 6,486.73 629.18 6,834.32 5,960,572.98 567,318.91 22.14 6,834.32 MWD(3) 10,334.97 86.07 92.12 6,592.91 6,488.61 629.14 6,863.53 5,960,573.18 567,348.12 14.12 6,063.53 MWD(3) l 10,368.06 79.69 91.60 6,597.01 6,492.71 628.08 6,896.33 5,960,572.38 567,380.92 19.34 6,896.33 MWD(3) I 10,399.05 79.59 93.86 6,602.58 6,498.28 626.63 6,926.78 5,960,571.17 567,411.38 7.18 6,926.76 MWD(3) 10,427.36 81.78 94.05 6,607.17 6,502.87 624.70 6,954.67 5,960,569.47 567,439.28 7.76 6,954.67 MD(3) 10,456.71 83.78 96.05 6,610.86 6,506.56 622.14 6,983.65 5,960,567.14 567,468.28 9.61 6,983.65 MD(3) yy 1 WW 10,486.12 84.46 98.72 6,613.87 6,509.57 618.38 7,012.66 5,960,563.62 567,497.31 9.32 7,012.66 MW1 D(3) 1 10,515.47 84.37 101.72 6,616.73 6,512.43 613.19 7,041.41 5,960,558.67 567,526.10 10.18 7,041.41 MWD(3) 10,546.08 86.12 104.82 6,619.26 6,514.96 606.19 7,071.09 5,960,551.90 567,555.83 11.60 7,071.09 MWD(3) l 10,576.32 89.42 103.87 6,620.44 6,516.14 598.71 7,100.36 5,960,544.66 567,585.16 11.36 7,100.36 MWD(3) I 10,605.03 89.91 103.65 6,620.61 6,516.31 591.68 7,128.25 5,960,538.05 567,613.10 1.87 7,128.25 MWD(3) 10,635.36 89.63 101.81 6,620.73 6,516.43 585.19 7,157.83 5,960,531.61 567,642.73 6.14 7,157.83 MWD(3) 10,666.09 89.17 99.86 6,621.05 6,516.75 579.42 7,188.01 5,960,526.08 567,672.95 6.52 7,188.01 MWD(3) 10,695.75 89.60 97.42 6,621.37 6,517.07 574.96 7,217.33 5,960,521.86 567,702.30 8.35 7,217.33 MWD(3) 10,725.45 93.78 96.33 6,620.49 6,516.20 571.41 7,246.79 5,960,518.54 567,731.79 14.54 7,246.79 MWD(3) 10,755.09 96.38 96.20 6,617.87 6,513.57 568 19 7,276.14 5,960,515.56 567 761.16 8.78 7,276.14 MWD(3) 10 786.40 97.06 95.05 6,614.21 6,509.91 565 147,307.08 5,960,512.76 557,792.13 4.25 7,307.08 MWD(3) 1/122018 2:26:30PM Page 4 COMPASS 5000.14 Build 85 i 0 ConocoPhillips f.s ConocoPhillipsDefinitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-12 p: Project:S Ku paruk River Unit TVD Reference: 1D-12(d 104.30usft Site: ;,Kuparuk 10 Pad MD Reference: 1D-12©104.30usft Well. 113-12 North Reference: True Wellbore: 10-12 Survey Calculation Method: Minimum Curvature Design: S.1D-12 Database: EDT Alaska Sandbox Survey -,... MD Inc Azi TVD TVDSS +N14' +EJ-W' . - Map DLS Vertical - usft) (");. (^j lusft No casting Section survey Tool Name ( ) (usftj NA ( --. '',, ifti ;. , lft) l°1100) ;,? (ft) Y 1Ua19(9G, 10,815.33 98.35 94.33 6,610 08 6,505.78 562.80 7,335.62 5,960,510.65 567620.68 8.29 7,335 62 MWD(3) 10,840.43 99.29 93.52 6,606.01 6,501.71 561.10 7,360.33 5,960,509.15 567,845.40 3.19 7,360.33 MWD(3) i 10,875.53 99.10 90.25 6,600.40 6,496.10 559.96 7,394.96 5,960,508.29 567,880.03 9.21 7,394.96 MWD(3) 10,899.99 97.24 87.79 6,596.93 6,492.63 560.38 7,419.16 5,960,508.90 567,904.23 12.53 7,419.16 MWD(3) 1 10,925.11 99.16 84.07 6,593.34 6,489.04 562.14 7,443.96 5,960,510.86 567,929.00 16.53 7,443.96 MWD(3) 10,955.49 98.94 80.41 6,588.56 6,484.26 566.19 7,473.68 5,960,515.15 567,958.69 11.92 7,473.68 MWD(3) 10,995.13 99.76 76.00 6,582.12 6,477.82 574.18 7,511.95 5,960,523.45 567,996.90 11.17 7,511.95 MWD(3) 11,026.20 99.53 77.82 6,576.91 6,472.61 581.12 7,541.79 5,960,530.63 568,026.67 5.82 7,541.79 MWD(3) 11,055.28 100.50 81.04 6,571.85 6,467.55 586.37 7,569.93 5,960,536.10 568,054.77 11.40 7,569.93 MWD(3) 11,085.47 100.40 84.04 6,566.38 6,462.08 590.23 7,599.37 5,960,540.20 568,084.17 9.78 7,599.37 MWD(3) 1 11,107.17 100.15 85.86 6,562.51 6,458.21 592.11 7,620.64 5,960,542.25 568,105.42 8.33 7,620.64 MWD(3) 11,148.00 100.15 85.86 6,555.31 6,451.01 595.01 7,660.72 5,960,545.47 568,145.48 0.00 7,660.72 PROJECTED to TD • 1/12/2018 2:26:30PM Page 5 COMPASS 5000.14 Build 85 • • -2 1 7 'I 6 3 BA ER0 1 � 4 UGHES PRINT DISTRIBUTION LIST a GE company Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska, Inc.7 p'E I\ ConocoPhillips Alaska, Inc. ''��ii Tom Osterkamp(WNS Petroleum Technician) WELL NAME 1D-12L3 700 G Street. DATA LOGGED JAN 2 6 2018 Anchorage,Alaska 99510ivr /BENDER FIELD Greater Kuparuk Area to acknowledge receipt of this data. s.",. COUNTY North Slope Borough LOG TYPE CR-RES BHI DISTRICT Alaska --- LOG DATE January 2,2018 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(a�bakerhughes.com TODAYS DATE January 24,2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY FIELD ' FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS _ CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF PKIN I S #OF COPIESn #OF COPIES #OF COPIES V v v Ii v 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&GWO Wells Admin Brenda Glassmaker&Peggy O'Neill 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 0 0 Atte:Ricky Elgarico ATO 708 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 1 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 0 1 1 0 Attn:Resource Evaluation 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 EP''*Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 1 I 1 1 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 s • • r- 01 IN- cn 7- mo W• W'° NN a Ii. gall T CO 0 %— Q.Q. 0 = N cn I Z 0 V Cr ...... t ca 0 0. co 0 0 W W Q H >+ cn Z G) _ • � , — ._ ._ — a) = s — co 0_ = E a. � 'a 90 CO N i co o C w a .- o ^O L mila I— N C _ N _ co c Q N N C E.U D a o CO a) V Y YLo m 0 • • S ! . ,.4,..,3„,,,,,...,..,.::,,.,,,,;,,t,,,,,i.j.,,,,i,;,..,:,,,,,,..,,.! 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JAN 2 9 2018 Letter of Transmittal AOGCC BAKER diff , Date: DATA LOGGED January 26, 2018 2/1/201.4 a GE company M K. BENDER To: I From: ---____-- Makana Bender Yosha Ragbirsingh /Michael Soper AOGCC Baker Hughes, a GE Company 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage,Alaska 99501 Anchorage,Alaska 99515 Please find enclosed the directional surveydata for the following well(s): 2G-15L1 2 1 7 1 4 6 28999 2G-15L1-01 21 71 47 29 C 00 2G-15L1-02 2 1 7 1 4 8 2 9 0 0 1 1D-12L3 2 1 7 1 6 3 2 9 0 0 2 1D-12L3-01 2 1 7 1 6 4 2 9 0 0 3 1D-12L3-02 2 1 7 1 6 5 2 9 0 0 4 1D-12L3-03 2 1 7 1 6 6 2 9 0 0 5 (7) Total prints Enclosed for each well(s): • 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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'� 2 Z y o + O O co co 4 0) co N r CO _ O CO. M CO N 0 N 7 0 O N (O a .- (O O N (r) W ..m m �)O (D '2 (D r m 0 0 0 0 �) 2_� + 1 O O M 0 O N O O r r O O N CO O (D O N O O CO N 0 V r N r N O O O O 0 O r r) c] co co (D (O Cl) N (O (O V V a (C ' N (C a (0 'Q > z CO CO 0 0 CO CO O O O O O 0 F f O O co V co N- «) O t1 _( O O V co co (D 0 O M (C) M 0 C �. O O O O M O N O .- O N U) 1/ 0 ' o o rn 0 m m N- N O O (D - co (D ``,,:l. D (n (n (D Nn (D (D `,`,D)- n (n (n U „ = (o co ( ( co co ( (D O (D ( m I (6 4k F in J d5'• CO N CO 0 N-0 0 N NI-0 0 CO O Q C CO Nl] N r O 0 O CO O O CO CO D Fo ;. yPj r a M O r V' O O r 7 (D (D 'Q v Ql 0 0 O N O f� r O O O O a - 0) d :$ L d Y Y O ) 0) O co ,.- O M O O U) a) U O (6 (0 � (N N M N N 0 r (D (D a ^: 0 0) 0) O) O O) O) O O O O L U Y Y _ _ _ _ °...' m m m rn rn rn rn m O O O o Loi Ur M '42 M o 0 O O 'rOr O N 0 kr) (rn D)) a) 8 0 N Oi O) 8 V iv i CC N O co co co 0 0 O) O O O O £ (Q :+ c C . 0 0 O O 0 0 O v ...-- t t V _ O� O N d d d r ,- O a to 0 Cn y 1., OF TA" 1 w\ I�j �s THE STATE Alaska Oil and Gas Lbw "���•"�7a Of TAsKA Conservation Commission L 333 West Seventh Avenue P GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ik ALAS Fax: 907.276.7542 www.aogcc.alaska.gov James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D-12L3 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-163 Surface Location: 224' FSL, 594' FEL, SEC. 14, T11N, R10E, UM Bottomhole Location: 805' FSL, 1781' FWL, SEC. 18, T11N, R11E, UM Dear Mr. Ohlinger: 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 199-084,API 50-029-22948-00- 00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, /;11.e...e45/7„___ Cathy . Foerster Commissioner DATED this U day of December, 2017. D STATE OF ALASKA Rt EIVE AL OIL AND GAS CONSERVATION COMMON PERMIT TO DRILL NOV 1 1 2017 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp /H�r1/�, i proposed for: Drill ❑ Lateral.EStratigraphic Test ❑ Development-Oil E Service- Winj ❑ Single Zone � ' Gb�Ibe a Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 5952180 • Kuparuk Riv Unit 1D-12L3 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11100'' TVD: 6473' ' Kuparuk River ' 4a. Location of Well(Governmental Section): 7.Property Designation: PigKuparuk River Oil Surface: 224'FSL,594'FEL,Sec 14,T11N,R10E,UM ADL 25650 i on`d+id Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date: 460'FSL,205'FEL,Sec 13,T11N,R10E,UM LONS 79-016 12/6/2017 Total Depth: 9.Acres in Property: ilii 14.Distance to Nearest Property: 805'FSL, 1781'FWL,Sec 18,T11N R11 E,UM . 2560l gypz, 9500' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 104.3 " 15.Distance to Nearest Well Open Surface: x-560491 y-5959889 Zone-4 " GL/BF Elevation above MSL(ft): 61.1 to Same Pool: 350' (1D-28) 16.Deviated wells: Kickoff depth: 9027 feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 96 degrees • Downhole: 3760 ' Surface: 3116• 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 lb/ft L-80 ST-L 1700' 9400' 6498' 11100' 6473' 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): 9250' 6688' N/A 9248' 6687' 9043'(straddle) Casing Length Size Cement Volume MD TVD Conductor/Structural 86' 16" 230 sx AS I 121' 121' Surface 5606' 9-5/8" 676 sx Class G,600 sx Class G 5641' 4328' Intermediate 8665' 7" 210 sx Class G 8696' 6323' Production Liner 706' 3-1/2" 164 sx Class G 9248' 6687' Perforation Depth MD(ft): 8377'-87',9001'-31',9051'-65', Perforation Depth TVD(ft): 6117'-24',6524'-43',6556'-65',6565'-82',6613'- 9064'-89',9136'-38',9171'-81' 14',6636'-43' Hydraulic Fracture planned? Yes❑ No ❑l 20. Attachments: Property Plat ❑ BOP Sketch — Drilling Program 7 Time v.Depth Plot — Shallow Hazard Analysis 7 Diverter Sketch Seabed Report Drilling Fluid Program ✓ 20 AAC 25.050 requirements 7 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be � ���� deviated from without prior written approval. Contact Name: William R.Long4/'//LX._ Authorized Name: James Ohlinger Contact Email: William.R.Lonq(u7COP.com Authorized Title: Staff CTD Engineer Contact Phone: 263-4372 Authorized Signature: . ?..powsds., / Date: //;J/�Commission Use Only Permit to Drill API Number: Permit Approval _ See cover letter for other �3 Number: a'7.- 1 50- 0/.7- aa.gyg—( o)a- Date: `d' `l 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: 21' Other: 37)p 5 f to 3 g UU p 5 ' , Samples req'd: Yes No[ ' Mud log req'd:Yes❑ No IZI �k-w-k 1 a Kip rt v/v-'-t/' firs to Z 5-0010IZS measures: Yes No Directional svy req'd:Yes ll'/-No El Spacing exception req'd: Yes❑ No Inclination-only svy req'd:Yes❑ No zr Post initial injection MIT req'd:Yes❑ No E1----- AO '- 1� APPROVED BY / Q /T Approved by�i r/f" C M S O R \ T E OMMISSION Datel Z E D^ L I v t �{/I V'rG /2/51/.7-- � \' Subs in Form and Form 10-401 -e!is�d�/1?Q1� This permit is valid or 24 mon f o�� r 20 AAC 25.005(g) Attachments in Duplicate • s ConocoPh i l l ip Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 21, 2017 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill quad laterals out of the KRU 1 D-12 (PTD# 199-084) using the coiled tubing drilling rig, Nabors CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The CTD objective will be to drill four laterals (1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03), targeting the Kuparuk C-sand interval. The work is scheduled to begin in December 2017. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 — Detailed Summary of Operations — Directional Plans for 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 — Current wellbore schematic prior to rig workover(Note: A rig workover is currently in process.) — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, 4/7/ - William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska • • ;t'w Kuparuk CTD Laterals ' 4,:iif 0 1D-12L33 1D-12L3-01 ) 1D-12L3-021 and 1D-12L3-03 °°°`°p""P Application for Permit to Drill Document 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 5 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 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 laterals 6 Attachment 2: Current Well Schematic for 1D-12 6 Attachment 3: Proposed Well Schematic for 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 laterals 6 Page 1 of 6 May 1, 2016 • • PTD Application: 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 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 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03. The laterals will be classified as "Development-Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03. 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 CDR3-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 3,800 psi. Using the L maximum formation pressure in the area of 3,760'psi in 1D-10 (i.e. 11.2 ppg EMW)°the maximum potential surface pressure in 1D-12, assuming a gas gradient of 0.1 psi/ft, would be 3,116 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 1 D-12 was measured to be 3,353 psi (9.9 ppg EMW) on 2/23/2016. The maximum downhole pressure in the 1 D-12 vicinity is to the southwest in the 1 D-10 injector at 3,760 psi (11.2 ppg EMW) from February of 2016. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) Wells on 1D pad have injected gas, so there is a chance of encountering free gas while drilling the 1 D-12 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 1D-12 lateral will be losses to the formation. Managed pressure drilling (MPD) target pressure will be reduced to manage losses to the formation. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1D-12 lateral 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 November 21,2016 AtApplication: 1D-12L3, 1D-12L3-IP, 1D-12L3-02, and 1D-12L3-03 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 1D-12L3 9400' 11100' 6498' 6473' 2-3/8", 4.7#, L-80, ST-L slotted liner 1D-12L3-01 9300' 11100' 6499' 6549' 2-3/8", 4.7#, L-80, ST-L slotted liner 1D-12L3-02 9400' 11500' 6491' 6516' 2-3/8", 4.7#, L-80, ST-L slotted liner 1D-12L3-03 9020' 11500' 6432' 6458' 2-3/8", 4.7#, L-80, ST-L slotted liner Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 0' 121' 0' 121' 1640 670 Surface 9-5/8" 40.0 L-80 BTC 0' 5641' 0' 4328' 5750 3090 Production 7" 26.0 L-80 BTC-MOD 0' 8696' 0' 6323' 7240 5410 Liner 3-1/2" 9.3 L-80 EUE8rd 8542' 9248' 6223' 6687' 10160 10540 L1 Slotted Liner 2-3/8" 4.7 L-80 ST-L 9134' 10695' 6612' 6633' 11200 11780 L2 Slotted Liner 2-3/8" 4.7 L-80 ST-L 9108' 10935' 6594' 6565' 11200 11780 Tubing 4-1/2" 12.6 L-80 IBT-MOD 0' 8446' 0' 6162' 8430 7500 Tubing 3-1/2" 9.3 L-80 EUE8rd 8446' 8542' 6162' 6223' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-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 CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based PowerVis mud (8.6 ppg) — Drilling operations: Chloride-based PowerVis 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 10.3 ppg NaCI/NaBr completion fluid in order to provide formation over-balance 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 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 1D-12 laterals we will target a constant BHP of 10.1 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 Page 3 of 6 November 21, 2016 S PTD Application: 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1D-12 Window(9027' MD, 6436' ND) Using MPD Pumps On (1.8 bpm) Pumps Off C-sand Formation Pressure (9.9 ppg) 3353 psi 3353 psi Mud Hydrostatic(8.6 ppg) 2878 psi 2878 psi Annular friction (i.e. ECD, 0.03 psi/ft) 271 psi 0 psi Mud + ECD Combined 3149 psi 2878 psi (no choke pressure) (Underbalanced —204 psi) (Underbalanced —475 psi) Target BHP at Window(10.1 ppg) 3380 psi 3380 psi Choke Pressure Required to Maintain 231 psi 502 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)(11)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 1D-12 is a Kuparuk C sand producer equipped with 4-1/2"tubing, 7" intermediate casing, and a 3-1/2"production liner. A previous CTD project drilled the L1 and L2 laterals in this wellbore. Rock production has prevented these laterals from producing/A rig workover is currently underway to replace tubing, isolate off depth perforations, and cleanout the liner to the new sidetrack depth. The 1D-12L3, 1D- 12L3-01, 1D-12L3-02, and 1D-12L3-03 CTD laterals will target the C sands to the east and north of 1D-12. The laterals will increase recovery and add additional resources. Pre-CTD Work 1. Rig Workover: Pull tubing and replace. Cleanout. Install whipstock. 2. RU Slickline: Pull SOV,Record SIBHP, Install GLV's, 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2"coil tubing. NU 7-1/16" BOPE,test. Page 4 of 6 November 21, 2016 4110 • PTD Application: 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 2. 1D-12L3 Lateral(C sand- east) a. Mill 2.80"window at 9027' MD. b. Drill 3" bi-center lateral to TD of 11100' MD. c. Run 2-3/8" slotted liner with aluminum billet from TD up to 9400' MD. 3. 1D-12L3-01 Lateral (C sand-east) a. Drill 3"bi-center lateral to TD of 11100' MD. b. Run 2-3/8" slotted liner with aluminum billet from TD up to 9300' MD. 4. 1D-12L3-02 Lateral(C sand -north) a. Drill 3"bi-center lateral to TD of 11500' MD. b. Run 2-3/8"slotted liner with aluminum billet from TD up to 9400' MD. 5. 1D-12L3-03 Lateral (C sand-north) a. Drill 3"bi-center lateral to TD of 11500' MD. b. Run 2-3/8" slotted liner with seal bore deployment sleeve from TD up to 9020' MD. 6. Freeze protect,ND BOPE, and RDMO Nabors CDR3-AC rig. Post-Rig Work 1. Slickline: Install liner top packer 2. Return well 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. — 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 1D-12 laterals will be displaced to an overbalancing fluid 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. Page 5 of 6 November 21, 2016 • • PTD Application: 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 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 AA C 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 Naris='t3ts n e 1D-12L3 9500' 1D-12L3-01 9500' 1D-12L3-02 10000' 1D-12L3-03 10000' — Distance to Nearest Well within Pool Lateral Name. _ Distance 1Net 1D-12L3 350' 1D-28 1 D-12L3-01 357' 1D-28 1D-12L3-02 862' 1D-28 1D-12L3-03 830' 1D-28 — The Kuparuk 28243-1 well is near the planned laterals. The well plan centers do NOT pass within 200' of the offset well center. Publicly available information indicates that Mobil Oil Corporation is the operator of this well and that the well has NOT been perforated and therefore NOT open in the same pool. The anti- collision scan will be completed using a Major Risk rule for Kuparuk 28243-1. — The Kuparuk Riv Unit 1 D-28 well is near the planned laterals. The well is operated by the applicant. The well is currently producing in the same formation as the proposed laterals at approximately the same pressure. The primary means of well control for the proposed laterals are managed pressure drilling techniques. The anti-collision scan will be completed using a Minor Risk rule for Kuparuk Riv Unit 1 D-28. 16. Attachments Attachment 1: Directional Plans for 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 laterals Attachment 2: Current Well Schematic for 1D-12 Attachment 3: Proposed Well Schematic for 1D-12L3, 1D-12L3-01, 1D-12L3-02, and 1D-12L3-03 laterals Page 6 of 6 November 21, 2016 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 10 Pad 10-12 10-12L3 Plan: 1 D-12L3_wp01 Standard Planning Report 20 September, 2017 BA ER UGHES a GE company 1.7 • ConocoPhillips e BA ER { ConocoPhillips Planning Report t�UGHES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1D-12 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1D-12 @ 104.30usft Site: Kuparuk 1D Pad North Reference: True Well: 1D-12 Survey Calculation Method: Minimum Curvature Wellbore: 1D-12L3 Design: 1 D-12L3_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 1D Pad,KRU Site Position: Northing: 5,959,669.68 usft Latitude: 70°18'1.318 N From: Map Easting: 561,086.45 usft Longitude: 149°30'18.921 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.47 ° Well 1D-12 Well Position +N/-S 0.00 usft Northing: 5,959,888.87 usft Latitude: 70°18'3.521 N +El-W 0.00 usft Easting: 560,490.53 usft Longitude: 149°30'36.243 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1D-12L3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2017 12/1/2017 17.37 80.91 57,481 Design 1 D-12L3_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,979.79 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 90.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 8,979.79 49.45 87.22 6,405.33 236.87 5,633.19 0.00 0.00 0.00 0.00 9,027.00 48.76 87.86 6,436.23 238.41 5,668.84 1.78 -1.46 1.36 145.17 9,048.00 51.70 87.86 6,449.67 239.01 5,684.97 14.00 14.00 0.00 0.00 9,199.29 90.00 68.17 6,498.81 270.82 5,820.76 28.00 25.31 -13.01 330.00 9,300.00 90.00 61.12 6,498.81 313.91 5,911.72 7.00 0.00 -7.00 270.00 9,500.00 92.88 74.83 6,493.76 388.72 6,096.59 7.00 1.44 6.85 78.00 9,700.00 92.80 60.81 6,483.80 463.95 6,281.10 7.00 -0.04 -7.01 270.00 9,900.00 90.55 74.64 6,477.93 539.53 6,465.64 7.00 -1.12 6.91 99.00 10,075.00 90.11 86.88 6,476.92 567.59 6,638.03 7.00 -0.25 7.00 92.00 10,175.00 87.16 93.23 6,479.31 567.50 6,737.94 7.00 -2.95 6.35 115.00 10,375.00 82.49 79.97 6,497.43 579.20 6,936.28 7.00 -2.34 -6.63 250.00 10,600.00 89.31 94.21 6,513.61 590.43 7,159.70 7.00 3.03 6.33 65.00 10,800.00 96.06 81.93 6,504.22 597.08 7,358.87 7.00 3.38 -6.14 299.00 11,100.00 95.65 103.04 6,473.27 584.21 7,655.31 7.00 -0.13 7.04 90.00 9/20/2017 11:31:39AM Page 2 COMPASS 5000.14 Build 85 ✓ • ConocoPhillips • ' 1 ConocoPhillips Planning Report Bi UGHES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1D-12 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1D-12 @ 104.30usft Site: Kuparuk 1D Pad North Reference: True Well: 1D-12 Survey Calculation Method: Minimum Curvature Wellbore: 1D-12L3 Design: 1 D-12L3_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 8,979.79 49.45 87.22 6,405.33 236.87 5,633.19 5,633.19 0.00 0.00 5,960,171.06 566,121.09 TIP 9,000.00 49.15 87.49 6,418.51 237.58 5,648.50 5,648.50 1.78 145.17 5,960,171.89 566,136.39 9,027.00 48.76 87.86 6,436.23 238.41 5,668.84 5,668.84 1.78 145.00 5,960,172.88 566,156.73 KOP 9,048.00 51.70 87.86 6,449.67 239.01 5,684.97 5,684.97 14.00 0.00 5,960,173.61 566,172.85 End 14 dls,Start 28 dls 9,100.00 64.59 79.86 6,477.08 243.93 5,728.72 5,728.72 28.00 -30.00 5,960,178.89 566,216.55 9,199.29 90.00 68.17 6,498.81 270.82 5,820.76 5,820.76 28.00 -25.75 5,960,206.51 566,308.37 End 28 dls,Start 7 dls 9,200.00 90.00 68.12 6,498.81 271.08 5,821.42 5,821.42 7.00 -90.00 5,960,206.78 566,309.02 9,300.00 90.00 61.12 6,498.81 313.91 5,911.72 5,911.72 7.00 -90.00 5,960,250.33 566,398.96 5 9,400.00 91.45 67.97 6,497.54 356.86 6,001.94 6,001.94 7.00 78.00 5,960,294.00 566,488.83 9,500.00 92.88 74.83 6,493.76 388.72 6,096.59 6,096.59 7.00 78.09 5,960,326.62 566,583.21 6 9,600.00 92.86 67.82 6,488.74 420.68 6,191.14 6,191.14 7.00 -90.00 5,960,359.34 566,677.49 9,700.00 92.80 60.81 6,483.80 463.95 6,281.10 6,281.10 7.00 -90.35 5,960,403.32 566,767.09 7 9,800.00 91.68 67.73 6,479.88 507.30 6,371.06 6,371.06 7.00 99.00 5,960,447.39 566,856.69 9,900.00 90.55 74.64 6,477.93 539.53 6,465.64 6,465.64 7.00 99.27 5,960,480.38 566,951.00 8 10,000.00 90.30 81.63 6,477.19 560.08 6,563.43 6,563.43 7.00 92.00 5,960,501.71 567,048.61 10,075.00 90.11 86.88 6,476.92 567.59 6,638.03 6,638.03 7.00 92.05 5,960,509.82 567,123.14 9 10,100.00 89.37 88.46 6,477.03 568.60 6,663.01 6,663.01 7.00 115.00 5,960,511.04 567,148.11 10,175.00 87.16 93.23 6,479.31 567.50 6,737.94 6,737.94 7.00 114.99 5,960,510.54 567,223.04 10 10,200.00 86.56 91.58 6,480.68 566.45 6,762.88 6,762.88 7.00 -110.00 5,960,509.69 567,247.98 10,300.00 84.20 84.97 6,488.74 569.45 6,862.45 6,862.45 7.00 -109.91 5,960,513.49 567,347.51 10,375.00 82.49 79.97 6,497.43 579.20 6,936.28 6,936.28 7.00 -109.38 5,960,523.83 567,421.25 11 10,400.00 83.23 81.57 6,500.54 583.18 6,960.76 6,960.76 7.00 65.00 5,960,528.01 567,445.70 10,500.00 86.24 87.91 6,509.72 592.29 7,059.85 7,059.85 7.00 64.80 5,960,537.92 567,544.71 10,600.00 89.31 94.21 6,513.61 590.43 7,159.70 7,159.70 7.00 64.22 5,960,536.86 567,644.56 12 10,700.00 92.70 88.09 6,511.86 588.42 7,259.60 7,259.60 7.00 -61.00 5,960,535.66 567,744.46 10,800.00 96.06 81.93 6,504.22 597.08 7,358.87 7,358.87 7.00 -61.11 5,960,545.11 567,843.65 13 10,900.00 96.01 88.97 6,493.69 604.97 7,457.94 7,457.94 7.00 90.00 5,960,553.80 567,942.64 11,000.00 95.88 96.00 6,483.32 600.66 7,557.24 7,557.24 7.00 90.74 5,960,550.29 568,041.97 11,100.00 95.65 103.04 6,473.27 584.21 7,655.31 7,655.31 7.00 91.47 5,960,534.63 568,140.15 Planned TD at 11100.00 9/20/2017 11:31:39AM Page 3 COMPASS 5000.14 Build 85 • ConocoPhillips . R d@) ConocoPhillips Planning Report I UGHES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1D-12 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1D-12 @ 104.30usft Site: Kuparuk 1D Pad North Reference: True Well: 1D-12 Survey Calculation Method: Minimum Curvature Wellbore: 1D-12L3 Design: 1 D-12L3_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +EJ-W Northing Easting -Shape (1 (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude • 1D-12L3_T02 0.00 0.00 6,494.00 -9,038.71 1,146,198.71 5,960,078.00 1,706,615.00 70°2'22.143 N 140°18'52.926 W -plan misses target center by 1138584.06usft at 11100.00usft MD(6473.27 TVD,584.21 N,7655.31 E) -Point 1D-12L3_T05 0.00 0.00 6,473.00 -8,843.231,147,757.48 5,960,286.00 1,708,172.00 70°2'21.736 N 140°18'7.791 W -plan misses target center by 1140141.15usft at 11100.00usft MD(6473.27 TVD,584.21 N,7655.31 E) -Point 1D-12L3_T01 0.00 0.00 6,499.00 -9,156.511,145,923.72 5,959,958.00 1,706,341.00 70°2'21.405 N 140°19'1.248 W -plan misses target center by 1138310.09usft at 11100.00usft MD(6473.27 TVD,584.21 N,7655.31 E) -Point 1D-12L3 CTD Polygon E 0.00 0.00 0.00 -9,033.161,145,757.69 5,960,080.00 1,706,174.00 70°2'22.848 N 140°19'5.432 W -plan misses target center by 1138161.43usft at 11100.00usft MD(6473.27 TVD,584.21 N,7655.31 E) -Polygon Point 1 0.00 0.00 0.00 5,960,080.00 1,706,174.00 Point2 0.00 305.40 829.55 5,960,392.04 1,707,000.99 Point 3 0.00 342.74 1,412.92 5,960,434.07 1,707,583.98 Point4 0.00 367.13 1,865.18 5,960,462.10 1,708,035.99 Point 5 0.00 348.02 2,503.10 5,960,448.12 1,708,673.98 Point6 0.00 42.11 2,487.65 5,960,142.13 1,708,660.99 Point7 0.00 61.16 1,855.73 5,960,156.09 1,708,029.00 Point 8 0.00 43.67 1,417.53 5,960,135.08 1,707,591.00 Point 9 0.00 6.94 882.17 5,960,094.04 1,707,056.00 Point 10 0.00 -327.24 25.39 5,959,753.01 1,706,202.02 Point 11 0.00 0.00 0.00 5,960,080.00 1,706,174.00 1D-12L3 CTD Polygon N 0.00 0.00 0.00 -8,926.461,146,542.65 5,960,193.00 1,706,958.00 70°2'22.724 N 140°18'42.667 W -plan misses target center by 1138945.45usft at 11100.00usft MD(6473.27 TVD,584.21 N,7655.31 E) -Polygon Point 1 0.00 0.00 0.00 5,960,193.00 1,706,958.00 Point2 0.00 506.99 9.06 5,960,700.00 1,706,962.98 Point 3 0.00 758.55 -181.96 5,960,949.99 1,706,769.96 Point4 0.00 1,011.14 -250.94 5,961,201.99 1,706,698.95 Point 5 0.00 1,509.04 -105.94 5,961,700.99 1,706,839.93 Point 6 0.00 2,217.29 -1.26 5,962,410.00 1,706,938.89 Point7 0.00 2,225.57 -285.23 5,962,415.99 1,706,654.89 Point 8 0.00 991.68 -569.14 5,961,179.97 1,706,380.95 Point9 0.00 -263.92 -639.19 5,959,923.97 1,706,321.02 Point 10 0.00 0.00 0.00 5,960,193.00 1,706,958.00 1D-12L3_T04 0.00 0.00 6,514.00 -8,837.251,147,262.46 5,960,288.00 1,707,677.00 70°2'22.526 N 140°18'21.829 W -plan misses target center by 1139646.10usft at 11100.00usft MD(6473.27 TVD,584.21 N,7655.31 E) -Point 1D-12L3_T03 0.00 0.00 6,477.00 -8,867.451,146,666.15 5,960,253.00 1,707,081.00 70°2'23.115 N 140°18'38.903 W -plan misses target center by 1139050.05usft at 11100.00usft MD(6473.27 TVD,584.21 N,7655.31 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,100.00 6,473.27 2 3/8" 2.375 3.000 9/20/2017 11:31:39AM Page 4 COMPASS 5000.14 Build 85 r•' • ConocoPhillips • BA ER ConocoPhillips Planning Report UGHES a GE company Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 1D-12 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1D-12 @ 104.30usft Site: Kuparuk 1D Pad North Reference: True Well: 1D-12 Survey Calculation Method: Minimum Curvature Wellbore: 1D-12L3 Design: 1 D-12L3_wp01 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (usft) (usft) (usft) (usft) Comment 8,979.79 6,405.33 236.87 5,633.19 TIP 9,027.00 6,436.23 238.41 5,668.84 KOP 9,048.00 6,449.67 239.01 5,684.97 End 14 dls,Start 28 dls 9,199.29 6,498.81 270.82 5,820.76 End 28 dls,Start 7 dls 9,300.00 6,498.81 313.91 5,911.72 5 9,500.00 6,493.76 388.72 6,096.59 6 9,700.00 6,483.80 463.95 6,281.10 7 9,900.00 6,477.93 539.53 6,465.64 8 10,075.00 6,476.92 567.59 6,638.03 9 10,175.00 6,479.31 567.50 6,737.94 10 10,375.00 6,497.43 579.20 6,936.28 11 10,600.00 6,513.61 590.43 7,159.70 12 10,800.00 6,504.22 597.08 7,358.87 13 11,100.00 6,473.27 584.21 . 7,655.31 Planned TD at 11100.00 9/20/2017 11:31:39AM Page 5 COMPASS 5000.14 Build 85 • Baker Hughes INTEQ , Bq ER c� ConocoPhillips Travelling Cylinder Report HUGHES a GEcompany Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1D-12 Project: Kuparuk River Unit TVD Reference: 1D-12 @ 104.30usft Reference Site: Kuparuk 1D Pad MD Reference: 1D-12 @ 104.30usft Site Error: 0.00 usft North Reference: True Reference Well: 1D-12 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1D-12L3 Database: OAKEDMP2 Reference Design: 1D-12L3_wp01 Offset TVD Reference: Offset Datum Reference 1 D-12L3_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: 8,979.79 to 11,100.01usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,299.57 usft Error Surface: Pedal Curve Survey Tool Program Date 11/20/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description 115,00 8,979.79 1D-12(1D-12) MWD MWD-Standard 8,979.79 11,100.01 1D-12L3_wp01 (1D-12L3) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 11,100.00 6,577.57 23/8" 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 1D Pad 1 D-02-1D-02-1D-02 Out of range 1D-12-1D-12-1D-12 9,000.00 9,000.00 0.00 3.39 -2.14 FAIL-Major Risk 1D-12-1D-12L1-1D-12L1 9,279.91 9,350.00 118.29 18.07 101.45 Pass-Major Risk 1D-12-1 D-12L1 PB1 -1 D-12L1 PB1 9,285.44 9,375.00 140.61 18.41 123.05 Pass-Major Risk 1D-12-1D-12L2-1D-12L2 9,408.20 9,425.00 45.15 26.24 23.66 Pass-Major Risk 1D-12-1D-12L3-01 -1 D-12L3-01_wp01 10,615.15 10,625.00 4.96 1.39 4.63 Pass-Minor 1/10 1D-12-1D-12L3-02-1 D-12L3-02_wp01 9,604.33 9,625.00 111.99 1.48 111.76 Pass-Minor 1/10 1D-12-1D-12L3-03-1D-12L3-03_wp01 9,603.30 9,625.00 116.32 1.51 116.09 Pass-Minor 1/10 1D-28-1D-28-1D-28 11,079.45 10,300.00 349.92 31.16 321.48 Pass-Minor 1/10 10-28-1D-28L1-1D-28L1 11,079.45 10,300.00 349.92 31.29 321.35 Pass-Minor 1/10 Kuparuk 1M Pad Kuparuk 28243-1 -Kuparuk 28243-1 -Kuparuk 28 10,528.81 8,300.00 455.55 432.48 58.22 Pass-Major Risk Offset Design Kuparuk 1D Pad- 1D-12-1D-12-1D-12 Offset Site Error: 0.00 usft Survey Program: 115-MWD 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) Fl (usft) (usft) ("I (usft) (usft) (usft) 9,000.00 6,522.81 9,000.00 6,522.81 0.19 0.24 119.38 237.58 5,648.50 6-5/16 0.00 3.39 -2.14 FAIL-Major Risk,CC,ES,SF 9,025.00 6,539.22 9,025.00 6,539.22 0.34 0.53 119.46 238.35 5,667.34 6-5/16 0.00 4.81 -3.02 FAIL-Major Risk 9,049.97 6,555.18 9,050.00 6,555.74 0.50 0.83 -96.63 239.00 5,686.09 6-5/16 0.72 6.24 -1.34 FAIL-Major Risk 9,074.48 6,569.17 9,074.96 6,572.36 0.67 1.12 -110.22 239.54 5,704.70 6-5/16 3.87 7.69 0.39 Pass-Major Risk 9,098.02 6,580.53 9,100.00 6,589.08 0.84 1.41 -115.77 240.24 5,723.33 6-5/16 9.88 9.11 5.46 Pass-Major Risk 9,120.07 6,589.18 9,125.00 6,605.71 1.01 1.69 -118.47 241.41 5,741.96 6-5/16 18.32 10.47 13.28 Pass-Major Risk 9,140.41 6,595.37 9,150.00 6,622.30 1.18 1.98 -120.46 243.04 5,760.59 6-5/16 28.92 11.80 23.41 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 11/20/2017 12:49:56PM Page 2 COMPASS 5000.14 Build 85 tiO • .•. 01 . 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Wellbore API/UWI Held Name Wellbore Statusncl(°I MD(ftKB) Act Btm(ftKB) cntr,lu -.cp� 500292294800 KUPARUK RIVER UNIT PROD 1 50.86 6,650.07 9,250.0 --. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-10-12,10/30/20175 1050 PM SSSV:NIPPLE 50 11/23/2015 Last WO: 11/18/2003 104.30 9/20/1999 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Dale HANGER;22.7 N-.: ". Last Tag SLM 9,078.0 2/23/2016 Rev Reason PERF&FISH IN HOLE--SEE pproven 10/30/2017 NOTES Casing Strings Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 121.0 121.0 62.58 H-40 WELDED I,, ,f Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...r Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 34.6 5,640.9 4,327.5 40.00 L-80 BTC I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 30.9 8,695,5 6,323.0 26.00 L-80 BTC-MOD CONDUCTOR,35.0-1210 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOW L2 4 2.992 9,100.0 9,110.0 6,595.7 9.30 Ink Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread NIPPLE;499.6 ,„ WINDOW L1 4 2.992 9,135.0 9,145.0 6,619.0 9.30 Mr Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 31/2 2.992 8,542.0 9,248.3 6,687,2 9.30 L-80 EUE8RDMO D Mt Liner Details GAS LIFT;2,963.1 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Teel(") Item Des Com _ (in) 8,542.0 6,223.2 50.35 HANGER BAKER SLZXP LT PACKER&HANGER w/PBR 3.500 8,559.0 6,234.1 50.29 SBE SEAL BORE EXTENSION 2.992 GAS LIFT;4,727.3 Tubing Strings Tubing DescriptionISlring Ma ID ID(in) Top(ftKB) I Set Depth(ft..f Set Depth(TVD)(,..I Wt(lb/ft) I Grade I Top Connection TUBING 4.5"x3.5" 11 4 1/2 3.958 22 7 8,508.11 6,201 6 12.60 L-80 IBT-MOD GAS LIFT;5,524.7 Completion Details Nominal ID ` [ Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com - (in) 22.7 22.7 0.00 HANGER FMC TUBING HANGER 4.500 SURFACE;34.6-5,640.9 499.6 499.4 3.60 NIPPLE CAMCO DB LANDING NIPPLE 3.813 8,408.5 6,137.6 49.61 NIPPLE CAMCO DB NIPPLE 3.750 GAS LIFT',6,651.0 8,446.1 6,161.9 50.03 XO Reducing CROSSOVER 4.5 x 3.5,ID 2.992,#9.3,L-80,EUE 8RD 3.500 8,453.5 6,166.6 50.06 PBR BAKER 80-40 PBR 3.000 GAS LIFT 7.653.9 8,467.1 6,175.4 50.12 PACKER BAKER RETRIEVABLE PACKER 3.000 8,490.7 6,190.4 50.21 NIPPLE CAMCO DS NO GO NIPPLE 1.810 FISH;8,104.0 8,501.8 6,197.5 50.26 OVERSHOT POOR BOY OVERSHOT 3.750 PATCH;8,1280 1 f Tubing Description 'String Me...I ID(in) (Top(ftKB) (Set Depth(B..J Set Depth(ND)(..11/4t(Iblft) (Grade (Tap Connection TUBING Original 3 1/2 2.992 8,502.0 8 542 01 6,223 2 9.30 L-80 EUEBrdMOD Completion Details GAS LIFT;8,355.7 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Com (in) 8,531.4 6,216.5 50.38 NIPPLE CAMCO'D'NIPPLE NO GO PROFILE,MILLED TO 2.80" 2.800 APERF;8,387.0-8,376.7- la 8,538.6 6,221.1 50.36 LOCATOR BAKER LOCATOR 3.000 NIPPLE;8,408.5 a:. 8,540.0 6,222.0 50.35 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) y y Top(ND) Top Incl I ) Top(RKB) (ftKB) 7) Des Com Run Date ID(in) PBR,8,453.5 (. 8,104.0 5,935.3 47.54 FISH FISH.6"x0.8" 5/9/2017 0.000- PACKER;8,467.1 I- 8,128.0 5,951.5 47,59 PATCH 4.5"WEATHERFORD PACKER MID ELEMENT 7/31/2008 2.250 w� @8143.3.75"PATCH ASSY IN LOWER ER PKR NIPPLE REDUCER;8490.7 ,:' (OAL-13.75',ID 2.25")TOP OF PKR @8128 NIPPLE;8,490.7, 11�: 8,490.0 6,190.0 50.21 SAND 1.81"C-LOCK W/20'SAND SCREEN @ 8490'RKB 2/23/2016 >f SANG SCREEN;8,490.0 jfSCREEN yyi� _ _ '°°{11 8,490.7 6,190.5 50.21 NIPPLE D-NIPPLE REDUCER 7/28/2008 1.810 OVERSHOT;8,501.8 I- REDUCER if 9,043.0 6,551.1 48.53 STRADDLE STRADDLE ASSEMBLY SET w/NEW LATERALS 7/10/2008 2.375 NIPPLE;8,531.4 - ASSY LOCATOR',8,538.6 Perforations&Slots SEAL ASSY',8,540 0 Shot Dens e Top(ND) Btm(ND) (shots /f Top(ftKB) Btm(ftKB) (ftKB) (RKB) Zone Date t) Type Com 8,387.0 8,3767 6,123.7 6,116.9 C-1,C-2,1D- 10/25/2017 4.0 APERF 2"x 2'TBG PUNCH(4 12L1 spf,0°phase) 9,001.0 9,031.0 6,523.5 6,543.2 UNIT D,C-4, 4/2/2004 6.0 APERF 1D-12 9,051.0 9,065.1 6,556.4 6,565.8 C-4,ID-12 4/2/2004 6,0 RPERF COVERED BY 2 3/8" PRODUCTION;30.9-8,695.5 STRADDLE ASSEMBLY APERF,9,001.0-9,031.0 w/SIDETRACK 9,064.0 9,089.0 6,565.0 6,581.7 C-4,C-3,10- 11/8/1999 4.0 APERF COVERED BY 2 3/8" RPERF;9,051.0-9965.1 I 12 STRADDLE ASSEMBLY STRADDLE ASSY;9043.0 w/SIDETRACK APERF;9084.0-9,089.0 9,136.0 9,138.0 6,613.0 6,614.3 C-1,1D-12 6/17/2008 6.0 APERF Pre-CTD squeeze perfs 9,171.0 9,181.0 6,636.2 6,642.8 C-1,1D-12 11/5/1999 4.0 IPERF 2.5"HC,DP,180 deg+/- 90 deg low side WINDOW L2;9,100.0-9,110.0 Mandrel Inserts sl k ani Top Valve Latch Port Size TRO Run LINER Li;9,133 8-10,6950 N Top(ftKB) (ftKB)KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com APERF;9,136.0-9,138.0 A 1 2,963.1 2,585.7 CAMCO KBG-2 1 GAS LIFT GLV BK 0.156 1,252.0 11/10/2015 SOZ;9,136.0 ftKB WINDOW L1;9,135.04145.0 2 4,727,3 3,734.8 CAMCO KBG-2 1 GAS LIFT OV BK 0.188 0.0 11/10/2015 IPERF;9,171.0-9,181.0 3- 5,524,7 4,251.8 CAMCO KBG-2 I 1 GAS LIFT DMY BK-5 0.000 0.0 7/20/2014 4 6,651,0 4,9801 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/26/2014 5 7,654,0 5,633.9 CAMCO KBG-2 1 GAS LIFT DMY BKO-3 0.000 0.0 5/27/2014 LINER;8,5420-9 248.3 KUP PROD • 1D-12 ConocoPhillipsE Alaska,Inc. -c'ocoxYNpc DEVIATED-17-12,10/30/2017 5'.17.51 PM Vertical schematic(actual) HANGER;22.7 —17_jig& t I _ -- Mandrel Inserts .__ ., St ah �-[- °n Top(ND) Valve Latch Port Size TRO Run rYk. 3j':. N Top IRKS) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 6 8,355.7 6,103.2 CAMCO KBG-2 1 GAS LIFT DMV BK-5 0.000 0.0 11/26/2003 110°°I�'conloucroR;35.o-1z1.o N'n Notes:General&Safety End Date Annotation NIPPLE;499.6 7/20/2008 NOTE L1 DRILLED 7/11/2008,L2 DRILLED 7/20/2008 5/9/2017 NOTE:Piece of ER Pulling tool,left in well @8,104'RKB Broken dog-0.6"x 0.8" 4-_3 GAS LIFT;2,963.1 GAS LIFT;4,727.3 9III GAS LIFT;5,524.7—.4.: le S SURFACE;34.6-5,640.9—k t GAS LIFT; 0-4 } GAS LIFT;7.653.9 4 -1- FISH;8.104.0 PATCH;8,128.0 Q D GAS LIFT;8.355.74 IN APERF;8,387.0-8,376.7 NIPPLE;8,408.5 27411 PBR;0,453.5 , , PACKER;8,467.1 _ NIPPLE REDUCER;8,490.7 11.1 NIPPLE;8.490.71 I SAND SCREEN;8,490.0 ) OVERSHOT;8,501.8 Li j 111 NIPPLE;8,531.4 _— LOCATOR;8.538.6 I, SEAL ASSY;8,540.0 PRODUCTION;30.9-8,695.5 APERF;9,001.0-9,031.0 RPERF;9,051.0-9,085.1 STRADDLE ASSY;9,043.0 APERF;9,064.0-9,089.0 WINDOW L2;9,100.0-9.110.0 k h LINER L1;9,133.8-10,695.0 APERF;9,136.0-9,138.0 SOZ;9,136.018(6 WINDOW L1;9,135.0-9,145.0 'k I IPERF;9,171.0-9,181.0 LINER;8,542.0-9.248.3 1 1 , •k -,.aIT .1 _ .2 , 0o t 14 �r t,-r 1 Tt{ 1 t -1-47----t --Lf-------,----r----;'. ,' I ao@ ? 1.- r F 0 1 _-- " . � t - - , . 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Nt JM N' m 4.0.4- N-13.CI M ,n Q('� m CO mOD� 'gocoh. m��° `o Yam mrnrnrnrn inM.-� t o • • TRANSMITTAL LETTER CHECKLIST WELL NAME: ki2(A, th- IZ 1,3 PTD: Q J(3 Development— Service Exploratory Stratigraphic Test Non-Conventional p ry FIELD: �V POOL: am4QV& 41)6(r J 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 existin well Permit LATERAL No. /99- (Sg I , API No. 50-O2 - j z - ad_ oc) (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 • • 00 o w p a) N o . co __ 3. N C 0 t. Q 2. 0 Ea). , , , . tilo O ° p c` , 0. Ui . 0 a), a) W. c c . E. ao. E O , m, -°. , ' o . . ' ' ' co a . . . C) .. o O, 7 U) a V w 3 , . . , 2.. 3 , c, , ; , v, v v, 2 0 a C r > N > C J, O co J Q. d . C, �, � p o, I y 3,, , Q .d a 01 �, 3 ° k+, y Y a O E, 0 • 2, c, .c. r. �i N' «Y' V? N' �i I- 5, . O, U y k E' :: pp d a I. . > 8, ' a' . E. . a O 6, 0' . O ..4 4 0, a 06 a' a ar 2 �, a. 3. ° N 10 _ . ° ., cp t0 . Y , U �, o, D ao c. 0 c E `t E. Y, N a) . �. y. . >r y, . .y gi CO, o, , E. Y' c_ ° 4 a) 7 W O o, p v) va 2. c, C' a a �, co a.• o E o coca. 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