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CO U aE _ct C7 E a a E E O G 0 1 0 • 21 (o ConocoPhillips0 Transmittal #1195 Detail Date: 12/7/2016 To (External Party): From (CPAI Contact): Email*: merdith.guhl@alaska.gov Email*: Richard.E.Elgarico@conocophillips.com First Name*: Meredith First Name*: Ricky Last Name*: Guhl Last Name*: Elgarico Phone 9077931235 Phone Number: 9072656580 Number: Company: AOGCC Company: ConocoPhillips Address: 333 W. 7th Avenue Address: 700 G Street City: Anchorage City: Anchorage State: AK State: AK Zip Code: 99501 Zip Code: 99501 Transmittal Info Sent Via: email Tracking #: Justification: Compliance Data Detail Quantity*: Description*: Type*: 2S-09 Chromatograph, Lith 4 Cuttings, Lith Interp, & Mudlog LAS LAS Files Attachments: alAXA R= -d By: S'= • .ture: Date: over: - - ature: Date: 1 �&rr /C di • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: oil❑ Gasp SPLUG❑ Other ❑ Abandoned O • Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q. Exploratory 0 GINJ 0 WINJ 0 WAG❑ WDSPL❑ No.of Completions: Service ❑ , Stratigraphic Test 0 2.Operator Name: 6.Date Comp.,Susp.,or wi of tto 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Abend.: 44319/2919 t.i- 216-098/316-517/ 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 9/14/2016 50-103-20749-00-00 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 3062'FNL,1496'FEL,Sec 17,T1ON,RO8E,UM 9/30/2016 KRU 2S-09, Top of Productive Interval: 9.Ref Elevations: KB:159 17.Field/Pool(s): N/A GL:120 BF: Kuparuk River Field/Kuparuk Oil Pool, Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: 4690'FNL,5217'FEL,Sec 9,T1 ON,ROBE,UM 2997/2743 . ADL 25603,ADL 25589,ADL 25590 • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 481074 y- 5929986 Zone- 4 11584/6303 • 2675,2676,2677,2678 TPI: x- N/A y-N/A Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 482631 y-5933634 Zone- 4 NONE 1399/1370 5.Directional or Inclination Survey: Yes 0 (attached) No j] 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) 1 N/A 22.Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 MC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res1 4 V 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 39 119 39 119 24 Pre-Driven Cement to Surface 10.75 45.5 L-80 39 2892 39 2661 13.5 1080 sx 11ppg Class G,286 sx 15 8 ono Clas¢A 7.625 29.7 L-80 2972 7247 2737 6264 9.875 Stag 1:484 sx 15.8 ppg Class G Stage 2:247 sx 15.8 Class G 24.Open to production or Injection? Yes ❑ No 0 25.TUBING RECORD If Yes,list each interval open(MD/ND of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 31/2 7985 N/A NOTE:7.625 INTERMEDIATE 1 WAS CUT AND PULLED WITH ABANDONMENT PLUG AND RE-DRIFTED AS 2S-09A 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes 0 No EI Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Cement @2440-2972 60.1 bbls 17ppg Class G cement @7007-8373 58.8 bbls 15.8 ppg,Class G 27. _ PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-011 Ratio: Test Period -0 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rale Form 10-407 Revised 11/2015 VT(_ 10/..z5-7 / 7tONTINUED ON PAGE 2 Submit ORIGINIAL only Ply - AF /0A.0/7 D�i RBAS Lt_ L - 6 2U16CI d \( O RECEIVED • STATE OF ALASKA •• NOV 2 $ 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN ► a • •►f- ,asla.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned 0 Suspended ❑ lb.Well Class: 20AAC 25.105 20MC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: ,v Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Corinp.,Susp.,or(o'11l16 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. band.: 40/0/2016 . 216-098/316-517/ 3.Address: 7. Date pudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 9/14/2016 50-103-20749-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3062'FNL, 1496'FEL,Sec 17,T1ON, RO8E, UM 9/30/2016 KRU 2S-09 Top of Productive Interval: 9.Ref Elevations: KB:159 17. Field/Pool(s): N/A GL: 120 BF: Kuparuk River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4690'FNL,5217'FEL,Sec 9,T1ON, ROBE, UM 2997/2743 ADL 25603,ADL 25589,ADL 25590 4b. Location of Well(State Base Plane Coordinates, NAD 27): '`` 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 482631 B10"4A y- 34"S412`4'1$6 Zone- 4 11584/6303 2675,2676,2677,2678 TPI: x- N/A y- N/A Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 482631 y- 5933634 Zone- 4 NONE 1399/1370 5.Directional or Inclination Survey: Yes 0 (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/iyttk. .tom "r7 .-:'4'C''1'."7--.� { 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 62.5 H-40 39 119 39 119 24 Pre-Driven Cement to Surface 10.75 45.5 L-80 39 2892 39 2661 13.5 1080 sx 11 ppg Class G,286 sx 158nnaClass G 7.625 29.7 L-80 39 2892 39 6369 9.875 Stag 1:484 sx 15.8 ppg Class G Stage 2:247 sx 15.8 Class G 24.Open to production or injection? Yes ❑ No III 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2 7985 N/A 4t4AN6NFo 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No III Per 20 AAC 25.283(i)(2)attach electronic and printed information (o/n//L?- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Cement @2440-2972 60.1 bbls 17ppg Class G cement @7007-8373 58.8 bbls 15.8 ppg,Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -# Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 RBDMS L DEC - 2016 Submit ORIGINIAL on? • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No ❑ Permafrost-Top Surface Surface Permafrost-Base 1399 1370 Top of Productive Interval N/A N/A Formation at total depth: 4/vy�it Aril A""t 31. List of Attachments: Daily Operations Summary, Definitive Survey,Cement Reports,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results.Der 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo A 265-1487 Email: Haibin.Guoacop.com Printed Name: G. Ivord 11 Title: Alaska Drilling Manager Signature: "(Se via,—,� uCtc\ Phone: 265-6120 Date: �-Z- -?9 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and 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. Submit ORIGINAL Only • • 25-09 -- GEOLOGICAL MARKERS NAME MD ND Permafrost Top Surface Surface Permafrost Base 1399 1370 Top of Production Interval N/A N/A West Sak D 1956 1853 C-80 3208 2921 C-37 5288 4860 HRZ 6725 6025 Kalubik 6972 6155 Kuparuk C(top C4) 7433 6316 Kuparuk A5 7468 6324 Kuparuk A4 7504 6330 TD(A4) 11524 6303 Formation at TD Kuparuk A4 Co{r(c KUP PROD • 2S-09 ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska, , Wellbore APVUWI Field Name Wellbore Status nU 1') MD(NKB) Ac10Un(BNB) Inc. ; 501032074900 KUPARUK RIVER UNfT PROD 95.16 10,968.90 11,584.0 <wiva Ifs - Comment 82$(ppm) Date Annotation End Date NBGrd(N) -Rig Release Date 25.09,6/21/2017 220:18 PM 39.10 10/28/2016 vertical schematic(actual) ' Annotation Depth BM) End Date Annotation last Mod By End Dale Last Tag: 11/17/2016 Rev Reason:NEW WELL pproven 11/17/2016 Casing Strings Casing Description OD(in) ID(in) Top(DNR) Sal Depth(MB) Set Depth TWO)...Wiflen(I...Grade Top Thread Intermediate 75/8 6.875 2972.0 7247.0 6,263.9 29.70 L-80 Hyd563 SL,m > Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) NANGFR;363�� i t ` !�2( Top(61(8 ii T BM) 7) Top Incl Des Com Run Date ID(16) 2,972.0 2,722.4 33.38 BRIDGE RIH and set CIBP in 7-5/8'casing with top at 2972'to 10/7/2016 C J PLUG abandon lateral and set cement kickoff plug.(CAST IRON) 7,052.0 6.191.1 65.04 Cement RIH and set cement retainer in 7-5/8'casing a17052' 10/6/2016 Retainer to abandon 6.314'lateral Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date 500,000.0 466.500.0 11/10/2016 Proppant Designed(Ib) Proppant In Formation pb) Oats 600,000.0 599.930.0 11/14/2016 ,....,,,,,,,,..,..,,,,,,,,,,,,,,,,,,,..„,,. i„.T,, J Cement Squeezes Top(1V8 elm(TVD) Top(908) Blm(f1N8) (BNB) (MB) Des Stool Dale Com 7,007.0 8,373.0 6,171.5 6,332.4 6-3/4'Lateral 10/612016 Cementers pump 10 bbls water and pressure lest Abandonment lines to 550/3500 psi-good test.Pump 58.8 bbls Plug 15.8ppg Class G cement at 4.5 bpm,1576 psi, holding 800 psi backpressure through nig choke to minimize u-tubing.Shut chokes to hold pressure while swapping from cement to water.Cementers pump 5 bbls of water at 3bpm,240 psi and sling into cement retainer.Bleed off backside pressure,open bag,and line up to rig pump.Pump 62 buts 1 O.oppg FloPro wl dg pump.Staged up to 1.5 bpm,1578 psi for 14.5 bbls and then observed pressure start to increase up VII I to 2860 psi with no breakover.Decreased rate 10 1 bpm and observed pressure breakover at 3039 psi. Continued pumping at 1 bpm,observing pressure climb to 3286 psi atter 36.5 bbls pumped and then continue to fluctuate between 3000-3200 psi.Shut down after 62 bbls pumped and observe pressure fall to 2400 psi.Sling out of cement retainer and pull out SURFACE;30.7-0022.0 of hole 4 x stands slowly to 6644'. CONDUCTOR;30.1-119.1 INTERMEDIATE 2:3724129.9 Cement in place Q 00:06 hrs. Squeezed 52 bbls of 15.8ppg Class G cement below cement retainer. �, Estimated top of cement inside 7-5/8'casing @ 6903' an C 2,440.0 2,972.0 2,270.8 2,722.4 Intermediate 1019/2016 Line up to cement unit 8.start batch mixing 17ppg Kickoff Plug cement.Pump 5 bbls of water to flood lines at 4 bpm, 137 psi.Test lines to 600/4000 psi.Reset high trip to 2500 psi.Batch mix 12.Sppg mudpush and pump at 6.5 bm,127Nets.Pum IMmd ereate wckoe Plow Class G cement at 6 bpm,1150 psof 35.i for total of 60.1ppg 2.440.0 face BRIDGE PLUG:2.9/20 bbls.Pump 12.5ppg mudpush at 4 bpm,30 psi or total of 4 bbls.Flush lines to rig floor wl 1.5 bbls mudpush.Swap to rig and pump.9.2ppg WBM at 6 bpm,76-350 psi for total of 28.6 Ibis.Observed pressure rapidly increase to 350 psi after 24.5 bbls pumped as fluid caught falling cement. Notes:General&Safety End Dale Annotation 11/17/2016 NOTE: flIkfW Cement Retairer;7.0520 F'.��__mr=.�- I " mo fi = . Inlerma Gale;2.972.0-7,247.0 6-3/4"Lateral W ralAntlornsenl M Pkg.70070 1000 KUP PROD 2S-09 ConocoPhillips 0 Well Attributes • Max Angle&MD TD Alaska,Inc. Wellbore APUINrI Field Name Wellbore Status •Intl 7) MD(ROB) Act Btm(ROB) IY6rR 501032074900 KUPARUK RIVER UNIT PROD 95.16 10,968.90 11,584.0 ••• .„„ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2S-09,6/21/2017 220:18 PM 39.10 10/28/2016 Vediral schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 11/17/2016 Rev Reason:NEW WELL ppmven 11/17/2016 Casing Strings Casing Description OD(in) ID(in) Top(ROB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Intermediate 7 5/8 6.875 2,972.0 7,247.0 6,263.9 29.70 L-80 Hyd563 00p `: Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) HANGER;35.3—� (1[)tai ... Top(TVD) Top Intl Top(MB) (ftKB) 7) Des Com Run Date ID(in) 2,972.0 2,722.4 33.38 BRIDGE RIH and set CIBP in 7-6/8”casing with top at 2972'to 10/7/2016 PLUG abandon lateral and set cement kickoff plug.(CAST n r IRON) LI L 7,052.0 6,191.1 65.04 Cement RIH and set cement retainer in 7-5/8'casing at 7052' 10/6/2016 Retainer to abandon 6-3/4"lateml Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date 500,000.0 466,500.0 11/10/2016 Proppant Designed(Ib) Proppant In Formation(lb) Date 600,000.0 599,930.0 11/14/2016 ] Cement Squeezes Top(TVD) Bbn(TVD) Top(ftKB) Blur(Ron) (ftKB) (61(8) Des Start Date Com 7,007.0 8,373.0 6,171.5 6,332.4 6-3/4'Lateral 10/8/2016 Cementers pump 10 bbls water and pressure test Abandonment lines to 550/3500 psi-good test.Pump 58.8 bbls Plug 15.Bppg Class G cement at 4.5 bpm,1576 psi, holding 800 psi backpressure through rig choke to P$ minimize u-tubing.Shut chokes to hold pressure while swapping from cement to water.Cementers pump 5 bbls of water at 3bpm,240 psi and sting into cement retainer.Bleed off backside pressure,open bag,and line up to rig pump.Pump 62 bbls 10.Oppg FloPm w/ rig pump.Staged up to 1.5 bpm,1578 psi for 14.5 bbis and then observed pressure start to increase up to 2860 psi with no breakover.Decreased rate to 1 bpm and observed pressure breakover at 3039 psi. • Continued pumping at 1 bpm,observing pressure climb to 3286 psi after36.5 Obis pumped and then continue to fluctuate between 3000-3200 psi.Shut down after 82 bbls pumped and observe pressure fall -- to 2400 psi.Sting out of cement retainer and pull out SURFACE;38.7.2,822.0 of hole 4 n stands slowly t0 6644'. CONDUCTOR;39.1-119.1 INTERMEDIATE 2:372.8.1299' Cement in place 00:06 hrs. Squeezed 52 bbls of 15.Bppg Class G cement below cement retainer. Estimated top of cement inside 7-5/8"casing @ 6903' MD. 2,440.0 2,972.0 2270.8 2,722.4'Intermediate 10/9/2016 -Line up to cement unit&start batch mixing 17ppg Kickoff Plug cement.Pump 5 bbls of water to flood lines at 4 bpm, 137 psi.Test lines to 600/4000 psi.Reset high trip to 2500 psi.Batch mix 12.5ppg mudpush and pump at R Pbg: 5.5 bpm,127 psi for a total of 35.5 bbls.Pump 17ppg Intermediate Kickoff 2,440D f miff Class G cement at 6 bpm,150 psi for total of 60.1 BRIDGE PLUG;2,972.0 bbls.Pump 12.5ppg mudpush at 4 bpm,30 psi for total of 4 bbls.Flush lines to rig floor w/1.5 bbls mudpush.Swap to rig and pump 9.2ppg WBM at 6 bpm,76-350 psi for total of 28.6 bbls.Observed pressure rapidly increase to 350 psi after 24.5 bbls pumped as fluid caught falling cement. Notes:General&Safety End Date Annotation 11/17/2016 NOTE: t, Cement Retainer;7,052 0 I,wp seses ';: v rYr Intermediate;2,972.0-7,217.0 Yw 6-314•Lateral Abandonment .:.,. Plug 7,007.0 rose w►' . . 2S-09 ConocoPhillips Proposed P&A Schematic 10/05/2016 CAMERON ,6"Conductor to-120' A 13.5" Surface Hole TOC: 2572'MD West Sak Sand:T 1,960'MD/1,853'TVD B 2,748'MD/2,596'ND A Surface Casing _ 10-3/4" 45.5# L-80 Hydril 563 2,822' MD/2,596'TVD (31' INC) 'l Bridge Plug 2997' MD 9-7/8" x 11" Intermediate Hole TOC: 5723'MD Growler(Iceberg):5,420'MD/4,986'TVD TOC: 7007'MD Cairn 4057',MD15,5,44"TVD Cement retainer: 7052'MD Bermuda 6,1a `MDf5.653''TVD \lir s, HRZ:6,725'MD/6,025'ND Kalubik:6,972'MD/6,159'ND 1 Kuparuk C.7,443'MD l6 318 TVD Kuparuk A4:7,504'MD/6,331'ND Jntermediate Casino 7-5/8" 29.7# L-80 Hyd563 Casing-•- 7,24T MD/6,264'TVD (71° INC) --- Current TD:11,584'MD/6,302'TVD Original planned TD:13,757'MD 1 6-3/4" Production Hole 6,349'ND cotyecttc_d • • • 2S-09A ConocoPhillips Proposed SideTrack Schematic 10/07/2016 _ .• '. CAMERON . 16"Conductor to-120' ' 13.5" Surface Hole • West Sak Sand:T 1,960'MD/1,853'TVD B 2,748'MD/2,596'ND A\ : Surface Casing 10-314"45.5#L-80 Hydril 563 - - 2,822'MD/2,596'TVD (31' INC) • 9-718" x 11" Intermediate Hole . . ,, 91.1(lir !• Hug i, n72' I' ail i) i: ?,': • tr` 2"'Stage TOC: 4918'MD,500MD above C-37• I, [ .., Stage Collar:5,518'MD *-40,,iliiiii,tii,.401i., .,1Viiiitalifit'''`iail':1.111:441T,I5460.`1,11ftv414-11 ,,\\1 '''''.'t! tfitikt4,it;•::11:1,,,tvi p':!,',,t,i!i;t•,:t',:[v.1, . .'01, 1 itPirlit . -' 1 14441 '' ,,,,,.i..4.010.,,,,!:„, . ,.., , ::':• : .• .,.:,''' ' .\\\'' ',.' ',I':4 RI,eitg 1,49fIgthlk•iigt000',6i;;;Pilli:tb.)??:1?ilVt..it!.111:nw.11/4..1!:,,,,••:,..!:•,,,...,,,...‘...1r.,,4:,t.....u:-1,..„,..::,•,..j ..:::•:::, . '- '•-•':.•'-'0 '..'::-.:'::-''''' '.-' ::.*:/..:''' --:.. • OrOWlei'lliebisiii0014AliOTY .":;"' -' . . ., .•.: . .. .... • • . .•.-. ..„,,, ,, , ._ .• •.•••••••.•••.,•,•. . . .., , ..:,...• ' -'•' •• • :- , • -- • • , . • . . .....,.: , MD i .. -,...i' Stage ICL at top . ' \•„(.9,1•?kl\.-@1:.iti.Y.Q. • ',.--,-•,••-%.',,'.•.;.\\\:,:,'...•-•:-.',,'--:-.::,. .:•','';';;,.:.1'.''',''":":':::'.- , „._."....'...-!....f.,„.0.0...... ',:;:i••t••b••k\•i‘tte.iiiitit.:'f ...,-V.-.•....,.\:":.\::.,•-;\.,..::,:..•;•..:•-.-2--.\:N''::':-,:\'-:'•N`-.::--:.`I.:-:‘\;''-:‘,..\-.:-''.•:;\:\•.::--:.•\-::-:..•--.:-...-\---:-;•\:\-\\:\.':`'.-..‘.i.: ",\;-:.-...;.t;'%•.-*•:.•:-,•':':,.<...•.:::N••:-‘‘,.'%_:-•:'2, .,;',';'".'•:•'-`:\',-•,',\.'S Calm (521Ns\ N •X. ' , cZ• 1eiica '41. kr18A344) ':'•,':'\', .,, a 7 . 1.• - .. - HRZ:8,,875'MD AL025'ND ., . Kalubik:7,187'MD/8,159'TVD • .. Kuparuk C:7.981'MD I 6.318'TVD — • Kuparuk A4:7,504'MD I 8,331'ND • "..: : 1 . • '..i — --r ,.. • . .... , jr101111Dr1taft 01153iJia 7-5/8" 29.70 L-80 Hyd563 Cas-IN intermediate Casing • 7,247'MD/6,264'TVD (71° INC) 7-5/8" 29.7#L-80 Hyd563 Casing TD:14,171'MD/6,339'TVD 8,155'MD/6,339'TVD0-1'RT/4w-Production Hole . ID • ,...., 2S-09A ConocoPhillips Proposed SideTrack Schematic 10/07/2016 CAMERON SUPERSEUEL ! ,1,4,. 16"Conductor to-120' A f.ii,.-,. -0, 4,..... 13.5" Surface Hole .45. West Sak Sand:T 1,960 MD/1,853'ND ...... B 2,748 MD/2,596'ND .., _ '''' Surface Casing 10-3/4" 45.5# L-80 Hydril 563 2,822' MD/2,596'TVD (31 INC) , , • 9-7/8" x 11" Intermediate r ' ' Hole ".".'.. ..'' , . 2nd Stage TOC: 4918'MD,500'MD above C-37 .._ L-' Stage Cellar 5,518.MD C-37: ._._ , . ,., , ' \\\,• \ ,. - '. Growler(Iceberg): , \ , 1t ' ...-‘.6;4.74,it'd 1,5,54..,\I )t),-....‘, frfnentre , 1062'0;;-, Bermuda:6,427 81111 — HRZ:6,875'MD/6,025'ND . ',.. Kalubik:7,187'MD/6,159'ND . '... \ \ \ --...... — N KKt.jupoaarurukk AC4:7:7.98 ',5041 .MOmD116.63,313VI.TYDND I 7 •„... '-•-.,... Jn,termediate Casing "..-....,i.,, 7-518" 29.7# L-80 Hyd563 Cas ; , ediate, 47' MD/6,264'TVD (71' )NC) • IntermCasing 2 7-5/8" 29.7# L-80 Hyd563 Casing TD:14,171'MD/6,339'TVD 8,155' MD/6,339' TVD&t°iiiNgoroduction Hole • r ii Operations Summary (with Timelog Depths) 2S-09 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/12/2016 9/13/2016 6.00 MIRU MOVE MOB P Pull odw esll.Mowell ve lg S-0mat6. BaBack web 0.0 0.0 18:00 00:00 base of 2S-09 with grader and spot rig mats. Remove hand rails on wellhouse 2S- 10 and 2S-08.Move sub base over well 2S-09. 9/13/2016 9/13/2016 2.00 MIRU MOVE MOB P PJSM-spot rig mats around 2S-09& 0.0 0.0 00:00 02:00 rig foot print. 9/13/2016 9/13/2016 1.50 MIRU MOVE MOB P PJSM- remove acent to 2S-09 rails f r mle well ull 0.0 0.0 02:00 03:30 houses sub base to spot over well. 9/13/2016 9/13/2016 1.50 MIRU MOVE MOB P PJSM- s spot sub baseid se over rig 2S-09, oor et 0. 0 0.0 03:30 05:00 stwell center,&remove tongue from sub base. 9/13/2016 9/13/2016 2.50 MIRU MOVE MOB P washer spot litmodules.pumps, SIMOmohtor, &p rock 0.0 0.0 05:00 07:30 steam,air,water,mud,&electrical interconnects. 9/13/2016 9/13/2016 1.50 MIRU MOVE MOB P PJSM-spot p t pipe all e ed module. 0.0 0.0 & 07:30 09:00 landings.Pull&connect electrical. Continue berming around the rig. 9/13/2016 9/13/2016 3.00 MIRU MOVE RURD P PJSM- S-continu installramp on skate,&e hooking up 0.0 0.0 09:00 12:00 complete pre-spud checklist.Rig accepted at 12:00 hrs. 9/13/2016 9/13/2016 1.50 MIRU MOVE NUND P PJSM-install riser on surface riser& 0.0 0.0 12:00 13:30 torque bolts on diverter system. SIMOPS bring on spud mud to the pits. Rig swapped to shore power at 13:30 hrs. 9/13/2016 9/13/2016 0.50 MIRU MOVE RURD P PJSM-install mouse hole in the rotary 0.0 0.0 13:30 14:00 le. 9/13/2016 9/13/2016 1.00 MIRU MOVE SFTY P team.Conduct pre-spud meeting with rig 0.0 0.0 14:00 15:00 9/13/2016 9/13/2016 4.00 MIRU MOVE PULD P of PJSM- -5" ckup in tup&drackck using backstands 0.0 0.0 15:00 19:00 mouse hole. 9/13/2016 9/13/2016 3.50 MIRU MOVE PULD P PJSM-pick up&rack back 5 stands of 0.0 0.0 19:00 22:30 5"HWDP&1 stand of 7"NMFC in the derrick,using the mouse hole. 9/13/2016 9/13/2016 0.50 MIRU MOVE BOPE P DP,PJSM-perform e orr closerter test ure time 21 ith,knife h 5" 0.0 0.0 22:30 23:00 valve opening time 6 sec.Initial system pressure 2950 psi,pressure after closure 1950 psi,200 psi recharge time 6 sec,full recharge time 45 sec.Average pressure of 6 nitrogen bottle 2500 psi.Pit&gas alarms tested.Witness of test waived by AOGCC Rep.Brian Bixby. 9/13/2016 9/14/2016 1.00 MIRU MOVE BHAH P PJSM- Maper SLB sDDace BHA#1 to 87' 0.0 87.0 23:00 00:00 9/14/2016 9/14/2016 1.25 MIRU MOVE BHAH P SLB PJSM- f/87ue makiMn g up BHA 1 per 87.0 118.0 00:00 01:15 9/14/2016 9/14/2016 0.25 MIRU MOVE SEQP P PJSM- Spstest thigh pressure mud lines to 118.0 118.0 01:15 01:30 3500 Page 1/58 Report Printed: 10/31/2016 • . 0 Operations Summary (with Timelog Depths) F 2S-09 o coc coPhUlips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/14/2016 9/14/2016 5.00 SURFAC DRILL DDRL P a PJSM-directional al drill 13-1 1 M/2 surface 118.0 559.0 01:30 06:30 hoTVD,550 gpm,1050 psi,50 rpm,Tq on 4K,off 3K,WOB 10K,FO 20%,PU 76K,SO 83K,ROT 83K,MW 9.0 ppg, Max gas 0,ADT 2.67,AST.89,Bit 2.67,Jars 47.56,Total Footage 440' MD. 9/14/2016 9/14/2016 1.50 SURFAC DRILL CIRC P PJSM-circulate while rigging up to run 559.0 559.0 06:30 08:00 gyro,390 gpm,400 psi. 9/14/2016 9/14/2016 4.00 SURFAC DRILL DDRL P PJSM- J holeM- directional on f/ al drill 13-1/2" 'MD,surface 559.0 933.0 08:00 12:00 TVD,550 gpm, 1200 psi,50 rpm,Tq on 5K,off 2K,WOB 23K,FO 21%,PU 85K,SO 91K,ROT 91K,MW 9.1 ppg, Max gas 0,ADT 1.68,AST.49,Bit 4.84,Jars 49.67,Total Footage 374' MD.Run gyro shots on connections f/ 559'to 835'MD. 9/14/2016 9/14/2016 6.00 SURFAC DRILL DDRL P PJSM-directional drill 13-1/2"surface 933.0 1,512.0 12:00 18:00 hole section f/933'-1512'MD, 1473' TVD,550 gpm,1428 psi,50 rpm,Tq on 5K,off 2K,WOB 28K,FO 20%,PU 95K,SO 93K,ROT 93K,MW 9.6 ppg, ADT 4.42,AST 2.7,Bit 9.26,Jars 54.18,Total Footage 579'MD. 9/14/2016 9/15/2016 6.00 SURFAC DRILL DDRL P PJSM-ddiiectioon f/directional rill1 3-1/2" u 1888''rface 1,512.0 1,997.0 18:00 00:00 hoTVD,750 gpm,2170 psi,60 rpm,Tq on 3K,off 2K,WOB 5-28K,FO 25%, PU 108K,SO 103K,ROT 107K,MW 10.0 ppg,ADT 3.34,AST.84,Bit 12.6, Jars 57.52,Total Footage 485'MD. 9/15/2016 9/15/2016 1.50 SURFAC DRILL DDRL P PJSM-directional drill 13-1/2"surface 1,997.0 2,166.0 00:00 01:30 hole section f/1997'-2166'MD,2034' TVD,700 gpm,2150 psi,100 rpm,Tq on 6-7K,off 2-3K,WOB 20K,FO 25%, PU 108K,SO 103K,ROT 107K,MW 10.0 ppg,ADT 1.07,AST 0,Bit 13.67, Jars 58.59,Total Footage 169'MD. 9/15/2016 9/15/2016 1.00 SURFAC DRILL CIRC T Real time decision made to ntrip lost with foBHA 2,166.0 1,979.0 01:30 02:30 LWD,change.CBU 2 times @ 770 gpm, 2250 psi, 100 rpm,Tq 2-3K,f/2166'- 1979'MD. 1,979.0 1,979.0 9/15/2016 9/15/2016 0.50 SURFAC DRILL OWFF T Moe itorDrill CRT72sec @ 03:00 hrs. 02:30 03:00 9/15/2016 9/15/2016 3.25 SURFAC DRILL TRIP T PJSM-TOH f/1979'-747'MD. 1,979.0 747.0 03:00 06:15 747.0 747.0 9/15/2016 9/15/2016 0.25 SURFAC DRILL OWFF T Monitor well,static. 06:15 06:30 9/15/2016 9/15/2016 1.50 SURFAC DRILL BHAH T PJSM-rack back HWDP,Jars,C.Lay down UBHO,MWD&747.0 0.0' LWD, 06:30 08:00 &NM Stab. 9/15/2016 9/15/2016 1.50 SURFAC DRILL BHAH T &MWD toe motorpew bit.NM Stunab ho eD 0.0 746.0 08:00 09:30 with NMFC,Jars,&HWDP to 746' MD. Page 2/58 Report Printed: 10/31/2016 • «, Operations Summary (with Timelog Depths) • >a r{ 2S-09 ,ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Operation (ftKB) End Depth(ftKB) Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X PJSM-TIH f/746'-1660'MD,work 746.0 1,660.0 9/15/2016 9/10/2016 1.50 SURFAC DRILL TRIP T through tight spots at 1117',1504',& 09:30 11:00 1623'MD. 1,660.0 2,070.0 9/15/2016 9/15/2016 2.00 SURFAC DRILL REAM T Ream f/ 16FO 0-212%070'0 rpm,D, TOq 2-3K, gpm, 11:00 13:00 500 PU 114K,SO 103K,ROT 107K. 9/15/2016 9/15/2016 1.00 SURFAC DRILL CIRC T Ci ul t ate9 onditMD.Observdd thick mud ion mud system 2,070.0 2,169.0 13:00 14:00 2w/clay returns blinding off shakers. Stage up pumps to 750 gpm, ICP 500 psi,FCP 2053 psi,FO 24%,50 rpm, Tq 2.5K,PU 115K,SO 103K,ROT 107K. 9/15/2016 9/15/2016 6.50 SURFAC DRILL DDRL P PJ holeM- directionon f/ al drill 13-1/2" 3' surfac2605 2,169.0 2,833.0 14:00 20:30 TVD,780 gpm,2557 psi,100 rpm,Tq on 6-7K,off 4K,WOB 26K,FO 25%, PU 126K,SO 114K,ROT 118K,MW 10.0 ppg,ADT 4.14,AST.94,Bit 17.81,Jars 62.73,Total Footage 664' MD. 9/15/2016 9/15/2016 1.00 SURFAC CASING CIRC P Circulate 33l to& ondition mud 78O gpm,system 249psi, 2,833.0 2,733.0 20:30 21:30 FO 24%, 100 rpm,Tq 4.5K,PU 126K, SO 114K,ROT 118K,7793 strokes pumped. 9/15/2016 9/15/2016 1.00 SURFAC CASING CIRC T Observe Clear lw inflow G pe&e ack off wperenceick 2,733.0 2,733.0 21:30 22:30 mushakers blind off.Clear shakers to resume circulating out thick mud w/ clay.Stage pumps back up to 170-750 gpm,340-2325 psi, 10-100 rpm. 9/15/2016 9/15/2016 1.00 SURFAC CASING CIRC P ZBU f/ 733'10 2626'q 4@K ,PU g26 pm, 2,733.0 2,626.0 22:30 23:30 SO 114K,ROT 118K. 9/15/2016 9/16/2016 0.50 SURFAC CASING OWFF P fluid Monitor well,observe slight drop in 2,626.0 2,626.0 23:30 00:00 9/16/2016 9/16/2016 3.50 SURFAC CASING TRIP P PJSM3blo8' down PU 1DOKOH omSO 2,626.0 388.0 00:00 03:30 2626'-Spill Drill CRT 79 sec @ 03:30 hrs. Jars 388.0 0.0 9/16/2016 9/16/2016 3.50 SURFAC CASING BHAH P PJSM r Lay ack back H BHA WDP, Clean up 03:30 07:00 NMFrig floor. 9/16/2016 9/16/2016 0.50 SURFAC CASING RURD P R/U Casing CRT,equipment u baiment on therigrfloor, 0.0 0.0 07:00 07:30 Volanelevators. 9/16/2016 9/16/2016 6.25 SURFAC CASING PUTB P PJSM baker-P/Uth10 0 3/4ch oshoeeck tracflack good.ats, 0.0 1,437.0 07:30 13:45 Run 10 3/4",45.5#,Hydril 563, dopeless casing,to 1468'MD.M/U torque 19,400#, fill every 10 joints. Rejected joints 5&6-bad pin/box. 9/16/2016 9/16/2016 0.75 SURFAC CASING CIRC P Ci rculat due conditiono extremely th ak ing upo 1,437. 0 1,437.0 13:45 14:30 pu2.5 bpm,235 gpm,128 psi,PU 105K, SO 87K, 2031 strokes pumps. 1,437.0 1,717.0 9/16/2016 9/16/2016 1.00 SURFAC CASING PUTB P dun 10 3/4",5.5#14y3dril563, MD. 14:30 15:30 M/U torque 19,400#, fill every 10 joints. Page 3/58 Report Printed: 10131/201E Alit °I Operations Summary (with Timelog Depths) 2S-09 Conoco Phillips i.uk.3 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/16/2016 9/16/2016 1.25 SURFAC CASING CIRC P Circulate&condition mud staging up 1,717.0 1,758.0 15:30 16:45 pumps,due to loss of down weight f/ 1717'-1758'MD.Stage up pump due to extremely thick mud, 1-4 bpm,400- 170 psi,FO 9%,PU 106K,SO 95K, 1168 strokes pumps. 9/16/2016 9/16/2016 1.25 SURFAC CASING PUTB P dopeless 3/4",5.5#1758'-2249'Hydril 563, 1,758.0 2,249.0 MD. 16:45 18:00 M/U torque 19,400#, fill every 10 joints. 9/16/2016 9/16/2016 1.25 SURFAC CASING CIRC P Circulate&condition mud staging up 2,249.0 2,291.0 18:00 19:15 pumps,due to loss of down weight f/ . 2249'-2291'MD.Stage up pump due to extremely thick mud,1-3 bpm,375- 130 psi,FO 8%,PU 130K,SO 115K, 1944 strokes pumps. 9/16/2016 9/16/2016 1.25 SURFAC CASING PUTB P Run 10 3/4",45.5#,Hydril 563, 2,291.0 2,780.0 19:15 20:30 dopeless casing,f/2291'-2780'MD. M/U torque 19,400#, fill every 10 joints.Ran a total of 68 joints,2 stop rings&68 bow spring centralizers. Rejected 2 joints&no remakes. 9/16/2016 9/16/2016 0.50 SURFAC CASING HOSO P Make up CIW 10.75"hanger&landing 2,780.0 2,823.0 20:30 21:00 joint,run in landing hanger at 2823' MD.PU 155K,SO 94K. 9/16/2016 9/16/2016 0.25 SURFAC CEMENT RURD P PJSM- hose down CRT.top drive,rig up 2,823.0 2,823.0 21:00 21:15 9/16/2016 9/17/2016 2.75 SURFAC CEMENT CIRC P Circulate&condition mud for cement 2,823.0 2,823.0 21:15 00:00 job,staging up pumps,2-7 bpm,ICP 410,FCP 330 psi,FO 4-11%,PU 151K,SO 130K, 9055 strokes pumps. SIMOPS hold PJSM with oncoming crew for cementing. 9/17/2016 9/17/2016 1.50 SURFAC CEMENT CIRC P Circulate&condition mud for 2,823.0 2,823.0 00:00 01:30 cementing,298 gpm,311 psi,PU 152K,SO 130K. 9/17/2016 9/17/2016 2.75 SURFAC CEMENT CMNT P Cement 5 bbls of H20.r /deines tail. to lines 2, 823.0 2,823.0 01:30 04:15 w3500 psi,good.Pump 50.2 bbls of CW -100 at 5.5 bpm,205 psi.Pump 68.6 bbls of 10.5 ppg Mud Push II at 4.5 bpm,190 psi.Drop bottom plug.Pump 360.7 bbls of 11.0 ppg lead cement at 6.5 bpm,225-360 psi. 9/17/2016 9/17/2016 0.25 SURFAC CEMENT CMNT T While pumterspingost prime on lead cement the their pump 2,823.0 2,823.0 04:15 04:30 with 291 bbls away.Pumping was resumed to finish lead cement. Between pumping the lead&tail cement SLB troubleshot the cement unit. Page 4/58 Report Printed: 10/31/2016 Summarywith Timelo Depths) 0.14 2S-09 conocoPt,iiiips Operations ( 9 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth MKS) 9/17/2016 9/17/2016 1.50 SURFAC CEMENT CMNT P Pump 59.1 bbls of 15.8 ppg tail 2,822.0 0.0 04:30 06:00 cement at 4.5 bpm,450 psi.Drop top plug.Pump 10 bbls of fresh H2O at 3 bpm,230 psi.Pump 253 bbls of 10.0 ppg mud at 3-5 bpm,340-665 psi. Plug bumped at 2508 strokes. Pressure up to 1100 psi&hold for 5 minutes.Bleed off pressure to check floats,good. 173 bbls of cement returns to surface.CIP @ 05:54 hrs. After swapping to the rig to displace cement the casing string was picked up to begin reciprocation.The string was picked up 2-3 feet with PU 180K, previous PU was 160K.Slacked off to verify ability to land back on hanger. Unable to slack off to land hanger. Continue attempts to land on hanger with no success.Pick up w/190K,to 18"from fully landed mark,to be able to set emergency slips.Displacement of cement was continuous. 9/17/2016 9/17/2016 0.50 SURFAC CEMENT OWFF P Monitor weor ll at alt s ing j joint & 0.0 0.0 06:00 06:30 begin rigging down cementing equipment. 9/17/2016 9/17/2016 5.00 SURFAC CEMENT WOC T Wait on ment.diverter I e from IMO PS S ii disconnect 0.0 0.0 06:30 11:30 remove.Lay down Volant CRT&put on 150 ton elevators.Remove mouse hole.Clear&clean rig floor.Clean mud pits.Load&strap 5"DP in the pipe shed. 9/17/2016 9/17/2016 1.25 SURFAC CEMENT NUND T PJSM-rig up bridge cranes to annular 0.0 0.0 11:30 12:45 &pick up with diverter tee.Clean cement debris from hanger&starting. 9/17/2016 9/17/2016 0.25 SURFAC CEMENT NUND T PJSM-ttemptweight too stretch to ncasatal,with 0.0 0.0 12:45 13:00 pick emergency slips. 0 9/17/2016 9/17/2016 2.50 SURFAC CEMENT NUND P PJSM-lay down Nipple dowing joint 0.0 annular, .0 13:00 15:30 diverter tee&starting head. 9/17/2016 9/17/2016 1.50 SURFAC CEMENT NUND T PJSM-install landing joint to hanger. 0.0 0.0 15:30 17:00 Pick up to 250K&install emergency slips as per CIW Rep.Remove&lay down landing joint. 9/17/2016 9/17/2016 1.00 SURFAC WHDBOP NUND P PJSM MBS wetall llhead as tpopClW Rep.drive& 0.0 0.0 17:00 18:00 instaTest seals on hanger to 5000 psi for 10 min,witnessed. 0.0 0.0 9/17/2016 9/17/2016 4.50 SURFAC WHDBOP NUND P Phoke/JSM-nipple upnes.riSser, BOP Ean ppits. 18:00 22:30 9/17/2016 9/18/2016 1.50 SURFAC WHDBOP MPDA P Phoke JSM-nipple up RCPSD& position pits& 0.0 0.0 22:30 00:00 grease choke.Pickup 4 stands of 5" DP racking back in derric. 9/18/2016 9/18/2016 3.75 SURFAC WHDBOP MPDA P PJS -NU and run lines. MPD equipment on stack 0.0 0.0 00:00 03:45 SIMOPS-P/U 5"DP&stand back 30 stands. Page 5158 Report Printed: 10/31/2016 • Operations (with Summary Timelog Depths) r 2S-09 conocoPhillips , Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB). End Depth(ftKB) 9/18/2016 9/18/2016 0.50 SURFAC WHDBOP RURD P PJSM-pull mouse hole from from 0.0 0.0 03:45 04:15 roatary table,P/U test joint and set test plug. 9/18/2016 9/18/2016 2.00 SURFAC WHDBOP MPDA P and-PJSM- lt BORE stack,E Test RCD and laR vDlve, 0.0 0.0 04:15 06:15 250 psi/mins 1500 psi/5 min's.Pull test plug. 9/18/2016 9/18/2016 1.25 SURFAC WHDBOP RURD P PJSM-install 5"TJ,R/U to test BOPE. 0.0 0.0 06:15 07:30 9/18/2016 9/18/2016 2.00 SURFAC WHDBOP BOPE T Leakon ed damaged linn sea)troubleshoot.g face and 0.0 0.0 07:30 09:30 Noticsmall gouge on inner Grey lock face. 9/18/2016 9/18/2016 1.00 SURFAC WHDBOP WAIT T f Discuss pland forward line d replacement adjusting grey 0.0 0.0 09:30 10:30 olocks. Service Top Drive,Iron roughneck& draw works. 9 0.0 0.0 9/1 10 3!2016 9/13/2016 1.00 SURFAC WHDBOP BOPE T PJSM piping all new tested piping nkchoke line. 10:30 11:30 9/18/2016 9/18/2016 0.50 SURFAC WHDBOP BOPE P Fill stack and shell test 250/3500. 0.0 0.0 11:30 12:00 9/18/2016 9/18/2016 0.50 SURFAC WHDBOP BOPE T JS-Kill connecline e h s smaeedoff ll leak onpressgrean 0.0 0.0 12:00 12:30 locktighten. Page 6/58 Report Printed: 10/31/201E 0-4 IIIOperations Summary (with Timelog Depths) 2S-09 0,I 0�iilips FP.sks Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Operation (ftKB) End Depth(EKE) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X 0(J 0.0 9/18/2016 9/18/2016 5.00 SURFAC WHDBOP BOPE P Guy CooTest k. waivll h by 5 TJ.0 Rep. 12:30 17:30 250/3500 psi,charted for 5 minutes each. 1)Annular;CV#1, 12,13, 14,4"Kill line Demco on mud manifold,&4-1/2" IF Dart valve. 2)Upper 3-1/2"X 6"VBR's,CV#9,11, Mezzanine Kill line Demco,&4-1/2"IF FOSV. 3)CV#8,10,&HCR Kill 4)CV#6&7. 5)Super choke&manual choke tested to 2000 psi. 6)CV#2,5&Manual Kill 7)HCR Choke 8)Manual Choke&upper Top Drive IBOP 9)Lower 3-1/2"X 6"VBR's&lower Top Drive IBOP. 10)Blind rams,CV#3,4,&6 Accumulator draw down performed w/ 2ea.Air pumps&electric triplex pumps, initial system pressure 3000 psi,after closure 1850 psi,200 psi attained in 10 sec,full pressure attained in 45 sec, 6 nitrogen bottles with an average pressure of 2516 psi. Test pit level&flow out alarms. All H2S and Combustible gas alarms tested.Primary&remote BOP controls were functioned. Initial shell test failed at gray lock connection on choke line,changed out spool because of fluid cut.Re-test shell,failed at gray lock connection on kill line,re-tightened.Re-tested shell passed. 9/18/2016 9/18/2016 0.50 SURFAC WHDBOP BOPE T PJSM-tes t 250/5000 Newly psi,5 iminulled ed ehoke line 0.0 0.0 17:30 18:00 to&rig down test equipment. 9/18/2016 9/18/2016 1.25 SURFAC WHDBOP RURD P PJSM-remove bushing w/10"testIDlugRILDinstall wear e out 0.0 0.0 18:00 19:15 rotary bushings for split bushings. SIMOPS modify trip nipple length. 9/18/2016 9/18/2016 0.25 SURFAC CEMENT PULD P back in tk he dery up 1 stand k. ndSIof 5' D P&rack 0.0 0.0 19:15 19:30 y trip nipple for higher elevation. 9/18/2016 9/18/2016 0.25 SURFAC CEMENT RURD P kill/choke s)atalesrip nipple&blow down 0.0 0.0 19:30 19:45 0.0 783.0 9/18/2016 9/18/2016 2.75 SURFAC CEMENT BHAH P PSM Make up ate BHA 3 per asLB DD to 19:45 22:30 783'MD,PU 87K,SO 92K 9/18/2016 9/19/2016 1.50 SURFAC CEMENT PULD P hole PJSM- hick BHA 3 f/83 single in the 783.0 1,826.0 22:30 00:00 9/19/2016 9/19/2016 1.25 SURFAC CEMENT PULD P PJSM- sM- TIHP f/1826he 2pi58'sMD,picking 1,826.0 2,580.0 00:00 01:15 ued 134K,SO 106K. Page 7/58 Report Printed: 10/31/2011 • Summarywith Timelog Depths) ,, Operations � `"` 2S-09 ConocoPhillips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Operation (ftKB) End Depth(ftKB) Start Time End Time Our(hr) Phase Op Code. Activity Code Time P-T-X 2,580.0 2,h8 •0 9/19/2016 9/19/2016 1.00 SURFAC CEMENT CIRC P Circpress ,ure test atate& d550 gpm, 1500 psicasingition mud for 40 01:151:15 022:15 rpm,Tq 4-6K,MW 10.0 ppg. 9/19/2016 9/19/2016 0.25 SURFAC CEMENT RURD P PJSM-rig up to test casing. 2,580.0 2,580.0 02:15 02:30up to 9/19/2016 9/19/2016 1.00 SURFAC CEMENT PRTS T Atte0 psi empt to tebserve st casing. prPressures u off. 2,580.0 2,580.0 02:30 03:30 1Trouble shoot surface equipment& replace pressure sensator on OA. Pressure up to 1929 psi&observe pressure drop off on test equipment. Trouble shoot&replace test hose. Test surface test equipment to 3500 psi,good. 9/19/2016 9/19/2016 0.75 SURFAC CEMENT PRTS P PJSM- S psitfo10-3/4m nst sa charted. to 2, 580.0 2,580.0 03:30 04:15 3500 Pressure up to 3550 psi with 35 strokes at 5 spm.Shut in&observed pressure for 30 minutes. Initial shut in pressure was 3550 psi.Final shut in pressure was 3530 psi.Rig down test equipment. 9/19/2016 9/19/2016 1.75 SURFAC CEMENT SLPC P PJSM-cut&slip 102'of drill line. 2,580.0 2,580.0 04:15 06:00 9/19/2016 9/19/2016 0.75 SURFAC CEMENT COCF P TOC 2,580.0 2,713.0 06:00 06:45 Wash down to f/2580'-2713' MD,at 84 gpm, 130 psi. PJSM-Drill out cement,plugs,shoe 2,713.0 2,833.0 9/19/2016 0/19/2016 2.50 SURFAC CEMENT DRLG P track&rat hole f/2713'-2833'MD at 06:45 09:15 300-510 gpm,550-1420 psi,50-90 rpm,Tq 4-10K,WOB 10-20K,PU 144K,SO 110K,ROT 122K,MW 10.0 ppg.Drill out shoe with 4K WOB. SCR @ 2770'MD,2562'TVD,MW 10.0,08:24 hrs #1 @ 30=130 psi,@ 40=190 psi #2@30=130 psi,@40= 190 psi PJSM-Ddrill f/2833'-2853'MD,2622' 2,833.0 2,853.0 0 0 0.25 SURFAC CEMENT DDRL P TVD,600 gpm,1775 psi,60 rpm,Tq 09:159/2016 09:309!2016 on 7.5K,off 5K,WOB 10K,PU 144K, SO 110K,ROT 122K,MW 10.0 ppg, ADT.17,Bit.17,Jars 42.29,total footage 20'MD. 9/19/2016 9/19/2016 0.50 SURFAC CEMENT CIRC P C&C mud system for FIT/LOT f/2853'- 2,853.0 2,769.0 2769'MD,650 gpm, 1990 psi,60 rpm, 09:30 10:00 Tq 4-7K,MW 10.0 ppg,pumped 3773 strokes. 9/19/2016 9/19/2016 0.25 SURFAC CEMENT OWFF P Monitor well,static. 2,769.0 2,769.0 10:00 10:15 9/19/2016 9/19/2016 1.25 SURFAC CEMENT LOT P PJSM-rig up test equipment.Perform 2,769.0 2,769.0 LOT to an EMW of 15.7 ppg.Pressure 10:15 11:30 up w/10.0 ppg mud to 810 psi in 11 strokes.Observe pressure decrease to 400 psi.Shut in&observe pressure for 10 minutes.Initial shut in pressure 400 psi.Final shut in pressure 320 psi. Confer with town on test.Blow down& rig down test equipment. Page 8158 Report Printed: 10/31/201 Operations Summary (with Timelog Depths) 0 03,11.i2S-09 croshitlips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Operation (ftK8) End Depth(itK6) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X PJSM-displace well to 9.2 ppg LSND 2,769.0S) 2,h 53.0 11:30 1 12:00 13/2016 9/19/2016 0.50 INTRMI DRILL DISP P f/2769'-2853'MD at 500 gpm,1050 psi,40 rpm,Tq 4-7K,2502 strokes. 9/19/2016 9/19/2016 7.00 INTRM1 DRILL DDRL P PJSM- intermediate directional declt'9-7/8f/"X12853'- 1" 2,853.0 2,962.0 12:00 19:00 2962'MD,2727 TVD,700 gpm,1593 psi,100 rpm,Tq on 5-6K,off 4-7K, WOB 10-30K,FO 23%,PU 144K,SO 110K,ROT 125K,MW 9.2 ppg,ADT 4.1,Bit 4.27,Jars 46.39,Total Footage 109'MD. SCR @ 2944'MD,2708'ND,MW 9.2+, 18:15 hrs #1 @ 30=120 psi,@ 40=160 psi #2 @ 30=120 psi,@40=160 psi 9/19/2016 9/19/2016 1.25 INTRMI DRILL CIRC T Experience problems with directional 2,962.0 2,962.0 19:00 20:15 steering,circulate at 706 gpm,1641 psi,60 rpm,Tq 5K,FO 23%,pumped 12867 strokes.Could not determine cause of steering issue(tools,junk in hole,or geology). 9/19/2016 9/19/2016 0.50 INTRM1 DRILL DDRL P PJSM- di ectiateona drisell 9-7/8 2962'- 2,962.0 3,006.0 20:15 20:45 in3006'MD,2750'ND,700 gpm,1611 psi,100 rpm,Tq on 5-6K,off 4-7K, WOB 2K,FO 23%,PU 144K,SO 110K,ROT 125K,MW 9.2 ppg,Max gas 5, ADT.25,Bit 4.52,Jars 46.64, Total Footage 44'MD. 9/19/2016 9/19/2016 0.25 INTRMI DRILL TRIP P PJSM- SO 1103006'-2924'MD,PU 3,006.0 2,924.0 20:45 21:00 144K, 9/19/2016 9/19/2016 0.25 INTRM1 DRILL CIRC P Open under reamer,drop RFID chips 2,924.0 2,924.0 21:00 21:15 &pump down at 700 gpm, 1603 psi, FO 23%,for 300 strokes.Reduce rate to 200 gpm,235 psi,FO 10%, 150 strokes.Increase rate to 700 gpm. Observed pressure decrease to 1348 psi&MWD turbine speed reduce to 2382 from 2929 previously.Pull test into shoe w/5K overpull to verify reamer open. 9/19/2016 9/19/2016 1.00 INTRM1 DRILL UREM P open rea f/hole f/29to14'3006' gD, o 2,924.0 3,006.0 21:15 22:15 1692 psi,FO 23%,100 rpm,Tq 4-6K, WOB 1-2K,ECD 9.74,PU 144K,SO 110K,ROT 125K,MW 9.3 ppg. SCR @ 2960'MD,2720'ND,MW 9.3,21:45 hrs #1 @ 30=120 psi,@ 40=160 psi #2@30=120 psi,@40=160 psi 9/19/2016 9/20/2016 1.75 INTRM1 DRILL DDRL P PJ5Medi dic ionalhole drilllt 9-7f/3006' 3,006.0 3,146.0 22:15 00:00 interm3146'MD,2866'ND,807 gpm,1735 psi,100 rpm,Tq on 6-8K,off 5.5K, WOB 6-12K,FO 23%,PU 136K,SO 115K,ROT 123K,MW 9.3 ppg,Max gas 38, ADT.75,Bit 5.27,Jars 47.39, Total Footage 140'MD. Page 9/58 Report Printed: 10/31/201( :isw • 0 Operations Summary (with Timelog epths) 2S-09, t.7..„ Cc nocoPhitrps , Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Operation (ftKB) End Depth(ftK6) Start Time End Time Dor(hr) Phase Op Code Activity Code Time P-T-X PJSM directional drill 9 7/8"X11" 3,146.0 3,h(5KB 9/20/201698.0 0: 9/20/20166: 6.00 INTRM1 DRILL DDRL P intermediate hole section f/3146'- 3798'D0:00 06:00 MD,3436'TVD,800 gpm,1885 psi,FO 25%,140 rpm,Tq on 7-9K, WOB 6-12K,ECD 10.03,Off Bottom 1875 psi,PU 158K,SO 127K,ROT 140K,off 6K,MW 9.2 ppg,Max gas 30, ADT 4.66,Bit 9.93,Jars 52.05, Total Footage 652'MD. SCR @ 3530'MD,3201'TVD,MW 9.2,03:46 hrs #1 @ 30=140 psi,@ 40=180 psi #2 @ 30=140 psi,@40=180 psi 9/2PJSM-directional drill 9-7/8"X11" 3,798.0 4,384.0 9/20/20166: 12:000/2016 6.00 INTRM1 DRILL DDRL P intermediate hole section f/3798'- 06:00 4384'MD,3967'TVD,800 gpm,2100 psi,FO 29%,140 rpm,Tq on 8-12K, WOB 7-15K,ECD 10.19,Off Bottom 2090 psi,PU 180K,SO 130K,ROT 148K,off 8K,MW 9.25 ppg,Max gas 22, ADT 4.56,Bit 14.49,Jars 56.61, Total Footage 586'MD. Kick w/Drilling CRT 180 sec @ 10:40 hrs. SCR @ 4006'MD,3616'TVD,MW 9.25,08:10 hrs #1 @ 30=150 psi,@ 40=200 psi #2 @ 30=160 psi,@ 40=200 psi 4,384.0 4,951.0 0/2016 3/2016 6.50 INTRM1 DRILL DDRL P intermediate directionalholseill ct on/00 12:004384'- 18:30 4951'MD,4527'TVD,800 gpm,2254 psi,FO 30%,140 rpm,Tq on 8-13K, WOB 11K,ECD 10.34,Off Bottom 2225 psi,PU 200K,SO 144K,ROT 167K,off 10K,MW 9.5 ppg,Max gas 21, ADT 4.67,Bit 19.17,Jars 61.29, Total Footage 567'MD. Kick w/Drilling CRT 160 sec @ 16:00 hrs. SCR @ 4473'MD,4045'TVD,MW 9.3+, 13:00 hrs #1 @30=175 psi,@40=210 psi #2@30=175 psi,@40=210 psi #2 mud 4,951.0 4,887.0 19:9/20/2016 9/20/2016 0.50 INTRM1 DRILL BKRM T PJSM-loose a swab pump.BROOH f/4951n 887 MD at 18:30 19:00 211 gpm,306 psi,FO 14%,20 rpm, Tq 10K. PJSM-remove trip nipple,install MPD 4,887.0 4,951.0 20:00 9/20/2016 9/20/2016 1.00 INTRM1 DRILL MPDA P bearing&drain nipple.Line up MPD 19:00choke skid.Calibrate chokes at drilling parameters f/4887'-4951'MD. SIMOPS change out swab on#2 mud pump. Page 10/58 Report Printed: 10/31/2011 z, tions Summary (with Timelog Depths) 0.--pnt 2S-09 ta Cc no }t,iElips Opera Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Operation (ftKB) End Depth(ftK8) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X PJSM-directional dril9-7/8"X11" 4,951.0 5,375.0 9/20/20160:00 00:00 9/21/20160:00 4.00 INTRM1 DRILL DDRL P intermediate hole section f/4951'- 20: 5375'MD,4945'TVD,800 gpm,2850 psi,FO 35%, 140 rpm,Tq on 7-16K, WOB 15K,ECD 10.84,Off Bottom 2550 psi,PU 212K,SO 143K,ROT 168K,Tq off 10-12K,MW 9.6 ppg, Max gas 136, ADT 3.20,Bit 22.37, Jars 64.49,Total Footage 424'MD. SCR @ 4950'MD,4528'TVD,MW 9.5,20:00 hrs #1 @ 30=200 psi,@ 40=240 psi #2 @ 30=200 psi,@ 40=240 psi PJSM-directional drill 9-7/8"X11" 5,375.0 5,897.0 9/21/ 16 0 06:00 6:00 16 6.00 INTRM1 DRILL DDRL P intermediate hole section f/5375'- 00:00 5897'MD,5419'TVD,790 gpm,2740 psi,FO 36%,140 rpm,Tq on 12-19K, WOB 22-24K,ECD 10.79,Off Bottom 2681 psi,PU 235K,SO 150K,ROT 177K,Tq off 13-14K,MW 9.7 ppg, Max gas 88, ADT 4.78,Bit 27.15, Jars 69.27,Total Footage 522'MD. SCR @ 5516'MD,5079'TVD,MW 9.7,01:28 hrs #1 @ 30=220 psi,@ 40=280 psi #2 @ 30=220 psi,@ 40=280 psi • 9/21/2016 9/21/2016 2.00 INTRM1 DRILL DDRL P PJSM- @ 40 diate =280 hodrillsec9-718n X11"5897 5'897.0 6,087.0 06:00 08:00 6087'MD,5578'TVD,790 gpm,2794 psi,FO 36%, 140 rpm,Tq on 12-19K, WOB 25K,ECD 10.91,Off Bottom 2753 psi,PU 236K,SO 154K,ROT 183K,Tq off 13-14K,MW 9.7 ppg, Max gas 52, ADT 1.57,Bit 28.72, Jars 70.84,Total Footage 190'MD. SCR @ 6087'MD,5578'TVD,MW 9.7,08:00 hrs #1 @ 30=190 psi,@ 40=260 psi #2@30=190 psi,@40=260 psi 9/21/2016 9/21/2016 0.50 INTRM1 DRILL LOT P Perform dynamic open hole LOT @ 6,087.0 6,087.0 6087'MD,5578'TVD,MW 9.7 ppg. 08:00 08:30 Top of Cairn at 5554'TVD.Close in choke while pumping at 790 gpm, 2765 psi,10 rpm,Tq 12K.Close in choke to observe pressure build up of 230 psi or an EMW of 11.46 ppg. Page 11/58 Report Printed: 10/31/201E • • _, 1111 0 Operation s Summary (with Timelog Depths) sz 2S-09 Conoc Phillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKa) End Depth(ftK8) 9/21/2016 9/21/2016 7.75 INTRM1 DRILL DDRL P PJSM-/2016 9/ diate21/2 declt9-7/8"X11"6087- 6,087.0 6,845.0 08:30 16:15 f/ 6845'MD,6091'TVD,750 gpm,2656 psi,FO 36%,120 rpm,Tq on 8-20K, WOB 25K,ECD 11.1,Off Bottom 2650 psi,PU 232K,SO 160K,ROT 187K,Tq off 13K,MW 10.0 ppg,Max gas 300, ADT 7.88,Bit 35.03,Jars 77.15,Total Footage 758'MD. Fire Drill CRT 110 sec @ 15:00 hrs. SCR @ 6653'MD,5988'TVD,MW 10.0,14:30 hrs #1 ©30=250 psi,@ 40=300 psi #2@30=250 psi,@40=300 psi 9/21/2016 9/21/2016 0.75 INTRM1 DRILL CIRC P CB36 68450 rpm,45'MD,685 9g m, 26 0000 psi, 6,845.0 6,845.0 16:15 17:00 FO strokes. 6,845.0 6,845.0 9/21 /2016 18:00 9/21/2016 1.00 INTRM1 DRILL LOT P Perfo6845'rm dynamic open hole MD,6091'TVD,MW 10.0 T ppg. 17:00 18:00 Top of Cairn at 5554'TVD.Close in choke while pumping at 200 gpm,200 psi,10 rpm,Tq 13K.Close in choke to observe pressure build up of 265 psi or an EMW of 10.92 ppg. 9/21/2016 9/21/2016 5.00 INTRM1 DRILL DDRL P PJSM- directional te ionalhole deiclti-7 9-7/88/6845' 6,845.0 7,190.0 18:00 23:00 in7190'MD,6248'TVD,790 gpm,3100 psi,FO 35%, 130 rpm,Tq on 11-19K, WOB 21K,ECD 11.22,Off Bottom 3080 psi,PU 234K,SO 160K,ROT 186K,Tq off 13-15K,MW 10.0+ppg, Max gas 202, ADT 3.68,Bit 38.71, Jars 80.83,Total Footage 345'MD. 7,190.0 7,130.0 9/21/2016 9/21/2016 0.50 INTRM1 DRILL CIRC P BU f/7190'-713025%' 190 713/0, MD, 6rpm,Tq 3- 23:00 23:30 17K,racking stand back in the derrick. 9/21/2016 9/22/2016 0.50 INTRM1 DRILL LOT P Perform static open hole LOT @ 7130' 7,130.0 7,130.0 MD,6222'TVD,MW 10.0+ppg.Top 23:30 00:00 of Cairn at 5554'TVD.Start test at the shut in pressure of 160 psi.Pressure up to 205 psi,in 7 strokes&observe 205 psi to 10 strokes.Shut in& observe for 10 minutes. Initial shut in pressure 205 psi,final shut in pressure 165 psi.205 psi is an EMW of 10.7 ppg. 7,190.0 7,257.0 9/22/2016 9/22/2016 3.00 INTRM1 DRILL DDRL P PJSM-intermediate hole dericlt- /8 7190' 00:00 03:00 7257'MD,6267'TVD,790 gpm,2906 psi,FO 26%,140 rpm,Tq on 10-19K, WOB 12K,ECD 10.92,Off Bottom 2887 psi,PU 265K,SO 147K,ROT 184K,Tq off 15-17K,MW 10.0 ppg, Max gas 64, ADT 1.91,Bit 40.62, Jars 82.74,Total Footage 67'MD. Page 12/58 Report Printed: 10/31/2016 • with Timelog Depths) ry __________ 2S-09 Conoco!hiiiipts Operations Summary Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth ftK6 End Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X CBU 3X at 650 Opgpera ion29psi,FO (ftKB) .0 7,h 57.0 9/22/20163: 9/22/20164: 1.75 INTRM1 CASING CIRC P 26%,100 rpm,Tq 12-18K, 19288 03:00 04:45 strokes.Obtain final surveys&SCR's. SCR @ 7257'MD,6267'TVD,MW 10.0,03:00 hrs #1 @ 30=235 psi,@ 40=295 psi #2 @ 30=235 psi,@ 40=295 psi 9/22/2016 9/22/2016 0.75 INTRM1 CASING OWFF P Perform MPD observing shut w test, in & 7,257.0 7,257.0 04:45 05:30 shut chokespressure each time.Trend showed signs of breathing. 7,257.0 7,228.0 9/22/2016 9/22/2016 1.75 INTRM1 CASING CIRC P WFTn-close Rep.f/7257-7228'MDreamer s drop 05:30per 07:15 RFID tags&pump down at 650 gpm, 2134 psi,FO 28%,for 1000 strokes. Reduce rate to 200 gpm,425 psi,FO 11%,400 strokes.Increase rate to 650 gpm with no indication of closure. Repeat process 2 more times. 9/22/2016 9/22/2016 0.75 INTRMI CASING CIRC P 90 Ointo e1to.2 peight g at 6up5 mud d ystem psi, 7,228.0 7,228.0 07:15 08:00 100 rpm,Tq 13-17K,PU 265K,SO 147K,ROT 187K. Spill Drill 180 sec©07:33 hrs. 9/22/2016 9/22/2016 1.50 INTRM1 CASING BKRM P 650M-BROOgpm, 3 f/p7 2 -708 ' 1D, 7,228. 0 7,080.0 08:00 09:30 17K.Continue weighting up mud system to 10.2 ppg. 9/22/2016 9/22/2016 1.75 INTRMI CASING PMPO P 650upgout t of 73 f hole e f 0 0-665257K,SOD 7,080.0 6,653.0 09:30 11:15 140K,ROT 183K,MW 10.2 ppg. 9/22/2016 9/22/2016 1.75 INTRMI CASING CIRC P CCiiirccul2te87&pcondisi, tio holetion lTq1117Kat 50 6,653.0 6,653.0 11:15 13:00 gpm,PU 250K,SO 140K,ROT 190K, 12150 strokes pumped. 9/22/2016 9/22/2016 1.00 INTRM1 CASING OWFF P Monitor well, 10 rpm,Tq 15K.Observe 6,653.0 6,653.0 well bore breathing,to static.Observe 13:00 14:00 static for 30 min. 9/22/2016 9/22/2016 0.25 INTRM1 CASING MPDA P PJSM-line up MPD system to trip out 6,653.0 6,653.0 of hole,blow down TD. 14:00 14:15 9/22/2016 9/22/2016 3.75 INTRM1 CASING SMPD P MPD,f/TOH665holdiingM5 - 0Psi with 6,653.0 2,772.0 14:15 18:00 SO 108K. CBU 2X at 500 gpm, 1200 psi,40 2,772.0 2,772.0 19:19:00 0/2016 0/2016 1.00 INTRM1 CASING CIRC P rpm,Tq 7K,PU138K,SO 108K,ROT 18:00122K,5329 strokes. 9/22/2016 9/22/2016 1.00 INTRM1 CASING OWFF P well Monitoreereathor ll,10 p ,tstatic .Observe 2,772.0 2,772.0 19:00 20:00 static for 30 min. PJSM-remove drain nipple&RCD 2,772.0 2,772.0 2 9/22/20161.00 INTRM1 CASING MPDA P bearing.Install trip nipple&line up 20:000/2016 21:00 returns system. 9/22/2016 9/22/2016 1.75 INTRMI CASING TRIP P PJSM-TOH f/2772'-783'MD. 2,772.0 783.0 21:00 22:45 9/22/2016 9/23/2016 1.25 INTRM1 CASING BHAH P PJSM-lay down 18 joints of 5"HWDP 783.0 193.0 &Jars 783'-193'MD. 22:45 00:00 Total losses for 24 hrs 7 bbls. Page 13/58 Report Printed: 10/31/201( • Operations Summary (with Timeiog Depths) ;~ti ' 2S-09 v r CoSIOCOPhi€lilac ,r'; Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Operation (ftKB) End Depth(ftK8) Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X 193.0 0.0 9/23/2016 9/23/2016 2.75 INTRM1 CASING BHAH P PJSM- per lay BdowDDn BHA 3 f/193'-0'MD, 00:00 02:45 asPJSM-make up stack wash tool& 0.0 0.0 9/23/2016 9/23/2016W 0.75 INTRM1 CASING WWH P flush stack at 400 gpm,40 rpm.Lay 02:45 03:30 down stack washing tool.SIMOPS clear&clean rig floor of BHA. PJSM-change out upper VBR's to 7- 0.0 0.0 9/23/2016 9/23/2016 1.50 INTRM1 CASING BOPE P 5/8"solid body rams.SIMOPS 03:30 05:00 mobilize casing equipment to rig floor. PJSM-remove wear ring&install test 0.0 0.0 0 9/23/20161.50 INTRM1 CASING BOPE P plug.Test upper rams to 250/3500 psi 05:000/2016 06:30 for 5 minutes each.Test annular to 250/2500 psi for 5 min each.All tests charted.Pull test joint&plug.Blow down&rig down test equipment. PJSM-ii upto run casing.Change 0.0 0.0 0 9/23/20161.00 INTRM1 CASING RURD P out bails f/121"to 131",install 4'bail 06:303/2016 07:30 extensions,side door elevators,& casing power tongs. PJSM-pick up7.625",29.7#,L-80, 0.0 2,747.0 0 9/23/2016 6.50 INTRM1 CASING PUTB P Hyd 563,dopeless casing.Baker-lok 07:303/2016 114:004:00 shoe track&check floats.TIH to 2747' MD filling on the fly&topping off every 10 joints.Install 88 Hydroform centralizers to joint#61,with 3 centralizers per 2 joints configuration. PU 110K,SO 103K. Circulate&condition f/2747'-2787' 2,747.0 2,787.0 15:15 15:150/2016 9/23/2016 1.25 INTRM1 CASING CIRC P MD,staging up pumps to 8 bpm,225 14:00psi,FO 15%,MW 10.0 ppg in&out, 4304 strokes pumped. Continue running 7.625",29.7#,L-80, 2,787.0 3,690.0 9/23/ 15:15 016 17:15 016 2.00 INTRM1 CASING PUTB P Hyd 563,dopeless casing f/2787'- 3690'15:15 17:15 MD.Fill each joint on the fly& top off every 10 joints.SO 103K Circulate and condition mud while 3,690.0 3,690.0 17:15 19:00 9/23/2016 016 1.75 INTRM1 CASING CIRC P reciprocating.Staged up pump to 6 17:15bpm,290 psi, 10%FO, 10 ppg MW in/out. 9/20/2016 9/23/2016 2.25 INTRM1 CASING PUTB P Continue running 7.625",29.7#,L-80, 3,690.0 4,913.0 21:15 Hyd 563,dopeless casing f/3690'- 19:004913'MD.Fill each joint on the fly& top off every 10 joints.PU 186K,SO 133K Break circulation to fill pipe for 4,913.0 4,913.0 2 9/24/20162.75 INTRM1 CASING CIRC T displacement strap w/1 bpm,365 psi, 211:15:15 16 00:00 FO 4%.Stage up to 2 bpm,350 psi, FO 4%.Shut down to strap displacement&record half of calculated displacement.Attempt to circulate at 2 bpm showing losses. Reduce rate to.5 bpm 270 psi,slight visual of flow out observed.Adjust rates to 2 bpm on the up stroke&.5 bpm on the down stroke with no improvement.Estimated losses 75% of bbls pumped. Calculated trip gain 22.05 bbls. Actual trip gain 16.95 bbls. Circulation losses 80 bbls. Total formation losses 84 bbls. Page 14/58 Report Printed: 10/31/201 0 • !perations Summary (with Timelog IIepths) 2S-09 ConocoPhiflips f,iska Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/24/2016 9/24/2016 1.75 INTRMI CASING CIRC T Circ late O min imcoondi ion 180K,SO at 2 bpm,2 135K,85 4,913.0 4,913.0 00:00 01:45 psstrokes 3637,loss rate—1.9 bpm. 9/24/2016 9/24/2016 1.25 INTRM1 CASING PMPO T PJ 9M3'pump 7-5/8" -5/MD2 casing out 85 ofpf hole 4,913.0 4,716.0 01:45 03:00 FO minimal,PU 170K. 4,716.0 4,716.0 9/24/2016 9/24/2016 0.50 INTRM1 CASING CIRC T Cirulate pscFO min mall,,iPU 170K,SO 130K. 03:00tion at 2 bpm,280 03:30 No success establishing good circulation.Decision made to wash in the hole to 6599'to try circulating again. 4,716.0 4,913.0 9/24/2016 9/24/2016 1.00 INTRM1 CASING PUTB T JSM-wash in the Iasi g f/4716'-4913'oMD le w/2 bpm,360 03:307-5/8" 04:4:30 psi,FO minimal. 4,913.0 5,450.0 9/24/2016 9/24/2016 1.50 INTRM1 CASING PUTB P casing f/491S-5450'JSM-wash in the MD,2 bpm,360 04:30le w/7-5/8" 06:00 psi,FO minimal,PU 200K,SO 143K. 9/24/2016 9/24/2016 6.00 INTRM1 CASING PUTB P Continue running 7.625",29.7#,L-80, 5,450.0 6,599.0 Hyd 563,dopeless casing f/5450'- 06:00 12:00 6599'MD.Wash each joint down at 2 bpm,328 psi,FO 4%(full returns @ 5969'MD),strokes 8714 PU 245K,SO 157K.Total losses for tour 540 bbls. on staging pump up 6,599.0 6,599.0 9/2 012016 9/24/2016 2.75 INTRM1 CASING CIRC P to 6 bpm,265 psi,FO 10%,PU 250K, 12:00 14:45 SO 160K,6250 strokes. 9/24/2016 9/24/2016 1.75 INTRM1 CASING PUTB P Hyd 563,running dop7.625", /29.7#,L 6599'80, 6, 599.0 7,205.0 14:45 16:30 7205'MD.Wash at 2 bpm,242 psi, FO 3%(wash down to 6715'MD) &landing 7,205.0 7,247.0 17:9/24/2016 9/24/2016 0.50 INTRM1 CASING HOSO P joint.PJSM-make up Wash down at hanger bpm,242 psi, 16:30 17:00 FO 3%,PU 267K,SO 160K.Land casing on hanger at 7247'MD. 9/24/2016 9/24/2016 0.25 INTRM1 CEMENT CIRC P CO 4%ot &conditiOPS on 2 po rrig 250 psi 7,247.0 7,247.0 17:00 17:15 Fp cement line to pump in sub on CRT. 9/24/2016 9/24/2016 0.25 INTRM1 CEMENT RURD P &oig douo cementtopdrve,isolate top drive 7,247.0 7,247.0 17:15 17:30 9/24/2016 9/24/2016 3.75 INTRM1 CEMENT CIRC P Circulate agig up tccondition e pumn tor6 ecement job 7,247.0 7,247.0 17:30 21:15 stpsi,FO 11%,PU 269K,SO 161K, 15053 strokes. 9/24/2016 9/24/2016 0.25 INTRMI CEMENT SFTY P Conti forue ceme tting at 6 8"casing.330 psi, 7,247.0 7,247.0 21:15 21:30 FO 11%. Circulate&condition for cement job at 7,247.0 7,247.0 29/24/2016 0.75 INTRM1 CEMENT CIRC P 6 bpm,330 psi,FO 11%,PU 269K, 211::3/2016 30 2215 SO 161K.SIMOPS batch up mud push&cement. Page 15/58 Report Printed: 10/31/2011 Operations Summary (with Timelog Depths) • 2S-09 Cor,occehillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth (ftKB) End Depth(ftKB) Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Line u to cement Operationait&pump 5 bbls 7,247.0 7,247.0 2:159/24/2016 9/25/20160: 1.75 INTRM1 CEMENT CMNT P of MPII to flood lines at 3 bpm,200 22:15 00:00 psi.Test lines to 518/4000 psi.Reset high trip to 2000 psi(for stage tool). Continue to pump 12.5 ppg MPII at 5 bpm,265 psi for a total of 42.6 bbls. Drop bottom plug.Pump 15.8 ppg Shark Tooth slurry as follows;10 bbls w/no cemnet,50 bbls w/1 ppb cemnet,and 40 bbls w/no cemnet at 5.2 bpm,215 psi,FO 11%.Drop closing plug.Pump 10 bbls of H2O at 6.1 bpm,103 psi.Swap to rig and pump 10.0 ppg LSND mud at 6 bpm, 125 psi,FO 10%.Observe losses start 1625 strokes.Pumped 2000 strokes of displacement at 24:00 hrs. Gained 68 bbls for tour,due to well bore breathing. Total losses 472 for last 24 hrs. 7,247.0 7,247.0 9/25/2016 9/25/2016 1.00 INTRM1 CEMENT CMNT P Continue a6 displacement psi,wF010 ppg Slow 00:00 01:00 Lrate(losses @ 1625 strokes)to 2 bpm,70 psi,FCP 571 psi @ 2 bpm. Bump plug at 3100 strokes.Check floats,good.CIP @ 00:58 hrs.Total Losses for first stage 6 bbls from cement around the shoe to CIP. 9/25/2016 9/25/2016 0.25 INTRM1 CEMENT OWFF P Monitor well,static. 7,247.0 7,247.0 01:00 01:157,247.0 7,247.0 0/25/2016 9/25/2016 3.75 INTRM1 CEMENT CIRC P PJSM-observe stagertool open bpmup at 2 t 2937 psi. 01:15 05:00 Circulate thru stage tool staging up pump to 6 bpm,275 psi,FO 10%, pumped 3200 strokes at 6 bpm. SIMOPS load,strap,&tally 4"DP in pipe shed.PJSM for 2nd stage cement. 9/25/2016 9/25/2016 2.25 INTRM1 CEMENT CMNT P Pump second ngstage cement t as pe er 7,247.0 0.0 05:00 07:15 bbls of 12.5 ppg MPII at 5.4 bpm,227 psi. Pump 50 bbls of 15.8 ppg Sharks Tooth slurry at 4 bpm, 160 psi.Drop closing plug.Pump 10 bbls of H2O at 6.1 bpm,95 psi.Swap to rig& displace with 10 ppg LSND at 6 bpm, 483 psi,FO 7%.Slow pump rate as losses were observed to 2 bpm,516 psi.Losses started at—1800 strokes (cement at stage tool at 1882 stk). Bump plug at 2349 strokes,pressuring up to 1700 psi to shift stage collar closed.Observed closing at 1300 psi. Hold for 5 minutes,bleed off,&check for flow.Tool closed.CIP @ 06:51 hrs. Total Losses for second stage 14 bbls from cement at tool to CIP. 9/25/2016 9/25/2016 0.25 INTRM1 CEMENT OWFF P Monitor well,static. 0.0 0.0 07:15 07:30 Page 16/58 Report Printed: 10/31/2011 „, liw 0_____--------Summary (with Timelog Depths) ry tz '”`0 Operations Su 2S-09 4. Conocophi61ips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Operation (EKE) End Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X PJSM-back out landing joint,drain& 0.0 0.0 9/25/2016 016 2.75 INTRM1 CEMENT WWSP P flush stack.Make up packoff running 07:30 10:15 10:15 tool to landing joint.Set packoff& RILDS,per CIW Rep.Test seals to 5000 psi for 10 minutes,witnessed. Lay down running tool&landing joint. SIMOPS lay down casing equipment &prep floor to lay down 5"DP from derrick. PJSM- laydown 37 stands of 5"DP 0.0 0.0 10:15 9/25/2016 14:30 9/25/2016 4.25 INTRM1 CEMENT PULD P from derrick.SIMOPS rig up to flush& 10:15 14:30 freeze OA. PJSM-pressure test lines to 2000 psi. 0.0 0.0 17:17:30 9/25/2016 9/25/2016 3.00 INTRM1 CEMENT FRZP P Flush OA w/123 bbls of fresh H2O,3 14:30bpm,ICP 520 psi,FCP 630 psi.Rig up LRS.Pump 90 bbls of Isotherm at 1 bpm,ICP 500 psi,FCP 1020 psi. Shut in pressure 900 psi.SIMOPS Lay down 26 stands of 5"DP from derrick. Clean pits. PJSM- la down 23 stands of 5"DP 0.0 0.0 9!25/2016 9/25/2016 2.75 INTRM1 CEMENT PULD P from derrick. 17:30 20:15 m0.0 0.0 9/25/2016 9/25/2016 2.75 INTRMI CEMENT RURD P PJSX"change eVBR's,outC/ ppsaerratoto 3- 20:15 23:00 XT39,dress roughneck for 4"DP,& C/O to 4"elevators w/4-5/16"ID. PJSM- ick u 5 stands of 4"DP, 0.0 0.0 9/25/2016 9/26/2016 1.00 INTRM1 CEMENT PULD P racking back in the derrick. 23:00 00:00 OA 460 psi at 24:00 hrs. 0.0 9/26/2016 9/26/2016 3.00 INTRM1 CEMENT PULD P PJSM-pick up&rack back 25 stands 0.0 of 4"HWDP. 00:00 03:00 0.0 0.0 PJSM-pick up&rack back 69 stands 9/26/2016 9/26/2016 8.50•INTRMI CEMENT PULD P of 4"DP. 03:00 11:30 0.0 0.0 9/26/2016 9/26/2016 1.50 INTRM1 WHDBOP RURD P PJSM-set test plug,rig up to test& perform shell test. 11:30 13:00 Page 17/58 Report Printed: 10/31/201 • • 0 :. Operations Summary (with Timelog Depths) F1. 2S-09 o 'hittiipts Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth (ftKB) End Depth(ftK8) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Test witness waived Operation by AOGCC Rep. 0.0 t0.0 KB 13:000/2016 9/26/2016 5.00 INTRM1 WHDBOP BOPE P Chuck Scheve.Tested with 3-1/2"&4- 18:00 1/2"test joints.250/3500 psi,charted for 5 minutes each. Test#1 with 3 1/2"test joint,testing Annular,CV#1,#12,#13,#14 and 4" kill line valve on mud manifold,XT-39 Dart valve. Test#2-Top Pipe rams,CV#9,#11, mezzanine kill valve,and XT-39 FOSV Test#3-CV#5,#8,#10,HCR Kill, and upper IBOP. Test#4-CV#4,#6,#7,and lower IBOP. Test#5-CV#2 Test#6-Lower Pipe rams Test#7-Blind rams,CV#3 Installed 4 1/2"test joint. Test#8-Annular,HCR Choke. Test#9-Super Choke to 1500 PSI. Test#10-Manual operated choke to 1500 PSI. Test#11 -Top Pipe rams,Manual choke Test#12-Lower Pipe rams Perform Koomey draw down test. Observed initial system pressure at ACC-3050 PSI,MAN-1500 PSI,and annular-1000 PSI.After Closure observed ACC-1775 PSI,200 PSI increase in 9 seconds,and full pressures at 52 seconds. Observed 6 nitrogen bottles with an average PSI of 2433 PSI. Performed CPAI drawdown test. Tested pit level sensors&flow out alarms.Gas detection alarms tested w/low&high level. PJSM-blow down&rig down test 0.0 0.0 19:19:00 0/2016 9/26/2016 1.00 INTRM1 WHDBOP RURD P equipment.Set wear bushing w/10" 18:00ID&RILDS.SIMOPS confirm 4"DP count in the shed. 9/26/2016 9/26/2016 3.00 INTRM1 CEMENT BHAH P 1/PJSM- BHA 4 make f/up productionas 6-pe3 4"X7- 0.0 419.0 19:00 22:00 SLB DD. 9/26/2016 9/27/2016 2.00 INTRMI CEMENT PULD P PJSM-single in the hole w/BHA 4 f/ 419.0 2,310.0 416'-2310'MD,PU 70K,SO 74K. 22:00 00:00 Kick w/Tripping CRT 148 sec @ 23:00 hrs. OA 450 psi at 24:00 hrs. 0 9/27/20160.50 INTRM1 CEMENT DHEQ P Shallow hole test MWD at 214 gpm, 2,310.0 2,310.0 00:000/2016 00:30 1100 psi,FO 11%.B/D topdrive. 9/27/2016 1.75 INTRMI CEMENT PULD P Continue to single in the oe on 4"DP 2,310.0 4,175.0 9/27/20160: f/2310'-4175monitoring 00:30 02:15 displacement on pit 1, ' sco a 4,175.0 4,175.0 sonic Fill pipe and cycle on P P pP Y 9/27/2016 9/27/20162: 0.50 INTRM1 CEMENT CIRC W 126k,SOW 97k.B/D topdrive. PU 02:15 02:45 Page 18/58 Report Printed: 10/31/201( S . Operations Summary (with Timelog Depths) 2S-09 m, ConocorPhitlips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) S/art End Time Dur(hr) Continue to single in the hole on 4"DP 4,175.0 4,585.0 9/27/20162: 9/27/20163: 0.25 INTRM1 CEMENT PULD P f/4175-4585'MD,monitoring 02:45 03:00 displacement on pit 1. Note:Logged section f/4210'-4305' MD with sonicscope at 800 ft/hr. Run in hole on 4"DP stands from 4,585.0 5,342.0 9/27/2016 0/27/2016 1.25 INTRM1 CEMENT QEVL P derrick f/4585'-5342'MD'at 800 ft/hr 03:00 04:15 for logging cement.PUW 145k,SOW 105k. 9/27/2016 9/27/2016 0.50 INTRM1 CEMENT COCF P Wash and ream down f/5342'and tag 5,342.0 5,389.0 hard cement at 5389'MD w/200 gpm, 04:15 04:45 1325 psi, 10%F/O,40rpm,ROT 121k w/6k TQ. Drill stage collar f/5389'-5404'MD, 5,389.0 5,404.0 9/27/2016 0/27/2016 2.25 INTRM1 CEMENT DRLG P 201 gpm,1460 psi,40-60 rpm,Tq 6K, 04:45 07:00 WOB 2-12K.Ream section 4X to ensure clear. Run in hole on 4"DP stands from 5,404.0 7,053.0 0 9/27/20162.50 INTRM1 CEMENT QEVL P derrick f/5404'-7053'MD'at 800 ft/hr 07:000/2016 09:30 for logging cement.PUW 187k,SOW 109k. Circulate&condition LSND mud at 7,053.0 7,053.0 9/27/2016 91 1.50 INTRM1 CEMENT CIRC P 250 gpm,2000 psi,FO 10%,80 rpm, 09:30 11:000/2016 Tq 8K.Observe 10.0ppg MW in/out after 3810 strokes. Rigupto ressure test intermediate 7,053.0 7,053.0 9/27/2016 9/27/2016 0.25 INTRM1 CEMENT RURD P casing. p 11:00 11:15 7,053.0 7,053.0 9/27/2 11:15 12: Pressure test 7-5/8",29.7#, 016 9/27/2016 1.25 INTRM1 CEMENT PRTS P intermediate casing to 3500 psi for 30 11:15 12:30 minutes,charted.Pumped 4.0 bbls and bled back 4.0 bbls. Service topdrive and adjust energy 7,053.0 7,053.0 9/27/2016 9/27/2016 0.50 INTRM1 CEMENT SVRG P track cable. 12 9/270 9/132700 4/2016 0.75 INTRM1 CEMENT COCF P Wash and ream down f/7053'-7091 w/ 7,053.0 7,091.0 13:13:45 0/2016 250 gpm,2055 psi,9%F/O,60rpm, 13:009.5k TQ,ROT 134k. Drill cement f/7091'-7120'MD w/250 7,091.0 7,120.0 13:459/2 14:004/2016 0/2016 0.25 INTRM1 CEMENT COCF P gpm,1950 psi,9%F/O,40-80 rpm,9- 12k TQ. 9/20/2016 9/27/2016 1.25 INTRM1 CEMENT DRLG P Drill plug and baffle collar f/7120'- 7,120.0 7,125.0 15:15 7125 MD w/250 gpm,2080 psi,9% 14:00F/O,40-80 rpm, 10k TQ,5-10k WOB. Drill cement f/7091'-7120'MD w/250 7,125.0 7,159.0 15:15 016 9/27/2016 1.50 INTRM1 CEMENT DRLG P gpm,2080 psi,9%F/O 40-80 rpm, 15:15 16:4510k TQ,5-10k WOB. 9/27/2016 9/27/2016 3.25 INTRM1 CEMENT DRLG P Drill plug and float collar f/7159'-7165' 7,159.0 7,165.0 MD w/205 gpm, 1390 psi,7%F/O,60 16:45 20:00 -80 rpm,9-10k TQ,5-18k WOB. Drill cement f/7165'-7243'MD w/205 7,165.0 7,243.0 9/27/20160: 9/27/201600 20:45 0.75 INTRM1 CEMENT DRLG P gpm, 1390 psi,7%F/O 60-80 rpm,9- 20: 10k TQ,5-18k WOB.Tag top of shoe @ 7243'MD. Page19158Report Printed: 101311201 /201 • Operations Summary (with Timelog Depths) 02S-09 Chico-hiElips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth (ftKB) End Depth(ftKB) Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation7,243.0 7,h 57.0 9/27/2016 2/23/2016 0.75 INTRM1 CEMENT DRLG P Drill float shoe and rathole f/7243'-7257'MD w/203 gpm, 1425 psi,9% 20:45 21:30 F/O,80 rpm,8-10k TQ, 1-5k WOB, PUW 187k,SOW 104k,ROT 133k w/ 8k TQ.Ream shoe 3 x times to ensure clear. SPR's at 7243'MD,6254'TVD,MW 10.0 ppg,20:55 hrs. #1 @ 20=420,@ 30=650 psi #2 @20=410,@30=620 psi Drill 20'of new formation f/7257'- 7,257.0 7,277.0 2 2 2.25 INTRM1 CEMENT DDRL P 7277'MD,6280'TVD,w/238 gpm, 21:303/2016 23:454/2016 1940 psi,8%F/O,80 rpm,8.5k TQ, 16-18k WOB,ECD 10.62ppg,Off bottom SPP 1930 psi,PUW 190k, SOW 105k,ROT 135k w/9k TQ,MW 10.0ppg,Gas 38 units,ADT 1.24,Bit 1.24,Jar 65.66. Note-Observed well pack off at 7260' MD.Necessary WOB to drill ahead thereafter increased from Ilk to 18k and pump pressure increased 120 psi. Obtain surveyand commence 7,277.0 7,207.0 2 9/28/20160.25 INTRM1 CEMENT CIRC P circulatingobtain even mud weight 23:454/2016 00:00 to for FIT w/240 gpm,1980 psi,9%F/0, 80 rpm,9k TQ. OA pressure=680 psi Continue circulating to obtain even 7,207.0 7,207.0 9/28/2016 0/28/2016 0.50 INTRM1 CEMENT CIRC P mud weight for FIT w/243 gpm,1940 00:00 00:30 psi,9%F/O,80 rpm,9k TQ for total of 2579 strokes,9.95ppg MW in/out. Rack back stand,Blow down top 7,207.0 7,207.0 0 0 0.50 INTRM1 CEMENT RURD P drive,and rig up test equipment for 00:30312016 01:000/2016 FIT test.Monitor well-static. 9/28/2016 9/28/2016 0.25 INTRMI CEMENT FIT P Perform FIT to an EMW of 13.0ppg at 7,207.0 7,207.0 7277'MD,6274'TVD,with a 9.95ppg 01:00 01:15 MW.Pressured up to 993psi w/1.1 bbls,shut in&observe pressure decrease 920 psi over 10 minutes. Bled back 1.0 bbls. 9/28/2016 9/28/2016 0.50 PROD1 DRILL SVRG P Service top drive. 7,207.0 7,207.0 01:15 01:45 Displace well from LSND to FloPro 7,277.0 7,207.0 0/24/2016 9/28/20161.25 PROD1 DRILL DISP P mud system.Pump 30 bbls Hi-Vis pill 01:45 03:00 followed by 318 bbls of 10.0 ppg FloPro @ 214 gpm, 1470 psi,FO 8%, reciprocating and rotating pipe at 60 rpm,Tq 7.5K. SPR's at 7277'MD,6274'TVD,MW 10.0 ppg,02:53 hrs. #1 @ 20=350,@ 30=570 psi #2@20=350,@30=570 psi Note:Initial concentration of Encapso lubricant at 1.75% Blow down topdrive and monitor well 7,207.0 7,207.1 9/28/2016 9/28/2016 0.25 PROD1 DRILL OWFF P for flow-static. 03:00 03:15 Page 20/58 Report Printed: 10/31/201 Operations Summary (with Timelog�epths) 411 __________ '‘'. 2S-09 ConocoPhilliias Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/28/2016 9/28/2016 0.75 PROD1 DRILL MPDA P Pull MPD trip nipple and install MPD 7,207.0 7,207.0 03:15 04:00 bearing/drain nipple. 9/28/2016 9/28/2016 0.50 PROD1 DRILL MPDA P system,Establish and wash n,calin bro te oboMPDtomw/ 7,207.0 7,277.0 04:00 04:30 209 gpm,1440 psi, 11%F/O,50 rpm, 7k TQ. 9/28/2016 9/28/2016 1.50 PROD1 DRILL DDRL P DDriIl 6-3/4" prodMDuc28n'sectionction TVD,w/259 f/ 7,277.0 7,307.0 04:30 06:00 727gpm, 1985 psi,11%F/O,70 rpm,Tq on 7.5K,off 7K,4-18K WOB,ECD 10.70ppg,Off Btm SPP 1975 psi, PUW 171K,SOW 116K,ROT 137K, MW 10.0 ppg,Gas 22 units,ADT 1.31,Bit 2.55,Jar 66.97.Footage 30' MD.Hold 312 psi MPD backpressure on connections. 9/28/2016 9/28/2016 3.00 PROD1 DRILL DDRL P DDDrill 6-3/4"production section TVD,w/259 f/ 7,307.0 7,410.0 06:00 09:00 73gpm, 1985 psi, 10%FIG, 100 rpm,Tq on 7.5K,off 7K,21K WOB,ECD 10.75 ppg,Off Btm SPP 1975 psi,PUW 171K,SOW 116K,ROT 137K,MW 10.0 ppg,Gas 1546 units,ADT 2.31, Bit 4.86,Jar 69.28.Footage 103'MD. Hold 312 psi MPD backpressure on connections. 9/28/2016 9/28/2016 1.00 PROD1 DRILL CIRC P Pump down un6rxeRmD as per ps or w/ 7,410.0 7,410.0 09:00 10:00 opening258 gpm,1958 psi,20 rpm,6k Tq. Pull to 7392'MD bit depth to test if reamer blocks open at casing shoe but see no over pull.Pump down additional 6 x RFID chips w/258 gpm, 1958 psi,20 rpm,6K Tq.Pull to 7390' MD bit depth and observe 7K overpull into shoe,confirming reamer blocks are open. Note:Underreamer nozzles are blanked off and flow tube mandrel removed from tool as lesson learned from 2S-12 washout 9/28/2016 9/28/2016 2.00 PROD1 DRILL DDRL P DDril16 3/4"41pMDuc33n5'section 0 TVDw/260 7,410.0 7,501.0 10:00 12:00 741gpm,2030 psi, 10%F/O,110 rpm,Tq on 7.5-10K,off 7K,22K WOB,ECD 10.83 ppg,Off Btm SPP 2010 psi, PUW 161K,SOW 114K,ROT 127K, MW 10.0 ppg,Gas 250 units,ADT 1.48,Bit 6.34,Jar 70.76.Footage 91' MD.Hold 312 psi MPD backpressure on connections. Page 21/58 Report Printed: 10/31/2016 Summary (with Timelog Depths) Operations 0_ 0 --,>,« 1-,, 2S-09 ConocOPhitlips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth .Operation (ftKB) End Depth(ftKB) Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X 7 501.0 7,h 44.0 0/2016 16:15 016 4.25 PROD1 DRILL DDRL P 7501'-7644'MD,6348'6-3/4"production sTVtD,w/262 12:00 16:15 gpm,2040 psi, 10%F/O,110 rpm,Tq on 8.5-10K,off 8K,14K WOB,ECD 10.89 ppg,Off Btm SPP 2010 psi, PUW 175K,SOW 106K,ROT 128K, MW 10.0 ppg,Gas 550 units,ADT 3.55,Bit 9.89,Jar 74.31.Footage 143' MD.Hold 312 psi MPD backpressure on connections. Note:7-1/2"hole TD at 7495.5'MD (reamer blocks 148.5'behind bit) Top of Kuparuk C observed at 7443' Top of A5 observed at 7468' Top of A4 observed at 7504','-50' TVD higher than expected Note:At 7613',start increasing Encapso lubricant concentration from 1.75%to 2.25%to help mitigate high stick-slip. 9/28/2016 9/28/2016 0.75 PROD1 DRILL CIRC P Pump down 6 x RFID chips to close 7,644.0 7,591.0 underreamer as per WFT.Obtain 16:15 17:00 SPR's and CBU w/250 gpm,1820 psi, 10%F/O,110 rpm,7-9k TQ,Pumped 2400 total strokes,MW in/out 10.0 PPg. SPR's at 7616'MD,6348'TVD,MW 10.0 ppg, 16:30 hrs. #1 @ 20=400,@ 30=625 psi #2 @ 20=400,@ 30=620 psi 7,591.0 7,230.0 17:450/2016 9/28/2016 0.75 PROD1 DRILL SMPD P Strip out of holding 420hpsi MPD backpresssure 17:00 17:45 out of slips and 312 psi in slips,PUW 170k,SOW 107k. Establish circulation and perform slack 7,230.0 7,230.0 18:00 18:004/2016 9/28/2016 0.25 PROD1 DRILL CIRC P off test w/230 gpm, 1640 psi, 10% 17:45F/O,PUW 168K,SOW 109K-confirm reamer blocks are closed. 9/28/2016 9/28/2016 1.00 PROD1 DRILL SMPD P Strip in hole f/7230'-7644'w/290 psi 7,230.0 7,644.0 MPD back pressure,PUW 172K, 18:00 19:00 SOW 101K. 9/28/2016 9/29/2016 5.00 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 7,644.0 8,090.0 7644'-8090'MD,6346'TVD,w/262 19:00 00:00 gpm,2160 psi,11%F/O, 180 rpm,Tq on 9-11K,off 8K,21K WOB,ECD 11.25 ppg,Off Btm SPP 2140 psi, PUW 172K,SOW 98K,ROT 126K, MW 10.0 ppg,Gas 69 units,ADT 3.83,Bit 13.72,Jar 78.14.Footage 446'MD.Hold 312 psi MPD backpressure on connections. OA pressure=725 psi Page 22/58 Report Printed: 10/31/201 i Operations Summary (with Timelog Depths) 2S-09 ConacoPhi€lips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Operation (ftK6) End Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X 8,090.0/4"production section f/ $,h40.0 9/29/20160: 9/29/20166: 6.00 PROD1 DRILL DDRL P DDrill09 -8740'MD,6325'TVD,w/264 00:00 06:00 gpm,2176 psi, 11%F/O, 180 rpm,Tq on 10-13K,off 9K,20K WOB,ECD 11.23 ppg,Off Btm SPP 2170 psi, PUW 165K,SOW 95K,ROT 125K, MW 10.0 ppg,Gas 528 units,ADT 3.97,Bit 17.69,Jar 82.11.Footage 650'MD.Hold 312 psi MPD backpressure on connections. SPR's at 8184'MD,6345'TVD,MW 10.15 ppg,00:40 hrs. #1 @ 20=510,@ 30=720 psi #2@20=510,@30=740psi DDrill 6-3/4"production section f! 8,740.0 9,300.0 9/29/2016012016 6.00 PROD1 DRILL DDRL P 8740'-9300'MD,6333'TVD,w/264 06:00 1 12:2:00 gpm,2260 psi,11%F/O, 160-180 rpm,Tq on 10-12K,off 9K,20K WOB, ECD 11.18 ppg,Off Btm SPP 2250 psi,PUW 169K,SOW 96K,ROT 128K,MW 10.0 ppg,Gas 534 units, ADT 3.59,Bit 21.28,Jar 85.70. Footage 560'MD.Hold 312 psi MPD backpressure on connections. SPR's at 8754'MD,6325'TVD,MW 10.0 ppg,06:12 hrs. #1 @ 20=520,@ 30=720 psi #2 @ 20=520,@ 30=720 psi DDrill 6-3/4"production section f/ 9,300.0 9,417.0 13:15 13:150/2016 9/29/2016 1.25 PROD1 DRILL DDRL P 9300'-9417'MD,6337'TVD,w/264 12:00gpm,2265 psi,10%F/O, 180 rpm,Tq on 13K,off 9.5K,21K WOB,ECD 11.12 ppg,Off Btm SPP 2245 psi, PUW 176K,SOW 95K,ROT 127K, MW 10.0 ppg,Gas 155 units,ADT 0.99,Bit 22.27,Jar 86.69.Footage 117'MD.Hold 312 psi MPD backpressure on connections. 9/29/2016 9/29/2016 2.00 PROD1 DRILL MPDA T Troubleshoot MPD choke#2, 9,417.0 9,417.0 13:15 15:15 circulating/reciprocating pipe w/279 13:15 gpm,2440 psi,11%F/O,140 rpm,9- 10k TQ,ECD 10.96 ppg.Replace shear pin and change out gate on choke#2 and put back into service. 9/29/2016 9/29/2016 2.75 PROD1 DRILL DDRL P DDrill 6-3/4"production section f/ 9,417.0 9,694.0 9417'-9694'MD,6327'WD,w/262 15:15 18:00 gpm,2290 psi,10%F/O, 180 rpm,Tq on 12-13K,off 9.5K,20K WOB,ECD 11.30 ppg,Off Btm SPP 2280 psi, PUW 173K,SOW 93K,ROT 126K, MW 10.0 ppg,Gas 464 units,ADT 1.83,Bit 24.10,Jar 88.52.Footage 277'MD.Hold 312 psi MPD backpressure on connections. SPR's at 9510'MD,6324'TVD,MW 10.0 ppg,16:10 hrs. #1 @20=560,@30=800 psi #2 @ 20=570,@ 30=790 psi Page 23/58 Report Printed: 10/31/201 • the) Operations Summary (with Timelog ep 0 . ..�t 2S-09 conoccehiilips . Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Operation (ftKB) End (ftKB) Start Time End Time Our(hr) Phase Op Cade Activity Code Time P-T-X DDrill 6 3/4"production section f/ 9,694.0 Depthh30.0 18:000/2016 9/30/20160: 6.00 PROD1 DRILL DDRL P 9694'-10330'MD,6333'TVD,w/264 00:00 gpm,2370 psi, 12%F/O,180 rpm,Tq on 13.5K,off 10.5K,18K WOB,ECD 11.37 ppg,Off Btm SPP 2375 psi, PUW 185K,SOW 90K,ROT 131K, MW 10.0 ppg,Gas 211 units,ADT 4.10,Bit 28.20,Jar 92.62.Footage 636'MD.Hold 312 psi MPD backpressure on connections. SPR's at 10175'MD,6336'TVD,MW 10.0 ppg,22:30 hrs. #1 @ 20=545,©30=790 psi #2 @ 20=540,©30=805 psi OA pressure=680 psi 9/30/2016 9/30/2016 6.00 PROD1 DRILL DDRL P DDrilI -149 pr action section f/w/ 10 ,330.0 10,934.0 00:00 06:00 1033262 gpm,2370 psi, 12%F/O,160 rpm,Tq on 14K,off 11K, 18K WOB, ECD 11.28 ppg,Off Btm SPP 2360 psi,PUW 193K,SOW 87K,ROT 126K,MW 10.0 ppg,Gas 33 units, ADT 4.05,Bit 32.25,Jar 89.75. Footage 604'MD.Hold 312 psi MPD backpressure on connections. SPR's at 10744'MD,6326'TVD,MW 10.0 ppg,03:30 hrs. #1 ©20=520,@ 30=760 psi #2@20=520,@30=760 psi 9/30/2016 9/30/2016 6.00 PROD1 DRILL DDRL P DDrill -3144 production r action section f/w/ 10934.0 11,410.0 06:00 12:00 260 gpm,2420 psi,10%F/O,140 rpm,Tq on 14K,off 11K, 15K WOB, ECD 11.16 ppg,Off Btm SPP 2420 psi,PUW 193K,SOW 88K,ROT 126K,MW 10.0 ppg,Gas 420 units, ADT 3.90,Bit 36.15,Jar 100.57. Footage 476'MD.Hold 312 psi MPD backpressure on connections. SPR's at 11399'MD,6302'TVD,MW 10.0 ppg,11:40 hrs. #1 @ 20=480,@ 30=730 psi #2 @ 20=480,@ 30=830 psi 9/30/2016 9/30/2016 2.00 PROD1 DRILL DDRL P DDrill6-3/4" -1/"prod du tion section 630tion f/ 11,410.0 11,584.0 12;00 14:00 114262 gpm,2550 psi, 11%F/O,135 rpm,Tq on 14K,off 11K,17K WOB, ECD 11.24 ppg,Off Btm SPP 2540 psi,PUW 195K,SOW 96K,ROT 128K,MW 10.0 ppg,Gas 166 units, ADT 1.36,Bit 37.51,Jar 101.93. Footage 174'MD.Hold 312 psi MPD backpressure on connections. Note:Observe failure on Periscope LWD @ 11,357'-continue to drill and discuss path forward with town. Page 24/58 Report Printed: 10/31/2016 • • :,. Operations Summary (with Timelog Depths) ram Yid P. 2S-09 ConocoPhitlips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End.Depth(ftKB) 9/30/2016 9/30/2016 0.25 PROD1 DRILL CIRC T D change out cision made BHA dto p pulltoout le dof ole and 11,584.0 11,584.0 14:00 14:15 Periscope LWD.Obtain slow pump rates,downlink to turn off tools,and pump up survey. SPRs at 11486'MD,6302'ND,MW 10.0 ppg,14:10 hrs. #1 @20=510,@30=775 psi #2 @ 20=510,@ 30=765 psi 9/30/2016 9/30/2016 0.75 PROD1 DRILL OWFF T PerformprMP a of drawforma onto BTetape 308 iermin e 11,584.0 11,584.0 14:15 15:00 psi,line up to trip tank,and reduce backpressure in steps until pressure was completely bled off.Observed well static at 10.0 ppg MW with no backpressure @ 6302'TVD,total of 0.5 bbls bled back. 9/30/2016 10/1/2016 9.00 PROD1 DRILL BKRM T Backream 9em 2035 psi,H 14f/ 804pm- 094 8-4' D 11,584.0 8,094.0 15:00 00:00 264 10K,ROT 128k,ECD 10.98 ppg. Target pulling speed 1000 ft/hr.Hold 312 psi MPD backpressure on connections. OA pressure=100 psi 0 10/1/2016 10/1/2016 2.00 PROD1 DRILL BKRM T Backream gpm,2060 f/p8014 '-r7716' T8D 8, 094.0 7,716.0 00:00 02:00 26010K,ROT 127k,PUW 172k,SOW 105k,ECD 10.95 ppg.Target pulling speed 1000 ft/hr.Hold 312 psi MPD backpressure on connections.Slow pulling speed to 150 ft/hr for last stand to circulate 1 x bottoms up prior to pulling through shales. 10/1/2016 10/1/2016 1.00 PROD1 DRILL SMPD T Strip BHA through Kalubik shales into 7,716.0 7,247.0 cased hole f/7716'-7247',holding 02:00 03:00 MPD backpressure at 420 psi out of slips and 312 psi in slips.Observed one tight spot at 7288'w/36k overpull but otherwise pulled very smoothly. PUW 172k,SOW 103k. Circulate 1.5 x bottoms up w/214 7,247.0 7,247.0 10/1/2016 10/1/2016 1.50 PROD1 DRILL CIRC T gpm, 1506 psi, 12%F/O,60 rpm,8K 03:00 04:30 Tq,10.85 ppg ECD,while preparing pits for displacement to brine.Dilute 11.8 ppg NaBr from upright tanks w/ freshwater and NaCI to obtain 11.0 PPg• 10/1/2016 10/1/2016 1.00 PROD1 DRILL SMPD T P m55 b0lsOhiH-vis/ 7.- 6747'MD laying spacer 7,247.0 6,747.0 04:30 05:30 for 5 x stands w/2 bpm,420 psi, holding 312 psi MPD backpressure on connections and 200 psi when spotting spacer.Chase spacer to bit w/11.0 ppg NaBr brine. Page 25158 Report Printed: 10/31/2011 Operations Summary (with Timelog epths) r , 2S-09 ConocoPhillilas "�n} Job: DRILLING ORIGINAL Rig: DOYON 142 Time Logstart Depth Operation {ftK6) End Depth(ftKB) Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Displace cased hole from 10.0 ppg 6,747.0 6h47.0 10/1/2016 16/1/2016 1.25 PROD1 DRILL DISP FloPro to 11.0 ppg NaBr brine w/213 05:30 06:45 gpm, 1300 psi,60 rpm,7.5k TQ,ECD 11.4 ppg,decreasing MPD backpressure as per stepdown schedule from rig engineer. 10/1/2016 10/1/2016 0.25 PROD1 DRILL OWFF T Monitor well-static. 6,747.0 6,747.0 06:45 07:006,747.0 420.0 10/1/2016 10/1/2016 4.00 PROD1 DRILL SMPD T Strip OOH to top of HWDP f/6747' 420',holding 150 psi MPD 07:00 11:00 backpressure. 10/1/2016 10/1/2016 0.25 PROD1 DRILL OWFF T Monitor well at top of BHA-static 420.0 420.0 11:00 11:15 Pull MPD bearing and drain nipple and 420.0 420.0 10/1/2016 10/1/2016 1.25 PROD1 DRILL MPDA T install trip nipple. 30 12/ 11/15 101/2016 15/11/1/2016 2.50 PROD1 DRILL BHAH T Pull OOH f/420' to surface,racking 420.0 0.0 back 4"HWDP and jar and laying out 12:30 15:00 BHA.Both plunger and flapper floats looked ok with small amount of debris around springs,but were both still functional.Underreamer grade:1-1- CT-D-X-0-RR-DTF.Bit grade:4-4-BT- A-X-0-CT-DTF.Observed 1 small chipped tooth on the second cutter block of underreamer and a few metal shavings lodged between the body and cutter block.Observed 8 x broken teeth on the bit. Calculated displacement for trip=63 bbls Actual hole fill=141 bbls 10/1/2016 10/1/2016 1.25 PROD1 DRILL CLEN T Clean and clear rig floor. 0.0 0.0 15:00 16:15 0.0 367.0 T Pickup BHA#5 as per SLB and RIH 10/1/2016 10/1/2016 2.75 PROD1 DRILL BHAH to 367'. 16:15 19:00 367.0 5,100.0 22:45 Run in hole on elevators w/4"DP 19/1/2016 10/1/2016 3.75 PROD1 DRILL TRIP T stands from derrick f/367'-5100', 19:00 22:45 monitoring displacement on pit 1. 10/1/2016 10/1/2016 0.50 PROD1 DRILL SVRG T Adjust top drive rail and torque tube. 5,100.0 5,100.0 22:45 23:15 Blow down top drive and change out 5,100.0 5,100. 10/1/2016 10/2/2016 0.75 PROD1 DRILL SVRG T0 washpipe. 23:15 00:00 Observe new washpipe leaking under 5,100.0 5,100.0 100/2016 1.00 PROD1 DRILL SVRG T hydrostatic pressure.Re-tighten and 00::0/2016 00 0 01:1:00 test to 3500 psi-good test. 10/2/2016 12/2/2016 1.50 PROD1 DRILL TRIP T Run in hole on elevators w/4"DP 5,100.0 7,182.0 02:30 stands from derrick f/5100'-7182', 01:00monitoring displacement on pit 1. Pull tripnipple and install new MPD 7,182.0 7,182.0 10/2/2016: 10/2/2016 1.00 PROD1 DRILL MPDA T bearing andpdrain nipple. 10/2/20160 02 03:30 Displace well from 11.0 ppg NaBr 7,182.0 7,182.0 : 10/2/2016 2.00 PROD1 DRILL DISP T brine to 10.0 ppg FloPro WBM.Pump 03:30 05:30 26 bbls hi-vis brine spacer and chase with 321 bbls 10.0 ppg FloPro w/216 gpm,1430 psi,10%F/O,11.0 ppg ECD,50 rpm,7.5K Tq, Page 26/58 Report Printed: 10/31/201 f F e•, • � Operations Summary (with Timelog Depths) rar, ;� "`+ 2S-09 ,Co ocoPhiliips .; Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Operation (ftKB) End Depth( Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X 7 B) l) 7,345.0(ftKB) ftKB 10/2/2016: 10/2/2016: 0.25 PROD1 DRILL SMPD T Strip MPDib backpressure of 105 psi out of 05:30 05:45 slips and 312 psi in slips.PUW 172K, SOW 106K. 10/2/2016 10/2/2016 1.50 PROD1 DRILL SMPD T Work tight hole at 7345',holding 312 7,345.0 7,187.0 psi MPD backpressure.Stage up 05:45 07:15 pumps to 2 bpm,640 psi and attempt to wash down through tight hole. Stage up rotary to 20 rpm,8-10 K Tq. Observe hole pack off.Work pipe free and pull up inside casing to 7187'. Circulate bottoms up inside cased 7,187.0 7,247.0 07:15 08:: 10/2/2016 10/2/20160.75 PROD1 DRILL CIRC T hole w/218 gpm,1445 psi, 12%F/O, 00 Ream down w/4 bpm,903 psi,10% 7,247.0 7,247.0 18 1 3.00 PROD1 DRILL REAM T F/O,20 rpm,6-7K Tq, 116 psi MPD 08::0/2016 00 111::0/2016 00 backpressure f/7247'-7277'and observe hole pack off.Work pipe free and pull up into casing shoe.Stage up pumps to 3 bpm,690 psi,20 rpm,7k TQ,140psi MPD backpressure.Ream down to 7257'and observe hole pack off.Jar pipe free and pull up into casing shoe. 18 0 7,247.0 7,247.0 10/2/2016 10/2/2016 0.50 PROD1 DRILL CIRC T Stage up% pumps F/ ps20 o 2607 5k gpm, 86d 11:00 11:30 confirm good circulation. 10/2/2016 10/2/2016 4.75 PROD1 DRILL REAM T Ream m section00 f/ p si247' rpm, '5k Tq,w/2-3 7,247.0 7,247.0 11:30 16:15 bpadjusting MPD back pressure as per ramp schedule.Observe erratic torque and pack off tendencies between 7340'-7343'.Observe hole pack off at 7343'and work pipe free.Pull up and observe hole pack off again at 7282'. Work pipe free and pull up into casing shoe. Circulate 1.5 bottoms up w/241 gpm, 7,247.0 7,247.0 10/2/2016 10/2/2016 1.00 PROD1 DRILL CIRC T 2290 psi, 10%F/O,40-60 rpm,9K Tq, 16:15 17:15 observing abrupt pressure drop to 1890 psi after pumping 3000 strokes. PUW 174k,SOW 106k. Ream section f/7247'-7344'w/2 7,247.0 7,247.0 10/2/2016 10/2/2016 3.25 PROD1 DRILL REAM T bpm,750 psi,12%F/O,20 rpm,7.5k 17:15 20:30 Tq,210 psi MPD backpressure, varying WOB from 10-22k.Work pipe back up inside casing Circulate 1.5 bottoms up WI 220-250 7,247.0 7,247.0 10 12 1.50 PROD1 DRILL CIRC T gpm,1945-2425 psi,12%F/O,80 20::3/2016 30 22::012016 00 rpm,7.5k Tq. 10/2/2016 10/2/2016 0.25 PROD1 DRILL SMPD T Strip in hole f/7247'-7343'w/MPD 7,247.0 7,343.0 backpressure of 150 psi out of slips 22:00 22:15 and 312 psi in slips.Slack off to block weight at 7343'with no success. Ream down f/7343'-7347'w/2-3 7,343.0 7,347.0 10/2/2016 10/2/20161.25 PROD1 DRILL REAM T bpm,640-838 psi,11%F/O,20-40 22:15 23:30 rpm,7-8k Tq,10-24k WOB.Observe hole pack off at 7347'. Page 27/58 Report Printed: 10/31/2011 • 0 Operations Summary (with Timelog Depths) . 2S-09 ConocOPhillips 'x �- Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation {ftKB) End Depth(ftKB) 10/2/2016 10/3/2016 0.50 PROD1 DRILL REAM T Work pipe free w/50-80k overpull and 7,347.0 7,247.0 pull back up into casing shoe.PUW 23:30 00:00 172k,SOW 106k. OA pressure=260 psi 10/3/2016 10/3/2016 1.25 PROD1 DRILL REAM T Stage up pumps and circulate bottoms 7,247.0 7,247.0 up inside casing wl 212 gpm/1800 00:00 01:15 psi,80 rpm,7K Tq,ROT 127K,PUW 175K,SOW 105K. 1.00 PROD1 DRILL REAM T Ream down f/7247'-7288'w/2.5 7,247.0 7,247.0 01:15 02:15 016 10/3/2016 bpm,740 psi,20 rpm,8K Tq,180 ft/hr 01:15 target speed.Observe hole pack off at 7288'.Work pipe free and pull up into casing shoe. 10/3/2016 10/3/2016 2.00 PROD1 DRILL REAM T Stage up pumps to 2.5 bpm,740 psi, 7,247.0 7,312.0 20 rpm,8K Tq and ream down f/7247' 02:15 04:15 -7342'.Observe hole pack off at 7342'.Work pipe free and pull up to 7312'. Ream down WI 2 bpm,680 psi,20 7,312.0 7,372.0 10/3/2016 10/3/2016 5.00 PROD1 DRILL REAM T rpm,8K Tq,5-15K WOB f/7312'- 04:15 09:15 7352'.Stage up pumps to 200 gpm, 1400 psi and pump up survey- confirmed that we are still in original hole w/73.9°INC at 7352'.Continue reaming down f/7352'-7372'w/same parameters.At 7372',attempt to stage up high enough to pump up another survey and packed off at 140 gpm. Work pipe free up to 7334'and 7,372.0 7,334.0 10/3/2016 10/3/2016 0.75 PROD1 DRILL REAM T attempt to stage up pumps.Observe 09:15 10:00 another pack off at 7334'.Work pipe free and stage up to 2 bpm. 4.50 PROD1 DRILL REAM T Ream down w/2bpm,680 psi,20 rpm, 7,334.0 7,657.0 0/2016 10:00 14:: 10 10/3/20168.5K Tq,2-7K WOB f/7334'-7657'. 30 Stripin hole f/7657'-9550'holding 7,657.0 9,550.0 10/3/2016 16/3/2016 1.75 PROD1 DRILL SMPD T MPD backpressure of 105 psi out of 14:30 16:15 slips and 312 psi in slips. 10/3/2016 10/3/2016 3.00 PROD1 DRILL CIRC T' Stage up pumps to 2.5 bpm, observe 9,550.0 9,550.0 hole pack off at 9550'.Work pipe free. 16:15 19:15 Stage up pumps and rotary to 262 gpm/2227 psi,30 rpm,and 10K Tq, 11.29ppg ECD,and observe hole pack off.Work pipe free. T Stage up pumps and rotary to 212 9,550.0 9,550.0 1 16 10/3/2016 1.75 PROD1 DRILL CIRC gpm, 1595 psi,90 rpm, 10K Tq, 199:15:15 2 21:1:00 11.35ppg ECD and observe hole pack off.Work pipe free. Stage upand rotary to 261 9,550.0 9,550.0 21:00 22:0/2016 12:0/2016 1.00 PROD1 DRILL CIRC T gpm,2142 psi, rpm,10KTq, 21: 00 11.35ppg ECD and observe hole pack off.Work pipe free. Stage upand rotary to 261 9,550.0 9,550.0 12 10/4/2016 2.00 PROD1 DRILL CIRC T gpm,2117 psi, rpm,9K Tq, 22::0/2016 00 00:00 11.35ppg ECD.Sustain drilling rate for 2 minutes and then observe hole pack off.Work pipe free.PUW 195k,SOW 90k. OA pressure=580 psi Page 28/58 Report Printed: 10/31/201 • • f Operations Summary (with Timelog Depths) 2S-09 fr Conoccehillips ' Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) Run in hole one stand deeper to 9645' 9,550.0 9,645.0 10 12 2.50 PROD1 DRILL REAM T and wipe section.Stage up pumps 00::012016 00 02:303/2016 and rotary to 2 bpm,763 psi,10 rpm, and observe hole packoff.Work pipe free.Stage up pumps to 3.3 bpm,974 psi and observe hole pack off.Work pipe free and wipe section. 10/4/2016 10/4/2016 1.25 PROD1 DRILL SMPD T Strip insole f/ 90645 '16ps o000t of MPD 9,645.0 10,500.0 02:30 03:45 backprelips and 312 psi in slips. 10/4/2016 10/4/2016 4.75 PROD1 DRILL REAM T Wipe section f/10500'-10590'and 10,500.0 10,590.0 stage up pumps to 2 bpm,816 psi. 03:45 08:30 Observe hole packoff.Work pipe free and stage up to 2 bpm,800 psi,18 rpm, 10K Tq.Observe hole packoff. Work pipe free 10/4/2016 10/4/2016 2.25 PROD1 DRILL REAM T Stage0 rpm,up pumps TTp and .4 bpm,erve hole pack 868 psi, 10,590.0 10,590.0 08:30 10:45 off.Work pipe free and stage up to 3.3 bpm,1025 psi,26 rpm,9.5K Tq and observe hole packoff.Work pipe free. 10/4/2016 10/4/2016 7.00 PROD1 DRILL REAM T Stage up pumps to 2 bpm,750 psi,20 10,590.0 11,436.0 rpm,9.8K Tq and ream in hole slowly 10:45 17:45 f/10590'-11436'w/MPD backpressure of 202 psi at rate and 312 psi in slips. Note:Start adding Asphasol to mud system at 14:00 hrs to help stabilize shales,6 lb/bbl concentration. 10/4/2016 10/4/2016 3.25 PROD1 DRILL REAM T aediprocate stand f/tage ep pumps and 6-11rotar3t ' 11,436.0 11,530.0 17:45 21:00 bpm, 1128 psi,30 rpm, 11.5K Tq and observe hole pack off.Work pipe free and stage up to 4.5 bpm, 1550 psi,35 rpm,11.5K Tq and observe hole pack off.Work pipe free. Note-observed large amount of shale coming out over shakers once we reached 3.5 bpm/35 rpm and up. 10/4/2016 10/4/2016 2.25 PROD1 DRILL REAM T Stage up to 1.5 bpm,831 psi,20 rpm, 11,530.0 11,530.0 11.5K Tq,and observe hole pack off. 21:00 23:15 Work pipe free.Stage up to 3.5 bpm, 1145 psi,30 rpm,10.5K Tq and observe hole pack off.Work pipe free. Note:Able to work through and regain circulation/rotation after pack off events much quicker with less overpull than previously. Page 29/58 Report Printed: 10/31/2011 • 0 Operations Summary (with Timelog Depths) t f 2S-09 coa + hillips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10 16 10/5/2016 0.75 PROD1 DRILL REAM T Stage up to 2.5 bpm,924 psi,25 rpm, 11,530.0 11,530.0 !4 10K Tq and observe hole start to pack 23:155 00:00 off-maintain rotation and work free. Stage up to 2 bpm,857 psi,25 rpm, 10.3K Tq. Note:Observed that the majority of pack off events occur when increasing parameters while moving pipe on the upstroke. DRILL REAM T Stage up to 4.1 bpm, 1300 psi,30 11,530.0 11,530.0 10 10/5/2016 1.25 PROD1 rpm, 10.3K Tq and observe start to 00::0/2016 00 0 01:151:15 pack off @ 11477'-maintain rotation and work free. 10/5/2016 10/5/2016 2.25 PROD1 DRILL REAM T 01:15Stage u to 5.0 bpm,1730 psi,60 11,530.0 11,530.0 rpm, 11.0K Tq,11.31 ppg ECD, 01:15 03:30 observe hole pack off at 11516'.Work pipe free maintaining rotation.Attempt to stage back up and observe hole continue to try to pack off-pick up and wipe section. Stage upto 5.0 b m,1696 psi,60 11,530.0 11,530.0 10/5/2016 p 10/5/2016 1.25 PROD1 DRILL REAM T gECD,observe rpm, 11 K Tq, 11.28ppg 03:30 04:45 hole pack off @ 11517'.Work pipe free Stage upto 4.0 bpm,1190 psi,45 11,530.0 11,530.0 14 17 2.75 PROD1 DRILL REAM T rpm,10.5K Tq,and slowly work 04::4/2016 45 07::3/2016 30 through lower part of stand between 11510'-11520'.Continue staging up to 5.5 bpm, 1940 psi,50 rpm,10.8K Tq and observe hole pack off at 11518'.Work pipe free.Attempt to stage back up between and observe hole continue to try and pack off. 10/5/2016 10/5/2016 3.00 PROD1 DRILL REAM T Stage up to 2.0 bpm,800 psi,20 rpm, 11,530.0 11,530.0 9.8K Tq and slowly work through 07:30 10:30 11510'-11520'.Continue staging up to 3.0 bpm,1027 psi,20 rpm,9.6K Tq and observe hole start to pack off @ 11510'.Maintain 20 rpm and wipe section,attempting to stage up pumps. 1.00 PROD1 DRILL REAM T Stage up to 3.0 bpm,1031 psi,60 11,530.0 11,530.0 10 10/5/2016rpm, 10.8K Tq and observe hole start 10:303/2016 11:30 to pack off @ 11497'.Decrease rotary to 20 rpm and work to regain circulation. Stage upto 4.0 bpm,1308 psi,45 11,530.0 11,530.0 10/5/2016 16 4.50 PROD1 DRILL REAM T rpm,10.7K Tq and ream stand down. 11:30 16:000/2016 Pump 19 bbls of 10.5ppg sweep(150 funnel viscosity)and circulate around w/3 bpm,1025 psi,45 rpm, 10K Tq. Did not observe much of an increase in cuttings when sweep came around. T Stage up without rotary to 4.5 bpm, 11,530.0 11,439.( 10/5/2016 10/5/2016 1.00 PROD1 DRILL CIRC 1540 psi,and observe hole pack off at 16:00 17:00 11464'.Work pipe free and rack stand back. Page 30/58 Report Printed: 10/31/201 • • Operations Summary (with Timelog Depths) .60,0 ' g . 2S-09 ConocoPhiiGprs Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/5/2016 10/5/2016 4.50 PROD1 DRILL SMPD T Sb00 ftut off hoe f/11speed w3 MPD 00'at 11,439.0 7,600.0 17:00 21:30 backpressure of 420 psi out of slips and 312 psi in slips.Observe 40k overpull at 9100',but otherwise pulled out ok.PUW 188k.SOW 95k. Note:Decision made to abandon the lateral and re-drill intermediate and production sections due to instability of the Kalubik shale zone. 10/5/2016 10/5/2016 1.75 PROD1 DRILL SMPD T Strip BHA through the Kalubik up into 7,600.0 7,247.0 casing f/7600'-7220'at 300 ft/hr pull 21:30 23:15 speed and MPD backpressure of 420 psi out of slips and 312 psi in slips. Observe 30-40k overpulls at 7597', 7466',7455',7382',and 7346'-7335'. Also observed 20k overpull inside casing @ 7215'. 10/5/2016 10/6/2016 0.75 PROD1 DRILL CIRC T, w 220 gpmx b500 psiottoms, p side 7 3K casing 7,247.0 7,185.0 23:15 00:00 Tq. Note:Did not see any signs of fresh Kalubik shale coming over the shakers throughout circulation,only the same coffee-ground size particles of shale. No increase in cuttings seen at bottoms up. Continue circulating total of 2 x 7,185.0 7,185.0 10/ 00::0/201600 0 01:1:00 00/2016 1.00 PROD1 DRILL CIRC T bottoms up inside casing w/220 gpm, 0 1500 psi,60 rpm,7.3K Tq. Note:Did not see any signs of fresh Kalubik shale coming over the shakers throughout circulation,only the same coffee-ground size particles of shale. No increase in cuttings seen at bottoms up. 10/6/2016 10/6/2016 0.50 PROD1 DRILL OWFF T Monitor well for 30 minutes-static. 7,185.0 7,185.0 01:00 01:30 10/6/2016 10/6/2016 0.25 PROD1 DRILL SVRG T Service top drive,grease crown and 7,185.0 7,185.0 wash pipe.Line up MPD system for 01:30 01:45 stripping out of hole. 10/6/2016 10/6/2016 4.25 PROD1 DRILL SMPD T Stip out t of46hold rackingMPback 4"DP f/ 7,185.0 460.0 01:45 06:00 backpressure at 420 psi out of slips and 312 psi in slips,pulling at 5000 ft/hr pull speed. 10/6/2016 10/6/2016 0.25 PROD1 DRILL OWFF T Monitor well for 10 minutes-well 460.0 460.0 06:00 06:15 Pull MPD bearing assembly and drain 460.0 460.0 10/6/2016 10/6/20161.75 PROD1 DRILL MPDA T nipple.Install trip nipple.Clear rig floor 06:15 08:00 of MPD equipment. Page 31/58 Report Printed: 10/31/2011 • • Drilling Operations Summary (with Timelog Depths) .=t wens 2S-09 conocoPhitlips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Operation End Time Dur(hr) Phase Op Code Activity Code Time P-T-X (ftKB) End Depth(ftKB) 10/6/2016 10/6/2016 3.00 PROD1 DRILL BHAH T Pull out of hole and lay down BHA. 460.0 0.0 08:00 11:00 The bit had 3 x chipped teeth and was graded 0-1-CT-G-X-O-NO-HP. Observed dull spiral markings across the BHA tools,especially noticeable on the Impulse tool. It is presumed that the BHA was spinning on a sharp ledge while going in the hole,possibly at the shoe. 10/6/2016 10/6/2016 0.50 PROD1 DRILL RURD T Clean/clear rig floor. 0.0 0.0 11:00 11:30 10/6/2016 10/6/2016 0.50 PROD1 DRILL SFTY T Perform mobilize derrick r inspectionric0.0 0.0 11:30 12:00 floor. 10/6/2016 10/6/2016 4.50 PROD1 PLUG TRIP T ' Make up cement retainer as per Baker 0.0 7,082.0 12:00 16:30 and run in hole on 4"DP stands to 7082'.PUW 164k,SOW 108k. Observe string take 5-10k weight at 7082'. 10/6/2016 10/6/2016 0.75 PROD1 PLUG CIRC T Circulate at 7082',staging up from 1 7,082.0 7,052.0 16:30 17:15 bpm,281 psi,3%F/O to 3.5 bpm,495 psi,8%F/O,picking up to 7052'. 10/6/2016 10/6/2016 0.25 PROD1 PLUG PACK T Set cementer retainer at 7052'as per 7,052.0 7,052.0 17:15 17:30 Baker rep. 10/6/2016 10/6/2016 0.25 PROD1 PLUG RURD T Lay down 2 x joints 4"DP and rig up 7,052.0 7,052.0 17:30 17:45 to pressure test retainer. 10/6/2016 10/6/2016 0.50 PROD1 PLUG PRTS T Pressure test cement retainer to 3000 7,052.0 7,052.0 17:45 18:15 psi for 10 minutes,charted-good test. 4.9 bbls pumped/returned 10/6/2016 10/6/2016 0.75 PROD1 PLUG LOT T Sting into cement retainer to perform 7,052.0 7,052.0 18:15 19:00 injectivity test.Pump at 1/4 bpm for 2.6 bbls and observe pressure increase to 2639.Kill pump and observe pressure bleed down to1640 psi.Resume pumping at 1/4 bpm and pump 1.6 bbls,observe pressure slowly increasing to 2246 psi and then observe returns from annulus.Shut down pumps and bleed off pressure. 10/6/2016 10/6/2016 0.25 PROD1 PLUG CIRC T ' Sting out from retainer, nd can off top of 3 7,052.0 7,052.0 19:00 19:15 retainer. 10/6/2016 10/6/2016 1.00 PROD1 PLUG LOT T Sting back into cement retainer to 7,052.0 7,052.0 19:15 20:15 perform injectivity test.Stage up pump in increments to 3 bpm and observe pressure stabilize at 1952psi,162 strokes.Pump 5 more bbls and observe pressure start to increase above 2200 psi.Reduced rate to 1.5 bpm,2195 psi,and continued pumping,total of 362 strokes pumped. Kill pump and observe pressure bleed down to 1690 psi. 10/6/2016 10/6/2016 0.25 PROD1 PLUG SFTY T Hold PJSM for pumping cement 7,052.0 7,052.0 20:15 20:30 squeeze. 10/6/2016 10/6/2016 1.00 PROD1 PLUG RURD T Line up and flush choke line/gas 7,052.0 7,052.0 20:30 21:30 buster for taking returns through choke manifold.Rig up cementers and blow down lines. Page 32158 Report Printed: 10/31/2016 e • Operations Summary (with Timelog Depths) 0 ° 2S-09 ConocoPhi ips Job: DRILLING ORIGINAL Rig: DOYON 142 Start Depth End Depth(ftK8) Time Log (ftKB) Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Cementers pump Operation10 water and 7,052.0 7th(eKE CMNT T 21:30 ,052.0 10/3/2016 10/6/2016: 1.00 PROD1 PLUG pressure test lines to 550/3500 psi- 22:30 good test.Pump 58.8 bbls 15.8ppg Class G cement at 4.5 bpm,1576 psi, holding 800 psi backpressure through rig choke to minimize u-tubing.Shut chokes to hold pressure while swapping from cement to water. Cementers pump 5 bbls of water at 3bpm,240 psi and sting into cement retainer.Bleed off backside pressure, open bag,and line up to rig pump. SQEZ T Pump 62 bbls 10.Oppg FloPro w/rig 7,052.0 7,052.0 10/6/2016 10/6/20161.00 PROD1 PLUG pump.Staged up to 1.5 bpm,1578 psi 22:30 23:30 for 14.5 bbls and then observed pressure start to increase up to 2860 psi with no breakover.Decreased rate to 1 bpm and observed pressure breakover at 3039 psi.Continued pumping at 1 bpm,observing pressure climb to 3286 psi after 36.5 bbls pumped and then continue to fluctuate between 3000-3200 psi.Shut down after 62 bbls pumped and observe pressure fall to 2400 psi. Note:Squeezed 52 bbls of 15.8ppg Class G cement below cement retainer. TRIP T Sting out of cement retainer and pull 7,052.0 6,644.0 23::3/2016 30 00::0/2016 13 10 0.50 PROD1 PLUG out of hole 4 x stands slowly to 6644'. 00 Cement in place @ 00:06 hrs. Estimated top of cement inside 7-5/8" casing @ 6903'MD. 1.00 PROD1 PLUG CIRC T Confirm circulation,install wiper ball, 6,644.0 6,644.0 100/2016 and circulate drill string clean with 417 00::0/2016 00 0 01:1:00 gpm,1332 psi for full surface-to- surface volume. 10/0/2016 10/7/2016 2.75 PROD1 PLUG TRIP T Pull OOH racking back 50 x stands 4" 6,644.0 1,910.0 03:45 DP f/6644'-1910',monitoring 01:00displacement on trip tank. 2.50 PROD1 PLUG PULD T Pull OOH sideways laying down 20 x 1,910.0 0.0 13 16/7/2016 stands 4"DP and Baker tool f/1910' 03::4/2016 45 06:15 to surface,monitoring displacement on the trip tank. 0.0 0.0 10/7/2016 10/7/2016 0.50 PROD1 PLUG RURD T Clean/clear rig floor 06:15 06:450.0 6,750.0 4.25 PROD1 PLUG TRIP T Run in hole with muleshoe on 4" 10/7/2016 10/7/2016 HWDP and 4"DP stands from derrick 06:45 11:00 to 6750',monitoring displacement on trip tank. 1.00 PROD1 PLUG WASH T Wash in hole on 4"DP f/6750'-7007' 6,750.0 7,007.( 10/7/2016 12 w/84 gpm,345 psi,PUW 192k,SOW 11:00 12:000/2016 128k.Tag top of cement at 7007'w/ 8k weight. 2.25 PROD1 PLUG TRIP T Trip OOH w/4"DP standing back in 7,007.0 2,770. 10/7/201614/7/2016 derrick,monitoring displacement on 12:00 14:15 trip tank. Page 33/58 Report Printed: 10131/20' • • ex 0Operations Summary (with Timelog Depths) wit 2S-09 Conn hitlips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/7/2016 10/7/2016 3.25 PROD1 PLUG PULD T Pull OOH sideways laying down 30 x 2,770.0 0.0 14:15 17:30 stands 4"HWDP,monitoring displacement on trip tank. 10/7/2016 10/7/2016 0.25 PROD1 PLUG RURD T Clean/clear rig floor 0.0 0.0 17:30 17:45 10/7/2016 10/7/2016 0.25 PROD1 PLUG SFTY T Hold PJSM for slip/cut drill line. 0.0 0.0 17:45 18:00 10/7/2016 10/7/2016 2.50 PROD1 PLUG SLPC T Slip and cut 140'of drill line,perform 0.0 0.0 18:00 20:30 drawworks inspection,and calibrate top drive on amphion system. 10/7/2016 10/7/2016 0.50 PROD1 PLUG PULD T Hold PJSM and make up CIBP as per 0.0 0.0 20:30 21:00 Baker. 10/7/2016 10/7/2016 1.75 PROD1 PLUG TRIP T Run in hole on 4"DP stands from 0.0 2,972.0 21:00 22:45 derrick to 2972.PUW 84k,SOW 79k. 10/7/2016 10/7/2016 0.25 PROD1 PLUG MPSP T Drop 1.45"ball and pump down on 2,972.0 2,972.0 22:45 23:00 seat and set as per Baker,pressuring up to 1300 psi,bleeding down to 200 psi,and P/U to shear at 110k. Note:Top of CIBP @ 2972' 10/7/2016 10/8/2016 1.00 PROD1 PLUG MPSP T Rig up and pressure test CIBP to 3000 2,972.0 2,945.0 23:00 00:00 psi for 10 minutes,charted-good test. 1.9 bbls pumped/returned. Blow down kill line,rack back stand,and prepare for displacement to 140°F seawater. OA pressure=750 psi 10/8/2016 10/8/2016 0.25 PROD1 PLUG SFTY T Hold PJSM for displacing well to 2,945.0 2,945.0 00:00 00:15 seawater. 10/8/2016 10/8/2016 1.75 PROD1 PLUG DISP T Displace cased hole to 140°F 2,945.0 2,945.0 00:15 02:00 seawater.Pump 30 bbl hi-vis spacer followed by 290 bbls seawater from insulated vac truck at 166 gpm,ICP 412 psi,FCP 73 psi. 10/8/2016 10/8/2016 1.50 PROD1 PLUG TRIP T Trip out of hole f/2945'to surface, 2,945.0 0.0 02:00 03:30 racking back 4"DP stands and laying out Baker CIBP running tool.Monitor displacement on trip tank. 10/8/2016 10/8/2016 3.00 PROD1 PLUG TRIP T Make up Baker MSC cutter and trip in 0.0 2,972.0 03:30 06:30 hole on 4"DP stands to 2972'at 1.5 min/stand running speed as per Baker.Tag CIBP at 2972'w/5K. SIMOPS:Pressure test hardline to open top tank to 1500 psi and bleed off OA pressure.780 psi initial pressure bled down to 0 psi.Observed 1.5 bbl bled back. 10/8/2016 10/8/2016 1.50 PROD1 PLUG CPBO T Pick up and spot cutter at 2962'. 2,972.0 2,962.0 06:30 08:00 Perform casing cut w/226 gpm,830 psi,80 rpm,2.7k Tq,observing pressure drop to 180 psi.Close annular and confirm cut by pumping down drill string taking returns up OA to open top tank w/42 gpm,470 psi. Pick up 10'and confirm circulation again w/42 gpm,415 psi. Page 34/58 Report Printed: 10/31/2016 • • r,�,; , Operations Summary with Timelog Depths) . .�t 2S-09 Cc noco hilli ,.,F. Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Operation (ftK6) End Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X 2 B) 2,945.0 RURD T Rack back 1 x stand,rig up Little Red 18 10/8/2016 1.00 PROD1 PLUG to pump down drill string,pressure 08::012016 00 0 09:009:00 test lines to 2000 psi,and hold PJSM for displacement. DISP T Displace isotherm out of OA.LRS 2,945.0 2,945.0 19 19 0.75 PROD1 PLUG pump 30 bbl 90°F diesel down drill 09::0/2016 00 09::412016 45 string to cutter at 4 bpm,518 psi, taking seawater returns to the rig. Close annular and open OA.LRS pump 60 bbls 90°F diesel staging up to 2.5 bpm,830 psi,observing pressure drop to 400 psi rapidly after 40 bbls pumped.Volume in open top tank at 82 bbls. 10/8/2016 10/8/2016 2.25 PROD1 PLUG DISP T Line up rig to pump down drill string w/ 2,945.0 2,945.0 annular closed,taking returns to OA. 09:45 12:00 Pump 25 bbl soap pill at 4 bpm,440 psi,followed by 10 bbls Hi-vis pill at 3 bpm,300 psi,followed by 35 bbls 9.2ppg WBM at 4.5 bpm,790 psi.Line up to kill line and pump 25 bbl soap pill at 4.5 bpm,330 psi,followed by 40 bbl Hi-vis pill at 4.5 bpm,325 psi, followed by 78 bbl 9.2ppg WBM at 5.0 bpm,216 psi.Shut down and suck down fluid level in open top tank. Continue pumping 103 bbl 9.2ppg WBM at 5.5 bpm,350 psi. Monitorgaugeon OA.Observe 2,945.0 2,945.0 10/8/201613 1.00 PROD1 PLUG OWFF T pressure increase from 10 psi to 30 12:00 13:000/2016 psi.Bleed off and open OA to the cellar to monitor for flow.Observe thick gelled fluid flowing back. 10/8/2016 10/8/2016 0.25 PROD1 PLUG CIRC T Line up to pump down IA w/annular 2,945.0 2,945.0 closed taking returns to open top tank. 13:00 13:15 Pump 35 bbls 9.2ppg WBM at 4.0 bpm,235 psi. Monitor well for flow out of OA into the 2,945.0 2,945.0 1 16 10/8/20162.25 PROD1 PLUG OWFF T cellar as well as the drill pipe and IA. 133:15:15 15:30 Observe fluid flowing back.Check volume with vis cup every 5 minutes, initial flowback rate of 1.2 bbl/hr decreased to 0.35 bbl/hr. TRIP T Pull out of hole f/2945'to surface, 2,945.0 0.0 10/8/201617/3/2016 2.00 PROD1 PLUG PUW 87k,SOW 82k,monitoring 15:30 17:30 displacement on trip tank.UD Baker MSC cutter assembly. Note:Monitored OA for flowback to cellar during trip,observe initial flowback taper off to static. RURD T Clean/clear rig floor. 0.0 0.0 10/8/2016 10/8/2016 0.50 PROD1 PLUG 17:30 18:00 Change out top3-1/2"x 6"VBR rams 0.0 0.0 18 10/8/2016 1.50 PROD1 PLUG BOPE T for 7-5/8"solid body casing rams. 18:000/2016 19:30 Simops:mobilize casing tools to rig floor Page 35/58 Report Printed: 10/31/201 • • Operations Summary (with Timelog Depths) 4 ora 2S-09 illiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/8/2016 10/8/2016 1.50 PROD1 PLUG BOPE T Remove wear ring&install test plug. 0.0 0.0 19:30 21:00 Test upper rams and annular to 250/3500 psi for 5 minutes each, charted.Pull test joint&plug.Blow down&rig down test equipment. 10/8/2016 10/8/2016 2.00 PROD1 PLUG PULL T Run in with pack off pulling tool on 4" 0.0 0.0 21:00 23:00 DP and make up to pack off.Bleed off pressure and run out lock down screws.Pull pack off to floor and lay out same. Simops:Reassemble double-stack casing tongs on rig floor-will not fit through beaver slide in one piece. 10/8/2016 10/9/2016 1.00 PROD1 PLUG PULL T Run in with landing joint and make up 2,962.0 2,923.0 23:00 00:00 to hanger,bumping 1 turn to the right and then 8 turns to the left.Pull hanger to the floor,PUW 118k,SOW 111k.Lay down landing joint and hanger and make up XO with circulating swedge to casing. 10/9/2016 10/9/2016 0.75 PROD1 PLUG CIRC T Circulate 2 x bottoms up w/11 bpm, 2,923.0 2,923.0 00:00 00:45 237 psi, 17%F/O until shakers clean up. 10/9/2016 10/9/2016 4.75 PROD1 PLUG PULL T POOH and lay out 7-5/8"casing f/ 2,923.0 0.0 00:45 05:30 2923'to surface,70 full joints plus 19.48'of cut joint#71,monitoring displacement on trip tank. 10/9/2016 10/9/2016 0.50 PROD1 PLUG RURD T Rig down casing tongs and clean/ 0.0 0.0 05:30 06:00 clear rig floor 10/9/2016 10/9/2016 2.50 PROD1 PLUG BOPE T Change out upper 7-5/8"casing rams 0.0 0.0 06:00 08:30 for 3-1/2"x 6"VBRs.Simops change out saver sub from XT39 to 4-1/2"IF 10/9/2016 10/9/2016 1.00 PROD1 WHDBOP RURD T Set test plug,rig up to test&perform 0.0 0.0 08:30 09:30 shell test. Page 36/58 Report Printed: 10/31/2016 . • Operations Summary (with Timelog Depths) 1 .i01111.r e' ,4�� 2S-09 amocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Operation (ftKB) End.Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Test witnessed by AOGCC Rep.Guy 0.0 0.0 10/9/2016 10/9/2016 4.50 PROD1 WHDBOP BOPS T Cook.Tested with 5"test joints. 09:30 14:00 250/3500 psi,charted for 5 minutes each. Test#1 with 5"test joint,testing Annular,CV#1,#12,#13,#14,4"kill line valve on mud manifold,and 4-1/2" IF Dart valve. Test#2-Top Pipe rams,CV#9,#11, mezzanine kill valve,and 4-1/2"IF FOSV Test#3-CV#8,#10,and HCR Kill. Test#4-CV#6,#7. Test#5-Super choke and manual choke to 1500 psi Test#6-CV#2,#5,and manual kill Test#7-HCR choke. Test#8-Manual choke Test#9-Lower pipe rams,upper IBOP Test#10- Lower IBOP Test#11 -Blind rams,CV#3,#4,and #6. Perform Koomey draw down test. Observed initial system pressure at ACC-3050 PSI,MAN-1500 PSI,and annular-1000 PSI.After Closure observed ACC-1800 PSI,200 PSI increase in 10 seconds,and full pressures at 55 seconds. Observed 6 nitrogen bottles with an average PSI of 2392 PSI. Tested pit level sensors&flow out alarms.Gas detection alarms tested w/low&high level. 10/9/2016 10/9/2016 1.00 PROD1 WHDBOP RURD T Blow down&rig down test equipment. 0.0 0.0 Pull test plug,set wear bushing w/10" 14:00 15:00 ID&RILDS. 10/9/2016 10/9/2016 0.50 PROD1 PLUG RURD T R2'U casing cemuipt sent for running 3- 0.0 0.0 15:00 15:30 0.0 937.0 10/9/2016 10/9/2016 2.00 PROD1 PLUG PULD T Run in hole w/30 x joints 3-1/2"EUE cement stinger from surface to 937', 15:30 17:30 monitoring displacement on trip tank. RIH on 5"DP singles from pipe shed f/ 937.0 2,960.0 10/9/201610/9/2016 2.75 PROD1 PLUG PULD T 937'-2960',monitoring displacement 17:30 20:15 on trip tank. 10/9/2016 10/9/2016 1.00 PROD1 PLUG PULD T Make up 15'pup and attempt to run in 2,960.0 2,964.0 and tag top of bridge plug.Observe 20:15 21:15 string tagging up on 7-5/8"casing cut at 2964'w/5k weight,PUW 92k,SOW 89k.Work section trying to get stinger inside casing.Rotate at 10-20 rpm, 1.5k tq,pump at 2-6 bpm,100-144 psi,and watch for sign of increase in pump pressure on tag w/4-7k weight- no increase observed.Discuss with engineer. Continue circulating 1 x bottoms up at 2,964.0 2,964.0 10/9/ 21:15 016 21:45 016 0.50 PROD1 PLUG CIRC T 10 bpm,214 psi,17%F/O,observe 21:15 21:45 9.2ppg MW in/out,total of 305 bbls pumped. Page 37/58 Report Printed: 10/31/2011 • Operations Summary (with Timelog Depths) J 1 }�( ,r,-' _ 4 2S-09 ConocoPfiilii Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/9/2016 10/9/2016 0.75 PROD1 PLUG RURD T Layout 15'pup and M/U 5'pup for 2,964.0 2,964.0 21:45 22:30 spaceout. Blowdown topdrive and rig up cement line.Establish circulation at 4bpm, 117 psi,7%F/O and hold PJSM for cement job. 10/9/2016 10/9/2016 1.25 PROD1 PLUG CMNT T Line up to cement unit&start batch 2,964.0 2,964.0 22:30 23:45 mixing 17ppg cement.Pump 5 bbls of water to flood lines at 4 bpm, 137 psi. Test lines to 600/4000 psi.Reset high trip to 2500 psi.Batch mix 12.5ppg mudpush and pump at 5.5 bpm, 127 psi for a total of 35.5 bbls. Pump pP9 17 Class G cement at 6 bpm,150 psi for total of 60.1 bbls. Pump 12.5ppg mudpush at 4 bpm,30 psi for total of 4 bbls.Flush lines to rig floor w/1.5 bbls mudpush.Swap to rig and pump 9.2ppg WBM at 6 bpm,76- 350 psi for total of 28.6 bbls. Observed pressure rapidly increase to 350 psi after 24.5 bbls pumped as fluid caught falling cement. 10/9/2016 10/10/2016 0.25 PROD1 PLUG RURD T Rig down cement line and lay out pup 2,964.0 2,929.0 23:45 00:00 joint and top single f/2964'-2929'. 10/10/2016 10/10/2016 1.25 PROD1 PLUG TRIP T Pull OOH at 1000 ft/hr f/2929'-2075', 2,929.0 2,075.0 00:00 01:15 racking back 5"DP.Observe first single pull slightly wet and then remaining stands pull wet. CIP @ 01:15 10/10/2016 10/10/2016 0.75 PROD1 PLUG CIRC T Drop wiper ball,kick out with 15 bbls 2,075.0 2,075.0 01:15 02:00 fresh water,and circulate drill string clean w/250 bbls 9.2ppg WBM at 10 bpm, 154 psi, 16%F/O. 10/10/2016 10/10/2016 1.50 PROD1 PLUG TRIP T Pull OOH racking back 5"DP f/2075'- 2,075.0 937.0 02:00 03:30 937',monitoring displacement on trip tank. 10/10/2016 10/10/2016 1.50 PROD1 PLUG PULD T Rig up tongs and Pull OOH layind 937.0 0.0 03:30 05:00 down 3-1/2"cement stinger f/937'to surface,monitoring displacement on trip tank. 10/10/2016 10/10/2016 1.50 PROD1 PLUG RURD T Rig down casing running equipment, 0.0 0.0 05:00 06:30 clean and clear rig floor from cement job,clear shed and prepare for picking up 5"DP. 10/10/2016 10/10/2016 6.00 PROD1 PLUG PULD T Pick up and rack back 46 x stands 5" 0.0 0.0 06:30 12:30 DP out of the mousehole. 10/10/2016 10/10/2016 1.00 PROD1 PLUG RURD T Clean and clear rig floor and mobilize 0.0 0.0 12:30 13:30 BHA to floor. 10/10/2016 10/10/2016 3.25 PROD1 PLUG BHAH T Pick up BHA#6 as per SLB and 0.0 781.0 13:30 16:45 single in with 5"HWDP and jars to 781'. 10/10/2016 10/10/2016 1.50 PROD1 PLUG PULD T Run in hole on 5"DP singles f/781'- 781.0 2,017.0 16:45 18:15 2017',filling pipe every 1000'and monitoring displacement on trip tank. PUW 117k,SOW 104k. 10/10/2016 10/10/2016 0.25 PROD1 PLUG TRIP T Continue running in hole on 5"DP 2,017.0 2,204.0 18:15 18:30 stands f/2017'-2204',monitoring displacement on trip tank. Page 38/58 Report Printed: 10/31/2016 0 • Operations Summary (with Timelog Depths) 2S-09 ConocoPhillips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth (ftKB) End Depth(ftKB) ation Oper Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Wash in hole f/220r tion 'at 2 bpm, 2,204.0 2,400.0 10/10/2016 10/10/2016 0.75 PROD1 PLUG WASH T 147 psi,6%F/O.Tag up at 2374'w/ 18:30 19:15 8k weight.Ream down from 2374'- 2400'w/12 bpm,50 rpm,1-3k WOB and observe hard cement at 2400'. TOC @ 2400'. Drill out cement f/2400'-2772',2554' 2,400.0 2,772.0 10/10/2016 10/11/2016 4.75 PROD1 PLUG DRLG T TVD w/350-500 gpm,750-1150 psi, 19:15 00:00 14-19%F/O,50-70 rpm,6-12k Tq on, 4-7k Tq off,5-12k WOB,PUW 130k, SOW 110k,ROT 123k,9.2ppg MW. Note:Shakers blinding off©2775' due to cement contamination,adjust flow rates,lower screen sizes,and treat mud to minimize fluid loss over shakers. Drill out cement f/2772'-2795',w/ 2,772.0 2,795.0 10/11/2016 10/11/2016 0.50 PROD1 PLUG DRLG T 350-500 gpm,750-1150 psi,14-19% 00:00 00:30 F/O,50-70 rpm,6-12k Tq on,4-7k Tq off,5-12k WOB,PU 130k,SO 110k, ROT 123k,9.2ppg MW. Note:Shakers blinding off due to cement contamination,adjust flow rates,lower screen sizes,and treat mud to minimize fluid loss over shakers. 10/11/2016 10/11/2016 0.50 PROD1 PLUG CIRC T PJSM-circulate at a reduced rate to 2,795.0 2,795.0 change shaker screens 116 gpm, 100 00:30 01:00 psi,70 rpm,Tq 5K. 10/112016 10/11/2016 1.50 PROD1 PLUG DRLG T Drill out cement f/2795'-2854',w/ 2,795.0 2,854.0 01:00 02:30 650 gpm, 1651 psi,FO 20%,60 rpm, 01:00 Tq on 6k,Tq off 4K,WOB 5-8K,PU 135K,SO 110K,ROT 123K,MW 9.2 PPg. PJSM-directional drill 9-7/8"X11" 2,854.0 2,958.0 -- 12/11/2016 10/11/2016 2.50 INTRM2 DRILL DDRL T intermediate hole section f/2854'- 02:30 05:00 2958'MD,2712'TVD,650 gpm,1650 psi,FO 20%,60 rpm,Tq on 6K,WOB 5-8K,ECD,Off Bottom 1600 psi,PU 135K,SO 110K,ROT 123K,Tq off K, MW 9.2 ppg,Max gas 136, ADT 1.32, Bit 2.91,Jars 85.65,Total Footage 104'MD. Kick w/Drilling CRT 150 sec @ 04:00 hrs. PJSM-displace well to 9.2 ppg LSND 2,958.0 2,958.0 10/11/2016 06:30 2016 1.50 INTRM2 DRILL DISP T at 615 gpm, 1226 psi,60 rpm. 05:00 06:30 2,958.0 2,958.0 10/11/2016 10/11/2016 0.50 INTRM2 DRILL CIRC T Drop RFID down at 640 gpm, 350 psi.Observe 06:30 07:00 no change in MWD turbine speed or pump pressure.Pull test to 15K over. Page 39/58 Report Printed: 10/31/201 • • Operations Summary (with Timelog Depths) r144: x 2S-09 CanacoPhitiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (1tKB) End Depth(ftKB) 10/11/2016 10/11/2016 1.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 2,958.0 3,024.0 07:00 08:00 intermediate hole section f/2958'- 3024'MD,2712'TVD,803 gpm,1965 psi,FO 25%,80-100 rpm,Tq on 7K, WOB 3-5K,ECD,Off Bottom 1900 psi,PU 135K,SO 110K,ROT 123K, Tq off 6K,MW 9.2 ppg,Max gas, ADT.74,Bit 3.65,Jars 86.39,Total Footage 66'MD. 10/11/2016 10/11/2016 1.50 INTRM2 DRILL CIRC T PJSM-TOH f/3024'-2822'MD, 3,024.0 2,822.0 08:00 09:30 observe no over pull as reamer enters the shoe. Drop below shoe&drop RFID chips to close as per WFT. Attempt to confirm opening&closing of reamer.Decision made to trip to surface&change out under reamer. 10/11/2016 10/11/2016 0.25 INTRM2 DRILL OWFF T Monitor well,static.SIMOPS blow 2,822.0 2,822.0 09:30 09:45 down TD. 10/11/2016 10/11/2016 2.25 INTRM2 DRILL TRIP T PJSM-TOH f/2822'-96'MD, 2,822.0 96.0 09:45 12:00 10/11/2016 10/11/2016 1.00 INTRM2 DRILL BHAH T PJSM-lay down reamer,pick up to 96.0 96.0 12:00 13:00 power drive inspecting pads,&make up back up reamer. 10/11/2016 10/11/2016 0.50 INTRM2 DRILL BHAH T PJSM-shallow test reamer at surface 96.0 96.0 13:00 13:30 at 502 gpm,615 psi.Reamer opened &closed as intended.Blow down top drive. 10/11/2016 10/11/2016 2.50 INTRM2 DRILL TRIP T PJSM-TIH f/96'-2944'MD,fill pipe 96.0 2,944.0 13:30 16:00 every 1000',PU 122K,SO 110K. 10/11/2016 10/11/2016 0.50 INTRM2 DRILL CIRC T Circulate to open reamer at 650 gpm, 2,944.0 2,944.0 16:00 16:30 1415 psi,FO 20%,20 rpm,Tq 5K,PU 122K,SO 120K,MWD turbine 2425 rpm.Drop RFID tags&pump down at 650 gpm.Reduce flow at 350 strokes to 200 gpm,pressure dropped f/1421 psi to 1185 psi.Torque increased 2K. With pumps at 650 gpm,MWD turbine at 2031 rpm.Reamer indicated open. 10/11/2016 10/11/2016 0.50 INTRM2 DRILL UREM T Ream f/2944'-3024',750 gpm, 1744 2,944.0 3,024.0 16:30 17:00 psi,FO 22%, 100 rpm,Tq 5-7K,WOB 1K,130 fph,PU 135K,SO 112K,ROT 125K. 10/11/2016 10/12/2016 7.00 INTRM2 DRILL DDRL T PJSM-directional drill 9-7/8"X11" 3,024.0 3,620.0 17:00 00:00 intermediate hole section f/3024'- 3620'MD,3287'TVD,815 gpm, 1950 psi,FO 22-24%, 120 rpm,Tq on 6- 14K,WOB 8-14K,ECD 9.8-10.1,Off Bottom 1935 psi, PU 155K,SO 117K, ROT 134K,Tq off 4-8K,MW 9.2 ppg, Max gas 46, ADT 5.07,Bit 8.72,Jars 91.46,Total Footage 596'MD. SCR @ 3525'MD,3205'TVD,MW 9.2 ppg,23:10 hrs. #1 @30= 140;@40=180 #2@30= 140;@40=180 Page 40/58 Report Printed: 10/31/2016 Operations Summary (with Timelog Depths) 3 2S-09 COVIOCOPhiiiipS ,, Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Operation (ftKB) End Dept End Time Dur(hr) Phase Op Code Activity Code Time P-T-X3,620.0 4,h90.0 S2/201 {ftKBj DDRL T PJSM-directional drill 9-7/8"X11" Depth 10/1 /2016 16/12/2016 6.00 INTRM2 DRILL intermediate hole section f/3620'- 00:000 06:00 4190'MD,3723'TVD,815 gpm,2100 psi,FO 22%, 120 rpm,Tq on 12K, WOB 15K,ECD 10.03,Off Bottom 1930 psi,PU 168K,SO 120K,ROT 136K,Tq off 11K,MW 9.2 ppg,Max gas 8, ADT 4.32,Bit 13.04,Jars 95.74,Total Footage 570'MD. DDRL T PJSM-directional drill 9-7/8"X11" 4,190.0 4,757.0 16 10/12/2016 6.00 INTRM2 DRILL intermediate hole section f/4190'- 06:: 0/2016 00 12:00 4757'MD,4222'TVD,815 gpm,2314 psi,FO 23%,140 rpm,Tq on 14K, WOB 15K,ECD 10.18,Off Bottom 2280 psi,PU 181K,SO 141K,ROT 145K,Tq off 12K,MW 9.2 ppg,Max gas 8, ADT 4.57,Bit 17.61,Jars 100.35,Total Footage 567'MD. SCR @ 4287'MD,3807'ND,MW 9.2 ppg,07:00 hrs. #1 @30=180;@40=220 #2 @30=180;@40=220 SCR @ 4757'MD,4222'TVD,MW 9.2 ppg,11:45 hrs. #1 @ 30=180;@ 40=220 #2 @30=180;@40=220 PJSM-directional drill 9-7/8"X11" 4,757.0 5,139.0 10/12/201615/1212016 3.50 INTRM2 DRILL DDRL T intermediate hole section f/4757'- 12:00 15:30 5139'MD,4609'TVD,815 gpm,2560 psi,FO 22%,140 rpm,Tq on 15K, WOB 13-18K,ECD 10.56,Off Bottom 2484 psi,PU 180K,SO 147K,ROT 163K,Tq off 7-10K,MW 9.2-9.6 ppg, Max gas 40, ADT 3.04,Bit 20.65, Jars 103.39,Total Footage 382'MD. Man Down Drill CRT 67 sec at 14:40 hrs. 10/12/2016 10/12/2016 0.50 INTRM2 DRILL CIRC T CBU at 815 gpm,2560 psi,FO 22%, 5,139.0 5,139.0 140 rpm,Tq 7-10K,PU 180K,SO 15:30 16:00 147K,ROT 163K,MW 9.6 ppg. Monitor well,static.SIMOPS blow 5,139.0 5,139.0 10/12/2016 10/12/2016 0.25 INTRM2 DRILL OWFF T down TD. 16:00 16:15 PJSM-remove trip nipple,install MPD 5,139.0 5,139.0 10/12/201617/12/2016 1.25 INTRM2 DRILL MPDA T bearing,&drain nipple.Break in 16:15 17:30 bearing at 30&60 rpm for 5 minutes each. Page 41158 Report Printed: 10/31/201 • Operations Summary (with Timelog Depths) V. � 2S-09 ConncoPhitiiips `' Job: DRILLING ORIGINAL Rig: DOYON 142 Start Depth Time Log End Depth(ftKB) Operation Start End Time Dur(hr) Phase Op Code Activity Code Time P-T-X PJSM-directional drill 9-7/8"X11" 5,139.0 5,705.0 12 DRILL DDRL T INTRM217: 0/2016 10/13/2016 6.50 intermediate hole section f/ 17:30 00:00 5139- 5705'MD,5139'TVD,815 gpm,2750 psi,FO 22%,140 rpm,Tq on 13-18K, WOB 15-25K,ECD 10.75,Off Bottom 2725 psi,PU 198K,SO 157K,ROT 169K,Tq off 7-10K,MW 9.7 ppg,Max gas 59, ADT 4.34,Bit 24.99,Jars 107.73,Total Footage 566'MD. SCR©5705'MD,3190'ND,MW 9.7 ppg,23:30 hrs. #1 @30=220;@40=270 #2 @ 30=220;@ 40=260 5,705.0 6,368.0 10/13/2016 10/13/2016 6.00 INTRM2 DRILL DDRL T intermediate ihole seiction/8 5705- 00:00ll 06:00 6368'MD,5711'ND,815 gpm,2850 psi,FO 22-30%, 140 rpm,Tq on 13- 18K,WOB 15-25K,ECD 10.7-11.0, Off Bottom 2825 psi,PU 210K,SO 158K,ROT 171K,Tq off 20K,MW 9.8 ppg,Max gas 50, ADT 4.95,Bit 29.94,Jars 112.68,Total Footage 663' MD. SCR @ 6272'MD,5634'TVD,MW 9.9 ppg,05:30 hrs. #1 @ 30=220;@ 40=280 #2 @ 30=220;@ 40=280 6,368.0 6,842.0 160/2016 10/13/2016 6.00 INTRM2 DRILL DDRL T inPJSM-termediiateiholeonal sectionrill /ff/6368'- 06:00 12:00 6842'MD,6015'TVD,800 gpm,2950 psi,FO 22-30%,140 rpm,Tq on 18- 22K,WOB 15-25K,ECD 10.7-11.0, Off Bottom 2900 psi,PU 230K,SO 149K,ROT 177K,Tq off 20K,MW 9.9 ppg,Max gas 50, ADT 3.93,Bit 33.87,Jars 116.61,Total Footage 474' MD. Spill Drill CRT 120 sec @ 07:00 hrs. PJSM-directional drill 9-7/8"X11" 6,842.0 7,235.0 10/13/201618/13/2016 6.00 INTRM2 DRILL DDRL T intermediate hole section f/6842'- 12:00 18:00 7235'MD,6179'ND,800 gpm,3200 psi,FO 25-30%,140 rpm,Tq on 16- 22K,WOB 15-25K,ECD 11.2-11.45, Off Bottom 3190 psi,PU 244K,SO 144K,ROT 179K,Tq off 18K,MW 10.1 ppg,Max gas 50, ADT 4.23,Bit 38.10,Jars 120.84,Total Footage 393' MD. Fire Drill CRT 69 sec @ 13:30 hrs. SCR @ 6935'MD,6060'ND,MW 10.1 ppg,13:00 hrs. #1 @ 30=250;@ 40=340 #2 @ 30=250;@ 40=340 Page 42158 Report Printed: 10/31/201 • • Operations Summary (with Timelog Depths) 4.kz. 2S-09 i yty S' ConocoPhi ltl S's Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Operation (ftKB) End Depth(ftKB) Start lime End Time Dur(hr) Phase Op Code Activity Code lime P-T-X 7,600.0 10/13/2016 10/14/2016 6.00 INTRM2 DRILL DDRL T PJSM -ddireiatectional hole drillsell9-7/8"X11" 7,235.0 18:00 00:00 7600'MD,6257'TVD,800 gpm,3265 psi,FO 22-30%,140 rpm,Tq on 14- 22K,WOB 15-25K,ECD 11.15-11.4, Off Bottom 3220 psi,PU 254K,SO 134K,ROT 175K,Tq off 17-20K,MW 10.1 ppg,Max gas 335, ADT 4.0,Bit 42.10,Jars 124.84,Total Footage 365' MD. Started having losses at 7599'MD,45 bbls initial loss during connection ramp schedule. SCR @ 7310'MD,6209'TVD,MW 10.0 ppg, 19:00 hrs. #1@30=270;@40=330 #2 @ 30=270;@ 40=330 10/14/2016 10/14/2016 6.00 INTRM2 DRILL DDRL TPJSM-intermediate ionaldrill9ole n/88/17600' 7,600.0 8,025.0 00:00 06:00 8025'MD,6325'TVD,800 gpm,3240 psi,FO 27%, 140 rpm,Tq on 22K, WOB 25K,ECD 11.27,Off Bottom 3100 psi,PU 254K,SO 131K,ROT 174K,Tq off 20K,MW 10.2 ppg,Max gas 101, ADT 5.62,Bit 47.72,Jars 130.46,Total Footage 365'MD. Kick w/Drilling CRT 180 sec @ 05:00 hrs. Observed losses while drilling ahead f/ 7600'-7884'MD,starting at 25 bph reducing to none. 10/14/2016 10/14/2016 3.00 INTRM2 DRILL DDRL TPJSM-intermediate directional hole dsrill t- f 8 9-7/8"X11" 025' 8,025.0 8,138.0 06:00 09:00 8138'MD,6334'TVD,800 gpm,3170 psi,FO 27%, 150 rpm,Tq on 25K, WOB 12K,ECD 11.27,Off Bottom 3000 psi,PU 280K,SO 115K,ROT 172K,Tq off 20K,MW 10.2 ppg,Max gas 101, ADT 2.44,Bit 50.16,Jars 132.9,Total Footage 113'MD. Drill ahead at 50 fph for hole cleaning, hold 150 psi on connections. 10/14/2016 10/14/2016 2.00 INTRM2 CASING CIRC T CBU f/8135'-8074'MD at 800 gpm, 8,138.0 8,074.0 09:00 11:00 3125 psi,100 rpm,Tq 15-20K,PU 280K,SO 115K,ROT 171. 10/14/2016 10/14/2016 1.00 INTRM2 CASING OWFF T Perform MPD no flow test,6 test 8,074.0 8,074.0 11:00 12:00 cycles,record pressure every 5 minutes.ISIP 101 psi,FSIP 57 psi. 10/14/2016 10/14/2016 0.50 INTRM2 CASING CIRC T PJSM-close under reamer as per 8,074.0 8,074.0 12:00 12:30 WFT Rep.650 gpm,2293 psi,10 rpm, Tq 19K,FO 27%,MWD turbine 2148 rpm.Drop RFID chips&circulate 1000 strokes at 650 gpm,decreasing to 200 gpm for 550 strokes.Pumps off for 10 minutes.Circulate at 650 gpm,2630 psi,10 rpm,Tq 19K,FO 27%,MWD turbine 2539 rpm. Page 43/58 Report Printed: 10/31/2016 • • Operations Summary (with Timelog Depths) elr 2S-09 ConocaPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Operation (ftKB) End Depth(EKE) Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Load 66 bbls of LCM pill in DP&spot 8,074.0E) 7,507. 0 12: 0/2016 4:3010/14/2016 2.00 INTRM2 CASING PMPO T f/8074'-7507'MD,3 bpm,360 psi, 12:30 14:30 1500 fph,PU 285K,SO 115K. 10/14/2016 10/14/2016 2.50 INTRM2 CASING PMPO T PJSM- 4' out at o6ho50le witgpmh MP psi,f/ 7,507.0 6,844.0 14:30 17:00 750FO 30%,PU 270K,SO 115K. 10/14/2016 10/14/2016 1.75 INTRM2 CASING CIRC T 6BU 2x till MD shakers clean t 700 gpm 2740 84psi4'0 66 ,844.0 6,747.0 17:00 18:45 30%,80 rpm,Tq 18K,PU 273K,SO 147K,ROT 188K. 6,747.0 6,747.0 10/14/2016 10/14/2016 3.25 INTRM2 CASING OWFF T Monitor well,breathing testy&ob erveerform lwell go static, l bore 18:45 22:00 10 rpm,Tq 19K. 10/14/2016 10/15/2016 2.00 INTRM2 CASING PMPO T / ad67171 bbls of LCM M 3 bplll,in DP0n psi&spot 6,747.0 6,100.0 22:00 00:00 1500 fph,PU 250K,SO 110K. 10/15/2016 10/15/2016 1.50 INTRM2 CASING PMPO T PJS - continue'MD,3 bpm,LCM ppilll 1f / 6,100.0 5,328.0 00:00 01:30 610Ufph,PU 221K,SO 131K. 10/15/2016 10/15/2016 1.75 INTRM2 CASING SMPD T PJSM-strip o1ut ofsi he out ofe hole ro 5328'- 2 5,328.0 4,280.0 01:30 03:15 4280'psi BP in slips. 10/15/2016 10/15/2016 0.25 INTRM2 CASING OWFF T M� itor well because of y shutting in the MPD proper holle 4e ,280.0 4,280.0 03:15 03:30 pressure build up,well static. 10/15/2016 10/15/2016 1.75 INTRM2 CASING SMPD T PJSM-strip o1ut ofsi he out ofe hole from slips,40 4280'- 4,280.0 3,052.0 03:30 05:15 3052'psi BP in slips. 10/15/2016 10/15/2016 0.25 INTRM2 CASING SRVY T Check shot survey @ 3052'MD. 3,052.0 3,052.0 05:15 05:30 10/15/2016 10/15/2016 0.50 INTRM2 CASING SMPD T StriSIDp out of 125 psit the hole out from oo ps5 2 2812' 3,052 .0 2,812.0 05:30 06:00 in slips,PU 135K,SO 107K. 10/15/2016 10/15/2016 1.00 INTRM2 CASING CIRC T C at 95 q 6 pm ROT 11609 psi, O 7% 2,812.0 2,812.0 06:00 07:00 10/15/2016 10/15/2016 1.25 INTRM2 CASING OWFF T Monitor well till static,bled back 1 bbl. 2,812.0 2,812.0 07:00 08:15 10/15/2016 10/15/2016 1.25 INTRM2 CASING MPDA T PJSM-removeblodPDbMPDg choke Ill 2,812.0 2,812.0 08:15 09:30 lines. 10/15/2016 10/15/2016 3.75 INTRM2 CASING TRIP T PJSM- TOH 65 ft 2812 192 MD,PU 2,812.0 192.0 09:30 13:15 10/15/2016 10/15/2016 1.75 INTRM2 CASING BHAH T PJSM-lay down BHA 7 as per SLB 192.0 0.0 13:15 15:00 0.0 10/15/2016 10/15/2016 1.00 INTRM2 CASING WWWH T PJSM-make up stack washer&clean 0.0 stack w/850 gpm, 145 psi,FO 25%. 15:00 16:00 Lay down stack washer. 0.0 0.0 10/15/2016 10/15/2016 1.00 INTRM2 CASING BHAH T PJSM-clear&clean floor of BHA. SIMOPS-empty stack&bring casing 16:00 17:00 running equipment to the rig floor. 0.0 0.0 10/15/2016 10/15/2016 1.00 INTRM2 CASING BOPE T PJSM- sol d change nboge outamspper upper ms tog 7- up 17:00 18:00 5/8to run casing. 10/15/2016 10/15/2016 1.00 INTRM2 CASING RURD T PJSM-remove wear ring&install test 0.0 0.0 18:00 19:00 Page 44/58 Report Printed: 10/31/2016 i • Operations Summary (with Timelog Depths) 2S-09 ContocoPhillips 't Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/15/2016 10/15/2016 1.00 INTRM2 CASING BOPE T chartedtest ot a m elates 2e50/25ch. e00 psi, 0.0 0.0 19:00 20:00 st upper rams to 250/3500 psi,charted for 5 minutes each.Remove test plug &blow down lines. 10/15/2016 10/16/2016 4.00 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 0.0 1,768.0 20:00 00:00 L80 casing as per detail to 1768'MD. Make up shoe track&Baker Lok all connections to the landing collar. Pump through&test floats.Hydroform centralizers installed w/3 centralizers per 2 joints.All connections torqued to 18,000 ft/lbs. 10/16/2016 10/16/2016 2.25 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 1,768.0 2,814.0 00:00 02:15 L80 casing as per detail f/1768'-2814' MD,PU 117K,SO 103K. Install stage collar between joints 64&65. Hydroform centralizers installed w/3 centralizers per 2 joints.A total of 117 centralizers installed.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 1.25 INTRM2 CASING CIRC T Circulate&condition staging up to 5 2,814.0 2,814.0 02:15 03:30 bpm, 182 psi,pumped 1582 strokes. 10/16/2016 10/16/2016 2.50 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 2,814.0 4,002.0 03:30 06:00 L80 casing as per detail f/2814'-4002' MD,PU 142K,SO 117K.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 1.50 INTRM2 CASING CIRC T Circulate&condition staging up to 4 4,002.0 4,002.0 06:00 07:30 bpm, 178 psi,pumped 2604 strokes. Losses 8 bbls. 10/16/2016 10/16/2016 1.25 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 4,002.0 4,539.0 07:30 08:45 L80 casing as per detail f/4002'-4539' MD,PU 167K,SO 130K.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 0.75 INTRM2 CASING CIRC T Circulate&condition staging up to 3 4,539.0 4,539.0 08:45 09:30 bpm,240 psi,pumped 786 strokes. Losses 6 bbls. 10/16/2016 10/16/2016 1.25 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 4,539.0 5,030.0 09:30 10:45 L80 casing as per detail f/4539'-5030' MD,PU 180K,SO 131K.All connections torque to 18,000 ft/lbs. 10/16/2016 10/16/2016 2.25 INTRM2 CASING CIRC T Circulate&condition staging up to 4 5,030.0 5,030.0 10:45 13:00 bpm, 152 psi,FO 7%,PU 195K,SO 135K,pumped 3500 strokes. 10/16/2016 10/16/2016 1.00 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 5,030.0 5,523.0 13:00 14:00 L80 casing as per detail f/5030'-5523' MD,PU 207K,SO 143K.All connections torque to 18,000 fUlbs. 10/16/2016 10/16/2016 0.75 INTRM2 CASING CIRC T Circulate&condition staging up to 3 5,523.0 5,523.0 14:00 14:45 bpm, 133 psi,FO 5%,PU 206K,SO 143K,pumped 762 strokes. 10/16/2016 10/16/2016 - 2.00 INTRM2 CASING PUTB T PJSM-run 7-5/8",Hyd 563 DL,29.7#, 5,523.0 6,386.0 14:45 16:45 L80 casing as per detail f/5523'-6386' MD,PU 245K,SO 147K.All connections torque to 18,000 fUlbs. 10/16/2016 10/16/2016 2.50 INTRM2 CASING CIRC T Circulate&condition staging up to 3 6,386.0 6,386.0 16:45 19:15 bpm,109 psi,FO 5%,PU 245K,SO 143K,pumped 3100 strokes. Page 45/58 Report Printed: 10/31/2016 • 0 Zr Operations Summary (with Timelog Depths) 4 r r �,,•4. 2S-09 ., ConocOPhillips Job: DRILLING ORIGINAL Rig: DOYON 142 Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ttKB) 10/16/2016 10/16/2016 1.00 INTRM2 CASING PUTB T PJSM- ng as per Hetayd56 6386-6869'L3 , 9.7# 6,386.0 6,869.0 19:15 20:15 L8MD,PU 257K,SO 157K.All connections torque to 18,000 ft/lbs. Spill Drill CRT 70 sec @ 20:00 hrs. Circulate&condition staging up to 5 6,869.0 6,869.0 10 10/16/2016 1.75 INTRM2 CASING CIRC T bpm,90 psi,FO 9%,PU 257K,SO 20::15/2016 15 2 22:00 200 157K,pumped 3600 strokes. 10/16/2016 10/17/2016 2.00 INTRM2 CASING PUTB T PJSM- ng as per Heta56 3 6ydDDL,29.7# 6,869.0 7,763.0 22:00 00:00 L8MD,PU 293K,SO 153K.All connections torque to 18,000 fUlbs. Losses for tour 37 bbls. 10/17/2016 10/17/2016 1.00 INTRM2 CASING PUTB T PJSM- ng as per Hetaiyd 56 3 7DL,29 .7# 7,763.0 8,089.0 00:00 01:00 L8MD.All connections torque to 18,000 fUlbs. 10/17/2016 10/17/2016 0.50 INTRM2 CASING HOSO T PJSM- make CIRep. angerWash &landing joint 8,089.0 8,129.0 01:00 01:30 as 1 bpm,201 psi,PU 312K,SO 138K. Land hanger at 8129'MD. 10/17/2016 10/17/2016 3.25 INTRM2 CEMENT CIRC T job it ullstate&condin g up pumn mte toud for 5 cement eabpmt 8,129. 0 8,129.0 01:30 04:45 201 psi,FO 7%,no losses. PJSM-blow down top drive,make up 8,129.0 8,129.0 10/17/2016 10/17/2016 0.25 INTRM2 CEMENT RURD T cement line onto CRT. 04:45 05:00 ceme 10/17/2016 10/17/2016 2.25 INTRM2 CEMENT CIRC T job itculate&staging upondition pump mte toud for6 bpm nt 8,129.0 8 129 05:00 07:15 315 psi,FO 10%,PU 300K,SO 149K, no losses.SIMOPS-PJSM for cementing. 8,129.0 8,129.0 10/17/2016 10/17/2016 3.00 INTRM2 CEMENT CMNT T Cement 1st t stage Pug 5 s perls SLB & 07:15 10:15 schepressure test lines to 600/4000 psi. Pump 40 bbls of 12.5 ppg mud push at 3.7 bpm, 150 psi.Drop bottom plug. Pump 15.2 bbls of 15.8 ppg neat cement at 5 bpm,265 psi.Pump 99.5 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.1 bpm, 175 psi.Pump 46 bbls of 15.8 ppg neat cement at 5.1 bpm,180 psi.Drop top plug&pump 10 bbls of H2O at 6 bpm,207 psi. Swap to rig&displace w/353.7 bbls of 10.0 ppg LSND mud at 7 bpm,120 psi.Slow rate to 3 bpm,830 psi& bump plug at 3502 strokes.Pressure up to 1340 psi&hold for 5 minutes. Bleed off&check floats,good.CIP 10:10 hrs. 10/17/2016 10/17/2016 0.25 INTRM2 CEMENT CIRC T Pressure tool upsto 2935npsi to bl observe 8,129.0 8,129.0 10:15 10:30 stcirculation through stage tool. 10/17/2016 10/17/2016 2.75 INTRM2 CEMENT CIRC T Stage up pump rate to 5 bpm,ICP 230 8,129.0 8,129.0 psi,FCP 197 psi,FO 8%,pumped 10:30 13:15 6414 strokes. 10/17/2016 10/17/2016 2.75 INTRM2 CEMENT CIRC T Circulate throusi,ghO tag e pcolcollarpeat 3 8,129.0 8,129.0 13:15 16:00 bstrokes.SIMOPS PJSM for 2nd stage cement job. Page 46/58 Report Printed: 10/31/201f ' 7 Operations Summary (with Timelog Depths) ):6 F ptio-` 2S-09 [onocoPhilliFb5 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End lime Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/17/2016 10/17/2016 2.00 INTRM2 CEMENT CMNT T Cement te2nd stage as Pump 5 bbls eor H20.er BPump 8,129.0 0.0 16:00 18:00 sche41.9 bbls of 12.5 ppg mud push at 4.1 bpm, 108 psi.Pump 10.2 bbls of 15.8 ppg neat cement at 5.5 bpm,252 psi. Pump 33.1 bbls of 15.8 ppg cement w/ 2 ppb of CemNet at 5.5 bpm,222 psi. Pump 4.2 bbls of 15.8 ppg neat cement at 4 bpm, 180 psi.Drop closing plug&pump 10 bbls of H2O at 5 bpm,7 psi.Swap to rig&displace w/243 bbls of 10.0 ppg LSND mud at 7 bpm,300 psi.Slow rate to 3 bpm, 600 psi&bump plug at 2404 strokes. CIP 18:05 hrs. 10/17/2016 10/17/2016 0.50 INTRM2 CEMENT CIRC T Pressure up to 2000 psi,observing 0.0 0.0 18:00 18:30 stage tool close at 1420 psi.Hold for 5 minutes.Bleed off pressure&fluid to trip tank,with 2.7 bbls.Check to ensure no flow back,good. 10/17/2016 10/17/2016 0.50 INTRM2 CEMENT OWFF T &Monitor low well,own ctatic. IlMOPSines. rigig down down 0.0 0.0 18:30 19:00 Volant CRT. PJSM-pulnp0.0 0.0 10/17/2016 10/17/2016 2.00 INTRM2 CEMENT WWSP T stack.Make up rug jjoin toole on landingy 19:00 21:00 joint w/pack off.Install pack off as per CIW Rep.RILDS.Test pack off to 5000 psi for 10 minutes,witnessed by CPAI.Lay down landing joint. SIMOPS clean manifold valves of cement. 10/17/2016 10/17/2016 0.50 INTRM2 CEMENT RURD T PJSM-clean&clear casing running 0.0 0.0 21:00 21:30 equipment from rig floor. 10/17/2016 10/17/2016 1.00 INTRM2 CEMENT PULD T PJSM-lay down 6 stands of 5"HWDP 0.0 0.0 21:30 22:30 from the derrick,using the mouse hole. Fire Drill CRT 120 sec @ 22:00 hrs. 10/17/2016 10/18/2016 1.50 INTRM2 CEMENT PULD T PJSM-lay derrick,dwn 16isstands g the mouse P 0 .0 0.0 22:30 00:00 from thehole. 10/18/2016 10/18/2016 9.50 INTRM2 CEMENT PULD T PJSM- lay derrick.S64 stands S ndschaof5" "oDP 0.0 0.0 00:00 09:30 fromt upper rams to 3-1/2"X 6"VBR's& clean pits. 10/18/2016 10/18/2016 3.00 INTRM2 CEMENT RURD T handling CIO saver sub equipment too 4"4, X 3 on 9, /O O 0.0 0.0 09:30 12:30 Roughneck die blocks for 4",&adjust stop plate.SIMOPS-load&process 90 joints of 4"HWDP in the pipe shed. 10/18/2016 10/18/2016 2.75 INTRM2 CEMENT PULD T PJSM-pick up&rack back 30 stands 0.0 0.0 12:30 15:15 of 4"HWDP in the derrick. 10/18/2016 10/18/2016 1.75 INTRM2 CEMENT FRZP T PJSM- -rig s of H2O at 3 5 bpm,l .P 7p0 0.0 0.0 15:15 17:00 12psi,FCP 625 psi.Line up&pump 91.5 bbls of Isotherm at 3.5-1 bpm, ICP 900 psi,FCP 650 psi.OA shut in pressure 550 psi.SIMOPS service top drive&crown.Rig up test equipment &set test plug. Page 47/58 Report Printed: 10/31/2016 • • " Operations Summary (with Timelog Depths) 2S-09 t , r ConocoPhillips ;s Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/18/2016 10/18/2016 0.50 INTRM2 WHDBOP RURD T PJSM Fill all lnes up Tw39 FOSh SV&dart m 0.0 0.0 17:00 17:30 valve.shell test,good. 10/18/2016 10/18/2016 4.00 INTRM2 WHDBOP BOPE T Test witness waived by AOGCC Rep. 0.0 0.0 17:30 21:30 Chuck Scheve.Tested with 3-1/2"&4- 1/2"test joints.250/3500 psi,charted for 5 minutes each. Test#1 with 3 1/2"test joint,testing Annular,CV#1,#12,#13,#14 and 4" kill line valve on mud manifold. Test#2-Top Pipe rams,CV#9,#11, mezzanine kill valve,and XT-39 Dart valve. Test#3- CV#8,#10,HCR Kill,and XT-39 FOSV. Test#4-CV#6,#7. Test#5- Super Choke & Manual operated choke to 2000 PSI. Test#6-CV#2,#5&Manual Kill Test#7-Lower Pipe rams Test#8-Blind rams,CV#3,#4,#6 Installed 4 1/2"test joint. Test#9-Annular,HCR Choke,upper IBOP. Test#10-Top Pipe rams,Manual choke,and lower IBOP Test#11 -Lower Pipe rams Perform Koomey draw down test. Observed initial system pressure at 3100 psi,after closure 1800 psi,200 psi increase in 6 seconds,and full pressures at 51 seconds. Observed 6 nitrogen bottles with an average PSI of 2608 PSI.Tested pit level sensors&flow out alarms.Gas detection alarms tested w/low&high level. 10/18/2016 10/18/2016 1.25 INTRM2 WHDBOP RURD T PJSM-blow down/rig down test 0.0 0.0 21:30 22:45 equipment&lines.Remove test plug. Install 10"ID wear bushing,RILDS X2. 10/18/2016 10/19/2016 1.25 INTRM2 CEMENT BHAH T PJSM-make up 6-3/4"production 0.0 137.0 22:45 00:00 BHA 8 as per SLB DD to 137'MD. OA pressure 500 psi @ 24:00 hrs. 10/19/2016 10/19/2016 1.50 INTRM2 CEMENT BHAH T PJSM-continue making up 6 3/4" 137.0 392.0 00:00 01:30 production BHA 8 as per SLB DD,f/ 137'-392'MD,PU 52K,SO 58K. 10/19/2016 10/19/2016 3.25 INTRM2 CEMENT PULD T PJSM-single in the hole f/392'-2666' 392.0 2,666.0 01:30 04:45 MD,72 joints. 10/19/2016 10/19/2016 1.00 INTRM2 CEMENT DHEQ T ' Shallow hole test MWD&LWD tools. 2,666.0 2,666.0 04:45 05:45 Down link to turn on sonic logging. 10/19/2016 10/19/2016 0.75 INTRM2 CEMENT PULD T PJSM-single in the hole f/2666'-3140' 2,666.0 3,140.0 05:45 06:30 MD,15 joints,PU 97K,SO 83K. 10/19/2016 10/19/2016 0.50 INTRM2 CEMENT TRIP T PJSM-TIH the/derrick.404372'MD with 4" 3,140.0 4,372.0 06:30 07:00 DP 10/19/2016 10/19/2016 2.00 INTRM2 CEMENT QEVL T TIH cement/4 72-5 282'MD,800 sofpnic logging ing 4,372.0 5,482.0 07:00 09:00 SO 99K. Page 48158 Report Printed: 10/31/2016 • • a Operations Summary (with Timelog Depths) 1,4.it 25-09 ConacoP'hithps . Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 10/19/2016 10/19/2016 2.50 INTRM2 CEMENT DRLG T PJSM- fdrill482u cement, 'MD at 248, gpme 5,482.0 5,518.0 09:00 11:30 co1650 psi,FO 6%,40-60 rpm,Tq 7- 10K,PU 161K,SO 100K,ROT 120K. Work through stage collar 6 times. 10/19/2016 4.00 INTRM2 CEMENT QEVL T TIH f/5518'-7875'MD,sonic logging 5,518.0 7,875.0 10/19/2016 PU 15:30 cement stage 1 at 800fph, 220K, 11:30 2000'MD. SO 100K,fill pipe every OA pressure 600 psi @ 12:00 hrs. Kick w/Tripping CRT 153 sec @ 15:00 hrs. 10/19/2016 10/19/2016 1.50 INTRM2 CEMENT CIRC T Circulate&condition for casing test at 7,875.0 7,875.0 15:30 17:00 230 gpm, 1642 psi,FO 7%,40 rpm, Tq 12K,PU 220K,SO 100K,ROT 137K. 10/19/2016 10/19/2016 1.00 INTRM2 CEMENT PRTS T PJSM-rig up to test casing.Test 7- 7,875.0 7,875.0 17:00 18:00 5/8"casing to 3500 psi,for 30 minutes charted.Pressure up with 43 strokes. Shut in&observe pressure decrease from 3590 psi to 3490 psi in 30 minutes.Pumped 4.4 bbls&bled back 4.3 bbls.Rig down&blow down test equipment. 10/19/2016 10/19/2016 0.50 INTRM2 CEMENT COCF T PJSM-wash&ream to TOC f/7875'- 7,875.0 7,963.0 18:00 18:30 7963'MD,220 gpm,1500 psi,FO 9%, 50 rpm,Tq 11-12K. 10/19/2016 10/19/2016 4.25 INTRM2 CEMENT DRLG T Drill out shoe track&rat hole cement 7,963.0 8,138.0 18:30 22:45 f/7963'-8138'MD,230 gpm,1680 psi,FO 9%,50-60 rpm,Tq 11-12K, WOB 3-7K,BTM of shoe at 8129'MD. 10/19/2016 10/19/2016 0.25 INTRM2 CEMENT DDRL T DDrill$154"MDdu6c35nTVD,section f/30 gpm, 8,138.0 8,158.0 22:45 23:00 8131680 psi,FO 11%,60 rpm,Tq 11- 12K,WOB 7-15K,PU 220K,SO 100K, ROT 132K,ADT.25,Bit.25,Jars.25, total footage 20'MD. 10/19/2016 10/20/2016 1.00 INTRM2 CEMENT CIRC T Circulate&condition at 230 gpm, 8,158.0 8,158.0 1660 psi,FO 9%,60 rpm,Tq 12K,PU 23::000000:00 220K,SO 100K,ROT 132K,2583 strokes.Lay down single&blow down TD. OA pressure 580 psi @ 24:00 hrs. SCR @ 8156'MD,6335'TVD,MW 10.0 ppg,23:45 hrs. #1 @ 30=580;@ 40=850 #2 @ 30=580;@ 40=850 10/20/2016 10/20/2016 1.00 INTRM2 CEMENT FIT T PJSM- lay down FIT.Perform FIT atingEMWrig gf 3for 8,158.0 8,125.0 00:00 01:00 ppg with a 10.0 ppg MW,at 8129'MD, 6333'TVD.Pressure up to 990 psi with 1.2 bbls in 12 strokes.Observe shut in pressure decrease to 900 psi in 10 minutes.Bled back 1.1 bbls.Rig down&blow down all lines. 10/20/2016 10/20/2016 1.25 PROD2 DRILL MPDA T PJSM-remove trip nipple,install RCD 8,125.0 8,158.0 01:00 02:15 bearing,&drain nipple.Break in bearing at 30&60 rpm.SIMOP's PJSM for displacement.Pick up single that is in string. Page 49/58 Report Printed: 10/31/2016 • . ' ' Operations Summary (with Timelog Depths) 2S-09 Cono,coPhiillps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log • Start Depth Operation (MB) End Depth(EKE) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X 8,158.0 8,429.0 10/20/2016 10/20/2016 3.75 PROD2 DRILL DDRL T PJSM- directional hole sl drill Crio n_3/4158' 8429' 02:15 06:00 MD,6343'TVD,260 gpm, 1886 psi, FO 10%,120-140 rpm,Tq on 9-12K, WOB 8-15K,ECD 10.9,Off Bottom 1874 psi,PU 193K,SO 102K,ROT 132K,Tq off 9K,MW 10.0 ppg,Max gas 368, ADT 3.12,Bit 3.37,Jars 3.37,Total Footage 271'MD. SCR @ 8253'MD,6344'TVD,MW 10.0 ppg,03:45 hrs. #1 @ 20=440;@ 30=650 #2 @ 20=420;@ 30=620 8,429.0 9,106.0 10/20/2016 10/20/2016 6.00 PROD2 DRILL DDRL T PJSM-directional hole sl drill lll 6-3/4n f/8429' 9106' 06:00 12:00 MD,6330'TVD,260 gpm,1994 psi, FO 10%,150 rpm,Tq on 11-13K, WOB 15K,ECD 11.13,Off Bottom 1990 psi,PU 193K,SO 100K,ROT 129K,Tq off 11K,MW 10.05 ppg,Max gas 218, ADT 3.95,Bit 7.32,Jars 7.32,Total Footage 667'MD. SCR @ 8821'MD,6332'TVD,MW 10.0 ppg,09:50 hrs. #1 @ 20=460;@ 30=650 #2 @ 20=480;@ 30=660 9,106.0 9,959.0 10/20/2016 10/20/2016 6.00 PROD2 DRILL DDRL T production hole seirectional dctilon 1//9106'-9959' 12:00 18:00 MD,6326'TVD,270 gpm,2205 psi, FO 11%, 150160 rpm,Tq on 14K, WOB 15K,ECD 11.23,Off Bottom 2210 psi,PU 191K,SO 99K,ROT 123K,Tq off 11-12K,MW 10.0 ppg, Max gas 357, ADT 3.42,Bit 11.16, Jars 11.16,Total Footage 853'MD. Kick w/Drilling CRT 43 sec @ 20:00 hrs. SCR @ 9484'MD,6323'TVD,MW 10.0+ppg, 14:30 hrs. #1 @20=510;@30=710 #2@20=510;@30=710 9,959.0 10,812.0 10/20/2016 10/21/2016 6.00 PROD2 DRILL DDRL T production directional hole sl drill on 3-3/9959'- 18:00 00:00 10812'MD,6329'TVD,271 gpm, 2295 psi,FO 13%, 150 rpm,Tq on 13K,WOB 15K,ECD 11.24,Off Bottom 2290 psi,PU 200K,SO 94K, ROT 126K,Tq off 12K,MW 10.0 ppg, Max gas 396, ADT 3.76,Bit 14.92, Jars 14.92,Total Footage 853'MD. OA pressure 760 psi at 24:00 hrs. SCR @ 10428'MD,6333'TVD,MW 10.0+ppg,21:30 hrs. #1 @ 20=520;@ 30=730 #2 @ 20=540;@ 30=740 Page 50/58 Report Printed: 10/31/2016 • Operations Summary (with Timelog Depths) � 2S-09 ConocoPhiliips ,Lr:ks Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/21/2016 10/21/2016 6.00 PROD2 DRILL DDRL T PJSM-directional holeiosl drill on-3/4" /10812'- 10,812.0 11,571.0 00:00 06:00 produc11571'MD,6301'TVD,271 gpm, 2385 psi,FO 10%,150 rpm,Tq on 14K,WOB 15K,ECD 11.37,Off Bottom 2380 psi,PU 208K,SO 90K, ROT 127K,Tq off 12.5K,MW 10.0+ ppg,Max gas 1974, ADT 3.97,Bit 18.89,Jars 18.89,Total Footage 759' MD. SCR @ 11000'MD,6333'TVD,MW 10.0+ppg,01:05 hrs. #1 @ 20=560;@ 30=800 #2 @ 20=560;©30=790 SCR @ 11570'MD,6300'TVD,MW 10.0+ppg,05:52 hrs. #1 @ 20=540;@ 30=760 #2 @ 20=540;@ 30=760 10/21/2016 10/21/2016 6.00 PROD2 DRILL DDRL P PJSM-directional holeiosl drill on-3/4" /11571'- 11,571.0 12,259.0 06:00 12:00 produc12259'MD,6296'TVD,271 gpm, 2470 psi,FO 10%,150 rpm,Tq on 14K,WOB 2-15K,ECD 11.4,Off Bottom 2465 psi,PU 228K,SO 80K, ROT 130K,Tq off 13K,MW 10.0 ppg, Max gas 690, ADT 3.62,Bit 22.51, Jars 22.51,Total Footage 688'MD. OA pressure 700 psi at 12:00 hrs Kick w/Drilling CRT 120 sec @ 11:25 hrs. Trouble time ended at 06:02 hrs at 11584'MD. SCR @ 12130'MD,6299'TVD,MW 10.1 ppg,09:35 hrs. #1 @20=600;@30=810 #2 @ 20=580;@ 30=800 10/21/2016 10/21/2016 6.00 PROD2 DRILL DDRL P prod-directional holeiosl drill on-3/4" /12259'- 12,259.0 12,930.0 12:00 18:00 12930'MD,6290'TVD,270 gpm, 2650 psi,FO 9%, 160 rpm,Tq on 15K, WOB 15K,ECD 11.55,Off Bottom 2645 psi,PU 234K,SO 92K,ROT 138K,Tq off 13K,MW 10.0 ppg,Max gas 190, ADT 3.98,Bit 26.49,Jars 26.49,Total Footage 671'MD. Page 51/58 Report Printed: 10/31/2016 0 • d.'' v Operations Summary (with Timelog Depths) try-i;. �v ConocOPtuilips ,, Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth O eration (ftK8) End Depth(ftKB) Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X p 12,930.0 13,533.0 10/21/2016 10/22/2016 6.00 PROD2 DRILL DDRL P PJSM-directional drill 6-3/4" 18:00 00:00 production hole section 0 12930'- 13533'MD,6298'TVD,270 gpm, 2780 psi,FO 10%,150 rpm,Tq on 15K,WOB 12K,ECD 11.65,Off Bottom 2760 psi,PU 235K,SO 94K, ROT 141K,Tq off 13.5K,MW 10.0 ppg,Max gas 240, ADT 4.22,Bit 30.71,Jars 30.71,Total Footage 603' MD. OA pressure 920 psi at 24:00 hrs. SCR @ 13421'MD,6295'TVD,MW 10.0 ppg,23:00 hrs. #1 @ 20=660;@ 30=900 #2 @ 20=660;@ 30=900 10/22/2016 10/22/2016 5.00 PROD2 DRILL DDRL P PJSM-directional drill 6-3/4" 13,533.0 14,172.0 00:00 05:00 production hole section f/13533'- 14172'MD,6300'TVD,272 gpm, 2974 psi,FO 10%, 150 rpm,Tq on 16.5K,WOB 15K,ECD 11.61,Off Bottom 2915 psi,PU 254K,SO 95K, ROT 144K,Tq off 14K,MW 10.0 ppg, Max gas 505, ADT 3.32,Bit 34.03, Jars 34.03,Total Footage 639'MD. SCR @ 13976'MD,6296'TVD,MW 10.0+ppg,02:50 hrs. #1 @ 20=700;@ 30=940 #2 @ 20=700;@ 30=930 10/22/2016 10/22/2016 1.00 PROD2 CASING CIRC P C at 270 15KFO gpm, 24820 strokes.s, 130 rpm, 14,172.0 14,172.0 05:00 06:00 SCR @ 14172'MD,6299'TVD,MW 10.0+ppg,06:15 hrs. #1 @ 20=620;@ 30=900 #2 @ 20=620;@ 30=900 10/22/2016 10/22/2016 0.25 PROD2 CASING OWFF P chokes,Monitor pressure pruon e hut do MPD 14,172.0 14,161.0 06:00 06:15 lay down working single&drop 2.375" rabbit w/105'of wire. 10/22/2016 10/22/2016 5.50 PROD2 CASING BKRM P PJSM-BROOH f/14161'-12317'MD, 14,161.0 12,363.0 06:15 11:45 272 gpm,2540 psi,FO 10%,150 rpm, Tq 14K,PU 212K,SO 97K,ROT 127K, 10/22/2016 10/22/2016 1.00 PROD2 CASING BKRM T Take surveys&ream twice to lessen 12,363.0 12,268.0 11:45 12:45 DLS from 12363'-12268'MD at 274 gpm,2580 psi,FO 10%, 150 rpm,Tq 9-12K. OA pressure 880 psi at 12:00 hrs. 10/22/2016 10/22/2016 5.25 PROD2 CASING BKRM P PJSM-BROOH f/12268'-10625'MD, 12,268.0 10,625.0 12:45 18:00 270 gpm,2360 psi,FO 10%,140 rpm, Tq 13K,ROT 127K,close chokes every 5 stands&monitor for pressure. Work minor tight spots @ 11140', 11020'-10920'MD. 10/22/2016 10/22/2016 5.75 PROD2 CASING BKRM P PJSM-BROOH f/10625-8162'MD, 10,625.0 8,162.0 18:00 23:45 270 gpm,2110 psi,FO 8%, 140 rpm, Tq 11K,ROT 131K,ECD 10.91,close chokes every 5 stands&monitor for pressure. Page 52158 Report Printed: 10/31/2016 • • :r Operations Summary (with Timelog Depths) ,.tkrii4 .M,� 2S-09 E`` ConocaPhitiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2016 10/23/2016 0.25 PROD2 CASING BKRM P BROOH into MD,220rmediat shoe 20 psi/ 8,162.0 8,027.0 23:45 00:00 FO 6%,80 rpm,Tq 10K.6 bbls losses for entire back ream to the shoe. OA pressure 820 psi at 24:00 hrs. 10/23/2016 10/23/2016 2.00 PROD2 CASING CIRC P Circulate 2 intermediate shoe,at 802 7'MD 0 gpm,1500 psi, 8,027.0 8,027.0 00:00 02:00 FO 9%,80 rpm,PU 179K,SO 112K, ROT 136K,4950 strokes. 10/23/2016 10/23/2016 0.75 PROD2 CASING OWFF P Monitorwell belllto static with wdown top drive. slight drop. 8,027.0 8,027.0 02:00 02:45 10/23/2016 10/23/2016 7.00 PROD2 CASING SMPD P PJSM-strip out of the hole w/MPD f/ 8,027.0 392.0 02:45 09:45 8027'-392'MD,PU 52K,SO 54K, Calculated fill 44 bbls,actual 66 bbls. Retrieve rabbit from top of jars. Spill Drill CRT 120 sec @ 05:52 hrs. 10/23/2016 10/23/2016 0.25 PROD2 CASING OWFF P Monitor well,static.SIMOPs PJSM to 392.0 392.0 09:45 10:00 remove RCD. 10/23/2016 10/23/2016 1.25 PROD2 CASING MPDA P Remove drain nipple&RCD.Install 392.0 392.0 10:00 11:15 trip nipple&line up.Clear&clean rig floor. 10/23/2016 10/23/2016 3.75 PROD2 CASING BHAH P PJSM-lay down BHA8 f/392'to 392.0 0.0 11:15 15:00 surface, as per SLB DD.Clear& clean rig floor. Bit grade 1,2,BT,A,X, 1,CT,TD. OA pressure 0 psi at 12:00 hrs. 10/23/2016 10/23/2016 1.50 COMPZN CASING RURD P PJSM-rig up casing equipment to run 0.0 0.0 15:00 16:30 4-1/2"liner. 10/23/2016 10/24/2016 7.50 COMPZN CASING PUTB P PJSM-RI H with BTC-M,12" ,12.6 , 80t,0 .0 4,350.0 16:30 00:00 o 4350'MD.Ran 97 joints,shoe joint, float collar joint,an WIV,an Alpha sleeve,Frac sleeves 1-7,9 swell packers, 108 Hydroform centralizers& 13 stop rings. OA pressure 0 psi at 24:00 hrs. 10/24/2016 10/24/2016 3.00 COMPZN CASING PUTB P PJSM-RIH BTC-M,with -112", 12.er 6 , 80f,4 ,350.0 6,170.0 00:00 03:00 4350'-6170'MD.Ran a total of 139 joints, 10 Frac sleeves, 12 swell packers, 153 Hydroform centralizers& 16 stop rings.PU 121K,SO 91K.No remakes or rejected 4-1/2"liner. 10/24/2016 10/24/2016 0.25 COMPZN CASING RURD P PJSM-change out handling 6,170.0 6,170.0 03:00 03:15 equipment to pick up liner hanger/packer. 10/24/2016 10/24/2016 0.50 COMPZN CASING OTHR P PJSM-make p hangerpackeu& RDoo 1-Estand of P liner 4" 6,170.0 6,213.0 03:15 03:45 DP as per Baker Rep. 10/24/2016 10/24/2016 1.00 COMPZN CASING CIRC P Circulate liner volume at 129 gpm,367 6,213.0 6,213.0 03:45 04:45 psi,FO 6%.SIMOPS mix&fill liner top with Pal-Mix.Clear rig floor of casing handling equipment. 10/24/2016 10/24/2016 1.25 COMPZN CASING RUNL P 6JSM- IH with linerU on14drill ilS0 101 K. 6,213.0 8,103.0 04:45 06:00 10/24/2016 10/24/2016 2.00 COMPZN CASING CIRC P Circulate surface to surface at 129 8,103.0 8,103.0 06:00 08:00 gpm,448 psi,FO 6%.SIMOPS PJSM to install RCD bearing. 10/24/2016 10/24/2016 0.25 COMPZN CASING OWFF P Monitor well,static.Blow down top 8,103.0 8,103.0 08:00 08:15 drive. Page 53/58 Report Printed: 10/31/2016 • • -� ` Operations Summary (with Timelog Depths) 2S-09 ConocoPhitrps ,F Ata;ku Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 10/24/2016 10/24/2016 0.75 COMPZN CASING MPDA P Remove trip nipple&install RCD 8,103.0 8,103.0 08:15 09:00 bearing with drain nipple. 10/24/2016 10/24/2016 7.00 COMPZN CASING RUNL P PJSM-obtain parameters at the shoe 8,103.0 14,163.0 09:00 16:00 PU 153K,SO 96K,ROT w/SO 110K, 30 rpm,Tq 6.5K.TIH w/4-1/2"liner on DP f/8103'-14163'MD,PU 230K,SO 111K. OA pressure 0 psi at 12:00 hrs. 10/24/2016 10/24/2016 0.75 COMPZN CASING CIRC P PJSM-establish circulation at 1 bpm, 14,163.0 14,163.0 16:00 16:45 540 psi.Tag bottom at 14172'MD w/ 5K,pick 7 set on depth at 14163'MD. Continue circulating liner volume at 3 bpm,848 psi,FO 7%. 10/24/2016 10/24/2016 0.75 COMPZN CASING CIRC P PJSM-pump down 1.5"ball at 3 bpm, 14,163.0 14,163.0 16:45 17:30 856 psi FO 6%.Ball on seat with 1373 strokes.Pressure up to 1500 psi to shut the WIV. 10/24/2016 10/24/2016 0.75 COMPZN CASING PACK P PJSM-pressure up to 2100 psi to set 14,163.0 7,999.0 17:30 18:15 liner hanger.Slack off to 50K to verify hanger set.Pressure up to 3500 psi to release from liner top.Not released. Pressure up to 3700 psi&bleed off, PU to 230K&SO to 50K(not released).Apply 2 wraps to the left& work string.Release torque&pick up to observe PU at 205K,released. Rotate at 20 rpm,ROT 158K,slack off to 40K w/rotary,set liner top packer. Pick up&lay down single.Liner top at 7955'MD. 10/24/2016 10/24/2016 0.75 COMPZN CASING PRTS P PJSM-rig up&test liner top packer 7,999.0 7,999.0 18:15 19:00 down the IA to 3000 psi for 10 minutes,charted.Rig down test equipment. 10/24/2016 10/24/2016 1.75 COMPZN WELLPR DISP P PJSM-displace well to 8.34 ppg sea 7,999.0 7,999.0 19:00 20:45 water at 6 bpm,968 psi,FO 8%. 10/24/2016 10/24/2016 1.50 COMPZN WELLPR CIRC P CBU 2X at 9 bpm, 1840 psi,FO 13%, 7,999.0 7,936.0 20:45 22:15 lay down 2 singles to 7936'MD. 10/24/2016 10/24/2016 0.50 COMPZN WELLPR OWFF P Close chokes to observe no pressure 7,936.0 7,936.0 22:15 22:45 increase.Flow check,static.Monitor well,static.SIMOP's pull drain nipple &rig up to remove RCD. 10/24/2016 10/25/2016 1.25 COMPZN WELLPR MPDA P PJSM-remove RCD,install trip nipple, 7,936.0 7,936.0 22:45 00:00 blow down&disconnect lines.Clean &lay down bearing,drain nipple,& stand.Blow down TD. OA pressure 300 psi at 24:00 hrs. 10/25/2016 10/25/2016 2.50 COMPZN WELLPR SLPC P Slip/cut 117'drill line,service top 7,936.0 7,936.0 00:00 02:30 drive,blocks,crown,and drawworks. 10/25/2016 10/25/2016 0.50 COMPZN WELLPR OWFF P Observe well out of balance-monitor 7,936.0 7,936.0 02:30 03:00 well. 10/25/2016 10/25/2016 1.00 COMPZN WELLPR CIRC P Circulate drill pipe volume at 422 gpm, 7,936.0 7,936.0 03:00 04:00 2218 psi, 14%F/O-observe well out of balance.Circulate 1 x bottoms up @ 422 gpm,2138 psi, 14%F/O. Observe well static. 10/25/2016 10/25/2016 4.50 COMPZN WELLPR PULD P Pull OOH sideways f/7936'-2138' 7,936.0 2,138.0 04:00 08:30 laying out 4"HWDP,PUW 131k,SOW 98k.Monitor displacement on trip tank. Page 54/58 Report Printed: 10/31/2016 • • '=44. xd Operations Summary (with Timelog Depths) { x;,-,-,K=1,;=0„,-' 2S-09 CorvocaPhillips ;t Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Operation (ftKB) End Depth MB)Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X 2,138.0 54.0 10/25/2016 10/25/2016 2.50 COMPZN WELLPR PULD P ulil out sidewa ys Mon 2138 54' 08:30 11:00 displacement on trip tank. 54.0 0.0 10/25/2016 10/25/2016 0.75 COMPZN WELLPR PULD P Pull 00H running54'tosurtooface nand lay 11:00 11:45 down ved good shear indication on dog sub. 10/25/2016 10/25/2016 4.25 COMPZN WELLPR PULD P Lay yddo down 34 x stands 4"DP using 0.0 0.0 11:45 16:00 e. Note-leave total of 65 x stands 4"DP racked back in derrick for rig move to 2S-13. 10/25/2016 10/25/2016 1.25 COMPZN RPCOMP WWWH P M/U stack rmasher and wash wellhead. 0.0 0.0 Pull r 16:00 17:150.0 0.0 10/25/2016 10/25/2016 0.50 COMPZN RPCOMP OTHR P Pick install ball Nirod and fill withle w/RHC lplug body,h 17:15 17:45 water to test for leaks-no leaks observed.Remove ball and rod and lay down D-nipple. 10/25/2016 10/25/2016 2.25 COMPZN RPCOMP RURD P Rig up to e out handling pper completito n 0.0 0.0 17:45 20:00 1/2",Mobilize cannon clamps and SLB tools to rig floor,Hang I-wire sheave in derrick,rig up spooler,and test I-wire. 10/25/2016 10/25/2016 0.25 COMPZN RPCOMP SFTY P Hold PJSM for running 3-1/2"upper 0.0 0.0 20:00 20:15 completion. 10/25/2016 10/25/2016 0.75 COMPZN RPCOMP PUTB P R2 Run c3. ",9.3 3n,tL-8 0,EaEp8RDa fd, 0.0 130.0 20:15 21:00 130'MD.Pick up WLEG w/No-Go Sub, 1 x joint tubing,D nipple w/RHC, Premier packer,and Gauge carrier. M/U torque 2240 ft-lbs. 130.0 130.0 10/25/2016 10/25/2016 1.00 COMPZN RPCOMP PRTS P Prealllugauge and I-wire a test gauge cable.irera 1:00 22:00 psi for 5 minutes.Test electrical function as per Camco rep-good test. 10/25/2016 10/26/2016 2.00 COMPZN RPCOMP PUTB P R2 c3.5",9.3n 3 ,tL-8 0,EaEp8RDdetail ff/d 130.0 1,042.0 22:00 00:00 130'-1042'MD,allowing pipe to self fill and monitoring displacement on trip tank.Make up CMU in closed position and GLM w/SOV for 2500psi casing- tubing shear.Install 1 x cannon clamp on every collar and mid-joint protectors below and above GLM's. OA pressure=0 psi 10/26/2016 10/26/2016 6.00 COMPZN RPCOMP PUTB P Run Ru c3.5",9.3 ,L-8 0,EaEp8RDail f/Mo1,042.0 4,564.0 00:00 06:00 1042'-4564'MD,allowing pipe to self fill and monitoring displacement on trip tank.Make up 2 x GLM with dummy valves.Install 1 x cannon clamp on every collar and mid-joint protectors below and above GLM's.PUW 85k, SOW 76k.Test I-wire every 2000'. Page 55/58 Report Printed: 10/31/201E • • Operations Summary (with Timelog Depths) 2S-09 Conoco i Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/26/2016 10/26/2016 6.00 COMPZN RPCOMP PUTB P Run 3.5"9.3#, L-80 EUE 8RD Mod R2 4,564.0 7,988.0 06:00 12:00 completion tubing as per detail f/4564' MD to No-Go @ 7958'MD(muleshoe @ 7988'),allowing pipe to self fill and monitoring displacement on trip tank. Sting into top of liner and set down on shear out sub,observed sub shear @ 14k down.Mark pipe and obtain space out measurements.Install 1 x cannon clamp on every collar.Test I-wire every 2000'.PUW 125k,SOW 84k. 3-1/2"Cross coupling clamps=248 3-1/2"Cross coupling mid clamps=8 3-1/2"x 4-1/2"Cross over clamp=1 4-1/2"Cross coupling clamp=1 4-1/2"Cross coupling mid clamp=1 Stainless steel bands=2 on CMU Total for tubing run. 10/26/2016 10/26/2016 1.75 COMPZN RPCOMP HOSO P Space out,UD 3 joints of 3-1/2"EUE 7,988.0 7,945.0 12:00 13:45 tubing,M/U 3-1/2"EUE pup(2.26'),3- 1/2"EUE X 4-1/2"IBTM XO,and 1 joint of 4-1/2"IBTM tubing. Space out to be 3.51'above fully located. 10/26/2016 10/26/2016 1.00 COMPZN RPCOMP THGR P M/U CIW hanger and landing joint, 7,945.0 7,945.0 13:45 14:45 install bail extensions,XO,head pin, and cement line hose. 10/26/2016 10/26/2016 2.00 COMPZN RPCOMP THGR P Feed I-wire through hanger,terminate 7,945.0 7,979.0 14:45 16:45 as per SLB rep and test wire and down hole gauge-good test. 10/26/2016 10/26/2016 0.75 COMPZN RPCOMP CRIH P Pump 53 bbls of corrosion-inhibited 7,979.0 7,979.0 16:45 17:30 seawater and chase w/68 bbls of neat seawater @ 4bpm,235psi,placing corrosion inhibited brine in annulus from top of liner @ 7958'MD to 6400' MD(above GLM#2). 10/26/2016 10/26/2016 0.75 COMPZN RPCOMP THGR P Land hanger,PUW 128k,SOW 87k. 7,979.0 7,984.9 17:30 18:15 RILDS.Test hanger void to 5000 psi for 15 minutes,CPAI witnessed.Drop ball&rod. 10/26/2016 10/26/2016 2.75 COMPZN RPCOMP PRTS P Pressure up tubing(setting packer at 7,984.9 0.0 18:15 21:00 1600 psi)to 4000 psi with mud pump &test for 30 minutes on chart-good test.Bleed tubing to 2300 psi. Pressure up IA to 4000 psi(tubing pressure increase to 2750 psi)&test for 30 minutes on chart-good test. Bleed off IA and then tubing pressure to 0 psi.Pressure up IA and shear SOV at 2570 psi.Observe communication verifying positive shear at 1 bpm, 125 psi.Observe well for 5 minutes-well static. Note:Rig changed mud pump pop- offs to 4500 psi prior to testing. Page 56/58 Report Printed: 10/31/2016 • • Operations Summary (with Timelog Depths) 0-,1, . rpt=°: 2S-09 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/26/2016 10/26/2016 0.50 COMPZN RPCOMP RURD P Blow/rig down circulating lines.Lay 0.0 0.0 21:00 21:30 down landing joint&remove bale extensions. 10/26/2016 10/26/2016 1.25 COMPZN WHDBOP MPSP P Install 4"type HP BPV.Test BPV and 0.0 0.0 21:30 22:45 tubing hanger in the direction of flow to 2500 psi for 30 minutes,charted- good test. 10/26/2016 10/26/2016 0.50 COMPZN WHDBOP OWFF P Monitor well,static.SIMOPS prep for 0.0 0.0 22:45 23:15 nipple down of MPD and BOPE. 10/26/2016 10/27/2016 0.75 COMPZN WHDBOP MPDA P Lay out trip nipple and nipple down 0.0 0.0 23:15 00:00 MPD equipment on stack. 10/27/2016 10/27/2016 2.00 COMPZN WHDBOP MPDA P Nipple down RCD head,Air valve,and 0.0 0.0 00:00 02:00 choke lines.Stage RCD head in mezzanine deck. 10/27/2016 10/27/2016 3.00 COMPZN WHDBOP NUND P Nipple down BOPE and adapter 0.0 0.0 02:00 05:00 spools.Perform between-well- maintenance on annular.Rack back BOPE stack on stump and secure same. 10/27/2016 10/27/2016 6.50 COMPZN WHDBOP THGR P Clean&prep top of hanger.Run I-wire 0.0 0.0 05:00 11:30 through adapter spool,install&test- note control line block had to be swapped out for spare.Set adapter spool&torque studs.Test hanger void to 250/5000 psi for 15 minutes,CPAI witnessed-good test.Test SRL seals to 10,000 psi for 15 minutes,CPAI witnessed-good test.Terminate(- wire as per Cameo and test line-good test.SIMOPS perform BWM on BOPE. Note:Rig swap from hi-line to generator power at 08:00 hrs. 10/27/2016 10/27/2016 3.25 COMPZN WHDBOP NUND P Nipple up tree,install wing valves. 0.0 0.0 11:30 14:45 SIMOPS complete BWM and disconnect interconnect lines between modules. 10/27/2016 10/27/2016 1.25 COMPZN WHDBOP PRTS P Fill tree with diesel&test to 250 psi for 0.0 0.0 14:45 16:00 5 min,5000 psi for 15 min.Switch over to Cameron and test to 10,000 psi for 15 min,CPAI witnessed-good tests. 10/27/2016 10/27/2016 2.75 COMPZN WHDBOP MPSP P Remove test dart and attempt to pull 0.0 0.0 16:00 18:45 BPV with dry rod-observed pressure below BPV with annulus on vacuum. Rig up lubricator and pressure test to 2000.Pull BPV.RID lubricator. 10/27/2016 10/27/2016 1.00 COMPZN WHDBOP RURD P Rig up to freeze protect,taking returns 0.0 0.0 18:45 19:45 directly to cuttings tank. 10/27/2016 10/27/2016 1.25 COMPZN WHDBOP FRZP P Hold PJSM with crews and freeze 0.0 0.0 19:45 21:00 protect well.Pressure test lines to 250/2500 psi.Pump 90 bbls of diesel down the IA,taking returns from the tubing to cuttings tank.Pump at 3 bpm, ICP 900 psi,FCP 1200 psi. 10/27/2016 10/27/2016 1.25 COMPZN WHDBOP FRZP P Allow well to U-tube.SIMOPS clean 0.0 0.0 21:00 22:15 cellar and lay down skate ramp. Page 57/58 Report Printed: 10/31/2016 f • • ` Ong Operations Summary (with Timelog Depths) i &Wells 2S-09 Crichillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/27/2016 10/27/2016 1.25 COMPZN WHDBOP MPSP P Rig up lubricator,pressure test to 0.0 0.0 22:15 23:30 2000 psi,and install 4",type H BPV. R/D and lay out lubricator. 10/27/2016 10/28/2016 0.50 DEMOB MOVE MOB P Secure well are 0 install ontubing,gauges. Final 0.0 0.0 23:30 00:00 pressurespsi psi on IA,and 200 psi on OA.SIMOPS prep for rig move to 2S-13. Rig release at 24:00 hrs. Page 58/58 Report Printed: 10/31/2016 • • NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-09 Definitive Survey Report 26 October, 2016 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 I Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-09 Well Position +N/-S 0.00 usft Northing: 5,929,986.08 usft Latitude: 70°13'11.559 N +E/-W 0.00 usft Easting: 481,074.22 usft Longitude: 150°9'9.654 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-09 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2016 10/1/2016 17.80 80.84 57,533 Design 9 Rig:2S-09 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) r) 39.10 0.00 0.00 15.00 Survey Program Date From To (usft) (usft) Survey(Wellborn) Tool Name Description Surrey Date 60.00 835.50 2S-09 Srvy 1-SLB_NSG+MSHOT(2S-0 GYD-GC-MS Gyrodata gyrocompassing m/s 9/14/2016 9:02: 858.68 2,088.06 2S-09 Srvy 2-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/14/2016 9:05: 2,184.78 2,758.43 2S-09 Srvy 3-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/15/2016 9:05: 2,800.11 2,800.11 2S-09 Srvy 4-SLB_Inc+Filler(2S-09) INC+TREND Inclinometer+known azi trend 9/19/2016 9:33: 2,877.83 7,191.58 2S-09 Srvy 5-SLB-MWD+GMAG(2S-09 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/19/2016 9:35: 7,274.27 11,523.93 2S-09 Srvy 6-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/28/2016 12:07 Survey Map Map Vertical MD Inc AZI TVD TVDSS +NI-S +EI-W Northing Easting; DLS Section (usft) (°) (°} (usft) (usft) (usf() {usft) (ft) (ft) (1100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -120.00 0.00 0.00 5,929,986.08 481,074.22 0.00 0.00 UNDEFINED 60.00 0.10 15.64 60.00 -99.10 0.02 0.00 5,929,986.10 481,074.22 0.48 0.02 GYD-GC-MS(1) 160.00 0.13 308.73 160.00 0.90 0.17 -0.06 5,929,986.25 481,074.16 0.13 0.15 GYD-GC-MS(1) 260.00 0.06 294.26 260.00 100.90 0.27 -0.20 5,929,986.35 481,074.02 0.07 0.21 GYD-GC-MS(1) 360.00 0.82 192.90 360.00 200.90 -0.41 -0.40 5,929,985.67 481,073.82 0.83 -0.50 GYD-GC-MS(1) 461.50 3.95 180.46 461.40 302.30 -4.62 -0.59 5,929,981.47 481,073.61 3.11 -4.61 GYD-GC-MS(1) 554.50 5.67 183.83 554.07 394.97 -12.40 -0.93 5,929,973.68 481,073.26 1.87 -12.22 GYD-GC-MS(1) 646.50 6.99 181.30 645.50 486.40 -22.54 -1.36 5,929,963.55 481,072.81 1.47 -22.12 GYD-GC-MS(1) 741.50 9.40 178.44 739.53 580.43 -36.07 -1.28 5,929,950.02 481,072.85 2.57 -35.17 GYD-GC-MS(1) 835.50 10.98 178.30 832.04 672.94 -52.69 -0.80 5,929,933.39 481,073.29 1.68 -51.11 GYD-GC-MS(1) 10/26/2016 1:11:42PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl� Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120©159.10usft(DoyonVV Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig.2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 858.68 11.28 178.34 854.78 695.68 -57.17 -0.67 5,929,928.92 481,073.41 1.29 -55.39 MWD+IFR-AK-CAZ-SC(2) 953.11 12.52 177.35 947.18 788.08 -76.62 0.07 5,929,909.46 481,074.10 1.33 -73.99 MWD+IFR-AK-CAZ-SC(2) 1,048.23 14.62 180.18 1,039.64 880.54 -98.93 0.51 5,929,887.16 481,074.48 2.31 -95.43 MWD+IFR-AK-CAZ-SC(2) 1,142.58 17.35 183.83 1,130.34 971.24 -124.88 -0.47 5,929,861.22 481,073.44 3.08 -120.74 MWD+IFR-AK-CAZ-SC(2) 1,238.16 19.02 183.31 1,221.14 1,062.04 -154.65 -2.32 5,929,831.45 481,071.51 1.76 -149.98 MWD+IFR-AK-CAZ-SC(2) 1,332.20 22.32 182.82 1,309.12 1,150.02 -187.79 -4.08 5,929,798.32 481,069.67 3.51 -182.45 MWD+IFR-AK-CAZ-SC(2) 1,426.66 24.35 183.54 1,395.85 1,236.75 -225.15 -6.17 5,929,760.97 481,067.49 2.17 -219.07 MWD+IFR-AK-CAZ-SC(2) 1,521.98 27.34 182.20 1,481.62 1,322.52 -266.64 -8.22 5,929,719.48 481,065.33 3.20 -259.69 MVVD+IFR-AK-CAZ-SC(2) 1,617.01 28.93 181.69 1,565.42 1,406.32 -311.43 -9.74 5,929,674.71 481,063.70 1.69 -303.34 MWD+IFR-AK-CAZ-SC(2) 1,712.12 33.22 175.92 1,646.88 1,487.78 -360.44 -8.56 5,929,625.70 481,064.75 5.49 -350.38 MWD+IFR-AK-CAZ-SC(2) 1,805.74 33.27 175.73 1,725.18 1,566.08 -411.63 -4.83 5,929,574.50 481,068.36 0.12 -398.85 MWD+IFR-AK-CAZ-SC(2) 1,900.89 31.00 176.13 1,805.75 1,646.65 -462.11 -1.23 5,929,524.02 481,071.83 2.40 -446.68 MWD+IFR-AK-CAZ-SC(2) 1,997.03 30.41 176.16 1,888.41 1,729.31 -511.09 2.07 5,929,475.04 481,075.01 0.61 -493.14 MWD+IFR-AK-CAZ-SC(2) 2,088.06 30.40 177.33 1,966.92 1,807.82 -557.09 4.69 5,929,429.04 481,077.51 0.65 -536.89 MWD+IFR-AK-CAZ-SC(2) 2,184.78 30.11 176.48 2,050.47 1,891.37 -605.75 7.32 5,929,380.38 481,080.02 0.53 -583.21 MWD+IFR-AK-CAZ-SC(3) 2,279.09 30.14 175.82 2,132.04 1,972.94 -652.97 10.50 5,929,333.15 481,083.08 0.35 -628.00 MWD+IFR-AK-CAZ-SC(3) 2,374.12 30.32 175.47 2,214.14 2,055.04 -700.68 14.13 5,929,285.44 481,086.59 0.27 -673.15 MWD+IFR-AK-CAZ-SC(3) 2,469.58 31.25 179.40 2,296.16 2,137.06 -749.46 16.29 5,929,236.65 481,088.63 2.32 -719.71 MVVD+IFR-AK-CAZ-SC(3) 2,564.15 32.39 179.93 2,376.52 2,217.42 -799.32 16.58 5,929,186.80 481,088.79 1.24 -767.80 MWD+IFR-AK-CAZ-SC(3) 2,658.68 31.12 179.05 2,456.90 2,297.80 -849.07 17.02 5,929,137.06 481,089.10 1.43 -815.73 MWD+IFR-AK-CAZ-SC(3) 2,758.43 31.67 180.06 2,542.04 2,382.94 -901.03 17.42 5,929,085.10 481,089.37 0.76 -865.82 MWD+IFR-AK-CAZ-SC(3) 2,800.11 31.87 180.00 2,577.48 2,418.38 -922.97 17.40 5,929,063.16 481,089.31 0.49 -887.02 INC+TREND(4) 2,822.00 31.96 179.53 2,596.06 2,436.96 -934.55 17.45 5,929,051.59 481,089.33 1.22 -898.19 MWD+IFR-AK-CAZ-SC(5) 103/4"x1311'2"• 2,877.83 32.20 178.33 2,643.36 2,484.26 -964.19 18.01 5,929,021.94 481,089.81 1.22 -926.68 MWD+IFR-AK-CAZ-SC(5) 2,894.31 32.78 177.93 2,657.26 2,498.16 -973.04 18.30 5,929,013.09 481,090.07 3.75 -935.15 MWD+IFR-AK-CAZ-SC(5) 2,989.46 33.52 179.11 2,736.93 2,577.83 -1,025.05 19.64 5,928,961.09 481,091.28 1.03 -985.04 MWD+IFR-AK-CAZ-SC(5) 3,085.15 32.56 179.53 2,817.14 2,658.04 -1,077.22 20.26 5,928,908.92 481,091.77 1.03 -1,035.27 MVVD+IFR-AK-CAZ-SC(5) 3,180.55 31.64 181.16 2,897.96 2,738.86 -1,127.91 19.96 5,928,858.24 481,091.35 1.32 -1,084.31 MWD+IFR-AK-CAZ-SC(5) 3,216.83 30.85 181.67 2,928.98 2,769.88 -1,146.72 19.50 5,928,839.43 481,090.84 2.30 -1,102.60 MWD+IFR-AK-CAZ-SC(5) 3,275.15 29.15 183.54 2,979.48 2,820.38 -1,175.85 18.18 5,928,810.31 481,089.45 3.33 -1,131.07 MWD+IFR-AK-CAZ-SC(5) 3,369.71 29.22 183.38 3,062.04 2,902.94 -1,221.87 15.40 5,928,764.29 481,086.56 0.11 -1,176.25 MWD+IFR-AK-CAZ-SC(5) 3,465.06 29.12 181.76 3,145.30 2,986.20 -1,268.30 13.32 5,928,717.88 481,084.36 0.83 -1,221.63 MWD+IFR-AK-CAZ-SC(5) 3,559.35 29.12 179.80 3,227.67 3,068.57 -1,314.17 12.69 5,928,672.01 481,083.62 1.01 -1,266.11 MVVD+IFR-AK-CAZ-SC(5) 3,654.21 29.11 175.20 3,310.56 3,151.46 -1,360.25 14.70 5,928,625.93 481,085.51 2.36 -1,310.10 MVVD+IFR-AK-CAZ-SC(5) 3,748.38 29.08 171.75 3,392.85 3,233.75 -1,405.73 19.90 5,928,580.45 481,090.60 1.78 -1,352.68 MWD+IFR-AK-CAZ-SC(5) 3,843.39 29.20 172.07 3,475.83 3,316.73 -1,451.53 26.41 5,928,534.63 481,096.99 0.21 -1,395.24 MWD+IFR-AK-CAZ-SC(5) 3,937.70 29.29 173.30 3,558.12 3,399.02 -1,497.23 32.28 5,928,488.92 481,102.74 0.64 -1,437.86 MWD+IFR-AK-CAZ-SC(5) 4,032.85 26.26 176.57 3,642.31 3,483.21 -1,541.37 36.26 5,928,444.78 481,106.61 3.56 -1,479.47 MWD+IFR-AK-CAZ-SC(5) 4,127.92 23.76 177.68 3,728.45 3,569.35 -1,581.51 38.29 5,928,404.64 481,108.54 2.68 -1,517.71 MWD+IFR-AK-CAZ-SC(5) 10/26/2016 1.11:42PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Toot Name 4,222.30 20.68 176.28 3,815.82 3,656.72 -1,617.14 40.14 5,928,369.00 481,110.30 3.31 -1,551.65 MWD+IFR-AK-CAZ-SC(5) 4,316.01 18.07 174.18 3,904.21 3,745.11 -1,648.12 42.69 5,928,338.02 481,112.77 2.88 -1,580.91 MWD+IFR-AK-CAZ-SC(5) 4,410.48 15.20 169.34 3,994.72 3,835.62 -1,674.87 46.47 5,928,311.26 481,116.48 3.37 -1,605.78 MWD+IFR-AK-CAZ-SC(5) 4,505.57 12.37 159.36 4,087.08 3,927.98 -1,696.66 52.37 5,928,289.46 481,122.33 3.88 -1,625.30 MW3+IFR-AK-CAZ-SC(5) 4,599.59 10.73 147.53 4,179.20 4,020.10 -1,713.48 60.62 5,928,272.63 481,130.53 3.06 -1,639.40 MWD+IFR-AK-CAZ-SC(5) 4,694.91 9.31 142.66 4,273.07 4,113.97 -1,727.09 70.06 5,928,258.99 481,139.94 1.73 -1,650.11 MWD+IFR-AK-CAZ-SC(5) 4,789.62 7.30 136.03 4,366.78 4,207.68 -1,737.52 78.88 5,928,248.54 481,148.74 2.35 -1,657.90 MWD+IFR-AK-CAZ-SC(5) 4,884.31 6.12 113.23 4,460.84 4,301.74 -1,743.84 87.70 5,928,242.20 481,157.54 3.05 -1,661.72 MWD+IFR-AK-CAZ-SC(5) 4,978.95 6.70 95.74 4,554.90 4,395.80 -1,746.38 97.83 5,928,239.63 481,167.66 2.14 -1,661.55 MWD+IFR-AK-CAZ-SC(5) 5,073.65 6.98 77.43 4,648.93 4,489.83 -1,745.68 108.94 5,928,240.31 481,178.77 2.31 -1,658.00 MWD+IFR-AK-CAZ-SC(5) 5,168.64 9.01 58.29 4,743.01 4,583.91 -1,740.51 120.91 5,928,245.44 481,190.75 3.50 -1,649.91 MWD+IFR-AK-CAZ-SC(5) 5,263.08 11.10 44.26 4,836.01 4,676.91 -1,730.11 133.55 5,928,255.81 481,203.41 3.39 -1,636.60 MWD+IFR-AK-CAZ-SC(5) 5,358.88 13.64 35.49 4,929.59 4,770.49 -1,714.31 146.54 5,928,271.58 481,216.45 3.29 -1,617.97 MWD+IFR-AK-CAZ-SC(5) 5,453.39 17.92 31.63 5,020.52 4,861.42 -1,692.84 160.65 5,928,293.01 481,230.60 4.66 -1,593.58 MWD+IFR-AK-CAZ-SC(5) 5,548.40 22.50 27.39 5,109.66 4,950.56 -1,664.24 176.68 5,928,321.57 481,246.71 5.06 -1,561.80 MWD+IFR-AK-CAZ-SC(5) 5,642.58 25.70 25.16 5,195.62 5,036.52 -1,629.75 193.66 5,928,356.02 481,263.77 3.53 -1,524.09 MWD+IFR-AK-CAZ-SC(5) 5,737.30 28.18 24.81 5,280.05 5,120.95 -1,590.85 211.78 5,928,394.86 481,281.99 2.62 -1,481.83 MWD+IFR-AK-CAZ-SC(5) 5,831.73 29.17 24.25 5,362.90 5,203.80 -1,549.63 230.59 5,928,436.03 481,300.90 1.09 -1,437.14 MWD+IFR-AK-CAZ-SC(5) 5,926.48 31.60 22.24 5,444.63 5,285.53 -1,505.59 249.47 5,928,480.02 481,319.89 2.78 -1,389.72 MWD+IFR-AK-CAZ-SC(5) 6,021.10 34.05 21.06 5,524.14 5,365.04 -1,457.92 268.38 5,928,527.64 481,338.91 2.68 -1,338.78 MWD+IFR-AK-CAZ-SC(5) 6,115.13 37.00 19.68 5,600.66 5,441.56 -1,406.70 287.37 5,928,578.81 481,358.03 3.25 -1,284.39 MWD+IFR-AK-CAZ-SC(5) 6,210.39 40.51 18.57 5,674.94 5,515.84 -1,350.36 306.88 5,928,635.09 481,377.68 3.76 -1,224.92 MWD+IFR-AK-CAZ-SC(5) 6,304.61 43.13 17.21 5,745.15 5,586.05 -1,290.57 326.16 5,928,694.82 481,397.11 2.94 -1,162.18 MWD+IFR-AK-CAZ-SC(5) 6,400.38 44.08 16.74 5,814.50 5,655.40 -1,227.40 345.44 5,928,757.94 481,416.55 1.05 -1,096.17 MWD+IFR-AK-CAZ-SC(5) 6,495.76 47.15 16.08 5,881.21 5,722.11 -1,162.02 364.69 5,928,823.27 481,435.95 3.26 -1,028.04 MWD+IFR-AK-CAZ-SC(5) 6,589.32 50.55 14.26 5,942.76 5,783.66 -1,094.03 383.09 5,928,891.20 481,454.53 3.92 -957.60 MWD+IFR-AK-CAZ-SC(5) 6,684.48 53.35 13.04 6,001.41 5,842.31 -1,021.22 400.76 5,928,963.96 481,472.37 3.11 -882.70 MWD+IFR-AK-CAZ-SC(5) 6,779.49 56.41 12.29 6,056.06 5,896.96 -945.40 417.78 5,929,039.73 481,489.59 3.28 -805.06 MWD+IFR-AK-CAZ-SC(5) 6,874.22 58.57 11.54 6,106.97 5,947.87 -867.24 434.27 5,929,117.84 481,506.27 2.38 -725.30 MWD+IFR-AK-CAZ-SC(5) 6,969.60 61.93 11.09 6,154.30 5,995.20 -786.05 450.51 5,929,198.98 481,522.71 3.55 -642.67 MWD+IFR-AK-CAZ-SC(5) 7,064.03 65.49 9.64 6,196.12 6,037.02 -702.79 465.72 5,929,282.20 481,538.13 4.01 -558.30 MVVD+IFR-AK-CAZ-SC(5) 7,159.23 68.52 9.24 6,233.30 6,074.20 -616.35 480.09 5,929,368.59 481,552.71 3.21 -471.09 MWD+IFR-AK-CAZ-SC(5) 7,191.58 69.53 9.91 6,244.88 6,085.78 -586.56 485.11 5,929,398.36 481,557.81 3.67 -441.02 MWD+IFR-AK-CAZ-SC(5) 7,247.00 70.27 9.51 6,263.93 6,104.83 -535.27 493.89 5,929,449.63 481,566.72 1.49 -389.20 MVVD+IFR-AK-CAZ-SC(6) 7-5/8"x 9-7/8"by 11" 7,274.27 70.63 9.31 6,273.05 6,113.95 -509.91 498.09 5,929,474.97 481,570.98 1.49 -363.62 MWD+IFR-AK-CAZ-SC(6) 7,369.08 74.93 10.12 6,301.12 6,142.02 -420.68 513.38 5,929,564.16 481,586.49 4.61 -273.47 MWD+IFR-AK-CAZ-SC(6) 7,464.12 78.11 12.48 6,323.27 6,164.17 -330.07 531.50 5,929,654.72 481,604.83 4.13 -181.26 MWD+IFR-AK-CAZ-SC(6) 7,559.11 81.49 14.52 6,340.09 6,180.99 -239.18 553.32 5,929,745.54 481,626.89 4.14 -87.82 MWD+IFR-AK-CAZ-SC(6) 7,652.43 85.49 14.46 6,350.67 6,191.57 -149.43 576.52 5,929,835.22 481,650.30 4.29 4.88 MVVD+IFR-AK-CAZ-SC(6) 10/28/2018 1:11:42PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl� Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl� Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Toot Name 7,747.44 89.17 12.66 6,355.10 6,196.00 -57.19 598.76 5,929,927.40 481,672.78 4.31 99.73 MWD+IFR-AK-CAZ-SC(6) 7,841.94 92.04 13.70 6,354.10 6,195.00 34.81 620.31 5,930,019.33 481,694.55 3.23 194.17 MVVD+IFR-AK-CAZ-SC(6) 7,935.82 91.64 15.01 6,351.08 6,191.98 125.71 643.57 5,930,110.16 481,718.04 1.46 287.99 MWD+IFR-AK-CAZ-SC(6) 8,029.46 91.30 12.66 6,348.68 6,189.58 216.59 665.95 5,930,200.98 481,740.65 2.53 381.57 MWD+IFR-AK-CAZ-SC(6) 8,124.26 91.90 10.58 6,346.03 6,186.93 309.41 685.04 5,930,293.74 481,759.96 2.28 476.17 MWD+IFR-AK-CAZ-SC(6) 8,221.24 93.86 7.18 6,341.16 6,182.06 405.09 699.99 5,930,389.37 481,775.15 4.04 572.45 MWD+IFR-AK-CAZ-SC(6) 8,315.09 93.22 7.30 6,335.36 6,176.26 498.01 711.79 5,930,482.25 481,787.19 0.69 665.27 MVVD+IFR-AK-CAZ-SC(6) 8,409.99 92.33 10.07 6,330.77 6,171.67 591.70 726.11 5,930,575.90 481,801.74 3.06 759.47 MWD+IFR-AK-CAZ-SC(6) 8,504.52 90.77 12.09 6,328.21 6,169.11 684.43 744.27 5,930,668.57 481,820.13 2.70 853.74 MVVD+IFR-AK-CAZ-SC(6) 8,598.11 90.61 10.71 6,327.08 6,167.98 776.16 762.76 5,930,760.25 481,838.85 1.48 947.13 MWD+IFR-AK-CAZ-SC(6) 8,692.69 90.54 10.39 6,326.14 6,167.04 869.14 780.08 5,930,853.17 481,856.40 0.35 1,041.42 MWD+IFR-AK-CAZ-SC(6) 8,787.42 89.19 13.76 6,326.36 6,167.26 961.76 799.89 5,930,945.73 481,876.44 3.83 1,136.01 MWD+IFR-AK-CAZ-SC(6) 8,882.76 89.68 15.15 6,327.30 6,168.20 1,054.07 823.69 5,931,037.98 481,900.47 1.55 1,231.34 MWD+IFR-AK-CAZ-SC(6) 8,977.23 89.19 14.43 6,328.23 6,169.13 1,145.41 847.80 5,931,129.24 481,924.81 0.92 1,325.81 MWD+IFR-AK-CAZ-SC(6) 9,072.52 89.76 13.50 6,329.10 6,170.00 1,237.87 870.80 5,931,221.64 481,948.03 1.14 1,421.07 MWD+IFR-AK-CAZ-SC(6) 9,167.49 88.62 15.48 6,330.45 6,171.35 1,329.81 894.56 5,931,313.51 481,972.02 2.41 1,516.03 MWD+IFR-AK-CAZ-SC(6) 9,261.50 88.28 20.17 6,332.99 6,173.89 1,419.25 923.32 5,931,402.87 482,001.00 5.00 1,609.86 MWD+IFR-AK-CAZ-SC(6) 9,357.09 92.42 21.48 6,332.41 6,173.31 1,508.57 957.29 5,931,492.10 482,035.19 4.54 1,704.93 MWD+IFR-AK-CAZ-SC(6) 9,451.70 91.02 20.56 6,329.57 6,170.47 1,596.84 991.21 5,931,580.27 482,069.33 1.77 1,798.97 MWD+IFR-AK-CAZ-SC(6) 9,546.44 90.30 18.14 6,328.48 6,169.38 1,686.22 1,022.60 5,931,669.56 482,100.94 2.66 1,893.43 MWD+IFR-AK-CAZ-SC(6) 9,640.95 90.06 14.74 6,328.18 6,169.08 1,776.85 1,049.34 5,931,760.12 482,127.91 3.61 1,987.89 MWD+IFR-AK-CAZ-SC(6) 9,736.74 88.64 11.94 6,329.27 6,170.17 1,870.04 1,071.44 5,931,853.24 482,150.24 3.28 2,083.63 MWD+IFR-AK-CAZ-SC(6) 9,830.99 88.52 11.92 6,331.60 6,172 50 1,962.22 1,090.91 5,931,945.37 482,169.94 0.13 2,177.71 MWD+IFR-AK-CAZ-SC(6) 9,925.49 88.72 12.63 6,333.88 6,174.78 2,054.54 1,111.00 5,932,037.62 482,190.26 0.78 2,272.08 MWD+IFR-AK-CAZ-SC(6) 10,020.41 89.31 14.37 6,335.51 6,176.41 2,146.81 1,133.15 5,932,129.83 482,212.64 1.94 2,366.95 MWD+IFR-AK-CAZ-SC(6) 10,114.99 90.03 14.18 6,336.05 6,176.95 2,238.47 1,156.47 5,932,221.42 482,236.19 0.79 2,461.52 MWD+IFR-AK-CAZ-SC(6) 10,209.83 90.78 14.31 6,335.38 6,176.28 2,330.39 1,179.81 5,932,313.28 482,259.75 0.80 2,556.34 MWD+IFR-AK-CAZ-SC(6) 10,304.67 90.92 16.10 6,333.98 6,174.88 2,421.90 1,204.68 5,932,404.71 482,284.85 1.89 2,651.17 MWD+IFR-AK-CAZ-SC(6) 10,399.73 90.99 18.38 6,332.39 6,173.29 2,512.67 1,232.85 5,932,495.40 482,313.24 2.40 2,746.14 MWD+IFR-AK-CAZ-SC(6) 10,494.18 91.09 19.00 6,330.68 6,171.58 2,602.12 1,263.11 5,932,584.77 482,343.72 0.66 2,840.38 MWD+IFR-AK-CAZ-SC(6) 10,588.79 90.92 18.57 6,329.02 6,169.92 2,691.68 1,293.57 5,932,674.24 482,374 41 0.49 2,934.76 MWD+IFR-AK-CAZ-SC(6) 10,684.13 90.92 16.93 6,327.49 6,168.39 2,782.47 1,322.63 5,932,764.94 482,403.69 1.72 3,029.98 MWD+IFR-AK-CAZ-SC(6) 10,778.37 91.52 15.55 6,325.48 6,166.38 2,872.92 1,348.98 5,932,855.33 482,430.27 1.60 3,124.17 MWD+IFR-AK-CAZ-SC(6) 10,873.71 94.51 14.84 6,320.47 6,161.37 2,964.79 1,373.93 5,932,947.12 482,455.45 3.22 3,219.37 MVVD+IFR-AK-CAZ-SC(6) 10,968.90 95.16 14.78 6,312.44 6,153.34 3,056.49 1,398.18 5,933,038.75 482,479.92 0.69 3,314.22 MWD+IFR-AK-CAZ-SC(6) 11,063.26 93.53 14.56 6,305.29 6,146.19 3,147.51 1,422.01 5,933,129.70 482,503.97 1.74 3,408.30 MWD+IFR-AK-CAZ-SC(6) 11,154.89 90.38 13.31 6,302.17 6,143.07 3,236.38 1,444.05 5,933,218.51 482,526.24 3.70 3,499.85 MWD+IFR-AK-CAZ-SC(6) 11,247.12 89.57 14.02 6,302.21 6,143.11 3,326.00 1,465.84 5,933,308.06 482,548.25 1.17 3,592.05 MWD+IFR-AK-CAZ-SC(6) 11,338.65 89.86 14.42 6,302.66 6,143.56 3,414.72 1,488.33 5,933,396.72 482,570.96 0.54 3,683.57 MWD+IFR-AK-CAZ-SC(6) 11,431.20 89.89 13.76 6,302.87 6,143.77 3,504.49 1,510.86 5,933,486.42 482,593.71 0.71 3,776.11 MWD+IFR-AK-CAZ-SC(6) 10/28/2016 1:11:42PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger 110 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit ND Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (*) (*) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Toot Name 11,523 93 90.03 14.29 6,302.93 6,143 83 3,594 45 1,533.33 5,933,576.32 482,616.41 0.59 3,868 83 MWD+IFR-AK-CAZ-SC(6) 11,584 00 90.03 14.29 6,302 90 6,143 80 3,652 66 1,548 16 5,933,634 49 482,631 38 0.00 3,928 89 PROJECTED to TD 6-3/4"open hole Final Definitive Survey Verified and Signed-off Al!targets and/or well position objectives have been achieved. 2 Yes Li No have checked to the best of my ability that the following data is correct: Cl Surface Coordinates Li Declination & Convergence El GRS Survey Corrections E Survey Tool Codes Vincent SLB DE Osara Client Representative: 44.27( Date: 26-Oct-2016 10/26/2016 1'11:42PM Page 6 COMPASS 5000.1 Budd 74 ' �' Cement Detail Report rlit, 1 rk '° �> , 2S-09 conacomillips` At String: Surface Casing Cement Job: DRILLING ORIGINAL,9/121201618:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 9/17/2016 02:46 9/17/2016 04:32 2S-09 Comment Cement as per SLB detail.Flood lines w/5 bbls of H20.PIT lines to 800/3500 psi,good.Pump 50.2 bbls of CW-100 at 5.5 bpm,205 psi.Pump 68.6 bbls of 10.5 ppg Mud Push II at 4.5 bpm,190 psi.Drop bottom plug.Pump 360.7 bbls of 11.0 ppg lead cement at 6.5 bpm,225-360 psi.While pumping lead cement the cemeniers lost prime on their pump with 291 bbls away.Pumping was resumed to finish lead cement.Between pumping the lead&tail cement SLB troubleshot the cement unit.Pump 59.1 bbls of 15.8 ppg tail cement at 4.5 bpm,450 psi.Drop top plug.Pump 10 bbls of fresh H2O at 3 bpm,230 psi.Pump 253 bbls of 10.0 ppg mud at 3-5 bpm,340-665 psi.Plug bumped at 2508 strokes.Pressure up to 1100 psi&hold for 5 minutes.Bleed off pressure to check floats,good. 173 bbls of cement returns to surface.CIP @ 05:54 hrs. After swapping to the rig to displace cement the casing string was picked up to begin reciprocation.The string was picked up 2-3 feet with PU 180K,previous PU was 160K.Slacked off to verify ability to land back on hanger.Unable to slack off to land hanger.Continue attempts to land on hanger with no success.Pick up w/190K,to 18"from fully landed mark,to be able to set emergency slips.Displacement of cement was continuous, Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 47.0 2,833.0 Yes 172.0 Yes Yes Q Pump mit(bbl/m...Q Pump Final(bbll...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 4 6 409.0 560.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 47.0 2,333.0 1,080 G 361.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa.., Free Water(%) Density(lb/gal) Plastic Viscosity(Pa's) Thickening Time(hr) CmprStr 1(psi) 1.88 6.50 11.00 146.0 3.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,333.0 2,833.0 286 G 59.1 Yield(ft/sack) Mix 1120 Ratio(gailsa... Free Water(%) Density(Iblgal) Plastic Viscosity(Pa's) Thickening Time(fir) CmprStr 1(psi) 1.16 5.07 15,80 169.2 3.75 Additives Additive Type Concentration Conc Unit label Page 111Report Printed: 6/15/2017 6✓t`x, • • Cement Detail Report kz &Maas SUPERSEUEU 2S-09 conocoPhillips. String: Surface Casing Cement Job: DRILLING ORIGINAL, 9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 9/17/2016 02:46 9/17/2016 04:32 2S-09 Comment Cement as per SLB detail.Flood lines w/5 bbls of H2O. P/T lines to 800/3500 psi,good.Pump 50.2 bbls of CW-100 at 5.5 bpm,205 psi. Pump 68.6 bbls of 10.5 ppg Mud Push II at 4.5 bpm, 190 psi.Drop bottom plug.Pump 360.7 bbls of 11.0 ppg lead cement at 6.5 bpm,225-360 psi.While pumping lead cement the cementers lost prime on their pump with 291 bbls away. Pumping was resumed to finish lead cement.Between pumping the lead&tail cement SLB troubleshot the cement unit. Pump 59.1 bbls of 15.8 ppg tail cement at 4.5 bpm,450 psi.Drop top plug.Pump 10 bbls of fresh H2O at 3 bpm,230 psi.Pump 253 bbls of 10.0 ppg mud at 3-5 bpm,340-665 psi.Plug bumped at 2508 strokes.Pressure up to 1100 psi&hold for 5 minutes.Bleed off pressure to check floats,good. 173 bbls of cement returns to surface.CIP @ 05:54 hrs. After swapping to the rig to displace cement the casing string was picked up to begin reciprocation.The string was picked up 2-3 feet with PU 180K,previous PU was 160K.Slacked off to verify ability to land back on hanger.Unable to slack off to land hanger.Continue attempts to land on hanger with no success. Pick up w/190K,to 18"from fully landed mark,to be able to set emergency slips.Displacement of cement was continuous. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 47.0 2,833.0 Yes 172.0 Yes Yes Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 4 6 409.0 560.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 47.0 2,333.0 1,080 G 361.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.88 6.50 11.00 146.0 3.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,333.0 2,833.0 286 G 59.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 169.2 3.75 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/4/2016 ,pc-c c.o�� i i r: Cement Detail Report �� ,: 2S-09 YT COnocoPi dills String: Intermediate Casing Cement Job: DRILLING ORIGINAL,91121201618:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/24/2016 21:35 9/25(2016 06:51 2S-09 Comment Cement 7-5/8"casing as per SLB cementing program.Pump 5 bbls of H20,test trips&PT lines to 518/4000 psi,good.Pump 42.6 bbls of 12.5 ppg MPII at 5.1 bpm,240 psi.Drop bottom plug.Pump 100.2 bbls of 15.8 ppg Sharks Tooth slurry at 5.2 bpm,215 psi.Drop top plug&pump 10.1 bbls of H2O at 6.1 bpm,100 psi.Swap to rig&displace with 10 ppg LSND at 6 bpm,127 psi,FO 8%,Slow rate(losses @ 1625 strokes)to 2 bpm,70 psi,FCP 571 psi @ 2 bpm.Bump plug at 3100 strokes.Check floats,good.CIP @ 00:58 hrs.Total Losses for first stage 6 bbls. Pump second stage cement as per SLB cementing program. Pump 40.6 bbls of 12.5 ppg MPII at 5.4 bpm,227 psi. Pump 50 bbls of 15.8 ppg Sharks Tooth slurry at 4 bpm,160 psi.Drop closing plug.Pump 10 bbls of H2O at 6.1 bpm,95 psi.Swap to rig&displace with 10 ppg LSND at 6 bpm,483 psi,FO 7%.Slow pump rate as losses were observed to 2 bpm,516 psi.Looses started at—1800 strokes(cement at stage tool at 1882 stk).Bump plug at 2349 strokes, pressuring up to 1700 psi to shift stage collar closed.Observed closing at 1300 psi.Hold for 5 minutes,bleed off,&check for flow.Tool closed,CIP @ 06:51 hrs.Total Losses for second stage 14 bbls. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement from TD of 7247' 6,099.0 7,247.0 No Yes Yes Cement to top of Cairn @ 6057' MD Q Pump Mit(bbllm...Q Pump Final(bbll...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 2 5 571.0 1,027.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 5,562.5 6,099.4 42.6 Yield(fPlsack) Mix H2O Ratio(gal/sa... Free Water(%) Density(ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) 6 099.4 Shark Tooth Slurry 7,247.0 484 G 100.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 Additives Additive Type Concentration Cone Unit label Additive Type Concentration Conc Unit label Antifoam D046 0.15 %BWOC Additive Type Concentration Cone Unit label Dispersant D065 0.6%BWOC Additive Type Concentration Cone Unit label Fluid Loss Control D167 0.7%BWOC Additive Type Concentration Cone Unit label Retarder D177 0.015 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement 500'above the C 4,948.0 5,402.0 No Yes No Cement -37 at 5402'MD Q Pump snit(bbllm...Q Pump Final(bbll...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 2 6 516.0 1,700.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 4,436.7 40.6 Yield(ft'/sack) Mix H2O Ratio(gahisa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa's) Thickening Time(hr) CmprStr 1(psi) 12.50 Page 1/2 Report Printed: 6/15/2017 • Drilling Cement Detail Report LI! &Wells k 2S-09 • ConocoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL,9/12/2016 18:00 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Shark Tooth Slurry 4,948.3 5,402.0 247 G 50.0 Yield(f isack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa's) Thickening Time(hr) CmprStr 1(psi) 1.16 5.06 15.80 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.15%BWOC Additive Type Concentration Conc Unit label Dispersant 0065 0.6%BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.7%BWOC Page 212 Report Printed: 6/15/2017 • • 0 . Cement Detail Report 2S-09 Cc nocoP'hillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL,9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/24/2016 21:35 9/25/2016 06:51 2S-09 Comment Cement 7-5/8"casing as per SLB cementing program.Pump 5 bbls of H2O,test trips&PT lines to 518/4000 psi,good.Pump 42.6 bbls of 12.5 ppg MPII at 5.1 bpm,240 psi.Drop bottom plug.Pump 100.2 bbls of 15.8 ppg Sharks Tooth slurry at 5.2 bpm,215 psi.Drop top plug&pump 10.1 bbls of H2O at 6.1 bpm, 100 psi.Swap to rig&displace with 10 ppg LSND at 6 bpm, 127 psi,FO 8%,Slow rate(losses @ 1625 strokes)to 2 bpm,70 psi,FCP 571 psi @ 2 bpm.Bump plug at 3100 strokes.Check floats,good.CIP @ 00:58 hrs.Total Losses for first stage 6 bbls. Pump second stage cement as per SLB cementing program. Pump 40.6 bbls of 12.5 ppg MPII at 5.4 bpm,227 psi. Pump 50 bbls of 15.8 ppg Sharks Tooth slurry at 4 bpm, 160 psi. Drop closing plug.Pump 10 bbls of H2O at 6.1 bpm,95 psi.Swap to rig&displace with 10 ppg LSND at 6 bpm,483 psi,FO 7%.Slow pump rate as losses were observed to 2 bpm,516 psi.Looses started at—1800 strokes(cement at stage tool at 1882 stk). Bump plug at 2349 strokes, pressuring up to 1700 psi to shift stage collar closed.Observed closing at 1300 psi.Hold for 5 minutes,bleed off,&check for flow.Tool closed.CIP @ 06:51 hrs.Total Losses for second stage 14 bbls. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement from TD of 7247' 6,099.0 7,247.0 No Yes Yes Cement to top of Cairn @ 6057' MD Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 2 5 571.0 1,027.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 5,562.5 6,099.4 42.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa...-Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Shark Tooth Slurry 6,099.4 7,247.0 484 G 100.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 Additives Additive Type Concentration Conc Unit label Additive Type Concentration Conc Unit label Antifoam D046 0.15 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.6 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.7 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement 500'above the C 4,948.0 5,402.0 No Yes No Cement -37 at 5402'MD Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 2 6 516.0 1,700.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 4,436.7 40.6 Yield(tV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Page 1/2 Report Printed: 11/4/2016 0 Cement Detail Report i&Mai UPERSFDEr 2S-09 Conaccehillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 9/12/2016 18:00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Shark Tooth Slurry 4,948.3 5,402.0 247 G 50.0 Yield(fV/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.06 15.80 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.15 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.6 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.7 %BWOC Page 2/2 Report Printed: 11/4/2016 i i �v^�� Cement Detail Report s1�n 1 2S-09 ConocoPhillips 7 String: 6-3/4"Lateral Abandonment Plug Job: DRILLING ORIGINAL,9/12/2016 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 6-3/4"Lateral Abandonment Plug 10/6/2016 21:30 10/6/2016 23:30 2S-09 Comment Cementers pump 10 bbls water and pressure test lines to 550/3500 psi-good test.Pump 58.8 bbls 15.Bppg Class G cement at 4.5 bpm,1576 psi,holding 800 psi backpressure through rig choke to minimize u-tubing.Shut chokes to hold pressure while swapping from cement to water.Cementers pump 5 bbls of water at 3bpm,240 psi and sting into cement retainer.Bleed off backside pressure,open bag,and line up to rig pump.Pump 62 bbls 10.0ppg FloPro w/rig pump. Staged up to 1.5 bpm,1578 psi for 14.5 bbls and then observed pressure start to increase up to 2860 psi with no breakover.Decreased rate to 1 bpm and observed pressure breakover at 3039 psi.Continued pumping at 1 bpm,observing pressure climb to 3286 psi after 36.5 bbls pumped and then continue to fluctuate between 3000-3200 psi.Shut down after 62 bbls pumped and observe pressure fall to 2400 psi.Sting out of cement retainer and pull out of hole 4 x stands slowly to 6644'. Cement In place @ 00:06 hrs. Squeezed 52 bbls of 15.8ppg Class G cement below cement retainer. Estimated top of cement inside 7-5/8"casing @ 6903'MD. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement,..Top Plug? Btm Plug? 6-3/4"Lateral Squeeze 50 bbis below 7,007.0 8,373.0 No No No Abandonment Plug retainer and 100'above Q Pump molt(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1 1 1 3,200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(In) 7,007.0 Work String Comment Squeezed total of 10 bbls of water and 52 bbis cement below retainer Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 6,903.0 8,373.0 G 58.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water("1) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 6/1 512 01 7 `G,v-0Q • 0 r Cement Detail Report .. ki & ■ , "� SUPERSEDED 2S-09 conoccehii)ips String: 6-3/4" Lateral Abandonment Plug Job: DRILLING ORIGINAL,9/12/2016 18:00 Cement Details Description (Cementing Start DateCementing End Date Wellbore Name 6-3/4"Lateral Abandonment Plug 10/6/2016 21:30 I 10/6/2016 23:30 I2S-09 Comment Cementers pump 10 bbls water and pressure test lines to 550/3500 psi-good test.Pump 58.8 bbls 15.8ppg Class G cement at 4.5 bpm, 1576 psi,holding 800 psi backpressure through rig choke to minimize u-tubing.Shut chokes to hold pressure while swapping from cement to water.Cementers pump 5 bbls of water at 3bpm,240 psi and sting into cement retainer.Bleed off backside pressure,open bag,and line up to rig pump.Pump 62 bbls 10.0ppg FloPro w/rig pump. Staged up to 1.5 bpm, 1578 psi for 14.5 bbls and then observed pressure start to increase up to 2860 psi with no breakover.Decreased rate to 1 bpm and observed pressure breakover at 3039 psi.Continued pumping at 1 bpm,observing pressure climb to 3286 psi after 36.5 bbls pumped and then continue to fluctuate between 3000-3200 psi.Shut down after 62 bbls pumped and observe pressure fall to 2400 psi.Sting out of cement retainer and pull out of hole 4 x stands slowly to 6644'. Cement in place @ 00:06 hrs. Squeezed 52 bbls of 15.8ppg Class G cement below cement retainer. Estimated top of cement inside 7-5/8"casing @ 6903'MD. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? 6-3/4"Lateral Squeeze 50 bbls below 7,007.0 8,373.0 No No No Abandonment Plug retainer and 100'above , Rotated? 'Pipe RPM(rpm) Q Pump Ind(bbl/m...IQ Pump Final(bbl/...Q Pump Avg(bbl/... IP Pump Final(psi) P Plug Bump(psi) Recip. Stroke(ft) P (P ) 1 1 1 3,200.0 I No I No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) I Drill Out Diameter(in) 7,007.0 Work String Comment Squeezed total of 10 bbls of water and 52 bbls cement below retainer Cement Fluids&Additives Fluid Volume Pumped bbl Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) CCllass P (bbl) $ Plug Back Cement 6,903.0 8,373.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 15.80 Additives (Concentration IConc Unit label Additive 'Type Page 1/1 Report Printed: 11/4/2016 0:: Cement Detail Report „. • P: 2S-09 ConotoPhillips .:, String: Intermediate Kickoff Plug Job: DRILLING ORIGINAL,9/12/2016 18:00 Cement Details Description (Cementing Start DateCementing End Date Wellbore Name Intermediate Kickoff Plug 10/9/2016 22:45 I 10/9/2016 23:41 I2S-09 Comment Line up to cement unit&start batch mixing 17ppg cement.Pump 5 bbls of water to flood lines at 4 bpm, 137 psi.Test lines to 600/4000 psi.Reset high trip to 2500 psi. Batch mix 12.5ppg mudpush and pump at 5.5 bpm, 127 psi for a total of 35.5 bbls.Pump 17ppg Class G cement at 6 bpm, 150 psi for total of 60.1 bbls.Pump 12.5ppg mudpush at 4 bpm,30 psi for total of 4 bbls.Flush lines to rig floor w/1.5 bbls mudpush.Swap to rig and pump 9.2ppg WBM at 6 bpm,76- 350 psi for total of 28.6 bbls.Observed pressure rapidly increase to 350 psi after 24.5 bbls pumped as fluid caught falling cement. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Kickoff Plug From CIBP to 250'above 2,440.0 2,972.0 No No No surface casing shoe Rotated? Pipe RPM(rpm) Q Pump%nit(bbllm...IQ Pump Final(bbl/...Q Pump Avg(bbll... IP Pump Final(psi) P Plug Bump(psi) IRecipo 'Stroke(ft) No 4 6 6 350.0 Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) 'Drill Out Diameter(in) Comment Line up to cement unit&start batch mixing 17ppg cement.Pump 5 bbls of water to flood lines at 4 bpm, 137 psi.Test lines to 600/4000 psi.Reset high trip to 2500 psi.Batch mix 12.5ppg mudpush and pump at 5.5 bpm, 127 psi for a total of 35.5 bbls. Pump 17ppg Class G cement at 6 bpm, 150 psi for total of 60.1 bbls.Pump 12.5ppg mudpush at 4 bpm,30 psi for total of 4 bbls.Flush lines to rig floor w/1.5 bbls mudpush.Swap to rig and pump 9.2ppg WBM at 6 bpm,76- 350 psi for total of 28.6 bbls.Observed pressure rapidly increase to 350 psi after 24.5 bbls pumped as fluid caught falling cement. Cement Fluids&Additives Fluid Volume Pumped(bbl) Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) CCllass P 60.1 Plug Back Cement 2,440.0 2,972.0 Yield(fP/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.00 3.66 17.00 5.10 Additives Additive 'Type (Concentration 'Cont Unit label Page 1/1 Report Printed: 11/4/2016 0 7-C 5,-L 0. Cement Detail Report tz d4 2S-09 ConocaPhiltips String: Intermediate 2 Casing Cement Job: DRILLING ORIGINAL,9112/2016 18:00 Cement Details Description (Cementing Start Datenting End Date Wellbore Name Intermediate 2 Casing Cement 10/17/2016 08:00 1 Cementing End 18:00 2S-09A Comment Cement 1st stage as per SLB schedule. Pump 5 bbls of H2O&pressure test lines to 600/4000 psi.Pump 40 bbls of 12.5 ppg mud push at 3.7 bpm,150 psi. Drop bottom plug.Pump 15.2 bbls of 15.8 ppg neat cement at 5 bpm,265 psi.Pump 99.5 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.1 bpm, 175 psi. Pump 46 bbls of 15.8 ppg neat cement at 5.1 bpm,180 psi.Drop top plug&pump 10 bbls of H2O at 6 bpm,207 psi.Swap to rig&displace w/353.7 bbls of 10.0 ppg LSND mud at 7 bpm, 120 psi.Slow rate to 3 bpm,830 psi&bump plug at 3502 strokes.Pressure up to 1340 psi&hold for 5 minutes.Bleed off&check floats,good.CIP 10:10 hrs. Cement 2nd stage as per SLB schedule.Pump 5 bbls of H2O.Pump 41.9 bbls of 12.5 ppg mud push at 4.1 bpm, 108 psi.Pump 10.2 bbls of 15.8 ppg neat cement at 5.5 bpm,252 psi.Pump 33.1 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.5 bpm,222 psi.Pump LSND.2 mold at s of 1 .8 g nat scement Slow mentat 4 rate to 3 , 180 psi.Drop closing plug&pump 10 bbls of H2O at 5 bpm,7 psi.Swap to rig&displace wl 243 bbls of 10.0 ppgbpm, P 600 psi&bump plug at 2404 strokes.CIP 18:05 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? 0... Yes Yes Intermediate Casing Cement from TD of 8138' 6,170.0 8,138.0 No Cement to top of Cairn @ 6170' MDd? 'Pipe RPM(rpm) Q Pump(nit(bbl/m...10 Pump Final(bbl/...Q Pump Avg(bbl/... IP Pump Final(psi) P Plug Bump(psi) IRecip? IStrokee(ft) 15.00 Rotalloteto II p 5 5 5 823.0 1,346.0 Yes TagMethod Depth Plug Drilled Out To(ftKB) 1 Drill Out Diameter(in) Tagged Depth(ftKB) Commentmud push at 3.7 bpm, 150 psi. Cement 1stplug. stage as per SLB of 15.8 Pump ppg neattlcement at s of H20&p bpm,265 psi.linesre test Pump 99.5/bblss of 15.8 ppg cement w/2 ppb ppgf CemNet at 5.1 bpm,175 psi. Drop bottom6pog.15.8mp 15.2 neat bbls of ppgplug&pump10 bbls of H2O at 6 bpm,207 psi.Swap to rig&displace w/353.7 bbls of 10.0 Pump 46 bbls of ppg cement at 5.1 bpm, 180 psi.Drop top p g ppg LSND mud at 7 bpm, 120 psi.Slow rate to 3 bpm,830 psi&bump plug at 3502 strokes. Pressure up to 1340 psi&hold for 5 minutes.Bleed off&check floats,good.CIP 10:10 hrs. Cement Fluids&Additives FluidClass Volume Pumped(bbl)778Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) 778 G 160.7 Intermediate Cement 6,170.0 8,138.0 Yield(Wlsack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(P 71)1 Thickening Time(hr) 5CmprStr 1(psi) 1.16 5.05 15.80 Additives Additive (Type (Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) 4,911.0Bottom Depth(ftKB)5,512.01 No 0... YesNo Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Cement 500'above the C Cement -37 at 5411'MD Rotated? 'Pipe RPM(rpm) Q Pump(nit(bbllm...IQ Pump Final(bbl/...Q Pump Avg(bbl/... IP Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) 1 p 6 6 682.0 1,241.01 No 1 No 6 Drill Out Diameter(in) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Comment neat Cement 2nd stage as per SLB schedule.Pump 5 bbls of H20.Pump 41.9 bbls of 12.5 ppg mud push at 4.1 bpm, 108 psi.Pump 10.2 of 15 8 at bpm,e180 cement at 5.5 bpm,252 psi.Pump 33.1 bbls of 15.8 ppg cement w/2 ppb of CemNet at 5.5 bpm,222 psi.Pump 4.2 bbls of mud at 15.8 7 .8 ppg neat psc Slow rate to 3 bpm, psi.Drop closing plug&pump 10 bbls of H2O at 5 bpm,7 psi.Swap to rig&displace w/243 bbls of 10.0 ppg 600 psi&bump plug at 2404 strokes.CIP 18:05 hrs. Cement Fluids&Additives Fluid Class Volume Pumped(bbl) Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) 47.3 YP 4,911.0 5,512.0 229 G Intermediate Cement Yield(ft/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(209)1 Thickening Time(hr) 75 CmprStr 1(psi) 1.16 5.05 15.80 Additives Additive Type (Concentration IConc Unit label Page 111 Report Printed: 111412016, RE&IVE • 216098 27 70 5 NOV 0 9 2096 ��C Schlumberger iliDring & Measurements Transmittal#: 09NOV2016-SP01 DATA LOGGED MWD/LWD Log Product Delivery 1, /14!2o1 to .L K. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2S-09 Date Dispatched: 9-Nov-16 Job#: 16AKA0109 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2"TVD x x VISION*Service 5'MD x x VISION*Service 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics: pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp@conocophillips.com AlaskaPTSPrintCenter(a�slb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 Received By: m,..gasze,„,4%) . . • 21 6098 27705 REcoveD NOV 0 9 20% FINAL AOGC NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-09 Definitive Survey Report 26 October, 2016 NAD 27 i r Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 25-09:39.10+120 @ 159.10usft(DoyonVV Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-09 Well Position +N/-S 0.00 usft Northing: 5,929,986.08 usft Latitude: 70°13'11.559 N +EI-W 0.00 usft Easting: 481,074.22 usft Longitude: 150°9'9.654 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-09 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2016 10/1/2016 17.80 80.84 57,533 Design Rig:2S-09 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.10 0.00 0.00 15.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 60.00 835.50 2S-09 Srvy 1-SLB_NSG+MSHOT(2S-0 GYD-GC-MS Gyrodata gyrocompassing m/s 9/14/2016 9:02: 858.68 2,088.06 2S-09 Srvy 2-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/14/2016 9:05: 2,184.78 2,758.43 2S-09 Srvy 3-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/15/2016 9:05: 2,800.11 2,800.11 2S-09 Srvy 4-SLB_Inc+Filler(2S-09) INC+TREND Inclinometer+known azi trend 9/19/2016 9:33: 2,877.83 7,191.58 2S-09 Srvy 5-SLB-MWD+GMAG(2S-09 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/19/2016 9:35: 7,274.27 11,523.93 2S-09 Srvy 6-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/28/2016 12:07 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -120.00 0.00 0.00 5,929,986.08 481,074.22 0.00 0.00 UNDEFINED 60.00 0.10 15.64 60.00 -99.10 0.02 0.00 5,929,986.10 481,074.22 0.48 0.02 GYD-GC-MS(1) 160.00 0.13 308.73 160.00 0.90 0.17 -0.06 5,929,986.25 481,074.16 0.13 0.15 GYD-GC-MS(1) 260.00 0.06 294.26 260.00 100.90 0.27 -0.20 5,929,986.35 481,074.02 0.07 0.21 GYD-GC-MS(1) 360.00 0.82 192.90 360.00 200.90 -0.41 -0.40 5,929,985.67 481,073.82 0.83 -0.50 GYD-GC-MS(1) 461.50 3.95 180.46 461.40 302.30 -4.62 -0.59 5,929,981.47 481,073.61 3.11 -4.61 GYD-GC-MS(1) 554.50 5.67 183.83 554.07 394.97 -12.40 -0.93 5,929,973.68 481,073.26 1.87 -12.22 GYD-GC-MS(1) 646.50 6.99 181.30 645.50 486.40 -22.54 -1.36 5,929,963.55 481,072.81 1.47 -22.12 GYD-GC-MS(1) 741.50 9.40 178.44 739.53 580.43 -36.07 -1.28 5,929,950.02 481,072.85 2.57 -35.17 GYD-GC-MS(1) 835.50 10.98 178.30 832.04 672.94 -52.69 -0.80 5,929,933.39 481,073.29 1.68 -51.11 GYD-GC-MS(1) 10/26/2016 1:11:42PM Page 2 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonll Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon)' Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 858.68 11.28 178.34 854.78 695.68 -57.17 -0.67 5,929,928.92 481,073.41 1.29 -55.39 MWD+IFR-AK-CAZ-SC(2) 953.11 12.52 177.35 947.18 788.08 -76.62 0.07 5,929,909.46 481,074.10 1.33 -73.99 MWD+IFR-AK-CAZ-SC(2) 1,048.23 14.62 180.18 1,039.64 880.54 -98.93 0.51 5,929,887.16 481,074.48 2.31 -95.43 MWD+IFR-AK-CAZ-SC(2) 1,142.58 17.35 183.83 1,130.34 971.24 -124.88 -0.47 5,929,861.22 481,073.44 3.08 -120.74 MWD+IFR-AK-CAZ-SC(2) 1,238.16 19.02 183.31 1,221.14 1,062.04 -154.65 -2.32 5,929,831.45 481,071.51 1.76 -149.98 MWD+IFR-AK-CAZ-SC(2) 1,332.20 22.32 182.82 1,309.12 1,150.02 -187.79 -4.08 5,929,798.32 481,069.67 3.51 -182.45 MWD+IFR-AK-CAZ-SC(2) 1,426.66 24.35 183.54 1,395.85 1,236.75 -225.15 -6.17 5,929,760.97 481,067.49 2.17 -219.07 MWD+IFR-AK-CAZ-SC(2) 1,521.98 27.34 182.20 1,481.62 1,322.52 -266.64 -8.22 5,929,719.48 481,065.33 3.20 -259.69 MWD+IFR-AK-CAZ-SC(2) 1,617.01 28.93 181.69 1,565.42 1,406.32 -311.43 -9.74 5,929,674.71 481,063.70 1.69 -303.34 MWD+IFR-AK-CAZ-SC(2) 1,712.12 33.22 175.92 1,646.88 1,487.78 -360.44 -8.56 5,929,625.70 481,064.75 5.49 -350.38 MWD+IFR-AK-CAZ-SC(2) 1,805.74 33.27 175.73 1,725.18 1,566.08 -411.63 -4.83 5,929,574.50 481,068.36 0.12 -398.85 MWD+IFR-AK-CAZ-SC(2) 1,900.89 31.00 176.13 1,805.75 1,646.65 -462.11 -1.23 5,929,524.02 481,071.83 2.40 -446.68 MWD+IFR-AK-CAZ-SC(2) 1,997.03 30.41 176.16 1,888.41 1,729.31 -511.09 2.07 5,929,475.04 481,075.01 0.61 -493.14 MWD+IFR-AK-CAZ-SC(2) 2,088.06 30.40 177.33 1,966.92 1,807.82 -557.09 4.69 5,929,429.04 481,077.51 0.65 -536.89 MWD+IFR-AK-CAZ-SC(2) 2,184.78 30.11 176.48 2,050.47 1,891.37 -605.75 7.32 5,929,380.38 481,080.02 0.53 -583.21 MWD+IFR-AK-CAZ-SC(3) 2,279.09 30.14 175.82 2,132.04 1,972.94 -652.97 10.50 5,929,333.15 481,083.08 0.35 -628.00 MWD+IFR-AK-CAZ-SC(3) 2,374.12 30.32 175.47 2,214.14 2,055.04 -700.68 14.13 5,929,285.44 481,086.59 0.27 -673.15 MWD+IFR-AK-CAZ-SC(3) 2,469.58 31.25 179.40 2,296.16 2,137.06 -749.46 16.29 5,929,236.65 481,088.63 2.32 -719.71 MWD+IFR-AK-CAZ-SC(3) 2,564.15 32.39 179.93 2,376.52 2,217.42 -799.32 16.58 5,929,186.80 481,088.79 1.24 -767.80 MWD+IFR-AK-CAZ-SC(3) 2,658.68 31.12 179.05 2,456.90 2,297.80 -849.07 17.02 5,929,137.06 481,089.10 1.43 -815.73 MWD+IFR-AK-CAZ-SC(3) 2,758.43 31.67 180.06 2,542.04 2,382.94 -901.03 17.42 5,929,085.10 481,089.37 0.76 -865.82 MWD+IFR-AK-CAZ-SC(3) 2,800.11 31.87 180.00 2,577.48 2,418.38 -922.97 17.40 5,929,063.16 481,089.31 0.49 -887.02 INC+TREND(4) 2,822.00 31.96 179.53 2,596.06 2,436.96 -934.55 17.45 5,929,051.59 481,089.33 1.22 -898.19 NOT an Actual Survey 10 3/4"x 13 1/2" IIJI 2,877.83 32.20 178.33 2,643.36 2,484.26 -964.19 18.01 5,929,021.94 481,089.81 1.22 -926.68 MWD+IFR-AK-CAZ-SC(5) 2,894.31 32.78 177.93 2,657.26 2,498.16 -973.04 18.30 5,929,013.09 481,090.07 3.75 -935.15 MWD+IFR-AK-CAZ-SC(5) 2,989.46 33.52 179.11 2,736.93 2,577.83 -1,025.05 19.64 5,928,961.09 481,091.28 1.03 -985.04 MWD+IFR-AK-CAZ-SC(5) 3,085.15 32.56 179.53 2,817.14 2,658.04 -1,077.22 20.26 5,928,908.92 481,091.77 1.03 -1,035.27 MWD+IFR-AK-CAZ-SC(5) 3,180.55 31.64 181.16 2,897.96 2,738.86 -1,127.91 19.96 5,928,858.24 481,091.35 1.32 -1,084.31 MWD+IFR-AK-CAZ-SC(5) 3,216.83 30.85 181.67 2,928.98 2,769.88 -1,146.72 19.50 5,928,839.43 481,090.84 2.30 -1,102.60 MWD+IFR-AK-CAZ-SC(5) 3,275.15 29.15 183.54 2,979.48 2,820.38 -1,175.85 18.18 5,928,810.31 481,089.45 3.33 -1,131.07 MWD+IFR-AK-CAZ-SC(5) 3,369.71 29.22 183.38 3,062.04 2,902.94 -1,221.87 15.40 5,928,764.29 481,086.56 0.11 -1,176.25 MWD+IFR-AK-CAZ-SC(5) 3,465.06 29.12 181.76 3,145.30 2,986.20 -1,268.30 13.32 5,928,717.88 481,084.36 0.83 -1,221.63 MWD+IFR-AK-CAZ-SC(5) 3,559.35 29.12 179,80 3,227.67 3,068.57 -1,314.17 12.69 5,928,672.01 481,083.62 1.01 -1,266.11 MWD+IFR-AK-CAZ-SC(5) 3,654.21 29.11 175.20 3,310.56 3,151.46 -1,360.25 14.70 5,928,625.93 481,085.51 2.36 -1,310.10 MWD+IFR-AK-CAZ-SC(5) 3,748.38 29.08 171.75 3,392.85 3,233.75 -1,405.73 19.90 5,928,580.45 481,090.60 1.78 -1,352.68 MWD+IFR-AK-CAZ-SC(5) 3,843.39 29.20 172.07 3,475.83 3,316.73 -1,451.53 26.41 5,928,534.63 481,096.99 0.21 -1,395.24 MWD+IFR-AK-CAZ-SC(5) 3,937.70 29.29 173.30 3,558.12 3,399.02 -1,497.23 32.28 5,928,488.92 481,102.74 0.64 -1,437.86 MWD+IFR-AK-CAZ-SC(5) 4,032.85 26.26 176.57 3,642.31 3,483.21 -1,541.37 36.26 5,928,444.78 481,106.61 3.56 -1,479.47 MW0+IFR-AK-CAZ-SC(5) 4,127.92 23.76 177.68 3,728.45 3,569.35 -1,581.51 38.29 5,928,404.64 481,108.54 2.68 -1,517.71 MWD+IFR-AK-CAZ-SC(5) 10/26/2016 1:11:42PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonlV Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1i Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/l00') (ft) Survey Tool Name 4,222.30 20.68 176.28 3,815.82 3,656.72 -1,617.14 40.14 5,928,369.00 481,110.30 3.31 -1,551.65 MWD+IFR-AK-CAZ-SC(5) 4,316.01 18.07 174.18 3,904.21 3,745.11 -1,648.12 42.69 5,928,338.02 481,112.77 2.88 -1,580.91 MWD+IFR-AK-CAZ-SC(5) 4,410.48 15.20 169.34 3,994.72 3,835.62 -1,674.87 46.47 5,928,311.26 481,116.48 3.37 -1,605.78 MWD+IFR-AK-CAZ-SC(5) 4,505.57 12.37 159.36 4,087.08 3,927.98 -1,696.66 52.37 5,928,289.46 481,122.33 3.88 -1,625.30 MWD+IFR-AK-CAZ-SC(5) 4,599.59 10.73 147.53 4,179.20 4,020.10 -1,713.48 60.62 5,928,272.63 481,130.53 3.06 -1,639.40 MWD+IFR-AK-CAZ-SC(5) 4,694.91 9.31 142.66 4,273.07 4,113.97 -1,727.09 70.06 5,928,258.99 481,139.94 1.73 -1,650.11 MWD+IFR-AK-CAZ-SC(5) 4,789.62 7.30 136.03 4,366.78 4,207.68 -1,737.52 78.88 5,928,248.54 481,148.74 2.35 -1,657.90 MWD+IFR-AK-CAZ-SC(5) 4,884.31 6.12 113.23 4,460.84 4,301.74 -1,743.84 87.70 5,928,242.20 481,157.54 3.05 -1,661.72 MWD+IFR-AK-CAZ-SC(5) 4,978.95 6.70 95.74 4,554.90 4,395.80 -1,746.38 97.83 5,928,239.63 481,167.66 2.14 -1,661.55 MWD+IFR-AK-CAZ-SC(5) 5,073.65 6.98 77.43 4,648.93 4,489.83 -1,745.68 108.94 5,928,240.31 481,178.77 2.31 -1,658.00 MWD+IFR-AK-CAZ-SC(5) 5,168.64 9.01 58.29 4,743.01 4,583.91 -1,740.51 120.91 5,928,245.44 481,190.75 3.50 -1,649.91 MWD+IFR-AK-CAZ-SC(5) 5,263.08 11.10 44.26 4,836.01 4,676.91 -1,730.11 133.55 5,928,255.81 481,203.41 3.39 -1,636.60 MWD+IFR-AK-CAZ-SC(5) 5,358.88 13.64 35.49 4,929.59 4,770.49 -1,714.31 146.54 5,928,271.58 481,216.45 3.29 -1,617.97 MWD+IFR-AK-CAZ-SC(5) 5,453.39 17.92 31.63 5,020.52 4,861.42 -1,692.84 160.65 5,928,293.01 481,230.60 4.66 -1,593.58 MWD+IFR-AK-CAZ-SC(5) 5,548.40 22.50 27.39 5,109.66 4,950.56 -1,664.24 176.68 5,928,321.57 481,246.71 5.06 -1,561.80 MWD+IFR-AK-CAZ-SC(5) 5,642.58 25.70 25.16 5,195.62 5,036.52 -1,629.75 193.66 5,928,356.02 481,263.77 3.53 -1,524.09 MWD+IFR-AK-CAZ-SC(5) 5,737.30 28.18 24.81 5,280.05 5,120.95 -1,590.85 211.78 5,928,394.86 481,281.99 2.62 -1,481.83 MWD+IFR-AK-CAZ-SC(5) 5,831.73 29.17 24.25 5,362.90 5,203.80 -1,549.63 230.59 5,928,436.03 481,300.90 1.09 -1,437.14 MWD+IFR-AK-CAZ-SC(5) 5,926.48 31.60 22.24 5,444.63 5,285.53 -1,505.59 249.47 5,928,480.02 481,319.89 2.78 -1,389.72 MWD+IFR-AK-CAZ-SC(5) 6,021.10 34.05 21.06 5,524.14 5,365.04 -1,457.92 268.38 5,928,527.64 481,338.91 2.68 -1,338.78 MWD+IFR-AK-CAZ-SC(5) 6,115.13 37.00 19.68 5,600.66 5,441.56 -1,406.70 287.37 5,928,578.81 481,358.03 3.25 -1,284.39 MWD+IFR-AK-CAZ-SC(5) 6,210.39 40.51 18.57 5,674.94 5,515.84 -1,350.36 306.88 5,928,635.09 481,377.68 3.76 -1,224.92 MWD+IFR-AK-CAZ-SC(5) 6,304.61 43.13 17.21 5,745.15 5,586.05 -1,290.57 326.16 5,928,694.82 481,397.11 2.94 -1,162.18 MWD+IFR-AK-CAZ-SC(5) 6,400.38 44.08 16.74 5,814.50 5,655.40 -1,227.40 345.44 5,928,757.94 481,416.55 1.05 -1,096.17 MWD+IFR-AK-CAZ-SC(5) 6,495.76 47.15 16.08 5,881.21 5,722.11 -1,162.02 364.69 5,928,823.27 481,435.95 3.26 -1,028.04 MWD+IFR-AK-CAZ-SC(5) 6,589.32 50.55 14.26 5,942.76 • 5,783.66 -1,094.03 383.09 5,928,891.20 481,454.53 3.92 -957.60 MWD+IFR-AK-CAZ-SC(5) 6,684.48 53.35 13.04 6,001.41 5,842.31 -1,021.22 400.76 5,928,963.96 481,472.37 3.11 -882.70 MWD+IFR-AK-CAZ-SC(5) 6,779.49 56.41 12.29 6,056.06 5,896.96 -945.40 417.78 5,929,039.73 481,489.59 3.28 -805.06 MWD+IFR-AK-CAZ-SC(5) 6,874.22 58.57 11.54 6,106.97 5,947.87 -867.24 434.27 5,929,117.84 481,506.27 2.38 -725.30 MWD+IFR-AK-CAZ-SC(5) 6,969.60 61.93 11.09 6,154.30 5,995.20 -786.05 450.51 5,929,198.98 481,522.71 3.55 -642.67 MWD+IFR-AK-CAZ-SC(5) 7,064.03 65.49 9.64 6,196.12 6,037.02 -702.79 465.72 5,929,282.20 481,538.13 4.01 -558.30 MWD+IFR-AK-CAZ-SC(5) 7,159.23 68.52 9.24 6,233.30 6,074.20 -616.35 480.09 5,929,368.59 481,552.71 3.21 -471.09 MWD+IFR-AK-CAZ-SC(5) 7,191.58 69.53 9.91 6,244.88 6,085.78 -586.56 485.11 5,929,398.36 481,557.81 3.67 -441.02 MWD+IFR-AK-CAZ-SC(5) 7,247.00 70.27 9.51 6,263.93 6,104.83 -535.27 493.89 5,929,449.63 481,566.72 1.49 -389.20 taw anActual survey 7-5/8"x 9-7/8"by 11" 7,274.27 70.63 9.31 6,273.05 6,113.95 -509.91 498.09 5,929,474.97 481,570.98 1.49 -363.62 MWD+IFR-AK-CAZ-SC(6) 7,369.08 74.93 10.12 6,301.12 6,142.02 -420.68 513.38 5,929,564.16 481,586.49 4.61 -273.47 MWD+IFR-AK-CAZ-SC(6) 7,464.12 78.11 12.48 6,323.27 6,164.17 -330.07 531.50 5,929,654.72 481,604.83 4.13 -181.26 MWD+IFR-AK-CAZ-SC(6) 7,559.11 81.49 14.52 6,340.09 6,180.99 -239.18 553.32 5,929,745.54 481,626.89 4.14 -87.82 MWD+IFR-AK-CAZ-SC(6) 7,652.43 85.49 14.46 6,350.67 6,191.57 -149.43 576.52 5,929,835.22 481,650.30 4.29 4.88 MWD+IFR-AK-CAZ-SC(6) 10/26/2016 1:11:42PM Page 4 COMPASS 5000.1 Build 74 III i Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,747.44 89.17 12.66 6,355.10 6,196.00 -57.19 598.76 5,929,927.40 481,672.78 4.31 99.73 MWD+IFR-AK-CAZ-SC(6) 7,841.94 92.04 13.70 6,354.10 6,195.00 34.81 620.31 5,930,019.33 481,694.55 3.23 194.17 MWD+IFR-AK-CAZ-SC(6) 7,935.82 91.64 15.01 6,351.08 6,191.98 125.71 643.57 5,930,110.16 481,718.04 1.46 287.99 MWD+IFR-AK-CAZ-SC(6) 8,029.46 91.30 12.66 6,348.68 6,189.58 216.59 665.95 5,930,200.98 481,740.65 2.53 381.57 MWD+IFR-AK-CAZ-SC(6) 8,124.26 91.90 10.58 6,346.03 6,186.93 309.41 685.04 5,930,293.74 481,759.96 2.28 476.17 MWD+IFR-AK-CAZ-SC(6) 8,221.24 93.86 7.18 6,341.16 6,182.06 405.09 699.99 5,930,389.37 481,775.15 4.04 572.45 MWD+IFR-AK-CAZ-SC(6) 8,315.09 93.22 7.30 6,335.36 6,176.26 498.01 711.79 5,930,482.25 481,787.19 0.69 665.27 MWD+IFR-AK-CAZ-SC(6) 8,409.99 92.33 10.07 6,330.77 6,171.67 591.70 726.11 5,930,575.90 481,801.74 3.06 759.47 MWD+IFR-AK-CAZ-SC(6) 8,504.52 90.77 12.09 6,328.21 6,169.11 684.43 744.27 5,930,668.57 481,820.13 2.70 853.74 MWD+IFR-AK-CAZ-SC(6) 8,598.11 90.61 10.71 6,327.08 6,167.98 776.16 762.76 5,930,760.25 481,838.85 1.48 947.13 MWD+IFR-AK-CAZ-SC(6) 8,692.69 90.54 10.39 6,326.14 6,167.04 869.14 780.08 5,930,853.17 481,856.40 0.35 1,041.42 MWD+IFR-AK-CAZ-SC(6) 8,787.42 89.19 13.76 6,326.36 6,167.26 961.76 799.89 5,930,945.73 481,876.44 3.83 1,136.01 MWD+IFR-AK-CAZ-SC(6) 8,882.76 89.68 15.15 6,327.30 6,168.20 1,054.07 823.69 5,931,037.98 481,900.47 1.55 1,231.34 MWD+IFR-AK-CAZ-SC(6) 8,977.23 89.19 14.43 6,328.23 6,169.13 1,145.41 847.80 5,931,129.24 481,924.81 0.92 1,325.81 MWD+IFR-AK-CAZ-SC(6) 9,072.52 89.76 13.50 6,329.10 6,170.00 1,237.87 870.80 5,931,221.64 481,948.03 1.14 1,421.07 MWD+IFR-AK-CAZ-SC(6) 9,167.49 88.62 15.48 6,330.45 6,171.35 1,329.81 894.56 5,931,313.51 481,972.02 2.41 1,516.03 MWD+IFR-AK-CAZ-SC(6) 9,261.50 88.28 20.17 6,332.99 6,173.89 1,419.25 923.32 5,931,402.87 482,001.00 5.00 1,609.86 MWD+IFR-AK-CAZ-SC(6) 9,357.09 92.42 21.48 6,332.41 6,173.31 1,508.57 957.29 5,931,492.10 482,035.19 4.54 1,704.93 MWD+IFR-AK-CAZ-SC(6) 9,451.70 91.02 20.56 6,329.57 6,170.47 1,596.84 991.21 5,931,580.27 482,069.33 1.77 1,798.97 MWD+IFR-AK-CAZ-SC(6) 9,546.44 90.30 18.14 6,328.48 6,169.38 1,686.22 1,022.60 5,931,669.56 482,100.94 2.66 1,893.43 MWD+IFR-AK-CAZ-SC(6) 9,640.95 90.06 14.74 6,328.18 6,169.08 1,776.85 1,049.34 5,931,760.12 482,127.91 3.61 1,987.89 MWD+IFR-AK-CAZ-SC(6) 9,736.74 88.64 11.94 6,329.27 6,170.17 1,870.04 1,071.44 5,931,853.24 482,150.24 3.28 2,083.63 MWD+IFR-AK-CAZ-SC(6) 9,830.99 88.52 11.92 6,331.60 6,172.50 1,962.22 1,090.91 5,931,945.37 482,169.94 0.13 2,177.71 MWD+IFR-AK-CAZ-SC(6) 9,925.49 88.72 12.63 6,333.88 6,174.78 2,054.54 1,111.00 5,932,037.62 482,190.26 0.78 2,272.08 MWD+IFR-AK-CAZ-SC(6) 10,020.41 89.31 14.37 6,335.51 6,176.41 2,146.81 1,133.15 5,932,129.83 482,212.64 1.94 2,366.95 MWD+IFR-AK-CAZ-SC(6) 10,114.99 90.03 14.18 6,336.05 6,176.95 2,238.47 1,156.47 5,932,221.42 482,236.19 0.79 2,461.52 MWD+IFR-AK-CAZ-SC(6) 10,209.83 90.78 14.31 6,335.38 6,176.28 2,330.39 1,179.81 5,932,313.28 482,259.75 0.80 2,556.34 MWD+IFR-AK-CAZ-SC(6) 10,304.67 90.92 16.10 6,333.98 6,174.88 2,421.90 1,204.68 5,932,404.71 482,284.85 1.89 2,651.17 MWD+IFR-AK-CAZ-SC(6) 10,399.73 90.99 18.38 6,332.39 6,173.29 2,512.67 1,232.85 5,932,495.40 482,313.24 2.40 2,746.14 MWD+IFR-AK-CAZ-SC(6) 10,494.18 91.09 19.00 6,330.68 6,171.58 2,602.12 1,263.11 5,932,584.77 482,343.72 0.66 2,840.38 MWD+IFR-AK-CAZ-SC(6) 10,588.79 90.92 18.57 6,329.02 6,169.92 2,691.68 1,293.57 5,932,674.24 482,374.41 0.49 2,934.76 MWD+IFR-AK-CAZ-SC(6) 10,684.13 90.92 16.93 6,327.49 6,168.39 2,782.47 1,322.63 5,932,764.94 482,403.69 1.72 3,029.98 MWD+IFR-AK-CAZ-SC(6) 10,778.37 91.52 15.55 6,325.48 6,166.38 2,872.92 1,348.98 5,932,855.33 482,430.27 1.60 3,124.17 MWD+IFR-AK-CAZ-SC(6) 10,873.71 94.51 14.84 6,320.47 6,161.37 2,964.79 1,373.93 5,932,947.12 482,455.45 3.22 3,219.37 MWD+IFR-AK-CAZ-SC(6) 10,968.90 95.16 14.78 6,312.44 6,153.34 3,056.49 1,398.18 5,933,038.75 482,479.92 0.69 3,314.22 MWD+IFR-AK-CAZ-SC(6) 11,063.26 93.53 14.56 6,305.29 6,146.19 3,147.51 1,422.01 5,933,129.70 482,503.97 1.74 3,408.30 MWD+IFR-AK-CAZ-SC(6) 11,154.89 90.38 13.31 6,302.17 6,143.07 3,236.38 1,444.05 5,933,218.51 482,526.24 3.70 3,499.85 MWD+IFR-AK-CAZ-SC(6) 11,247.12 89.57 14.02 6,302.21 6,143.11 3,326.00 1,465.84 5,933,308.06 482,548.25 1.17 3,592.05 MWD+IFR-AK-CAZ-SC(6) 11,338.65 89.86 14.42 6,302.66 6,143.56 3,414.72 1,488.33 5,933,396.72 482,570.96 0.54 3,683.57 MWD+IFR-AK-CAZ-SC(6) 11,431.20 89.89 13.76 6,302.87 6,143.77 3,504.49 1,510.86 5,933,486.42 482,593.71 0.71 3,776.11 MWD+IFR-AK-CAZ-SC(6) 10/26/2016 1:11:42PM Page 5 COMPASS 5000.1 Build 74 • is Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 11,523.93 90.03 14.29 6,302.93 6,143.83 3,594.45 1,533.33 5,933,576.32 482,616.41 0.59 3,868.83 MWD+IFR-AK-CAZ-SC(6) 11,584.00 90.03 14.29 6,302.90 6,143.80 3,652.66 1,548.16 5.933,634.49 482,631.38 0.00 3,928.89 PROJECTED to TD NOT an Actual Survey 6-3/4"open hole Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. El Yes U No I have checked to the best of my ability that the following data is correct: El Surface Coordinates Q Declination & Convergence E GRS Survey Corrections Digitally signed by Vincent Osara Survey Tool Codes Vincent °Ncn--V°KmtNara emkMutrberger, O s a ra anal sosaraanlb cony�u8 SSB DE: Date.2016.1112E 143265.0680 Client Representative: — ( - r As`>=t:C) Date: 26-Oct-2016 10/26/2016 1:11:42PM Page 6 COMPASS 5000.1 Build 74 • • 21 695 Z7 7 ® 5 o 9 Vo FINAL No(lo ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-09 Definitive Survey Report 25 October, 2016 NAD 83 Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2S-09 Well Position +N/-S 0.00 usft Northing: 5,929,735.67 usft Latitude: 70°13'10.439 N +E/-W 0.00 usft Easting: 1,621,107.54 usft Longitude: 150°9'20.804 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-09 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BG G M2016 10/1/2016 17.80 80.84 57,533 Design Rig:2S-09 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.10 0.00 0.00 15.00 Survey Program Date 10/25/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 60.00 835.50 2S-09 Srvy 1-SLB_NSG+MSHOT(2S-0 GYD-GC-MS Gyrodata gyrocompassing m/s 9/14/2016 9:02: 858.68 2,088.06 2S-09 Srvy 2-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/14/2016 9:05: 2,184.78 2,758.43 2S-09 Srvy 3-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/15/2016 9:05: 2,800.11 2,800.11 2S-09 Srvy 4-SLB_Inc+Filler(2S-09) INC+TREND Inclinometer+known azi trend 9/19/2016 9:33: 2,877.83 7,191.58 2S-09 Srvy 5-SLB-MWD+GMAG(2S-09 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/19/2016 9:35: 7,274.27 11,523.93 2S-09 Srvy 6-SLB_MWD+GMAG(2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/28/2016 12:07 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -120.00 0.00 0.00 5,929,735.67 1,621,107.54 0.00 0.00 UNDEFINED 60.00 0.10 15.64 60.00 -99.10 0.02 0.00 5,929,735.68 1,621,107.55 0.48 0.02 GYD-GC-MS(1) 160.00 0.13 308.73 160.00 0.90 0.17 -0.06 5,929,735.84 1,621.107.48 0.13 0.15 GYD-GC-MS(1) 260.00 0.06 294.26 260.00 100.90 0.27 -0.20 5,929,735.93 1,621.107.35 0.07 0.21 GYD-GC-MS(1) 360.00 0.82 192.90 360.00 200.90 -0.41 -0.40 5,929,735.26 1,621.107.14 0.83 -0.50 GYD-GC-MS(1) 461.50 3.95 180.46 461.40 302.30 -4.62 -0.59 5,929,731.05 1,621,106.94 3.11 -4.61 GYD-GC-MS(1) 554.50 5.67 183.83 554.07 394.97 -12.40 -0.93 5,929,723.27 1,621,106.58 1.87 -12.22 GYD-GC-MS(1) 646.50 6.99 181.30 645.50 486.40 -22.54 -1.36 5,929,713.14 1,621,106.13 1.47 -22.12 GYD-GC-MS(1) 741.50 9.40 178.44 739.53 580.43 -36.07 -1.28 5,929,699.60 1,621,106.17 2.57 -35.17 GYD-GC-MS(1) 835.50 10.98 178.30 832.04 672.94 -52.69 -0.80 5,929,682.98 1,621,106.60 1.68 -51.11 GYD-GC-MS(1) 10/25/2016 2:23:50PM Page 2 COMPASS 5000.1 Build 74 • • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonlL Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyon1z Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El-W Northing Fasting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/l00') (C) Survey Tool Name 858.68 11.28 178.34 854.78 695.68 -57.17 -0.67 5,929,678.51 1,621,106.72 1.29 -55.39 MWD+IFR-AK-CAZ-SC(2) 953.11 12.52 177.35 947.18 788.08 -76.62 0.07 5,929,659.05 1,621,107.41 1.33 -73.99 MWD+IFR-AK-CAZ-SC(2) 1,048.23 14.62 180.18 1,039.64 880.54 -98.93 0.51 5,929,636.75 1,621,107.80 2.31 -95.43 MWD+IFR-AK-CAZ-SC(2) 1,142.58 17.35 183.83 1,130.34 971.24 -124.88 -0.47 5,929,610.80 1,621,106.75 3.08 -120.74 MWD+IFR-AK-CAZ-SC(2) 1,238.16 19.02 183.31 1,221.14 1,062.04 -154.65 -2.32 5,929,581.04 1,621,104.83 1.76 -149.98 MWD+IFR-AK-CAZ-SC(2) 1,332.20 22.32 182.82 1,309.12 1,150.02 -187.79 -4.08 5,929,547.90 1,621,102.98 3.51 -182.45 MWD+IFR-AK-CAZ-SC(2) 1,426.66 24.35 183.54 1,395.85 1,236.75 -225.15 -6.17 5,929,510.56 1,621,100.80 2.17 -219.07 MWD+IFR-AK-CAZ-SC(2) 1,521.98 27.34 182.20 1,481.62 1,322.52 -266.64 -8.22 5,929,469.07 1,621,098.64 3.20 -259.69 MWD+IFR-AK-CAZ-SC(2) 1,617.01 28.93 181.69 1,565.42 1,406.32 -311.43 -9.74 5,929,424.30 1,621,097.01 1.69 -303.34 MWD+IFR-AK-CAZ-SC(2) 1,712.12 33.22 175.92 1,646.88 1,487.78 -360.44 -8.56 5,929,375.28 1,621,098.06 5.49 -350.38 MWD+IFR-AK-CAZ-SC(2) 1,805.74 33.27 175.73 1,725.18 1,566.08 -411.63 -4.83 5,929,324.09 1,621,101.66 0.12 -398.85 MWD+IFR-AK-CAZ-SC(2) 1,900.89 31.00 176.13 1,805.75 1,646.65 -462.11 -1.23 5,929,273.61 1,621,105.13 2.40 -446.68 MWD+IFR-AK-CAZ-SC(2) 1,997.03 30.41 176.16 1,888.41 1,729.31 -511.09 2.07 5,929,224.62 1,621,108.31 0.61 -493.14 MWD+IFR-AK-CAZ-SC(2) 2,088.06 30.40 177.33 1,966.92 1,807.82 -557.09 4.69 5,929,178.63 1,621,110.80 0.65 -536.89 MWD+IFR-AK-CAZ-SC(2) 2,184.78 30.11 176.48 2,050.47 1,891.37 -605.75 7.32 5,929,129.97 1,621,113.31 0.53 -583.21 MWD+IFR-AK-CAZ-SC(3) 2,279.09 30.14 175.82 2,132.04 1,972.94 -652.97 10.50 5,929,082.74 1,621,116.36 0.35 -628.00 MWD+IFR-AK-CAZ-SC(3) 2,374.12 30.32 175.47 2,214.14 2,055.04 -700.68 14.13 5,929,035.03 1,621,119.88 0.27 -673.15 MWD+IFR-AK-CAZ-SC(3) 2,469.58 31.25 179.40 2,296.16 2,137.06 -749.46 16.29 5,928,986.24 1,621,121.91 2.32 -719.71 MWD+IFR-AK-CAZ-SC(3) 2,564.15 32.39 179.93 2,376.52 2,217.42 -799.32 16.58 5,928,936.38 1,621,122.07 1.24 -767.80 MWD+IFR-AK-CAZ-SC(3) 2,658.68 31.12 179.05 2,456.90 2,297.80 -849.07 17.02 5,928,886.64 1,621,122.38 1.43 -815.73 MWD+IFR-AK-CAZ-SC(3) 2,758.43 31.67 180.06 2,542.04 2,382.94 -901.03 17.42 5,928,834.69 1,621,122.65 0.76 -865.82 MWD+IFR-AK-CAZ-SC(3) 2,800.11 31.87 180.00 2,577.48 2,418.38 -922.97 17.40 5,928,812.74 1,621,122.58 0.49 -887.02 INC+TREND(4) 2,822.00 31.96 179.53 2,596.06 2,436.96 -934.55 17.45 5,928,801.17 1,621,122.60 1.22 -898.19 NOT an Actual Survey(5) 10 3/4"x 13 1/2" 2,877.83 32.20 178.33 2,643.36 2,484.26 -964.19 18.01 5,928,771.53 1,621,123.08 1.22 -926.68 MWD+IFR-AK-CAZ-SC(5) 2,894.31 32.78 177.93 2,657.26 2,498.16 -973.04 18.30 5,928,762.68 1,621,123.35 3.75 -935.15 MWD+IFR-AK-CAZ-SC(5) 2,989.46 33.52 179.11 2,736.93 2,577.83 -1,025.05 19.64 5,928,710.67 1,621,124.55 1.03 -985.04 MWD+IFR-AK-CAZ-SC(5) 3,085.15 32.56 179.53 2,817.14 2,658.04 -1,077.22 20.26 5,928,658.51 1,621,125.04 1.03 -1,035.27 MWD+IFR-AK-CAZ-SC(5) 3,180.55 31.64 181.16 2,897.96 2,738.86 -1,127.91 19.96 5,928,607.82 1,621,124.61 1.32 -1,084.31 MWD+IFR-AK-CAZ-SC(5) 3,216.83 30.85 181.67 2,928.98 2,769.88 -1,146.72 19.50 5,928,589.01 1,621,124.10 2.30 -1,102.60 MWD+IFR-AK-CAZ-SC(5) 3,275.15 29.15 183.54 2,979.48 2,820.38 -1,175.85 18.18 5,928,559.89 1,621,122.72 3.33 -1,131.07 MWD+IFR-AK-CAZ-SC(5) 3,369.71 29.22 183.38 3,062.04 2,902.94 -1,221.87 15.40 5,928,513.88 1,621,119.81 0.11 -1,176.25 MWD+IFR-AK-CAZ-SC(5) 3,465.06 29.12 181.76 3,145.30 2,986.20 -1,268.30 13.32 5,928,467.47 1,621,117.61 0.83 -1,221.63 MWD+IFR-AK-CAZ-SC(5) 3,559.35 29.12 179.80 3,227.67 3,068.57 -1,314.17 12.69 5,928,421.60 1,621,116.87 1.01 -1,266.11 MWD+IFR-AK-CAZ-SC(5) 3,654.21 29.11 175.20 3,310.56 3,151.46 -1,360.25 14.70 5,928,375.52 1,621,118.76 2.36 -1,310.10 MWD+IFR-AK-CAZ-SC(5) 3,748.38 29.08 171.75 3,392.85 3,233.75 -1,405.73 19.90 5,928,330.03 1,621,123.85 1.78 -1,352.68 MWD+IFR-AK-CAZ-SC(5) 3,843.39 29.20 172.07 3,475.83 3,316.73 -1,451.53 26.41 5,928,284.22 1,621,130.24 0.21 -1,395.24 MWD+IFR-AK-CAZ-SC(5) 3,937.70 29.29 173.30 3,558.12 3,399.02 -1,497.23 32.28 5,928,238.51 1,621,135.99 0.64 -1,437.86 MWD+IFR-AK-CAZ-SC(5) 4,032.85 26.26 176.57 3,642.31 3,483.21 -1,541.37 36.26 5,928,194.36 1,621,139.85 3.56 -1,479.47 MWD+IFR-AK-CAZ-SC(5) 4,127.92 23.76 177.68 3,728.45 3,569.35 -1,581.51 38.29 5,928,154.22 1,621,141.78 2.68 -1,517.71 MWD+IFR-AK-CAZ-SC(5) 10/25/2016 2:23:50PM Page 3 COMPASS 5000.1 Build 74 • . Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl2 Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100) (ft) Survey Tool Name 4,222.30 20.68 176.28 3,815.82 3,656.72 -1,617.14 40.14 5,928,118.59 1,621,143.54 3.31 -1,551.65 MWD+IFR-AK-CAZ-SC(5) 4,316.01 18.07 174.18 3,904.21 3,745.11 -1,648.12 42.69 5,928,087.61 1,621,146.01 2.88 -1,580.91 MWD+IFR-AK-CAZ-SC(5) 4,410.48 15.20 169.34 3,994.72 3,835.62 -1,674.87 46.47 5,928,060.85 1,621,149.72 3.37 -1,605.78 MWD+IFR-AK-CAZ-SC(5) 4,505.57 12.37 159.36 4,087.08 3,927.98 -1,696.66 52.37 5,928,039.04 1,621,155.56 3.88 -1,625.30 MWD+IFR-AK-CAZ-SC(5) 4,599.59 10.73 147.53 4,179.20 4,020.10 -1,713.48 60.62 5,928,022.21 1,621,163.77 3.06 -1,639.40 MWD+IFR-AK-CAZ-SC(5) 4,694.91 9.31 142.66 4,273.07 4,113.97 -1,727.09 70.06 5,928,008.57 1,621,173.17 1.73 -1,650.11 MWD+IFR-AK-CAZ-SC(5) 4,789.62 7.30 136.03 4,366.78 4,207.68 -1,737.52 78.88 5,927,998.13 1,621,181.97 2.35 -1,657.90 MWD+IFR-AK-CAZ-SC(5) 4,884.31 6.12 113.23 4,460.84 4,301.74 -1,743.84 87.70 5,927,991.78 1,621,190.77 3.05 -1,661.72 MWD+IFR-AK-CAZ-SC(5) 4,978.95 6.70 95.74 4,554.90 4,395.80 -1,746.38 97.83 5,927,989.22 1,621,200.89 2.14 -1,661.55 MWD+IFR-AK-CAZ-SC(5) 5,073.65 6.98 77.43 4,648.93 4,489.83 -1,745.68 108.94 5,927,989.89 1,621,212.01 2.31 -1,658.00 MWD+IFR-AK-CAZ-SC(5) 5,168.64 9.01 58.29 4,743.01 4,583.91 -1,740.51 120.91 5,927,995.02 1,621,223.98 3.50 -1,649.91 MWD+IFR-AK-CAZ-SC(5) 5,263.08 11.10 44.26 4,836.01 4,676.91 -1,730.11 133.55 5,928,005.39 1,621,236.65 3.39 -1,636.60 MWD+IFR-AK-CAZ-SC(5) 5,358.88 13.64 35.49 4,929.59 4,770.49 -1,714.31 146.54 5,928,021.16 1,621,249.68 3.29 -1,617.97 MWD+IFR-AK-CAZ-SC(5) 5,453.39 17.92 31.63 5,020.52 4,861.42 -1,692.84 160.65 5,928,042.59 1,621,263.84 4.66 -1,593.58 MWD+IFR-AK-CAZ-SC(5) 5,548.40 22.50 27.39 5,109.66 4,950.56 -1,664.24 176.68 5,928,071.15 1,621,279.95 5.06 -1,561.80 MWD+IFR-AK-CAZ-SC(5) 5,642.58 25.70 25.16 5,195.62 5,036.52 -1,629.75 193.66 5,928,105.59 1,621,297.01 3.53 -1,524.09 MWD+IFR-AK-CAZ-SC(5) 5,737.30 28.18 24.81 5,280.05 5,120.95 -1,590.85 211.78 5,928,144.44 1,621,315.23 2.62 -1,481.83 MWD+IFR-AK-CAZ-SC(5) 5,831.73 29.17 24.25 5,362.90 5,203.80 -1,549.63 230.59 5,928,185.61 1,621,334.14 1.09 -1,437.14 MWD+IFR-AK-CAZ-SC(5) 5,926.48 31.60 22.24 5,444.63 5,285.53 -1,505.59 249.47 5,928,229.60 1,621,353.13 2.78 -1,389.72 MWD+IFR-AK-CAZ-SC(5) 6,021.10 34.05 21.06 5,524.14 5,365.04 -1,457.92 268.38 5,928,277.22 1,621,372.16 2.68 -1,338.78 MWD+IFR-AK-CAZ-SC(5) 6,115.13 37.00 19.68 5,600.66 5,441.56 -1,406.70 287.37 5,928,328.38 1,621,391.28 3.25 -1,284.39 MWD+IFR-AK-CAZ-SC(5) 6,210.39 40.51 18.57 5,674.94 5,515.84 -1,350.36 306.88 5,928,384.66 1,621,410.94 3.76 -1,224.92 MWD+IFR-AK-CAZ-SC(5) 6,304.61 43.13 17.21 5,745.15 5,586.05 -1,290.57 326.16 5,928,444.39 1,621,430.37 2.94 -1,162.18 MWD+IFR-AK-CAZ-SC(5) 6,400.38 44.08 16.74 5,814.50 5,655.40 -1,227.40 345.44 5,928,507.51 1,621,449.81 1.05 -1,096.17 MWD+IFR-AK-CAZ-SC(5) 6,495.76 47.15 16.08 5,881.21 5,722.11 -1,162.02 364.69 5,928,572.84 1,621,469.22 3.26 -1,028.04 MWD+IFR-AK-CAZ-SC(5) 6,589.32 50.55 14.26 5,942.76 5,783.66 -1,094.03 383.09 5,928,640.77 1,621,487.79 3.92 -957.60 MWD+IFR-AK-CAZ-SC(5) 6,684.48 53.35 13.04 6,001.41 5,842.31 -1,021.22 400.76 5,928,713.53 1,621,505.64 3.11 -882.70 MWD+IFR-AK-CAZ-SC(5) 6,779.49 56.41 12.29 6,056.06 5,896.96 -945.40 417.78 5,928,789.29 1,621,522.86 3.28 -805.06 MWD+IFR-AK-CAZ-SC(5) 6,874.22 58.57 11.54 6,106.97 5,947.87 -867.24 434.27 5,928,867.40 1,621,539.55 2.38 -725.30 MWD+IFR-AK-CAZ-SC(5) 6,969.60 61.93 11.09 6,154.30 5,995.20 -786.05 450.51 5,928,948.54 1,621,555.99 3.55 -642.67 MWD+IFR-AK-CAZ-SC(5) 7,064.03 65.49 9.64 6,196.12 6,037.02 -702.79 465.72 5,929,031.76 1,621,571.42 4.01 -558.30 MWD+IFR-AK-CAZ-SC(5) 7,159.23 68.52 9.24 6,233.30 6,074.20 -616.35 480.09 5,929,118.15 1,621,586.00 3.21 -471.09 MWD+IFR-AK-CAZ-SC(5) 7,191.58 69.53 9.91 6,244.88 6,085.78 -586.56 485.11 5,929,147.92 1,621,591.11 3.67 -441.02 MWD+IFR-AK-CAZ-SC(5) 7,247.00 70.27 9.51 6,263.93 6,104.83 -535.27 493.89 5,929,199.19 1,621,600.01 1.49 -389.20 NOT an Actual Survey (6) 75/8"x 9-7/8"by 11" 7,274.27 70.63 9.31 6,273.05 6,113.95 -509.91 498.09 5,929,224.53 1,621,604.28 1.49 -363.62 MWD+IFR-AK-CAZ-SC(6) 7,369.08 74.93 10.12 6,301.12 6,142.02 -420.68 513.38 5,929,313.72 1,621,619.79 4.61 -273.47 MWD+IFR-AK-CAZ-SC(6) 7,464.12 78.11 12.48 6,323.27 6,164.17 -330.07 531.50 5,929,404.28 1,621,638.14 4.13 -181.26 MWD+IFR-AK-CAZ-SC(6) 7,559.11 81.49 14.52 6,340.09 6,180.99 -239.18 553.32 5,929,495.10 1,621,660.20 4.14 -87.82 MWD+IFR-AK-CAZ-SC(6) 7,652.43 85.49 14.46 6,350.67 6,191.57 -149.43 576.52 5,929,584.78 1,621,683.62 4.29 4.88 MWD+IFR-AK-CAZ-SC(6) 10/25/2016 2:23:50PM Page 4 COMPASS 5000.1 Build 74 III 111 Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonll • Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl4 Well: 2S-09 North Reference: True • • • Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical 1 MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,747.44 89.17 12.66 6,355.10 6,196.00 -57.19 59876 5,929,676.95 1,621,706.10 4.31 9973 MWD+IFR-AK-CAZ-SC(6) 7,841.94 92.04 13.70 6,354.10 6,195.00 34.81 620.31 5,929,768.88 1,621,727.87 3.23 194.17 MWD+IFR-AK-CAZ-SC(6) 7,935.82 91.64 15.01 6,351.08 6,191.98 125.71 643.57 5,929,859.71 1,621,751.37 1.46 287.99 MWD+IFR-AK-CAZ-SC(6) 8,029.46 91.30 12.66 6,348.68 6,189.58 216.59 665.95 5,929,950.53 1,621,773.98 2.53 381.57 MWD+IFR-AK-CAZ-SC(6) • 8,124.26 91.90 10.58 6,346.03 6,186.93 309.41 685.04 5,930,043.29 1,621,793.30 2.28 476.17 MWD+IFR-AK-CAZ-SC(6) • 8,221.24 93.86 7.18 6,341.16 6,182.06 405.09 699.99 5,930,138.92 1,621,808.49 4.04 572.45 MWD+IFR-AK-CAZ-SC(6) 8,315.09 93.22 7.30 6,335.36 6,176.26 498.01 711.79 5,930,231.80 1,621,820.54 0.69 665.27 MWD+IFR-AK-CAZ-SC(6) • 8,409.99 92.33 10.07 6,330.77 6,171.67 591.70 726.11 5,930,325.45 1,621,835.09 3.06 759.47 MWD+IFR-AK-CAZ-SC(6) 8,504.52 90.77 12.09 6,328.21 6,169.11 684.43 744.27 5,930,418.12 1,621,853.48 2.70 853.74 MWD+IFR-AK-CAZ-SC(6) 8,598.11 90.61 10.71 6,327.08 6,167.98 776.16 762.76 5,930,509.80 1,621,872.21 1.48 947.13 MWD+IFR-AK-CAZ-SC(6) • • 8,692.69 90.54 10.39 6,326.14 6,167.04 869.14 780.08 5,930,602.72 1,621,889.76 0.35 1,041.42 MWD+IFR-AK-CAZ-SC(6) 8,787.42 89.19 13.76 6,326.36 6,167.26 961.76 799.89 5,930,695.28 1,621,909.81 3.83 1,136.01 MWD+IFR-AK-CAZ-SC(6) • 8,882.76 89.68 15.15 6,327.30 6,168.20 1,054.07 823.69 5,930,787.52 1,621,933.84 1.55 1,231.34 MWD+IFR-AK-CAZ-SC(6) 8,977.23 89.19 14.43 6,328.23 6,169.13 1,145.41 847.80 5,930,878.79 1,621,958.19 0.92 1,325.81 MWD+IFR-AK-CAZ-SC(6) 9,072.52 89.76 13.50 6,329.10 6,170.00 1,237.87 870.80 5,930,971.19 1,621,981.42 1.14 1,421.07 MWD+IFR-AK-CAZ-SC(6) 9,167.49 88.62 15.48 6,330.45 6,171.35 1,329.81 894.56 5,931,063.05 1,622,005.41 2.41 1,516.03 MWD+IFR-AK-CAZ-SC(6) 9,261.50 88.28 20.17 6,332.99 6,173.89 1,419.25 923.32 5,931,152.41 1,622,034.39 5.00 1,609.86 MWD+IFR-AK-CAZ-SC(6) 9,357.09 92.42 21.48 6,332.41 6,173.31 1,508.57 957.29 5,931,241.63 1,622,068.59 4.54 1,704.93 MWD+IFR-AK-CAZ-SC(6) 9,451.70 91.02 20.56 6,329.57 6,170.47 1,596.84 991.21 5,931,329.81 1,622,102.73 1.77 1,798.97 MWD+IFR-AK-CAZ-SC(6) 9,546.44 90.30 18.14 6,328.48 6,169.38 1,686.22 1,022.60 5,931,419.09 1,622,134.35 2.66 1,893.43 MWD+IFR-AK-CAZ-SC(6) 9,640.95 90.06 14.74 6,328.18 6,169.08 1,776.85 1,049.34 5,931,509.65 1,622,161.32 3.61 1,987.89 MWD+IFR-AK-CAZ-SC(6) 9,736.74 88.64 11.94 6,329.27 6,170.17 1,870.04 1,071.44 5,931,602.77 1,622,183.65 3.28 2,083.63 MWD+IFR-AK-CAZ-SC(6) 9,830.99 88.52 11.92 6,331.60 6,172.50 1,962.22 1,090.91 5,931,694.90 1,622,203.36 0.13 2,177.71 MWD+IFR-AK-CAZ-SC(6) 9,925.49 88.72 12.63 6,333.88 6,174.78 2,054.54 1,111.00 5,931,787.15 1,622,223.68 0.78 2,272.08 MWD+IFR-AK-CAZ-SC(6) 10,020.41 89.31 14.37 6,335.51 6,176.41 2,146.81 1,133.15 5,931,879.36 1,622,246.07 1.94 2,366.95 MWD+IFR-AK-CAZ-SC(6) 10,114.99 90.03 14.18 6,336.05 6,176.95 2,238.47 1,156.47 5,931,970.95 1,622,269.62 0.79 2,461.52 MWD+IFR-AK-CAZ-SC(6) 10,209.83 90.78 14.31 6,335.38 6,176.28 2,330.39 1,179.81 5,932,062.80 1,622,293.19 0.80 2,556.34 MWD+IFR-AK-CAZ-SC(6) 10,304.67 90.92 16.10 6,333.98 6,174.88 2,421.90 1,204.68 5,932,154.24 1,622,318.29 1.89 2,651.17 MWD+IFR-AK-CAZ-SC(6) 10,399.73 90.99 18.38 6,332.39 6,173.29 2,512.67 1,232.85 5,932,244.92 1,622,346.69 2.40 2,746.14 MWD+IFR-AK-CAZ-SC(6) 10,494.18 91.09 19.00 6,330.68 6,171.58 2,602.12 1,263.11 5,932,334.29 1,622,377.18 0.66 2,840.38 MWD+IFR-AK-CAZ-SC(6) 10,588.79 90.92 18.57 6,329.02 6,169.92 2,691.68 1,293.57 5,932,423.76 1,622,407.87 0.49 2,934.76 MWD+IFR-AK-CAZ-SC(6) 10,684.13 90.92 16.93 6,327.49 6,168.39 2,782.47 1,322.63 5,932,514.46 1,622,437.16 1.72 3,029.98 MWD+IFR-AK-CAZ-SC(6) 10,778.37 91.52 15.55 6,325.48 6,166.38 2,872.92 1,348.98 5,932,604.84 1,622,463.73 1.60 3,124.17 MWD+IFR-AK-CAZ-SC(6) 10,873.71 94.51 14.84 6,320.47 6,161.37 2,964.79 1,373.93 5,932,696.64 1,622,488.92 3.22 3,219.37 MWD+IFR-AK-CAZ-SC(6) 10,968.90 95.16 14.78 6,312.44 6,153.34 3,056.49 1,398.18 5,932,788.27 1,622,513.39 0.69 3,314.22 MWD+IFR-AK-CAZ-SC(6) 11,063.26 93.53 14.56 6,305.29 6,146.19 3,147.51 1,422.01 5,932,879.22 1,622,537.45 1.74 3,408.30 MWD+IFR-AK-CAZ-SC(6) 11,154.89 90.38 13.31 6,302.17 6,143.07 3,236.38 1,444.05 5,932,968.02 1,622,559.73 3.70 3,499.85 MWD+IFR-AK-CAZ-SC(6) 11,247.12 89.57 14.02 6,302.21 6,143.11 3,326.00 1,465.84 5,933,057.57 1,622,581.74 1.17 3,592.05 MWD+IFR-AK-CAZ-SC(6) • 11,338.65 89.86 14.42 6,302.66 6,143.56 3,414.72 1,488.33 5,933,146.23 1,622,604.45 0.54 3,683.57 MWD+IFR-AK-CAZ-SC(6) 11,431.20 89.89 13.76 6,302.87 6,143.77 3,504.49 1,510.86 5,933,235.93 1,622,627.21 0.71 3,776.11 MWD+IFR-AK-CAZ-SC(6) 10/25/2016 2:23:50PM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2S-09 Project: Kuparuk River Unit TVD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(DoyonVV Site: Kuparuk 2S Pad MD Reference: 2S-09 Actual 2S-09:39.10+120 @ 159.10usft(Doyonl Well: 2S-09 North Reference: True Wellbore: 2S-09 Survey Calculation Method: Minimum Curvature Design: Rig:2S-09 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 11,523.93 90.03 14.29 6,302.93 6,143.83 3,594.45 1,533.33 5,933,325.83 1,622.649.91 0.59 3,868.83 MWD+IFR-AK-CAZ-SC(6) 11,584.00 90.03 14.29 6,302.90 6,143.80 3,652.66 1,548.16 5,933,383.99 1,622,664.88 0.00 3,928.89 PROJECTED to TD NOT an Actual Survey 6-3/4"open hole Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. ID Yes (] No I have checked to the best of my ability that the following data is correct (] Surface Coordinates Li Declination & Convergence D GRS Survey Corrections Cig.taly seoed by Yircen Coara El Survey Tool Codes Vincent DN.cn=Y'ncerrMara. ocSclurrberger, ou=Schhrmeerger. O s a ra emai6vosaralysib.mm,c 115 SLB DE: Date:2016,02014:32115 oeroo Client Representative: = 7— ( or Date: 26-Oct-2016 10/25/2016 2:23:50PM Page 6 COMPASS 5000.1 Build 74 21 6098 RECEIVED . . 2 7 6 4 6 DATA LOGGED AOGCC TRANSMITTAL .KBE201G M.K.BENDER FROM: Sandra D. Lemke, ATO3-0346 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99510 RE: 2S-09 DATE: 10/17/2016 Transmitted: Kuparuk River Unit, Alaska 2S-09 1 CD & 1 color print each Surface data logging- Final log file color images and log viewers 2" MD Formation Evaluation log 2" MD Drilling Engineering log 2" MD Gas ration log Please promptly sign, scan and return electronically to Sandra.D.LemkeCa�Conocophi//ips.com CC: 2S-09 transmittal folder, production well files, eSearch Receipt: MA12.0.42cLieittett: 1:14 .. - GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907,265,6947 yorTkt \ //7;4. THE STATE Alaska Oil and Gas ti -s1o Conservation Commission :_ fALAsKA. 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Y' Fax: 907.276.7542 www.aogcc.alaska.gov Haibin Guo Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-09 Permit to Drill Number: 216-098 Sundry Number: 316-517 Dear Mr. Guo: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this //day of October, 2016. RBDMS E U. i 1 l 2016 • • RECEIVED STATE OF ALASKA O C T 0 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0' Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development 0 • 216-098 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 50-103-20749-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A " Will planned perforations require a spacing exception? Yes ❑ No 0 / KRU 2S-09 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL25603, 25589, 25590 • Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11584 6302 11584 6302 3292psi Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16" 120 120 Surface 2882 10-3/4" 2596 2882 5210 2470 Intermediate 7247 7-5/8" 7247 6264 6890 4790 Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development 0 Service ❑ 14.Estimated Date for 10/6/2016 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended 0 ' 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Haibin Guo Email Haibin.Guo a(�conocophillips.com Printed Name Haibin Guo 265-1487 Title Drilling Engineer ( 'h C,3 ,,a ikr-acs ? /01a/z', 6 Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3ICQ -6 (7 Plug Integrity V BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: zc,p ffs to 35--7D � �v-Lvla� pr-fV?v7 r,-- trs ZSa PS S io��t 110 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: `C —4c7 , RBDMS ( - OCT 1 2 2016 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:,/Q—(�// �d ta/ 5•- H° i"t ' /P/ Subs in Form ane Form 10-403 Revised 11/2015 d for 12 months from the date of approval. Attachments in Duplicate • • Application for Permit to Drill,Well 2S-09 Saved:6-Oct-16 Post Office Box 100360 Anchorage,Alaska 99510-0360 Phone(907)263-4180 October 26,2016 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 OCT 0 6 2016 Re: Application for Permit to plug and suspend Well 2S-09 PTD#216-098 AOGCC Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a permit to plug and suspend Well 2S-09 PTD#216-098. Rig Doyon 142 started to drill well 2S-09 production lateral on 9/28/2016.On 9/30/2016, after 4337' new hole was drilled,the PeriScope Geo-Steering tool failed.Decision was made to trip out of hole for new BHA.On 10/2/2016,the drill string with new BHA lost S/O weight at 7243' (-96' outside casing shoe)due to the collapsed unstable Kalubik shale.Attempted to ream through the shale,experienced multiple hole packoffs.Full circulation couldn't be established after that.After 2 days fighting with packoffs,the BHA was slowly reamed to bottom—11530' with 2bpm/20rpm. Attempted to establish full circulation since yesterday,no success.Hole packed off very often,even at very low flow rate 2-3bpm. It is unlikely we are able to establish full circulation and continue drill the lateral because the unstable shale keeping falling on us. We added high concentration and different type shale stable additives into the mud system to attempt to stabilize the shale,unsuccessful. The decision was made to plug and abandon the current production lateral. Cut and pull 7-5/8"intermediate casing. Sidetrack below the surface casing shoe to re-drill the intermediate hole and production hole. Since we knew the pore pressure in Kuparuk sand is less than 10.0ppg now,we can land the intermediate casing in Kuparuk sand and put the unstable Kalubik shale behind the intermediate casing. Please find attached the information required by 20 ACC 25.112 (a) and (g) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 Application for Permit to plug and abandon per 20 ACC 25.112 (a). 2. Casing program. 3. A proposed plug and suspension program. 4. A proposed plug and suspension diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment,diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). If you have any questions or require further information, please contact Haibin Guo at 265-1487 (Haibin.Guo@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Haibin Guo Drilling Engineer • • Proposed Suspend Program The proposed program is listed below. Please refer to attachment for proposed well schematic Trip out of hole and abandon current production lateral 1. Strip BHA into 7-5/8" casing shoe with MPD keeping 11.0ppg at open shale. 2. Circulate and clean the 7-5/8" casing with maximum pump rate and rotation (minimum 260gpm, 120rpm). 3. Perform 30min no flow test. 4. Strip OOH and L/D BHA. 5. Run and set 7-5/8" cement retainer at 7097' MD, 150' above intermediate casing shoe (@7247'), pressure test to 3,9DOpsi/10min. _ _ At least 24 hours notice of the plugging operations must be given to AOGCC so that a representative can (witness the o.erations. -- — -- 6. Sting in and perform inj ctivity test to ensure ability to pump into formation. 7. Squeeze 50bbl of 15.8# lass G cement to abandonment the production hole below cement retainer. 8. Un-sting, lay 5bbl (100' of cement on top of the retainer. 9. P/U and circulate w. string and casing clean. Drop 2-3 wipe balls to avoid cement ring on connections. 10. WOC.Tag the top o cement and record in well report. Consider SIMOPS to P/U 5" DP while WOC if possible. Shallow Abandonment/Kickoff Plug 1. Run and set CIBP at 2997'MD (175' MD below surface shoe), pressure test to 3000psi/10min. 2. PU and run Baker MSC cutter and perform casing cut at 2972'MD(150' MD below surface shoe). 3. POOH and L/D MSC cutter. 4. Pull wear bushing. M/U and install 7-5/8" landing joint. 5. Circulate out the freeze protect Isothermal diesel. 6. Pull and L/D 7-5/8" casing. 7. PU 30 joints of 3-1/2" cement stinger and circulate BU. 8. Pump 50bbl 17#KO plug placing from CIBP to 250' inside surface shoe. 9. Drop 2-3 wipe balls and circulate the pipe and casing clean to avoid cement rings on DP connections. 10. P/U and RIH 9-7/8 x 11" BHA. 11. Kick off and re-drill new hole once cement compressive strength >500psi. The re-drill directional plan will be 100-200' east of the current directional plan.We are still working on it.Once it is completed, it will be sent to AOGCC with 10-401 form for new PTD application. Attachments: Attachment 1 Well Suspension Schematic • • 2S-09 ConocoPhillips Proposed P&A Schematic 10/05/2016 CAMERON ;6"Conductor to-120' 4.1 13.5" Surface Hole TOC: 2572'MD West Sak Sand:T 1,960'MD/1,853 TVD B 2,748'MD/2,596'TVD Surface Casing 10-3/4"45.5# L-80 Hydril 563 2,822' MD/2,596'TVD (31° INC) ,e Bridge Plug 2997'MD 9-7/8" x 11" Intermediate Hole Crq TOC: 5723'MD TOC: Growler(Iceberg):5,420'MD/4,986'TVD 6997'MD Cairn:6,057'MD/5,554'TVD Cement retainer: 7097'MD Bermuda:6,183'MD/5,653'TVD \111011r HRZ:6,725'MD/6,6025'TVD Kalubik:6,972'MD/6,159'TVD Kuparuk C:7,443'MD/6,318'TVD Kuparuk A4:7,504'MD/6,331'TVD Intermediate Casing 7-5/8" 29.7#L-80 Hyd563 Casino •_, 7,247' MD/6,264'TVD (71° INC) Current TD:11,584'MD/6,302'TVD Original planned TD:13,757'MD/ 6-3/4" Production Hole 6,349'TVD I Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or / "Suspend" boxes are also checked, cross out that erroneous entry and ✓ initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed G7gist work)the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July,the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. i • • hl ) 2 /6 . o�� Loepp, Victoria T (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Saturday, September 24, 2016 12:41 PM To: Loepp,Victoria T(DOA) Subject: Re: [EXTERNAL]Re: Kuparuk 2S-09 PTD#216-098 Request wavier on topsetting production casing above production interval. Follow Up Flag: Follow up Flag Status: Flagged Victoria,thank you so much for your quick approval!Appreciate. Thanks, Haibin On Sep 24,2016,at 11:49 AM, Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>wrote: Haibin, Approval is granted to topset the intermediate casing above the Kuparuk sands as outlined below. Thanx, Victoria Sent from my iPhone On Sep 24,2016, at 11:24 AM,Guo, Haibin<Haibin.Guo@conocophillips.com>wrote: Hi Victoria, Kuparuk 2S-09 PTD#216-098 was permitted to set the 7-5/8" intermediate casing into Kuparuk sands. However, based on OH FIT while drilling the 9-7/8 x 11"wellbore was broke at 10.8ppg EWM at K-1 Marker.The maximum estimated pore pressure in Kuparuk sands is 11.0ppg.This makes it infeasible to set the intermediate casing into Kuparuk sands. We have to topset the casing, at"35'TVD below K-1 marker. It is very similar to most of the previous 2S pad wells(2S-01, 2S-02,2S-03,25-07,2S-08, 2S-12, 2S-14 etc.). Please refer to the attached schematic for a diagram and a waiver request. Can you please approve this well to topset 7-5/8"casing at"'35'TVD below K-1 marker ("55'TVD above Kuparuk sands)? Thanks, Anything you need let me know. Haibin Guo Sr. Drilling Engineer 1 • • 2S-09 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic(wp8.1) ffil J CAMERON Last Edited: 4-1/2"tree,top joint is 4h"12.6#IBTM Guo 9/24/16 16"Conductor to-120' 0 O of a GL J 13.5" Surface Hole West Sak Sand:T 1,934'MD/1,843'TVD B 2,740'MD/2,531'TVD GL J 41 1 1 3-Y."x 1"KBMG GLM — 16,1 Surface Casing(-50'TVD below W Saki Al 10-3/4"45.5# L-80 Hydril 563 2,822' MD/2,596'TVD (31° INC) 9-7/8" x 11" Intermediate Hole Tubing; 3-1/2" 9.3#L-80 EUE 8RD-MOD GL J GLMw/SOV 9 a. L. A n '4 71 .0__._ 2nd Stage TOC= 500'MD above C-37 Formation at 4,800'MD/4,369'TVD i z n 1 1 1 1 1 1 1 1 o4--- C-37: :99 MD/4,863'TVD Growler(Iceberg):5,440'MD/4,999' 1 Baker 2.812"CMU Sliding Sleeve Calm: P.076'MD/5,567'TVD 110 — 3-'/:"x 7-5/8",Premier Packer Bermuda:6,310'MD 15,749'TVD �,� ®��' 3-'/:"2.75"D Nipple ,4 HRZ:6,819'MD 16,075'TVD 4j, Kalublk:7,022'MD/6,175'TVD \► SLB DHGi 5.75"x 4'/"Swell Packer _ "I� Kuparuk C: 6,351'TVD f 75/8"x 4-% Baker ZXP •/ M '-Kuparuk A4: l/6,381'TVD Packer/Flex Lock Liner / (►r{ (li`4 r 4'6'Silver Bullet Hanger —� .an. I .w. / � ��� snoe�.... Intermediate Casing •i s�°< re d Ate. 7-5/8" 29.7# L-80 Hyd563 Casing•- '' '' 7,257' MD/6,267'TVD (71° INC) TD:13,757'MD/6,349'TVD Production Liner; 6-3/4" Production Hole 4-1/2" 12.6# L-80 TXP 13,757' MD/6,349'TVD (91° INC) • • Loepp, Victoria T (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Wednesday, October 05, 2016 8:59 PM To: Loepp,Victoria T(DOA) Subject: Re: [EXTERNALJRe: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria!! Appreciate your quick approval so much! Thanks, Haibin On Oct 5, 2016, at 8:27 PM, Loepp,Victoria T(DOA)<victoria.loepp a,alaska.gov>wrote: Haibin, Approval is granted to proceed with plugging operations on 2S-09 production lateral. The lower plug must be tagged and the AOGCC inspectors must be given 24 hours notice to witness the tag. Please submit as soon as possible a 10-403 plug for redrill for 2S-09(PTD 216-098)and note that verbal approval has been granted. The PTD for the redrill should follow to allow review and approval by the AOGCC. Thanx, Victoria On Oct 5, 2016, at 7:34 PM, Guo,Haibin<Haibin.Guo@conocophilli_ps.com>wrote: Hi Victoria, This is to seeking your approval to P&A Kuparuk 25-09 PTD#216-098 production lateral and re-drill intermediate and production hole. Background summary Rig Doyon 142 started to drill well 2S-09 production lateral on 9/28/2016. On 9/30/2016,after 4337' new hole was drilled,the PeriScope Geo-Steering tool failed. Decision was made to trip out of hole for new BHA.On 10/2/2016,the drill string with new BHA lost S/O weight at 7243' (^'96'outside casing shoe)due to the collapsed unstable Kalubik shale.Attempted to ream through the shale,experienced multiple hole packoffs. Full circulation couldn't be established after that.After 2 days fighting with packoffs,the BHA was slowly reamed to bottom 11530'with 2bpm/20rpm.Attempted to establish full circulation since yesterday, no success. Hole packed off very often,even at very low flow rate 2-3bpm. It is unlikely we are able to establish full circulation and continue drill the lateral because the unstable shale keeping falling on us.We added i high concentration and different type shale stable additives into the mud system to attempt to stabilize the shale, unsuccessful. So the decision was made to plug and abandon the current production lateral. Cut and pull 7-5/8" intermediate casing.Sidetrack below the surface casing shoe to re-drill the intermediate hole and production hole.Since we knew the pore pressure in Kuparuk sand is less than 10.0ppg now,we can land the intermediate casing in Kuparuk sand and put the unstable Kalubik shale behind the intermediate casing. Currently the rig is tripping out of hole with BHA. Can you please review and approve the proposed P&A and re-drill plan below? A P&A schematic is attached.Thanks. Plan Forward Procedure Trip out of hole and abandon current production lateral 1. Strip BHA into 7-5/8"casing shoe with MPD keeping 11.0ppg at open shale. 2. Circulate and clean the 7-5/8"casing with maximum pump rate and rotation (minimum 260gpm, 120rpm). 3. Perform 30min no flow test. 4. Strip OOH and LID BHA. 5. Run and set 7-5/8" cement retainer at 7097'MD, 150'above intermediate casing shoe(@7247'), pressure test to 3,000psi/10min. At least 24 hours notice of the plugging operations must be given to AOGCC so that a representative can witness the operations. 6. Sting in and perform injectivity test to ensure ability to pump into formation. 7. Squeeze 50bbI of 15.8#Class G cement to abandonment the production hole below cement retainer. 8. Un-sting, lay Sbbl (100')of cement on top of the retainer. 9. P/U and circulate work string and casing clean. Drop 2-3 wipe balls to avoid cement ring on connections. 10. WOC.Tag the top of cement and record in well report. Consider SIMOPS to P/U 5" DP while WOC if possible. Shallow Abandonment/Kickoff Plug 1. Run and set CIBP at 2997'MD(175' MD below surface shoe), pressure test to 3000psi/10min. 2. PU and run Baker MSC cutter and perform casing cut at 2972'MD(150' MD below surface shoe). 3. POOH and L/D MSC cutter. 4. Pull wear bushing. M/U and install 7-5/8" landing joint. 5. Circulate out the freeze protect Isothermal diesel. 6. Pull and L/D 7-5/8"casing. 7. PU 30 joints of 3-1/2"cement stinger and circulate BU. 8. Pump 50bbl 17#KO plug placing from CIBP to 250' inside surface shoe. 9. Drop 2-3 wipe balls and circulate the pipe and casing clean to avoid cement rings on DP connections. 10. P/U and RIH 9-7/8 x 11" BHA. 11. Kick off and re-drill new hole once cement compressive strength>500psi. 2 • • The re-drill directional plan will be 100-200'east of the current directional plan.We are still working on it.Once it is completed I'll send to you with the ST schematic. If you have any question or need anything please let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office:907.265.1487 Cell:907.227.6048 <2S-09 Production Lateral P&A 10-5-2016.pdf> 3 4110 1110 Loepp, Victoria T (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Wednesday, October 12,2016 9:33 AM To: Loepp,Victoria T(DOA) Subject: RE: Log requirement Follow Up Flag: Follow up Flag Status: Flagged Will do.Thank you Victoria! Have a great day! Haibin Original Message From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,October 12, 2016 9:32 AM To:Guo, Haibin<Haibin.Guo@conocophillips.com> Subject: [EXTERNAL]RE: Log requirement Haibin, ConocoPhillips can proceed with logging just the gamma ray. If the RES log in memory is available,operator shall submit that log to AOGCC. Thanx, Victoria Original Message From: Guo, Haibin [mailto:Haibin.Guo@conocophillips.com] Sent:Tuesday,October 11, 2016 9:09 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: Log requirement Hi Victoria, I have a quick question on the log requirements for 2S-09 intermediate redrill.We planned to run GR/RES log. I just heard from the rig the real time RES log is intermittent.Since we have good logs on the original wellbore and the redrill is only^'200'away.We can drill with GR only for formation picking. I checked the regulations it requires either GR or RES. I'd like to double check with you that it's ok to drill ahead with GR only. We may still have RES log in memory,but not sure. If we do,we'll submit it with the complete report. Thanks, Haibin 1 • Loepp, Victoria T (DOA) From: Kanady, Randall B <Randall.B.Kanady@conocophillips.com> Sent: Wednesday,October 12,2016 4:47 PM To: Loepp,Victoria T(DOA) Cc: Quick, Michael J (DOA);Schwartz, Guy L(DOA);Guo, Haibin; Bearden,J Daniel Subject: RE: Kuparuk 2S-09 PTD#216-098 Cement Plug PT and Tag Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the feedback. If the future, If CPA has to conduct a plug back and side track,we will work closely with AOGCC to ensure we meet all of your requirements while trying optimize rig operations. Randy From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,October 11,2016 2:19 PM To: Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Cc:Quick,Michael J (DOA)<michael.quick@alaska.gov>;Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>;Guo, Haibin<Haibin.Guo@conocophillips.com>; Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com> Subject: [EXTERNAL]FW: Kuparuk 2S-09 PTD#216-098 Cement Plug PT and Tag From:Quick, Michael J (DOA) Sent:Tuesday,October 11,2016 1:46 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov Subject: RE: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill The AOGCC has recent records of cement retainers not sealing after squeeze cementing and"un-stinging"from the retainer,and therefore the plug was not able to pass a pressure test, resulting in the need for remedial work. Any mechanical plug with a leak path will need to be pressure tested AFTER cement is placed to ensure the plug and cement are holding pressure to meet the"competent plug"component of the regulation. Any mechanical plug set needs to be weight tested to ensure proper set and to meet the"record the actual location" component of the regulation,additionally the commission may require a tag of the top of cement in certain cases as well. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1231(phone) (907) 276-7542(fax) mike.quickPalaska.gov 1 • CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Mike Quick at 907-793-1231 or mike.auick@alaska.gov. Begin forwarded message: From: "Kanady, Randall B" <Randall.B.Kanady@conocophillips.com> Date: October 11, 2016 at 12:58:59 PM AKDT To: "victoria.loepp@alaska.gov" <victoria.loepp@alaska.gov> Cc: "Guo, Haibin" <Haibin.Guo@conocophillips.com>, "Bearden,J Daniel" <J.Daniel.Bearden(&,,conocophillips.com> Subject: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill Hello Victoria, I wanted to discuss with you your request to tagged the lower plug on the 2S-09 production lateral P&A. When the 7-5/8" cement retainer was set at 7097' MD,sufficient weight was set on the plug to confirm its location and to confirm that the plug had set. The cement retainer was also pressure tested to 3,000psi/10min. This meets the requirement set forth in 20 MC 25.112(g) listed below: 20 AAC 25.112(g) Except for surface plugs,the operator shall record the actual location and integrity of cement plugs,cement retainers,or bridge plugs required by this section, using one of the following methods,which in the case of a cement retainer or bridge plug may be performed before cement is placed on top of the plug: (1) placing sufficient weight on the plug to confirm its location and to confirm that the plug has set and a competent plug is in place; (2)testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe,whichever is greater,and tagging the plug to confirm location; however,surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. When using a cement retainer in the future,CPA would like to request that we only have to comply with 20 MC 25.112(g)(1) not 20 MC 25.112(g)(1)AND 20 MC 25.112(g)(2). I will give you a call this afternoon to review this request. Thanks, Randy Randall Kanady P.E. ConocoPhillips Alaska Drilling and Wells Office:907-263-4126 Cell:907-575-0742 randall.b.kanady@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,October 05,2016 8:24 PM To:Guo, Haibin<Haibin.Guo@conocophillips.com> 2 Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Bearden,J Daniel <1.Daniel.Bearden@conocophillips.com> Subject: [EXTERNAL]Re: Kuparuk 25-09 PTD#216-098 Production lateral P&A and Re-drill Haibin, Approval is granted to proceed with plugging operations on 2S-09 production lateral. The lower plug must be tagged and the AOGCC inspectors must be given 24 hours notice to witness the tag. Please submit as soon as possible a 10-403 plug for redrill for 2S-09(PTD 216-098)and note that verbal approval has been granted. The PTD for the redrill should follow to allow review and approval by the AOGCC. Thanx, Victoria On Oct 5,2016, at 7:34 PM, Guo,Haibin<Haibin.Guoconocophillips.com>wrote: Hi Victoria, This is to seeking your approval to P&A Kuparuk 2S-09 PTD#216-098 production lateral and re-drill intermediate and production hole. Background summary Rig Doyon 142 started to drill well 2S-09 production lateral on 9/28/2016. On 9/30/2016,after 4337' new hole was drilled,the PeriScope Geo-Steering tool failed. Decision was made to trip out of hole for new BHA.On 10/2/2016,the drill string with new BHA lost 5/0 weight at 7243' ("96'outside casing shoe)due to the collapsed unstable Kalubik shale.Attempted to ream through the shale,experienced multiple hole packoffs. Full circulation couldn't be established after that.After 2 days fighting with packoffs,the BHA was slowly reamed to bottom 11530'with 2bpm/20rpm.Attempted to establish full circulation since yesterday, no success. Hole packed off very often,even at very low flow rate 2-3bpm. It is unlikely we are able to establish full circulation and continue drill the lateral because the unstable shale keeping falling on us.We added high concentration and different type shale stable additives into the mud system to attempt to stabilize the shale, unsuccessful. So the decision was made to plug and abandon the current production lateral. Cut and pull 7-5/8" intermediate casing.Sidetrack below the surface casing shoe to re-drill the intermediate hole and production hole.Since we knew the pore pressure in Kuparuk sand is less than 10.0ppg now,we can land the intermediate casing in Kuparuk sand and put the unstable Kalubik shale behind the intermediate casing. Currently the rig is tripping out of hole with BHA. Can you please review and approve the proposed P&A and re-drill plan below? A P&A schematic is attached.Thanks. Plan Forward Procedure 3 • Trip out of hole and abandon current production lateral 1. Strip BHA into 7-5/8"casing shoe with MPD keeping 11.0ppg at open shale. 2. Circulate and clean the 7-5/8"casing with maximum pump rate and rotation (minimum 260gpm, 120rpm). 3. Perform 30min no flow test. 4. Strip OOH and L/D BHA. 5. Run and set 7-5/8" cement retainer at 7097' MD, 150'above intermediate casing shoe(@7247'), pressure test to 3,000psi/10min. At least 24 hours notice of the plugging operations must be given to AOGCC so that a representative can witness the operations. 6. Sting in and perform injectivity test to ensure ability to pump into formation. 7. Squeeze 50bbl of 15.8#Class G cement to abandonment the production hole below cement retainer. 8. Un-sting, lay 5bbl (100')of cement on top of the retainer. 9. P/U and circulate work string and casing clean. Drop 2-3 wipe balls to avoid cement ring on connections. 10. WOC.Tag the top of cement and record in well report.Consider SIMOPS to P/U 5" DP while WOC if possible. Shallow Abandonment/Kickoff Plug 1. Run and set CIBP at 2997'MD(175' MD below surface shoe), pressure test to 3000psi/10min. 2. PU and run Baker MSC cutter and perform casing cut at 2972'MD(150' MD below surface shoe). 3. POOH and L/D MSC cutter. 4. Pull wear bushing. M/U and install 7-5/8" landing joint. 5. Circulate out the freeze protect Isothermal diesel. 6. Pull and L/D 7-5/8"casing. 7. PU 30 joints of 3-1/2"cement stinger and circulate BU. 8. Pump 50bbl 17#KO plug placing from CIBP to 250' inside surface shoe. 9. Drop 2-3 wipe balls and circulate the pipe and casing clean to avoid cement rings on DP connections. 10. P/U and RIH 9-7/8 x 11" BHA. 11. Kick off and re-drill new hole once cement compressive strength>500psi. The re-drill directional plan will be 100-200'east of the current directional plan.We are still working on it. Once it is completed I'll send to you with the ST schematic. If you have any question or need anything please let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office:907.265.1487 Cell:907.227.6048 <2S-09 Production Lateral P&A 10-5-2016.pdf> 4 • Loepp, Victoria T (DOA) From: Kanady, Randall B <Randall.B.Kanady@conocophillips.com> Sent: Wednesday, October 12, 2016 4:47 PM To: Loepp,Victoria T(DOA) Cc: Quick, Michael J (DOA);Schwartz, Guy L(DOA);Guo, Haibin; Bearden,J Daniel Subject: RE: Kuparuk 2S-09 PTD#216-098 Cement Plug PT and Tag Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the feedback. If the future, If CPA has to conduct a plug back and side track,we will work closely with AOGCC to ensure we meet all of your requirements while trying optimize rig operations. Randy From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,October 11,2016 2:19 PM To: Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Cc:Quick, Michael J (DOA)<michael.quick@alaska.gov>;Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>;Guo, Haibin<Haibin.Guo@conocophillips.com>; Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com> Subject: [EXTERNAL]FW: Kuparuk 2S-09 PTD#216-098 Cement Plug PT and Tag From:Quick, Michael J (DOA) Sent:Tuesday, October 11,2016 1:46 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill The AOGCC has recent records of cement retainers not sealing after squeeze cementing and"un-stinging"from the retainer,and therefore the plug was not able to pass a pressure test, resulting in the need for remedial work. Any mechanical plug with a leak path will need to be pressure tested AFTER cement is placed to ensure the plug and cement are holding pressure to meet the"competent plug"component of the regulation. Any mechanical plug set needs to be weight tested to ensure proper set and to meet the"record the actual location" component of the regulation,additionally the commission may require a tag of the top of cement in certain cases as well. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1231(phone) (907)276-7542 (fax) mike.quick@alaska.gov 1 • CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Mike Quick at 907-793-1231 or mike.guick@alaska.gov. Begin forwarded message: From: "Kanady, Randall B" <Randall.B.Kanady@conocophillips.com> Date: October 11, 2016 at 12:58:59 PM AKDT To: "victoria.loepp@alaska.gov" <victoria.loepp@alaska.gov> Cc: "Guo, Haibin" <Haibin.GuoAconocophillips.com>, "Bearden,J Daniel" <J.Daniel.Bearden(Zi conocophillips.com> Subject: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill Hello Victoria, I wanted to discuss with you your request to tagged the lower plug on the 2S-09 production lateral P&A. When the 7-5/8" cement retainer was set at 7097' MD,sufficient weight was set on the plug to confirm its location and to confirm that the plug had set. The cement retainer was also pressure tested to 3,000psi/10min. This meets the requirement set forth in 20 AAC 25.112(g) listed below: 20 AAC 25.112 (g) Except for surface plugs,the operator shall record the actual location and integrity of cement plugs,cement retainers,or bridge plugs required by this section, using one of the following methods,which in the case of a cement retainer or bridge plug may be performed before cement is placed on top of the plug: (1) placing sufficient weight on the plug to confirm its location and to confirm that the plug has set and a competent plug is in place; (2)testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe,whichever is greater,and tagging the plug to confirm location; however,surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. When using a cement retainer in the future,CPA would like to request that we only have to comply with 20 AAC 25.112(g)(1) not 20 AAC 25.112 (g)(1)AND 20 MC 25.112(g)(2). I will give you a call this afternoon to review this request. Thanks, Randy Randall Kanady P.E. ConocoPhillips Alaska Drilling and Wells Office:907-263-4126 Cell:907-575-0742 randall.b.kanady@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,October 05,2016 8:24 PM To:Guo, Haibin<Haibin.Guo@conocophillips.com> 2 • • Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Subject: [EXTERNAL]Re: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill Haibin, Approval is granted to proceed with plugging operations on 2S-09 production lateral. The lower plug must be tagged and the AOGCC inspectors must be given 24 hours notice to witness the tag. Please submit as soon as possible a 10-403 plug for redrill for 2S-09(PTD 216-098)and note that verbal approval has been granted. The PTD for the redrill should follow to allow review and approval by the AOGCC. Thanx, Victoria On Oct 5, 2016, at 7:34 PM, Guo, Haibin<Haibin.Guo@conocophillips.com>wrote: Hi Victoria, This is to seeking your approval to P&A Kuparuk 2S-09 PTD#216-098 production lateral and re-drill intermediate and production hole. Background summary Rig Doyon 142 started to drill well 2S-09 production lateral on 9/28/2016.On 9/30/2016,after 4337' new hole was drilled,the PeriScope Geo-Steering tool failed. Decision was made to trip out of hole for new BHA.On 10/2/2016,the drill string with new BHA lost 5/0 weight at 7243' (-96'outside casing shoe)due to the collapsed unstable Kalubik shale.Attempted to ream through the shale,experienced multiple hole packoffs. Full circulation couldn't be established after that.After 2 days fighting with packoffs,the BHA was slowly reamed to bottom 11530'with 2bpm/20rpm.Attempted to establish full circulation since yesterday, no success. Hole packed off very often,even at very low flow rate 2-3bpm. It is unlikely we are able to establish full circulation and continue drill the lateral because the unstable shale keeping falling on us.We added high concentration and different type shale stable additives into the mud system to attempt to stabilize the shale, unsuccessful. So the decision was made to plug and abandon the current production lateral. Cut and pull 7-5/8" intermediate casing.Sidetrack below the surface casing shoe to re-drill the intermediate hole and production hole.Since we knew the pore pressure in Kuparuk sand is less than 10.0ppg now,we can land the intermediate casing in Kuparuk sand and put the unstable Kalubik shale behind the intermediate casing. Currently the rig is tripping out of hole with BHA. Can you please review and approve the proposed P&A and re-drill plan below? A P&A schematic is attached.Thanks. Plan Forward Procedure 3 • Trip out of hole and abandon current production lateral 1. Strip BHA into 7-5/8"casing shoe with MPD keeping 11.Oppg at open shale. 2. Circulate and clean the 7-5/8"casing with maximum pump rate and rotation (minimum 260gpm, 120rpm). 3. Perform 30min no flow test. 4. Strip OOH and L/D BHA. 5. Run and set 7-5/8"cement retainer at 7097' MD, 150'above intermediate casing shoe(@7247'), pressure test to 3,000psi/10min. At least 24 hours notice of the plugging operations must be given to AOGCC so that a representative can witness the operations. 6. Sting in and perform injectivity test to ensure ability to pump into formation. 7. Squeeze 50bbI of 15.8#Class G cement to abandonment the production hole below cement retainer. 8. Un-sting, lay Sbbl (100')of cement on top of the retainer. 9. P/U and circulate work string and casing clean. Drop 2-3 wipe balls to avoid cement ring on connections. 10. WOC.Tag the top of cement and record in well report.Consider SIMOPS to P/U 5" DP while WOC if possible. Shallow Abandonment/Kickoff Plug 1. Run and set CIBP at 2997'MD(175' MD below surface shoe),pressure test to 3000psi/10min. 2. PU and run Baker MSC cutter and perform casing cut at 2972'MD(150' MD below surface shoe). 3. POOH and L/D MSC cutter. 4. Pull wear bushing. M/U and install 7-5/8" landing joint. 5. Circulate out the freeze protect Isothermal diesel. 6. Pull and L/D 7-5/8"casing. 7. PU 30 joints of 3-1/2"cement stinger and circulate BU. 8. Pump 50bbl 17#KO plug placing from CIBP to 250' inside surface shoe. 9. Drop 2-3 wipe balls and circulate the pipe and casing clean to avoid cement rings on DP connections. 10. P/U and RIH 9-7/8 x 11" BHA. 11. Kick off and re-drill new hole once cement compressive strength>500psi. The re-drill directional plan will be 100-200'east of the current directional plan.We are still working on it.Once it is completed I'll send to you with the ST schematic. If you have any question or need anything please let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office:907.265.1487 Cell:907.227.6048 <2S-09 Production Lateral PM 10-5-2016.pdf> 4 • • 2S-09 ConocoPhillips Proposed P&A Schematic 10/05/2016 CAMERON I ;6"Conductor to—120' 13.5" Surface Hole TOC: 2572'MD West Sak Sand:T 1,960'MD/1,853'TVD B 2,748'MD/2,596'TVD Surface Casing A- 10-3/4"45.5# L-80 Hydril 563 : : : : : 2,822' MD/2,596' TVD (31° INC) Bridge Plug 2972' MD 9-7/8" x 11" Intermediate Hole I TOC: 5723'MD TOC: Growler(Iceberg):5,420'MD/4,986'TVD 7007'MD Cairn:6,057'MD/5,554'TVD Cement retainer: 7052'MD Bermuda:6,183'MD/5,653'TVD HRZ:6,725'MD/6,025'TVD Kalubik:6,972'MD/6,159'ND Kunaruk C:7.443'MDI 6.318'TVD Kuparuk A4:7,504'MD/6,331'TVD jntermediate Casingr 7-5/8" 29.7# L-80 Hyd563 7,247' MD/6,264' TVD (71° INC) - - Current TD:11,584'MD/6,302'ND Original planned TD: 13,757'MD/ 6-3/4" Production Hole 6,349'TVD • • Loepp, Victoria T (DOA) From: Guo, Haibin <Haibin.Guo@conocophillips.com> Sent: Monday,October 10, 2016 1:17 PM To: Loepp, Victoria T(DOA) Subject: RE: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill Follow Up Flag: Follow up Flag Status: Flagged Thank you! From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,October 10,2016 12:57 PM To:Guo, Haibin<Haibin.Guo@conocophillips.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE: Kuparuk 25-09 PTD#216-098 Production lateral P&A and Re-drill Haibin, Yes a new PTD is required as the redrill will be have a different name,2S-09A. Thanx, Victoria From:Guo, Haibin [mailto:Haibin.Guo@conocophillips.com] Sent: Monday,October 10,2016 12:19 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill Victoria, o , I have a quick question.Since we only moved the landing point^'200'away from original wellbore. Do we need a new PTD for the sidetrack?If we don't, I can pull the submitted new PTD application back. Thanks, Haibin From:Guo, Haibin Sent: Friday, October 07,2016 6:40 PM To:'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> Subject: RE: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill Hi Victoria, I apologize that I attached the wrong schematic in last email. Please the attached for the corrected schematic. I also attached the 10-401 re-drill PTD for you. It will be submitted to AOGCC on Monday. 1 • • Currently,we are laying down 4" DP.We'll P/U and run the CIBP tonight.And cut the casing tomorrow morning. Thank you very much for your help. Have a great weekend! Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office:907.265.1487 Cell:907.227.6048 From:Guo, Haibin Sent: Friday,October 07,2016 1:47 PM To:'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> Subject: RE: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill Hi Victoria, This is to give you an update on well 25-09 PTD#216-098 production lateral P&A and seeking your approval to move on. A 7-5/8"cementer retainer was run and set 7052'yesterday. Pressure tested to 3000psi/10min. A total of 52bbl 15.8ppg Class G cement,which is "1175'in 6-3/4" hole,was squeezed to below the retainer.And laid 6.8bbl cement, ^'145' in casing,on top of the retainer.WOC until this morning.We just tagged the TOC in casing with 10k1b.TOC is at 7007',which is 45'above the retainer. It is lower than we expected, probably because contamination with mud/water. In my understanding,the regulation wants a 50'cap above the retainer.We have 45',which is 5'short. Can you please waive this and let us move on? A schematic is attached for your reference. The 10-403 sundry has been submitted yesterday.The new 10-401 PTD will be submitted shortly. If you have any question let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office:907.265.1487 Cell:907.227.6048 From: Loepp,Victoria T(DOA) [mai!to:victoria.loepp@alaska.gov] Sent:Wednesday,October 05, 2016 8:24 PM To:Guo, Haibin<Haibin.Guo@conocophillips.com> 2 • • Cc:Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com> Subject: [EXTERNAL]Re: Kuparuk 2S-09 PTD#216-098 Production lateral P&A and Re-drill Haibin, Approval is granted to proceed with plugging operations on 2S-09 production lateral. The lower plug must be tagged and the AOGCC inspectors must be given 24 hours notice to witness the tag. Please submit as soon as possible a 10-403 plug for redrill for 2S-09(PTD 216-098) and note that verbal approval has been granted. The PTD for the redrill should follow to allow review and approval by the AOGCC. Thanx, Victoria On Oct 5, 2016, at 7:34 PM, Guo, Haibin<Haibin.Guo(a,conocophillips.com>wrote: Hi Victoria, This is to seeking your approval to P&A Kuparuk 2S-09 PTD#216-098 production lateral and re-drill intermediate and production hole. Background summary Rig Doyon 142 started to drill well 2S-09 production lateral on 9/28/2016. On 9/30/2016,after 4337' new hole was drilled,the PeriScope Geo-Steering tool failed. Decision was made to trip out of hole for new BHA.On 10/2/2016,the drill string with new BHA lost S/O weight at 7243' (^'96'outside casing shoe)due to the collapsed unstable Kalubik shale.Attempted to ream through the shale,experienced multiple hole packoffs. Full circulation couldn't be established after that.After 2 days fighting with packoffs,the BHA was slowly reamed to bottom 11530'with 2bpm/20rpm.Attempted to establish full circulation since yesterday, no success. Hole packed off very often,even at very low flow rate 2-3bpm. It is unlikely we are able to establish full circulation and continue drill the lateral because the unstable shale keeping falling on us.We added high concentration and different type shale stable additives into the mud system to attempt to stabilize the shale, unsuccessful. So the decision was made to plug and abandon the current production lateral. Cut and pull 7-5/8" intermediate casing.Sidetrack below the surface casing shoe to re-drill the intermediate hole and production hole.Since we knew the pore pressure in Kuparuk sand is less than 10.0ppg now,we can land the intermediate casing in Kuparuk sand and put the unstable Kalubik shale behind the intermediate casing. Currently the rig is tripping out of hole with BHA. Can you please review and approve the proposed P&A and re-drill plan below? A P&A schematic is attached.Thanks. Plan Forward Procedure Trip out of hole and abandon current production lateral 1. Strip BHA into 7-5/8"casing shoe with MPD keeping 11.0ppg at open shale. 3 • • 2. Circulate and clean the 7-5/8"casing with maximum pump rate and rotation (minimum 260gpm, 120rpm). 3. Perform 30min no flow test. 4. Strip OOH and L/D BHA. 5. Run and set 7-5/8"cement retainer at 7097' MD, 150'above intermediate casing shoe (@7247'), pressure test to 3,000psi/10min. At least 24 hours notice of the plugging operations must be given to AOGCC so that a representative can witness the operations. 6. Sting in and perform injectivity test to ensure ability to pump into formation. 7. Squeeze 50bbl of 15.8#Class G cement to abandonment the production hole below cement retainer. 8. Un-sting, lay 5bbl (100')of cement on top of the retainer. 9. P/U and circulate work string and casing clean. Drop 2-3 wipe balls to avoid cement ring on connections. 10. WOC.Tag the top of cement and record in well report.Consider SIMOPS to P/U 5" DP while WOC if possible. Shallow Abandonment/Kickoff Plug 1. Run and set CIBP at 2997'MD(175' MD below surface shoe), pressure test to 3000psi/10min. 2. PU and run Baker MSC cutter and perform casing cut at 2972'MD(150' MD below surface shoe). 3. POOH and L/D MSC cutter. 4. Pull wear bushing. M/U and install 7-5/8" landing joint. 5. Circulate out the freeze protect Isothermal diesel. 6. Pull and L/D 7-5/8"casing. 7. PU 30 joints of 3-1/2"cement stinger and circulate BU. 8. Pump 50bbl 17#KO plug placing from CIBP to 250' inside surface shoe. 9. Drop 2-3 wipe balls and circulate the pipe and casing clean to avoid cement rings on DP connections. 10. P/U and RIH 9-7/8 x 11" BHA. 11. Kick off and re-drill new hole once cement compressive strength>500psi. The re-drill directional plan will be 100-200'east of the current directional plan.We are still working on it. Once it is completed I'll send to you with the ST schematic. If you have any question or need anything please let me know. Thanks, Haibin Guo Sr. Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Cell:907.227.6048 <2S-09 Production Lateral P&A 10-5-2016.pdf> 4 IIIb s KUP PROD 1A-22 ConocoPhillips ; Well Attributes Max Angle&MD TD 11I , I.: Wellbore API/DWI Field Name Wellbore Status ncl(') MO(ftKB) Act Btm(aKB) connc4,...kpn 500292212700 KUPARUK RIVER UNIT PROD 50.35 7,800.00 8,250.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) --Rig Release Date 1A-22,1/6/2015 4,4026 PM SSSV:LOCKED OUT 70 12/16/2013 Last WO: 35.01 2/10/1991 - Verscal sahema50(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;31.0� �� Last Tag: 7,638.0 6/10/2014 Rev Reason:PULL PLUG lehallf 1/6/2015 ,,,,,„,,.,,,.,.,,,„a,,.,,,""'„,� Casing Strings Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set W Depth(TVD)... ULen(I...Grade top Thread CONDUCTOR 16 15.062 360 80.0 80.0 65.00 H-40 WELDED IIEl Lasing Description OD(in) ID(in) Top(OKB) Set Depth(ftKB) Set Depth(TVD)._ WULen(I...Grade Top Thread CONDUCTOR;3s.oa100_11 SURFACE 9 5/8 8.921 35.0 4,281.9 3,863.4 36.00 J-55 BTC Casing Description OD(in) ID(In) Top(117(6) Set Depth(ftKB) Set Depth(TVD)...•WULen(I...Grade Top Thread --'' ^''''\'‘-i''PRODUCTION 7 6.276 35,0 7,983.6 6,578.1 26.00 J-55 BTCABMOD Tubing Strings � -�� Tubing Description String Ma...1D(in) Top(ftKB) SM Depth(ft..Set Depth(TVD)(...Wt(Ib/R) Grade Top Connection SLEEVE-C;1,1101.0 tragi TUBING 4x3.5x2.875 4 3.476 31.0 7,614.4 6,341.8 11.00 J-55 DSS-HTC SAFETY VLV;1,801.4, *eta Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inst(7 Item Des Com (in) GAS LIFT,2,641.6 lit 31.0 31.0 0.03'HANGER MCEVOY GEN IV HANGER 4.000 1,801.4 1,801.0 7.46'SAFETY VLV CAMCO TRDP-4A SAFETY VALVE;Locked out 12/15/99 3.312 - 4,395.8 3,946.1 42.14 XO Reducing CROSSOVER 4 X 3.5 3.500 GAS LIFT:3,6734 II cr£i I 7,216.1 6,083.1 48.91 PER -BAKER PBR w/10'STROKE 3.000 -- I 7,231.1' 6,093.0 48.91 PACKER BAKER HE RETRIEVABLE PACKER 2.870 7,288.4' 6,130.7 48.88 BLAST RING CARBIDE BLAST RING(1) 2.992 7,317.5 6,149.8 48.99 BLAST RINGS CARBIDE BLAST RINGS(2) 2.992 SURFACE;3504,2819-J i 7,382.5 6,192.3 49.37 NIPPLE AVATPL NIPPLE 2.370 7,391.3 6,198.1 49.43 PACKER BAKER HB RETRIEVABLE PACKER 2.870 ` 7,407.7 6,208.7 49.52 BLAST RING CARBIDE BLAST RING(1) 2.992 GAS LIFT;4,489.1 7,437.9 6,228.3 49.68 BLAST RING CARBIDE BLAST RING(1) 2.992 7,551.0 6,301.1 50.03 NIPPLE AVA EPL NIPPLE 2.750 GAS LIFT;5,149.4 II 7,559.9 6,306.8 50.03 XO CROSSOVER 3.5 x 2.875 2.875 REDUCING GAS LIFT;5,649.9 ® 7,560.4 6,307.11 50.03 I SEAL ASSY TIW LOCATOR SEAL ASSEMBLY 2.500' GAS LIFT;6,1490 M 7,562.4 6,308.4 50.03 PACKER TIW SS PERMENANT PACKER 3.250 ill 7,565.5 6,310.4' 50.03 SBE TIW SEAL BORE EXTENSION 2.441 GAS LIFT;8,529.5 II 7,602.0 6,3339 50.04 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,613.6 6,341.3 50.07 SOS BAKER SHEAR OUT SUB 2.441 GAS LIFT;7,164.6 In Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) rI Ges Com Run Date ID(in) 1,801.0 1,800.6 7.44 SLEEVE-C ISO SLEEVE(2.7"10 x 66"long) 1/31/2009 2.700 PBR;7,216.1 7,382.5 6,192.3 49.38 SLEEVE-0 AVA TPC SLEEVE 1/31/2009 2.320 PACKER;7,231.1 7,551.0 6,301.1 50.03 SLEEVE-C AVA BPI SLEEVE 1/31/2009 2.320 -- Perforations&Slots PRODUCTION;7,273.8 Shot • Dens g S Top(TVD) Btm(TVD) (stats _ Top(ftKB) Min(ftKB) (ftK8) (ftKB) Zone Date t) Type Corn (PERF;7,300.0-7,340.0-.-.- 7,300.0 7,340.0 6,138.3 6,164.6 C-4,1A-22 4/29/1991 10.0 IPERF HES 4.5"CG "" - 7,340.0 7,346.0 6,164.6 6,168.5 C-4,C-3,1A- 4/29/1991 5.0 IPERF HLS 4.5"CG !PERF;7,3[0.0.7,348.0 22 - (PERF;7,356.137,362.0-. 7,356.0 7,362.0 6,175.0 6,178.9 C-2,1A-22 4/29/1991 5.0 IPERF HLS 4.5"CG 7,409.0 7,435.0 6,209.5 6,226.4 C-1,UNITE, 4/29/1991 10.0'(PERF HLS 4.5"CG 1A-22 SLEEVE-0;7,382.5 NIPPLE;7,382.51 7,628.0 7,634.0 6,350.5 6,354.4 A-5,1A-22 4/29/1991 4.0 (PERF HLS 4.5"CG 7,650.0 7,696.0 6,364.6 6,394.0 A-4,1A-22 4/29/1991 4.0 (PERF HLS 4.5"CG PACKER;7,311.3 • Mandrel Inserts St (PERF;7,408.0.7,435.0+ Ori o^ Top(TVD) Valve Latch Part Size TRO Run N Tap(ftKB) (ftKB) Make Model OD(in) Sera Type Type (in) (psi) Run Data Com -( 2,641.6 2,600.9 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,240.0 8/23/2005 _ 2 3,678.4 3,413.0 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,270.0 8232005 3 4,489.1 4,017.3 MACCO SPM-1A 1 GAS LIFT OV BK 0.188 12/21/2014 PRODUCTION;7,505.8 4 5,149.4 4,511.6 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 12/15/1999 NIPPLE;7,551.0 • • SLEEVE-C:7.551.0 @ 5 5,649.9 4,901.2 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 6/11/2005 ® 6 6,149.6 5,316.0 MACCO SPM-1A 1 GAS LIFT DMY 'BK 0.000 0.0 8/122005 SEAL ASSY;7,580.4 PACKER;7,582.4 7 6,529.5 5,617.0 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 7/3/2001 SBE;7,565.5 ••: _ . 8 7,164.6 6,049.3 CAMCO MMG-2 1 12 GAS LIFT DMY •RK 0.000 0.0 7/3/2001 9 7,273.8 6,121.1 MERLA TGPDC 11/2 PROD DMY RK 0.000 0.0 2/16/1992 Close d 1 7,505.6 6,271.9 MERLA TGPDC 1 1/2 PROD DMY RK 0.000 0.0 2/16/1992 Close NIPPLE;7,602.0 605;7,613.8 Notes:General&Safety End Date Annotation 12/31/1992 NOTE:LDL shows 3 leaks downhole©7316',7230',7185' (PERF;7,628.0-7,634 0- 8/42010 NOTE:View Schematic w/Alaska Schematic9.0 (PERF;7, 0.0-7,896.0 PRODUCTION;35.0-7,983.6 •OF T7� • ew,A//7 s, THE STATE Alaska Oil and Gas t� - � of® TT ®® SKA Conservation Commission _ _ 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Ty- Main: 907.279.1433 LAS Fax: 907.276.7542 www.aogcc.alaska.gov G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-09 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-098 Surface Location: 3062' FNL, 1496' FEL, SEC. 17, T1ON, RO8E, UM Bottomhole Location: 2590' FNL,4647' FEL, SEC. 9, T1ON, RO8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. 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. 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, Cath P. Foerster Chair sf- DATED this J1 day of August, 2016. RECtl STATE OF ALASKA - ALiICA OIL AND GAS CONSERVATION COMML ON .5 PERMIT TO DRILL ► 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG 0 Service-Disp ❑ lc.Specify if well is proposed for: Drill ID . Lateral 0 Stratigraphic Test 0 Development-Oil 9 s Service- Winj 0 Single Zone 9' Coalbed Gas 0 Gas Hydrates 0 Redrill❑ Reentry 0 Exploratory-Oil 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Geothermal 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket 2 . Single Well 0 11.Well Name and Number: ConocoPhillips Alaska,Inc. . Bond No. 59-52-180 ' KRU 2S-09 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13,757 • TVD: • 6,349 Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3062'FNL, 1496'FEL, Sec 17, T1ON,R008E, UM ADL 25603,25)44,25589,25590 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2980'FNL,876'FEL,Sec 17,T1ON,R008E,UM 2675,2676,2677,2678 9/1/2016 Total Depth: 9.Acres in Property: 4 14.Distance to Nearest Property: 2590'FNL,4647'FEL,Sec 9,T1ON,R008E,UM 7VS.2 7S? 3900' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 159 ' 15.Distance to Nearest Well Open Surface:x-481,074.22' y-5,929,986.08' Zone-4 4 GL Elevation above MSL(ft): 120 ' to Same Pool: 1700'f/2S-07 16.Deviated wells: Kickoff depth: 350 feet % 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91 degrees . Downhole: 3650 . Surface: 3012 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) 24" 16" 62.5# H-40 Welded 80' 39' 39' 119' 119' pre-driven,cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 2853' 39' 39' 2892' 2661' 1079sx 11#DeepCRE,274sx 15.8# G 9.875" 7.625" 29.7# L-80 Hydril 563 7703' 39' 39' 7742' 6369' 644sx 1st stg,232sx 2nd stg 15.8#G 6.75" 4.5" 12.6# L-80 IBTM 5865' 7592' 6352' 13757' 6349' N/A-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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch 9 Seabed Report 0 Drilling Fluid Program 9 20 AAC 25.050 requirements9 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 Haibin Guo @ 907-265-1487 ( Email Haibin.GuoCOP.com Printed Name AL_G.L.Alvord Title Alaska Drilling Manager Signature ad, Phone 265-6120 Date g(T2.oi6 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: a/6) 0?' 50- (el 3 oC0? 1 { -QA-0Q Date: (-' A\li Y 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: I/ Other: 73 0 P f-e 5 /- tp 3 5 )0 p 5 ) 9Samples req'd: Yes�❑/ Nora/ Mud log req'd:Yes❑ No[ ' /4 N,I-7 1./1 a✓ p✓G V r vi + te-rSt 2 SUUr�1 easures: Yes I,Q No❑ Directional svy req'd:YesV No0 Ce 1,'ti>•� f- c V tet,t V a .f e"c' 16 GI Spacing exception req'd: Yes 0 NoV Inclination-only svy req'd:Yes❑ NoE / p ." f - 1-r"r �r -c G(,cc tf wc n y c c L rev./ - 1 re' Post initial injection MIT req'd:Yes❑ Noe vb f loq �` 1,-, frr-prct-a1--/`c ±-0 /t-Ob cc `/ Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: 8-31-/G, i il 'c,,, / 3i(c71b V7-1_ 8/30/16 /� RnIGIld �\' Subs in Form ane Form 10-401(Revised 11/2015) i oiiirrr222�ttttt�ppp from the date of approval(20 AAC 25.005(8)) Attachments in Duplicate • • Application for Permit to Drill,Well 2S-09 Saved:4-Aug-16 Post Office Box 100360 Anchorage,Alaska 99510-0360 � � � ��� � � Phone(907)263-4180 Jul 25,2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2S-09,A Kuparuk A4 Sand Producer Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a permit to drill an onshore grassroots producer well from the 2S pad. The expected spud date for this well is September 1st,2016. It is planned to use rig Doyon 142. / 2S-09 is planned to be a horizontal well in the Kuparuk A4 sand.The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-2,892' MD/2,661' TVD. The intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 7,742'MD/6,369'TVD. The production hole will be drilled with 6-3/4"bit and run 4- 1/2"slotted liner to+/- 13,757'MD/6,349'TVD.The upper completion will be run with 3-1/2"tubing. 2S-09 will be fractured after rig being released. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Haibin Guo at 265-1487 (Haibin.Guo@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Haibin Guo Drilling Engineer i • Application for Permit to Drill Document Kuparuk Well 2S-09 ConocoPhiilips' Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2S-09 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identi,/j ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth.referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface.referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 3062' FNL, 1496' FEL, Sec 17, TION,R008E,UM NGS Coordinates RKB Elevation 159'AMSL Northings: 5,929,986.1' Eastings: 481,074.2' Pad Elevation 120' AMSL Location at Top of 2980' FNL, 876' FEL, Sec 17,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 7,893' Northings: 5,930,066.7'Eastings: 481,694.1 Total Vertical Depth, RKB: 6,381' Total Vertical Depth, SS: 6,222' Location at Total Depth 2590' FNL,4647' FEL,Sec 9,T1ON,R008E,UM NGS Coordinates Measured Depth, RKB: 13,757' Northings: 5,935,732.3'Eastings: 483,199.8' Total Vertical Depth, RKB: 6,349' Total Vertical Depth, SS: 6,190' and (D)other information required by 20 AAC 25.050(b): Requirements of 20 AAC 25.050(b) If a well is to he intentionally deviated.the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all hells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) ,4n application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036.or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 142. • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,exceptfor an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 2S-09 is calculated using an estimated maximum reservoirpressure of 3 650psi (11.0 ppg, based on offset development wells), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,381' TVD (WP08.1): A Sand Estimated. BHP = 3,650 psi A Sand estimated depth(WP08.1) = 6,381' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 638 psi (6,381' TVD * 0.10 psi/ft) MPSP =BHP—gas column =3,012 psi / (3,650 psi—638psi) (B)data on potential gas zones: The well bore is not expected to penetrate any shallow gas zones. And (C)data concerningpotential causes ofholeproblems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a 1 1b p propensity for differential sticking; See attached 2S-09 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the,following items,except,for an item already on file with the commission and identified in the application: (5)a description of the procedure for conductingformation integrity tests,as required under 20 AAC 25.030(f): A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre-perforated liner,or screen to be installed Casing and Cement Program Casing and Cementing Program Csg/Tbg OD Hole Weight Length Top MD/TVD Btm MD/TVD (in) Vii) (tb/ft) Grade Conn. (ftp (ft) (ftp Cement Program 16 24 62.5 H-40 Welded 80 Surf 119/119 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,853 Surf 2,892/2,661 1,079 sx DeepCRETE Lead 11.0 ppg, 274 sx Class G Tail Slurry 15.8 ppg Stage 1: 644 sx Class G at 15.8 ppg w/ 9-7/8 Hydril TOC at 6,076 MD 7-5/8 X 29.7 L-80 563 7,703 Surf 7,742/6,369 Stage 2: 232 sx Class G at 15.8 ppg w/ 11 TOC at 4,799 MD 4 1/2 6-3/4 12.6 L-80 IBTM 5,865 7,592/6,352 13,757/6,349 Uncemented Liner with Frac Sleeves • • Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items.except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference attached diverter schematic for Doyon 142 on 2S pad slot 09. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Mud Program Summary Surface Intermediate Production 9-7/8"x 11" 13-1/2" Hole Hole 6-3/4" Hole 10-3/4"Casing 7-5/8" Casing 4-1/2" Liner Spud LSND FloPro Mud System (WBM) (WBM) (WBM) Density. _ 8.8-10.0 9.2-10.5 10.3-11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC < 6 < 6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A- Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A - Application is not for an exploratory or stratigraphic test well. • • Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic • • 1. Move in/rig up Doyon Rig 142. Install Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-2,892' MD/2,661' TVD as per directional plan. Survey with MWD,Gamma,Resistivity./ 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. Notify AOGCC if this occurs. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. yytvfron d tyts3J 6. PU 9-7/8"PDC bit with 11"underreamer on directional drilling assembly,MWD/LWD(Gamma,resistivity)./ J RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg,maximum of 16 ppg EMW leak off,recording results. 8. Directionally drill 9-7/8"x 11"intermediate hole TD at+/-7,742' MD/6,369' TVD,wellsite geologist will call intermediate TD. Using MPD to hold near constant BHP of+/-11.5 ppg across HRZ and Kalubik shale. 9. Circulate hole clean and condition mud to kill weight for POOH on elevators. Lay down intermediate BHA and rack back 5"DP 10. Run 7-5/8",29.7#L80,Hydril 563 casing and pump cement as per plan. 7 jt)b 5 1-'1 '-v �' " �d6-GC 11. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 12. PU 4"DP,6-3/4"bit,RSS drilling assembly(Gamma,resistivity,Periscope,and neutron density).RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. ✓ 13. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg,maximum of 14.5 ppg EMW. 14. Swap mud to FloPro reservoir drill-in mud system,using MPD to hold near constant BHP of+/-11.5 ppg on the heel. 15. Directionally drill 6-3/4"hole geosteering through the Kuparuk A4 sand to TD+/-13,757' MD/6,349'TVD as per directional plan. 16. Circulate hole clean and POOH into casing shoe.Displace casing to kill weight brine for running liner. 17. Lay down production BHA. 18. PU and run 4-1/2", 12.6#liner. The top of liner will be placed at+/-7,592' MD,allowing for 150' of overlap in the 7-5/8"casing. 19. Set liner hanger. Slackoff and set liner top packer. 20. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 21. Flow check well for 30 minutes and POOH 22. Run 3-1/2"upper completion. 23. Nipple down ROPE,nipple up tree and test. 24. Freeze protect well with diesel and install BPV. 25. RDMO. 26. 2S-09 will be fractured after rig being released. • • Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) In application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (1 l)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 28.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B)/All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and(if free of hazardous substances)used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. / Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary Attachment 5 Cementing program • • 2S-09 ConocoPhillips Grassroots Horizontal A-Sand Producer Proposed Wellbore Schematic(wp8.1) `t\ J 'CAMERON Last Edited: 4-1/2"tree,top joint is 4-%"12.6#IBTM Guo 7/25/16 a16"Conductor to-120' 0 0 13.5" Surface Hole West Sak Sand:T 1,934'MD/1,843'TVD B 2,740'MD/2,531'TVD 3'/2"x 1" KBMG GLM Surface Casing (-50'TVD below W Sak) 10-3/4"45.5# L-80 Hydril 563 2,892' MD/2,661'TVD (31° INC) 9-7/8" x 11" Intermediate Hole Tubing: 3-1/2" 9.3#L-80 EUE 8RD-MOD GL J GLMw/SOV C7 O.. a, 1 N °' ,-41- 2nd Stage TOC= 500'MD above C-37 Formation at 4,800'MD/4,369'TVD V> ti1,i 1"Yeklr.•.. 1 1 1 1 1111 '.; r'I Stag- "99'ncn C-37:5,299 MD 14,863'TVD Growler(Iceberg):5.440'MD/4,999'TVD Baker 2.812"CMU Sliding Sleeve Cairn:6,076'MD/5,567'TVD \\11\1\11 3-1/2"x 7-5/8",Premier Packer Bermuda:6,310'MD/5,749'TVD Illoir-4.r— f� � 3'A 2.75"DNipple HRZ:6,819'MD/6,075'TVD it Kalubik:7,022'MD 16,175'TVD SLB DHG -'•.,• 6"x 4-%"Swell Packer Kuriaruk C:7.598'MD/6.351'TVD 1 7 Kuparuk A4:7,893'MD/6,381'ND ' . — .- —.....-..- — a,A"Silver Bullet shoe 7-5/8"x 4-'/"Baker ZXP I I I I I I M Packer/Flex Lock Liner O ° ,- Hanger ® ® ® �---------_® ::::d leeve .---'--- wvo"dnplho O a_ 0TD:13,757'MD/6,349'TVD la- Intermediate Casing Production Liner; 6-3/4" Production Hole 7-5/8" 29.7# L-80 Hyd563 Casing 4-1/2" 12.6# L-80 TXP 7,742' MD/6,369'TVD (85° INC) 13,757' MD/6,349'TVD (91° INC) • • igo (.:". - 0 A Ri le z L V" C Z c' o N u Tl --, , F P N N _ i..„. IIS O n -0 —( . m r 4 O o ' 8 v D —< Z O m --c g g 8 I' I x.'-1., o . ;.F A F v � m 0 © L.=.7 cz v I � 0 [1] \ MN o of s VI ' limn NI I i I I..§11111hk�‘..94) ": :IC L 1—3 /11111111.°11 IN) az) Nk =b" Uli i). � x 8 Ell 0 = ® - 8 0 o® El 0 m ® ri goo D �N LJ R I --2.- E r> m 3 ® >— , . , 0 .. , , NU i NIC5 1 C r a 0 0 >_ � c 0 ro a m `5 >_. o Z a ' m T T T T T T / 1 2S-09wp08. 1 6.537 Plan Summary -...„...:, - Base permafrost(?) Top Cairn Top Bermuda - K 1S Marker / Growler-AA J 5- I ,/ C-e B7 Base perrnuda,-- Top HRZ(K-2 mkr) 5 / ,S, A5 _. r -Base W Saki ` > , - --- Kuparuk C(Top C4) - ` , ,s, "'-- -rte Lower Kalubik K-1 mkr �' ( ) A3 t Pop W, pA(>6, D) , Upper _ Kalubik(base HRZ) ` o J! , C-80 C-35 p ` \ x 175/8"x 9-7/8"by 111 11 0 / t I 1 11 9 till t I i I I I I 1 ( d i 3500 7000 10500 14000 � ,- top T-3 Sand 10-3/4"x 13-1/2I' Measured Depth /® ' I' 44111 o__ Geodetic Datum: North American Datum 1983 ' / -0° 110-3/4"x 13-1/21' Depth Reference: Plan:120+39 @ 159.00usft(Doyon142) 11111111Wir/././ �Qa Rig: Doyon142 o r1OI _ ft�QO I7-5l8"x 9-7/8"by 111 iii 2qu, , 14 1/2"x 6-3/4'1 0 5"ro.�. o a ,`':`O �oo,o o I1 AlIllriliIllr- 4 o ° 'O • ra,n m, w rn I AillOr 1 1 I 1 t I r II I I § I I / I O O IO I I ,/ I I nt I zit i O O N Ins- 39 .- 350 0 1000 2000 3000 4000 5000 06000 07000 X8000 09000, 10000 y' _42s-fol 350 - 540 Horizontal Departure ,,,,:a,,1' 540 - 740 330 �, ►,1 30 'now()lsamann - 30 I2S.r2 pmt hall i f��: i,; 930 - 1120 1 a a ...._ I „���r per: " 13 1120 -- 1320 60 p \\I: \ -'- - 300 '``�a#41 �•�cerg,• .•180 1320 - 1510 e. _. 'li�i x `1 L.... -.. f1:�.•.1,�0:00v. 1 +� 42, 2s- 1510 .-- 1700 f!) _ I. M,� x , __ •ii 4r=��ri 1700 - 2200 N - x , p i���� i; � .a; 2200 2700 c 30 x x x . •p''/I e.` F y, 2700 - 3200 y U -. `\ \ x 2510 _.._ T �� may„ . : ,% 1. „ 190 3200 - 3700 O - , x " _. _ 270 :" --" .- 700 - 4200 y �. - .ic 4200 - 4700 520 5700 0 I I i I ill I I I i I I I I I I i'''''-'-',..„,....,....:......., � 0 - 0 I INA PI 6' - j� z,a80 5700 - 6710 0 1500 3000 4500 6000 75::ce 9000 240 �To,: ��,,•', /�/`/ 6710 - 7710 �' -- /// /°�'� 7710 - 8720 SURVEY PROGRAM 6,f,•/"� zs-0r Location • •, 9 y�y,,;.� I I North/Y. 5929735.67 �i�i:••1?:�� 8720 - 9730 Depth From 39.00 Depth 50.00 2S-09wp08.1(Plan 2S-09) INC+TREND Plan Tool East/X: 1621107.54 210 - -- -- " +1;��• 150 9730 - 10740 450.00 1450.00 2S-09wp08.1(Plan 2S-09) MWD Pad Elevation: 120.00 I-. 12�5�� 10740 11740 450.00 2892.08 2S-09wp08.1 Plan 25-09) MWD+IFR-AK-CAZ-SC 180 11740 12750 39.00 450.00 2S-09wp08.1(Plan 2S-09) GYD-GC-SS CASING DETAILS 12750 - 13757 2892.08 4392.08 2S-09wp08.1(Plan 2S-09) MWD 2892.08 7750.05 25-09wp08.1(Plan 2S-09) MWD+IFR-AK-CAZ-SC TVD MD Name -fr 7750.05 9250.05 25-09wp08.1(Plan 2S-09 MWD 2661.00 2892.41 10-3/4"x 13-1/2" Magnetic Model: BGGM2016 T 7750.05 13756.73 25-09wp08.1(Plan 2S-09) MWD+IFR-AK-CAZ-SC 6369.00 7742.32 7-5/8"x 9-7/8"by 11" Magnetic Model Date: 01-Oct-16 6349.00 13756.73 4 1/2"x 6-3/4" Magnetic Declination: 17.80° To convert a Magnetic Direction to a True Direction,Add 17.80°East SECTION DETAILS - 384 2gy T-3 Sand Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,180"TF,for 250.18' K-15 Marker 3 600.18 3.75 180.00 600.00 -8.19 0.00 1.50 180.00 -7.91 Start 2.5°/100'DLS,0°TF,for 918.16' 4 1518.34 26.71 180.00 1480.00 -247.77 0.00 2.50 0.00 -239.33 Hold for 111.94' 5 1630.28 26,71 180.00 1580.00 -298.08 0.00 0.00 0.00 -287.92 Start 3°/100'DLS,-9.04°TF,for 156.52' -1424.0 6 1786.79 31.35 178.58 1716.82 -374.00 1.01 3.00 -9.04 -360.99 Hold for 2098.92' Base permafrost(7 7 3885.71 31.35 178.58 3509.27 -1465.72 27.99 0.00 0.00 -1408.53 Start 3°/100'DLS,-167.36"TF,for 3856.6' 8 7742.32 85.00 10.00 6369.00 -65.16 592.89 3.00 -167.36 90.46 25-Tiger 1.Heel 061616 PB Held for 20' -1843.0 9 7762.32 85.00 10.00 8370.74 -45.54 596.15 0.00 0.00 110.31 Start 1°/100'DLS,41.81°TF,for 743.33' 10 8505.85 90.55 14.95 6399.60 679.18 756.53 1.00 41.81 851.84 Hold for 5251.08' Top W Sak(W Sak)) 11 13756.73 90.55 14.95 6349.00 5752.32 2110.96 0.00 0.00 6102.68 2S-Tiger 2.Toe 061616 PB TD.13756.73'MD,6349'TVD -2531.0 Base W Sak -2919.0 C-80 -4269.0 C-50 -4587.0 gC3-40 -4999:047 Growler-AA =6p6pgq99 979�9�6I aa gR C-358g RKZg���//uUlll{{{pp22�KK��jjkr aa =eiitiHaFJR°Nf"(7b,i`C VRZ) E signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and ollision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Vincent Osara Nate Beck Erik Sterk • o • ,. .._ N Northing (35110 risftlin) CO N N f- 11,\‘-';'-'1*%-. 1, -• N�� co N N — a co3 Y Y Q11$ M _ N 03 O (h - - s;,' 1 Y N N _ C-1 N s!-- J _ Q O _ M M O N 3 - sr ,N Y Y o O L N - N ': .6.N - _ N d 1 i: •• M - -Na C , O Y ` ( N jr-I________--------j3) MO N N — O O ,_2 6 O O J N N Y (n O O N Cn - -� N N O m Ii NID --'-- Ct3410 CI3 d tL N . O LL _ J J ,F,,..,,II C _ so N M FA - C M ' 44 N _- m =• O N N i 1;.*::.---1.--__41111111110A11111 1 N !�.! - OO Lo - _ r, cr, \NNJ • L4 03 _ of• N AJ E \ _ N Ca O _ O ` N 3 : co 0 M ,_ N .,-,- i. pp k M - � Q 3•crM- N U) U),- - N _ Ch Ch N M CO _ NN N a d — 3 a O O M _ M - CO Z J M OM N N J N Zd N N — CO • ir---1.1 a3N p J M 1.5. N J MO N C1 - dM M ^ 3 M _ O J M CO M O N J CO - M O N J--I _ N CO M O N _ tIt , 1/Iii> co , _ N J N Z N t0 - N M NO `- M Z N N Z N M / N — a / 5 i i l l ITS i t ui snlii buil .o itiiiiiiiiiiIii "' ( ini OOse) .4p N N O • • 0 03 0 O . ti O '_ O _o 0 0 CO t.MN = 0 (70 O CO 0 0 C 4). - sco o Immo _ d CL Fa rn0. (---0- CX. 4 , H m o ' 0) 0 0 O N , N 76 O CO N F1 = C m Co n O .- i5 = _ o 0 r (I oLOo a) co I' N r- -:117'O x c ' 0 + V) O N LW CZ --0 17) ri •3 N cts c (0 Lo x ti `r 00 O o CO v ' 0 Q) Oo ;00 v —o c, "t' 0 ' e Q. , co . _o N 0 0 0 0 0 0 0 0 0 o co d (uUlisr000 L) (+)u}a41/(-)ginoS • • 0 0 0 0) 2S-09wp08.1 o 0 A+ N W N , CU ' co (0 , s) o 0 sa- 0 3757 0 Q �a F° = CO iii millY �. , CO Ilia U L 131100 U °' a1` 0 ; : I x W L 1 (B Q N CDO I' ' 12600 c Lo N \ _ I , i 4- �1i Cl) vil 1 , • O L o = s�' k' \' p00 0 0 O (6 CO QS LO (n ~ \\\ 111 11' ` ! ' O O C �\ L I 1 1 I C 4- (0 LU U) 1 �G "O 1, Cr3 \\ \\ II ',', 11 O N O \ \ 1 11I Ln L (!1 L + 16000 \ 1 O \ 1 f — `\ \ VJ M \ II 1+ III I as CD I IY Q.v ` v o \ ,1 11 III I O c O (0 /n `\ I\\ \I it 11,1 III I —O Q +' CO i. CO l l vI- v 1 \ 1v I' ,,1 1 I LO `\ \\ 2 \ \\ \� I L\',\ ,{JyywJ�\I 1\II it II `11 I.s�1OO \ \ \ \ \ !+ \ I\1 (y�I I, 111 /� \ \ \ \ :\ `\ U) \\ j \ i I 06\II co \ \ \ \ I \ \U {..J \ I I A 1i 1 i II CZ 0` Q \\ \\ I I\ 11h II U Q \ \ \ ,4 III ,1 = 45\ \ (2 \ 1 II \I I' r I I\ ` I ` \ \ 'O �(I,1 . \\ 0 1 Q\ \\ \ V `\ DtT ill \ `\ \\ \ Y ` \ III II \ ."VJ ` \\, \\ I\ Cj \ I LII ' COO W `d d �j �p \I Il x © I\ QQ .§ \4 c>r O I , co I ` \ ` ,,^^ \ \ LO O r ' O \l N CO 1\ 0 ° M E O = no O ^^ 1 1 x —o u (U 1 N O n (1) . II (0 ' n m f .N n 1n I u In O I II O LO I I I n I O 0 O O co O O O O O O O O LU LU O LU O LI) (o ,r O N- (ui/l}sn 009 i,) q deQ Iea!1JeA anal • • 0 2S-09wp08.1 o , ,, o 5 i 3757 138 0 co o x II MIN f2tbo 0 Ca) C ritr000 CO -- 0000 , o o CN = O °06 9000 0 0 N. 0 N 0008 c a O _ POO O �- c O�QO O op I _o csi O ----9-y. ,�' 000 00 • �� c 0, o 0 Lo x .z. O U 00 O N O R- NTo N U r LA) 1 \W M / x • O CO \M O ` 0 O - 1 O. O O —O C) CO 0 OL-SZ O CV 2S-08 O —a 1 I �_ _ T I 0 0 o O o 0 O O o 0 0 in o cc) o co co ti (ui/TJsn 0090 uadea Iea eA anal • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-09 Plan: 2S-09 Plan: 2S-09wp08.1 Report 25 July, 2016 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-09 Project: Kuparuk River Unit TVD Reference: Plan:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan:120+39©159.00usft(Doyon142) Well: Plan:2S-09 North Reference: True Wellbore: Plan:2S-09 Survey Calculation Method: Minimum Curvature Design: 2S-09wp08.1 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: 5,929,785.73 usft Latitude: 70°13'10.937 N From: Map Easting: 1,621,342.25usft Longitude: 150°9'13.991 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14° Well Plan:2S-09 Well Position +N/-S 0.00 usft Northing: 5,929,735.67 usft Latitude: 70°13'10.439 N +E/-W 0.00 usft Easting: 1,621,107.54 usft Longitude: 150°9'20.804 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan:2S-09 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BG G M2016 10/1/2016 17.80 80.84 57,533 Design 2S-09wp08.1 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 15.00 Survey Tool Program Date 7/25/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 450.00 2S-09wp08.1 (Plan:2S-09) INC+TREND Inclinometer+known azi trend 450.00 1,450.00 2S-09wp08.1 (Plan:2S-09) MWD MWD-Standard 450.00 2,892.08 2S-09wp08.1 (Plan:2S-09) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 39.00 450.00 2S-09wp08.1 (Plan:2S-09) GYD-GC-SS Gyrodata gyro single shots 2,892.08 4,392.08 2S-09wp08.1 (Plan:2S-09) MWD MWD-Standard 2,892.08 7,750.05 2S-09wp08.1 (Plan:2S-09) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,750.05 9,250.05 2S-09wp08.1 (Plan:2S-09) MWD MWD-Standard 7,750.05 13,756.73 2S-09wp08.1 (Plan:2S-09) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (°) (usft) 39.00 0.00 0.00 39.00 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -59.00 0.00 0.00 0.41 200.00 0.00 0.00 200.00 41.00 0.00 0.00 1.60 284.00 0.00 0.00 284.00 125.00 0.00 0.00 2.64 top T-3 Sand 300.00 0.00 0.00 300.00 141.00 0.00 0.00 2.64 7/25/2016 3:07:30PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-09 Project: Kuparuk River Unit TVD Reference: Plan:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan:120+39 @ 159.00usft(Doyon142) Well: Plan:2S-09 North Reference: True Wellbore: Plan:2S-09 Survey Calculation Method: Minimum Curvature Design: 2S-09wp08.1 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 350.00 0.00 0.00 350.00 191.00 0.00 0.00 3.12 KOP:Start 1.5°1100'DLS,180°TF,for 250.18' 384.00 0.51 180.00 384.00 225.00 1.50 180.00 3.13 K-15 Marker 400.00 0.75 180.00 400.00 241.00 1.50 0.00 3.13 500.00 2.25 180.00 499.96 340.96 1.50 0.00 2.76 600.00 3.75 180.00 599.82 440.82 1.50 0.00 2.76 600.18 3.75 180.00 600.00 441.00 1.50 0.00 2.76 Start 2.5°100'DLS,0°TF,for 918.16' 700.00 6.25 180.00 699.43 540.43 2.50 0.00 2.78 800.00 8.75 180.00 798.57 639.57 2.50 0.00 2.82 900.00 11.25 180.00 897.04 738.04 2.50 0.00 2.89 1,000.00 13.75 180.00 994.67 835.67 2.50 0.00 3.01 1,100.00 16.25 180.00 1,091.25 932.25 2.50 0.00 3.18 1,200.00 18.75 180.00 1,186.62 1,027.62 2.50 0.00 3.43 1,300.00 21.25 180.00 1,280.58 1,121.58 2.50 0,00 3.76 1,400.00 23.75 180.00 1,372.96 1,213.96 2.50 0.00 4.18 1,456.07 25.15 180.00 1,424.00 1,265.00 2.50 0.00 3.37 Base permafrost(?) 1,500.00 26.25 180.00 1,463.59 1,304.59 2.50 0.00 3.37 1,518.34 26.71 180.00 1,480.00 1,321.00 2.50 0.00 3.40 Hold for 111.94' 1,600.00 26.71 180.00 1,552.95 1,393.95 0.00 2.90 3.54 1,630.28 26.71 180.00 1,580.00 1,421.00 0.00 0.00 3.59 Start 3°/100'DLS,-9.04°TF,for 156.52' 1,700.00 28.77 179.32 1,641.70 1,482.70 3.00 -9.04 3.73 1,786.79 31.35 178.58 1,716.82 1,557.82 3.00 -8.43 3.92 Hold for 2098.92' 1,800.00 31.35 178.58 1,728.09 1,569.09 0.00 0.00 3.95 1,900.00 31.35 178.58 1,813.49 1,654.49 0.00 0.00 4.19 1,934.55 31.35 178.58 1,843.00 1,684.00 0.00 0.00 4.44 Top w Sak(W Sak DJ 2,000.00 31.35 178.58 1,898.89 1,739.89 0.00 0.00 4.44 2,100.00 31.35 178.58 1,984.29 1,825.29 0.00 0.00 4.70 2,200.00 31.35 178.58 2,069.69 1,910.69 0.00 0.00 4.98 2,300.00 31.35 178.58 2,155.09 1,996.09 0.00 0.00 5.26 2,400.00 31.35 178.58 2,240.49 2,081.49 0.00 0.00 5.54 2,500.00 31.35 178.58 2,325.89 2,166.89 0.00 0.00 5.83 2,600.00 31.35 178.58 2,411.29 2,252.29 0.00 0.00 6.13 2,700.00 31.35 178.58 2,496.68 2,337.68 0.00 0.00 6.43 2,740.18 31.35 178.58 2,531.00 2,372.00 0.00 0.00 6.73 Base W Sak 1 2,800.00 31.35 178.58 2,582.08 2,423.08 0.00 0.00 6.73 2,892.41 31.35 178.58 2,661.00 2,502.00 0.00 0.00 6.93 10-3/4"x 13-1/2" 7/25/2016 3:07:30PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-09 Project: Kuparuk River Unit TVD Reference: Plan:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan:120+39 @ 159.00usft(Doyon142) Well: Plan:2S-09 North Reference: True Wellbore: Plan:2S-09 Survey Calculation Method: Minimum Curvature Design: 2S-09wp08.1 Database: OAKEDMP2 Planned Survey l MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°1100usft) (°) (usft) 2,900.00 31.35 178.58 2,667.48 2,508.48 0.00 0.00 6.93 3,000.00 31.35 178.58 2,752.88 2,593.88 0.00 0.00 7.02 3,100.00 31.35 178.58 2,838.28 2,679.28 0.00 0.00 7.19 3,194.52 31.35 178.58 2,919.00 2,760.00 0.00 0.00 7.45 C-80 3,200.00 31.35 178.58 2,923.68 2,764.68 0.00 0.00 7.45 3,300.00 31.35 178.58 3,009.08 2,850.08 0.00 0.00 7.77 3,400.00 31.35 178.58 3,094.48 2,935.48 0.00 0.00 8.16 3,500.00 31.35 178.58 3,179.87 3,020.87 0.00 0.00 8.61 3,600.00 31.35 178.58 3,265.27 3,106.27 0.00 0.00 9.10 3,700.00 31.35 178.58 3,350.67 3,191.67 0.00 0.00 9.63 3,800.00 31.35 178.58 3,436.07 3,277.07 0.00 0.00 10.20 3,885.71 31.35 178.58 3,509.27 3,350.27 0.00 0.00 10.70 Start 3%100'DLS,-167.36°TF,for 3856.6' 3,900.00 30.93 178.40 3,521.50 3,362.50 3.00 -167.36 10.76 4,000.00 28.02 176.99 3,608.55 3,449.55 3.00 -167.20 11.02 4,100.00 25.11 175.27 3,697.98 3,538.98 3.00 -165.97 11.28 4,200.00 22.24 173.15 3,789.56 3,630.56 3.00 -164.44 11.53 4,300.00 19.40 170.43 3,883.02 3,724.02 3.00 -162.49 11.74 4,400.00 16.61 166.83 3,978.12 3,819.12 3.00 -159.95 7.67 4,500.00 13.91 161.86 4,074.59 3,915.59 3.00 -156.53 7.59 4,600.00 11.35 154.62 4,172.17 4,013.17 3.00 -151.73 7.40 4,698.40 9.10 143.77 4,269.00 4,110.00 3.00 -144.67 6.99 C-50 4,700.00 9.07 143.56 4,270.58 4,111.58 3.00 -133.99 6.99 4,800.00 7.32 126.30 4,369.57 4,210.57 3.00 -133.77 6.15 4,900.00 6.54 102.08 4,468.86 4,309.86 3.00 -116.69 5.11 4,998.81 7.06 77.21 4,567.00 4,408.00 3.00 -92.64 5.12 C-40 5,000.00 7.07 76.94 4,568.18 4,409.18 3.00 -67.94 5.12 5,100.00 8.66 58.20 4,667.25 4,508.25 3.00 -67.67 5.91 ' 5,200.00 10.87 46.08 4,765.81 4,606.81 3.00 -49.10 6.56 5,299.41 13.36 38.27 4,863.00 4,704.00 3.00 -37.15 6.97 C-37 5,300.00 13.38 38.23 4,863.58 4,704.58 3.00 -29.51 6.97 5,400.00 16.06 32.89 4,960.29 4,801.29 3.00 -29.48 7.24 5,440.39 17.17 31.20 4,999.00 4,840.00 3.00 -24.31 7.42 Growler-AA 5,500.00 18.83 29.06 5,055.69 4,896.69 3.00 -22.69 7.42 5,600.00 21.66 26.19 5,149.50 4,990.50 3.00 -20.65 7.56 5,700.00 24.53 23.97 5,241.48 5,082.48 3.00 -17.96 7.67 5,800.00 27.43 22.18 5,331.36 5,172.36 3.00 -15.91 7.77 5,900.00 30.34 20.71 5,418.91 5,259.91 3.00 -14.31 7.86 6,000.00 33.27 19.48 5,503.89 5,344.89 3.00 -13.02 7.96 7/25/2016 3:07:30PM Page 4 COMPASS 5000,1 Build 74 • 4111 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-09 Project: Kuparuk River Unit TVD Reference: Plan:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan:120+39 @ 159.00usft(Doyon142) Well: Plan:2S-09 North Reference: True Wellbore: Plan:2S-09 Survey Calculation Method: Minimum Curvature Design: 2S-09wp08.1 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 6,076.49 35.52 18.66 5,567.00 5,408.00 3.00 -11.98 8.06 Top Cairn 6,100.00 36.21 18.43 5,586.05 5,427.05 3.00 -11.30 8.06 6,189.48 38.85 17.60 5,657.00 5,498.00 3.00 -11.11 8.18 Top Bermuda 6,200.00 39.16 17.51 5,665.18 5,506.18 3.00 -10.46 8.18 6,300.00 42.11 16.71 5,741.05 5,582.05 3.00 -10.39 8.31 6,310.74 42.43 16.63 5,749.00 5,590.00 3.00 -9.77 8.45 Base Bermuda 6,379.62 44.47 16.13 5,799.00 5,640.00 3.00 -9.71 8.45 C-35 6,400.00 45.07 15.99 5,813.47 5,654.47 3.00 -9.35 8.45 6,500.00 48.04 15.34 5,882.23 5,723.23 3.00 -9.25 8.62 6,600.00 51.00 14.75 5,947.14 5,788.14 3.00 -8.81 8.81 6,700.00 53.97 14.21 6,008.03 5,849.03 3.00 -8.42 9.01 6,800.00 56.94 13.70 6,064.73 5,905.73 3.00 -8.09 9.25 6,818.97 57.51 13.61 6,075.00 5,916.00 3.00 -7.81 9.51 Top HRZ(K-2 mkr) 6,900.00 59.92 13.23 6,117.08 5,958.08 3.00 -7.76 9.51 7,000.00 62.89 12.79 6,164.94 6,005.94 3.00 -7.56 9.79 7,022.33 63.55 12.69 6,175.00 6,016.00 3.00 -7.35 10.09 Upper Kalubik(base HRZ) 7,100.00 65.87 12.37 6,208.18 6,049.18 3.00 -7.31 10.09 7,200.00 68.84 11.97 6,246.68 6,087.68 3.00 -7.17 10.42 7,246.70 70.23 11.79 6,263.00 6,104.00 3.00 -7.01 10.76 Lower Kalubik(K-1 mkr) 7,300.00 71.82 11.58 6,280.33 6,121.33 3.00 -6.95 10.76 7,400.00 74.80 11.21 6,309.05 6,150.05 3.00 -6.88 11.13 7,500.00 77.78 10.85 6,332.74 6,173.74 3.00 -6.78 11.52 7,597.75 80.69 10.50 6,351.00 6,192.00 3.00 6.69 11.92 Kuparuk C(Top C4) 7,600.00 80.76 10.49 6,351.36 6,192.36 3.00 -6.62 11.92 7,667.25 82.76 10.26 6,361.00 6,202.00 3.00 -6.62 12.34 A5 7,700.00 83.74 10.15 6,364.85 6,205.85 3.00 -6.59 12.34 7,742.32 85.00 10.00 6,369.00 6,210.00 3.00 -6.58 12.52 Hold for 20'-7-518"x 9-7/8"by 11" 7,762.32 85.00 10.00 6,370.74 6,211.74 0.00 0.00 12.59 Start 1°1100'DLS,41.81°TF,for 743.33' 7,800.00 85.28 10.25 6,373.94 6,214.94 1.00 41.81 12.72 7,892.64 85.97 10.87 6,381.00 6,222.00 1.00 41.79 13.19 A4 7,900.00 86.03 10.92 6,381.51 6,222.51 1.00 41.74 13.19 8,000.00 86.77 11.59 6,387.79 6,228.79 1.00 41.74 13.85 8,100.00 87.52 12.25 6,392.77 6,233.77 1.00 41.70 14.66 8,200.00 88.27 12.92 6,396.45 6,237.45 1.00 41.67 15.60 7/25/2016 3:07:30PM Page 5 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-09 Project: Kuparuk River Unit TVD Reference: Plan:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan:120+39 @ 159.00usft(Doyon142) Well: Plan:2S-09 North Reference: True Wellbore: Plan:2S-09 Survey Calculation Method: Minimum Curvature Design: 2S-09wp08.1 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 8,300.00 89.01 13.58 6,398.82 6,239.82 1.00 41.64 16.65 8,400.00 89.76 14.25 6,399.89 6,240.89 1.00 41.62 17.78 8,500.00 90.51 14.91 6,399.65 6,240.65 1.00 41.62 19.00 8,505.65 90.55 14.95 6,399.60 6,240.60 1.00 41.62 19.06 Hold for 5251.08' 8,600.00 90.55 14.95 6,398.69 6,239.69 0.00 0.00 20.14 8,700.00 90.55 14.95 6,397.72 6,238.72 0.00 0.00 21.20 8,800.00 90.55 14.95 6,396.76 6,237.76 0.00 0.00 22.30 8,900.00 90.55 14.95 6,395.80 6,236.80 0.00 0.00 23.45 9,000.00 90.55 14.95 6,394.83 6,235.83 0.00 0.00 24.63 9,100.00 90.55 14.95 6,393.87 6,234.87 0.00 0.00 25.84 9,200.00 90.55 14.95 6,392.91 6,233.91 0.00 0.00 27.07 9,300.00 90.55 14.95 6,391.94 6,232.94 0.00 0.00 16.61 9,400.00 90.55 14.95 6,390.98 6,231.98 0.00 0.00 16.97 9,500.00 90.55 14.95 6,390.01 6,231.01 0.00 0.00 17.35 9,600.00 90.55 14.95 6,389.05 6,230.05 0.00 0.00 17.73 9,700.00 90.55 14.95 6,388.09 6,229.09 0.00 0.00 18.12 9,800.00 90.55 14.95 6,387.12 6,228.12 0.00 0.00 18.52 9,900.00 90.55 14.95 6,386.16 6,227.16 0.00 0.00 18.94 10,000.00 90.55 14.95 6,385.20 6,226.20 0.00 0.00 19.36 10,100.00 90.55 14.95 6,384.23 6,225.23 0.00 0.00 19.79 10,200.00 90.55 14.95 6,383.27 6,224.27 0.00 0.00 20.22 10,300.00 90.55 14.95 6,382.31 6,223.31 0.00 0.00 20.66 10,400.00 90.55 14.95 6,381.34 6,222.34 0.00 0.00 21.11 10,500.00 90.55 14.95 6,380.38 6,221.38 0.00 0.00 21.57 10,600.00 90.55 14.95 6,379.42 6,220.42 0.00 0.00 22.03 10,700.00 90.55 14.95 6,378.45 6,219.45 0.00 0.00 22.50 10,800.00 90.55 14.95 6,377.49 6,218.49 0.00 0.00 22.97 10,900.00 90.55 14.95 6,376.53 6,217.53 - 0.00 0.00 23.44 11,000.00 90.55 14.95 6,375.56 6,216.56 0.00 0.00 23.92 11,100.00 90.55 14.95 6,374.60 6,215.60 0.00 0.00 24.41 11,200.00 90.55 14.95 6,373.63 6,214.63 0.00 0.00 24.90 11,300.00 90.55 14.95 6,372.67 6,213.67 0.00 0.00 25.39 11,400.00 90.55 14.95 6,371.71 6,212.71 0.00 0.00 25.89 11,500.00 90.55 14.95 6,370.74 6,211.74 0.00 0.00 26.39 11,600.00 90.55 14.95 6,369.78 6,210.78 0.00 0.00 26.89 11,700.00 90.55 14.95 6,368.82 6,209.82 0.00 0.00 27.39 11,800.00 90.55 14.95 6,367.85 6,208.85 0.00 0.00 27.90 11,900.00 90.55 14.95 6,366.89 6,207.89 0.00 0.00 28.41 12,000.00 90.55 14.95 6,365.93 6,206.93 0.00 0.00 28.93 ' 12,100.00 90.55 14.95 6,364.96 6,205.96 0.00 0.00 29.44 12,200.00 90.55 14.95 6,364.00 6,205.00 0.00 0.00 29.96 12,300.00 90.55 14.95 6,363.04 6,204.04 0.00 0.00 30.48 12,400.00 90.55 14.95 6,362.07 6,203.07 0.00 0.00 31.00 7/25/2016 3:07:30PM Page 6 COMPASS 5000.1 Build 74 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2S-09 Project: Kuparuk River Unit TVD Reference: Plan:120+39 @ 159.00usft(Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan:120+39 @ 159.00usft(Doyon142) Well: Plan:2S-09 North Reference: True Wellbore: Plan:2S-09 Survey Calculation Method: Minimum Curvature Design: 2S-09wp08.1 Database: OAKE DM P2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 12,500.00 90.55 14.95 6,361.11 6,202.11 0.00 0.00 31.53 12,600.00 90.55 14.95 6,360.15 6,201.15 0.00 0.00 32.05 12,700.00 90.55 14.95 6,359.18 6,200.18 0.00 0.00 32.58 12,800.00 90.55 14.95 6,358.22 6,199.22 0.00 0.00 33.11 12,900.00 90.55 14.95 6,357.25 6,198.25 0.00 0.00 33.64 13,000.00 90.55 14.95 6,356.29 6,197.29 0.00 0.00 34.17 13,100.00 90.55 14.95 6,355.33 6,196.33 0.00 0.00 34.71 13,200.00 90.55 14.95 6,354.36 6,195.36 0.00 0.00 35.24 13,300.00 90.55 14.95 6,353.40 6,194.40 0.00 0.00 35.78 13,400.00 90.55 14.95 6,352.44 6,193.44 0.00 0.00 36.32 13,500.00 90.55 14.95 6,351.47 6,192.47 0.00 0.00 36.86 13,600.00 90.55 14.95 6,350.51 6,191.51 0.00 0.00 37.40 13,700.00 90.55 14.95 6,349.55 6,190.55 0.00 0.00 37.94 13,756.73 90.55 14.95 6,349.00 6,190.00 0.00 0.00 38.24 TD:13756.73'MD,6349'TVD 7/25/2016 3.07.30PM Page 7 COMPASS 5000.1 Build 74 • • N O. E c N_ 1 c O • R C 3 o. o m m o ) a 41 O u)°' O C1 ,- N O O ONO.1%, CC cc0; O RS w a K m o M. LG o • o 'A t N ? 61 O v+ O O ? c 0 E C 03 o r O 0 N a y T E N N d O N r rci %Imo E a. i• .r.. L y0 TD .. N LO 0 auW 3 0. Ro W■i U an d imm pa co o m a. ili r) a Z E A\ ■� Cr) N M V cKW W Ci. E_ i M M N J O L c4 0 v x ap O /� O` n N r r Q Q Lt 0 r• a Y m '6 m o W N co O x O CO O up r •c N 1°E. c `2 0 m _i `� - v! N X SIM N CZ a N y C t N N O <C f4 N N XM O ^+ �J >, C o d c .a o "' a s Q al TO C C O : ci E v o = c V < _ U Y 1 a Q. Ln N > w ' A R o A m N r= o �n in c� > in an Is • • i N .-' GL ' 0) = Q I u. a) C. .- E 00 / 1R t CY Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y 1C N N N N N N N N N N N N (/) N Ul N N (A N d) W N N N N N N N 12 c (6 O O O O O O O O O O O O O• O O O O O 0000001 i ci 0000"'-- '4cTi d Y 0. 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CL d CL d d d a a a a CL n. n. n. 0_ a Pi C O 0 O a 00F 7 a) U U i U O O O O O O O a) 8 (O O O O O a) O 0 O O O O O o O or, U U U U m O O O U U o U 0 -8 o U o U or, or, 0 m E 0 (00 (00 (0 t- t- t- C () C (p C (0 0 (0 0 (0 C (0 0 (1) 0 (0 U 2•.0 2 LL YLL R LL Y6 LL R LL 2 LL w0 LL 2 LL 2 LL 2 LL R LL 2 LL YLL R LL tl1 O N O N O N O N O N O U) O 0 N N a) N O tl) a) N a) N a) N a) R a U a U a U o O o U o U 0 O o U o U o U a U 0 U o U a U C C C C C C C C C C C C C C E (D R a) (0 N CO d CO m (0 a) 00 a) CO a) CO N 01 N CO a) CO C) R `) N N N O C (0C ca C R C R C co C l9 C R C (6 C f0 C co C co C co C O C R y a) a) a) a1 a) N y a1 a) a) a) N a) N a) N a) N 0 a) a) N a) N a) N a) a) 000000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0000 O 0) C) V' CO V M N ,- N ,- N V 1- N- (0) 0) M N CO N (0 V CO V N. N N- N 0) 0 CO N CO N r N- V 0 10 (0 0 0 CO M CO C) CO (n V) N ✓ , 0) C) C) V 03 V CO M (O M (O 10 (0 0) CO M N (o U) N N 0) 0) 0) O) (O V Co r r r M M N M N0 06 O Ci N n N N4 N <- V V C) C) C) N N (O ( v`0 s-- s- r A- N W C) C i A' IL U 0 0 0 0 0 0 0 0 0 0 0 a o 0 0 0 o a 0 0 0 0 0 0 o OO v 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 (n o 0 0 0 0 u) O (n 0 0 0 0 0 0 0 0 0 0 0 0 vi o vi o 6 (ri O r•-: ((i o 6o 6C 0r-: 0 0 0 • L (0 O (0 (0 (0 O (0 O C) N- (n N- 0 N r 0 N N 0 N O N N O N O 0 0) (I) 1 ig M V N CO CO V CO V V 1,- V N- V CO V CO V CO CO V V (O co co (o N 8 p2 V co (0 0 0 0) (0 0) (0 0) 0) O N O M CO O O (0 (0 .- (0 N- C O N. 10 CO 0 N 0 N 0) CO 0) CO O V CO co r N N CO N 0) N 0) N O (O NW O V M n V V V V V N N N N4 M O) CO Ci (O 6i 6i V V Ci co CI N C'i N R N N 0) CO CO CO C) CO M CO CO M 0 0 M CO N A- V V CO N- CO 1- N- N- C A N N N A- .- A- A- s- A- W N.0.. CO co .... O CO 1,- O V 0) CO 0) (0 V (O V CO 0 0 0 C) 0 M 0) CO 0) C) 0 N 0 N N- M N •a CO CO C) CO N CO N (0 (0 1- C) N. 0 s- 0 V 0 0 CO N V C) 0 N- 0 1` N 0 0 6 O 6 O W ci ai O 6iA- V C) O W C) A- C) 0) V CO A- (n _ N N a) O L V CO CO COO V CO V CO (0 r (O n A— M 0J M M A— CO 0) N CO A— CO (0 R R a W M co N co CO CO CO M V n V N V co V (o V (O (O M V CO (0 CO CO R N 7 Q. pgp 0 ) V E C co CO V 0 CO r r OD N 0 r 0)CO r r N. 0) Cp 60) r (0 N COM ((00 00) (00 0)O) 0) N. 0 E a) t` Oi O C Ci n Ci 1` oi 1: m i` 0) O) O O O V V C) 6 61 6) co 6i O = V CO M 0 N- r N. N. V V V V (0 (n N M N N 10 10 CO 0) co 0)) CO CO C w N N N N .- e- s- A- C O •C N a co a O 01 CO CO r 0 V 0) CO 0) (0 V CO V CO 0 0 0 CO 0 CO 0) (O 0) CO 0 N 0 N N- M Om a1 •a CO CO C) CO. N (O N CO (0 N. 10 n O s- O V a O CO N V 10 O N. O 1` N O • a y 0 cd 0) co 0) 00 O O) a 0) — V C) O O) (O s- M 0 V 0) 0) s- N N 01 C• ap f0 O.y M CO CD N M M CO CD M M VCD O' N (0 r V CO V (0 CO MV (0 (0 0) NV C') (0 M (0 (0 CO O d 0 W N 7. U) 003) 2 N cN 0) 0) ? m E O R 9 •c CO N M U) O R N v Ac tar o a) = 00 O) a( 0 0 Ri Y9 0 ` c o y a A i .12N a) V d IE O C O (LR co U R m m z n 4O 0 . 2 C (d. 00 00 t .a O d d c m v' R a O O _ O (j d w N W m m m m m m d d O Q. N M o co co V V N N N N Y r • O O 0 O N i �' a I.L 'K R n 7 l�0 N N M M N N V V N N C) C) I� N. CO C) O O N N N N N N 2 o o o o o o ( ( O O ( . 0 0 a 0 O a `- r d >• n (0 6 6 (A oh 6 u) on on on on on on on on to 6 u) (!) _ _ _ _ N • d N N N N N N m m N N m m N N N N N N N N N N N N m m m m 0 . •• " (1`O_ to I n_ d . . 0 a ( . d a a d C O N N CO M CO M V V V V C) C) 1- N- W CO 0 0 A- A- N N N N N N : Z O — C N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o o 0 0 ,- .- •- r .- .- r ( 0 R y Y (h Uh (n U) U) n Uh UUh uUUUoUUUU1 CUon n OOCNy a) E ▪ 7 N N N N N N N N N N N N N N N N N N N N N N N N N N co C 'a Z a Q N N M M CO CO V V V V (() U) N- N- 00 C) 0 0 c- e- N N N N N N V •j( C R R r O O co O O O 0 O O 0 O 0 O O O O O O .F.i 0 a) IX d' e. O on (n (n on W 6 U) co (n U) U) U) U) U) U) U) co U) U) O C (n UJ W (n fn (n on '- 5 . c c N 0 Y N N N N N N N N N N N N N N N N N N N N N N N N N N N N < R R F C2 N N 0 S • • H cn a. c O m Y Y Y Y Y Y Y Y Y Y Y Y Y O w w w N w w N w w N w w N •� Q' ee Le D_' d' Q' 2' R' d' iY d' d' ri) F O O O O O O O O O O O O O -c 4/ a m m m m m m m m m m m m m N V) w w <0 w J) w w w N w w w w = w w w CO w w w w w w w w (0 CO CO CO CO (0 CO CO CO CO CO (0 CO CO a_ 0_ 0_ 0_ 0_ 0_ a. 0_ a_ a_ a_ 0_ a Pi 0 O O c) a Cm E ` ` ` ` ` ` ` CO CO CO (0 (0 CO (0O mE C C C cc c U 2".E N LL Si LL (6 LL (0 tL LL 2 LL 2 LL 16 o Cw) o (w) a u p u cwi p u o u E c c c c c c c0 0 0 E N N N CO N N `7 E E N E N E O u) (n 9 • c w c CO c w c ca CO c co c CO H N N N 0 0 0 0 0 0 0 0 0 0 0 00 Z 0 0 0 co 7 to V 00 7 0 N CO CO Cf) N- CC) 3 p Q u) Q( Q 7 c') a CO 7 CO 0) 7 N. 7 N ✓ (O co CO CO( o co N 0) N CO z a' IX O O r C6 (` M r C (o r (O C O O to LL 0 LL LL 1` w r r as al + 0060000 0 2202222 0 0 0 0 0 0 0 0 0 0 0 0 0 'a co o co o co o 0 0 o O o 0 0 r` O p o (; 0 66666 66 111 N (O Nco N (O CO 0 N 0 0 N 0 M M M M 7 M 7 M V a N N N 0) CO 0 CO CO N C ONONON (0 (0O0 00 O• r (Oo N- con (00 r (NO co M co CO M a� � x- •- a- rr w a O, N CoO O 0) 0 0) 0 0) 0 (0 00 O N 0) M '0 N r N r N r 0 0 V 0 V 03 CO i 0) 0) 0) O 1� N O 0 V 0 c m c .c CO (O CO (O CO CD (O N 0 0 N 0 (0 CO I 1Y'; co co co CO N V CO V CO V d Q. N 7 N T a 01 ©pp`� O E N C 0 N 0 h O N O r ,- O n N 7 m E d O O O 0 (C) 0 0 O 0) 0) CO 7 () - M m lb a0 00 OO 0) (0 (N co co N' . c E CO w O C _N a T.. m " 0 COa. a OA. m N N 0)0 CO0) 0 0) 0 0) 0 CO 00 O -- Ol N r N N n 0 0 7 0 7 CON COM w ` W ao ro 00 W O ro • C' i Cr)M (o Cr;M CO M CD 0 N 0 0 N d 0 0 0 0 0 0 0 0 0) c 0°• 6 rn y G. 'w M M CO CO N V CO V CO V' C1. O. O_ O. Cl d CZ Q CO (' a % N 0)) Cr) 0) 0) CD 0) 0) 0) U)I w 3 l0 2 O O O o 0 0 0 0 C1 - co 2 co N N N co co N N co 6 ch N I O N W CO ? a E 0 O 00 O W co co M 0 O 0 0 0 O 0 h Q +�-( CO C O O N O N O O o V/ l0 N N CO O) (O 0 (O CO (O 0, O y ' ' 1` 1` N m0 u c - VV v —(Ni ,FRoccn- - > o. r o a) a .y c c (U N o 0 U 0 E E Ny c @ m ^ ,y, (n 'O O) o o N O. N E' g E �. 0000 (0 (0 (0 (0 L U E w LL (0 0 0 3 r r lQ 0 0 0 0 0 0 0 0 O (0 O. Z lO i o O O o N N O O C d c 3 3 c� o a E 4 M v v M ro g N- N O O o w t c a a o o (� 3 3 chch LL N N ri r 0 N W N (n 0) N V V N N O^ rn uai V C73 C71 3 a_ a. N N 6 6 °C O) c Lei O i.f. • Y r '• O) r .JM- M V) 0 0 M N N a= a= 0 6i. K N 7 R M M A th CO CO (n (n N r r r CO `O 7 d n Z co CO N N ' ' N N C N N N N O c a C C CO N Y r y NN — — m °3 (O CO a_ •� O L ul J J a_ d o_ a_ T a T O (/� �Iw • p N C:, M co CO CO CO ( ( R' d' ll' U) Z O r C ( ( '(0 o w l0 N CO u) u) CO u) u) 0 0 CO <T V' V [t N to 'y E N N N N N N (n r r - ', O O a) 2 (0 (0 COCOCOCOCOCON N N (n u) u) u) C O) C .a z E N N N N iJ V O ( R' ::',2o U) u) V) V) V) V) (0 (6 N O) O) O) a) _, > ,.. C C CO O N N N N N N a_ a_ D_ d' d' d' Q' as oa • • • E § \ / \ 2 / HI '� Q n ( � 11 CO \ 9 c ) . \ ) - j k § m ƒ \ / E 2 2_ o - \ \ § 2 / - \ } } \ 0 \ a \ ffi — \ ■ _ - e \F2 La `) a) 0▪g - 8 \ a co / §E. } § \ e \ ~ k \ \ \ c \ j \ < ) \ j \ S • • 15:46, July 25 2016 Ladder View 2S-09wp08.1 The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors m s I m - • A m _gg m � i rb. ; a 4.. a a` ; M _ e n ,c iw it N iv r r n H 300—.. ._ OP � / 1 Io II / II l 1I 1 1�iIIIIIIII /11111' II ' IlIilI � " II I IQI ,//11111/I II IIII I . - -"ill 10411Iflg1 %I H1111111I) llIi ' I �10ppIp � "II1� � H1gINIIIIC�p�IIIIIIIIIIIII 8 ....01001111 ,II ;Q�i(� IDQ�Id� IfI���, �iII�IIIII , ipIl� �r _ N II ". II 1111 � 11I c150 IIItl� [1Ip111IIII1l1IllIII ) 11!ug41111l1Mile I � 1FIIII1I,14,1U} pII ?I1II w, iIHI1 ,,A Pl �, � �O \ 11 9'...) allierOlill 1111111dII'11 II ,, III„ I1rIIII (Im _ EquivelannMagneLc Distant '4V,,,11',nniin 1lllllllllln,• ill IO _IIIIIIIDD.ata11U1. ••.umlglN j 0 I I I I 1 I I I I I I I 1 I I I I I I I I I I I I 0 1500 3000 4500 6000 7500 9000 Displayed interval could be less than entire well:Measured Depth 39.00 To 13756.73 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 450.00 25-09wp08.1 (Plan: 2S-09) INC+TREND 2661.0892.41 10-3/4" x 13-1/2" 450.00 1450.00 2S-09wp08.1 (Plan: 2S-09) MWD 6369.CRY42732/8"x 9-7/8" by 11" 450.00 2892.08 2S-09wp08.1 (Plan: 2S-09) MWD+IFR-AK-CAZ-SC 63491E0756.73 4 1/2"x 6-3/4" 39.00 450.00 25-09wp08.1 (Plan: 2S-09) GYD-GC-SS 2892.08 4392.08 25-09wp08.1 (Plan: 2S-09) MWD 2892.08 7750.05 25-09wp08.1 (Plan: 2S-09) MWD+IFR-AK-CAZ-SC 7750.05 9250.05 25-09wp08.1 (Plan: 2S-09) MWD 7750 0513756 73 2S-09wo08 1 (Plan. 2S-091 MWD+IFR-AK-CA7-SC Equivelant Magnetic Distance , i ro / 4 4 6 N N N N �N N 60 I 1 , 11 ' , c ''''SjIgpoi- , , ..,,,, pAiliii r. ogle 22 —AA / 8 ,,palimmillogrir - K.._ _ Ili "SII 0I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth c 2S-®9V1/p08.1 MD• SU s5u Inc Azi TVD Dleg TFace Ta get 350 540 39.00 0.00 0.00 39.00 0.00 0.00 39.00 To 13756.73 350.00 0.00 0.00 350.00 0.00 0.00 540 740 600.18 3.75 180.00 600.00 1.50 180.00 740 930 1518.34 26.71 180.00 1480.00 2.50 0.00 15:14,July 25 2016 1630.28 26.71 180.00 1580.00 0.00 0.00 930 ---- 1120 1786.79 31.35 178.58 1716.82 3.00 -9.04 CASING DETAILS 3885.71 31.35 178.58 3509.27 0.00 0.00 1120 1320 7742.32 85.00 10.00 6369.00 3.00 -167.36 2S-Tiger 1. Heel 061616 PB 1320 " " """ 1510 TVD MD 2661.00 2892.41 10-3/4" x 13 1/2" 7762.32 85.00 10.00 6370.74 0.00 0.00 6369.00 7742.32-5/8" x 9-7/8" by 11" 8505.65 90.55 14.95 6399.60 1.00 41.81 1510 1700 6349.00 13756.73 4 1/2" x 6-3/4,43756.73 90.55 14.95 6349.00 0.00 0.00 2S-Tiger 2. Toe 061616 PB 1700 2200 .,,9 P9449.a 2200 2700 Dept,3=®Dept.90 Survey/Plan,Plat 44 -49:009.1 (Plan:29-09) 2700 3200 450.44 1450 500 2S-09,08.1 (Plan: 2S-09) DOM 4!4.44 P .09 29-09,09 I (Plan: 28-09) -Sc 39 00 450 00 2892 08 4392 08 09,03. (Plea:25.05; �9 3200 3700 2892 09 7750 05 9-09.009.1(Plan:P-09, -M-090-SC 000050:05 13,50,5 �9-49.049.1 (Plan:Pg 09) 1111134126-55-045-6C MD 3700 4200 .-49.,49.1 (Plan:29-09) 4200 -- 4700 4700 5200 5200 5700 2S-08 5700 6710 2S-12wp10.1 [Bull] 2S-04PB10/360 2S-10 ,' 6710 ---- 7710 2S-04 ' ♦i�!%�r= 7710 8720 2S-12PB1', '21 ii..,,1�, , All 1: �►y ►U►�"s► 8720 9730 2S-12 \ -3Q/330.a�`1atigig iib�i'i.'1� 113 1 tli!�1 .z 1p 2S-03PB1 .®., . �v®® B ►► zl,�4s`..ifi• 9730 10740 4;t:_t.r��% lA."VT y kr� ►1 2S-03 10740 11740 r~ ►A;tt-'`l' �i _ / nl✓�rrvA+. ' //,.'1 !10.' I t/®�: =i�;-�_�'l(f' ', vialb"''. r �io.' �. , 11740 12750 ,,,-`"rte+®I•`�♦•,•���®,i,. ®/� `L1.11: 1 ( i -SR®,, •. ►������I�`“•Lai�►„«� �•,e:z,, ,qd: ) ` `,' 12750 13757 �i:fr..,•t 4 N�/ +tom 1.-,40'� � ( .��'G( . 9�®��� 1����,����1 �: ���� ►�I• �' 60/300 Altar, `+04Q�`i \•dt' '- (4 •ar:r►► It I:,r:i:, 414-1.4,-.0 60 - Jt Y, i IIS ���. � ,/ i. 1't Ota / ,1,1a t d . bt k, A 2S315w 02 �� Lw,.� �, . ��� 1�� 1 \•p `e`i� 16110.". • L4111420!!, i• ! • •.s r� 2S-11 .r1 "age �t I�� ►� -.: vvA"• �I_�� IS...---•1,,,,4:.► r r �,� 14 `..et 2S-13P 4,1%11• 'CT`b: -� Ac ,!// I ►j.,,t w �k� " ' `' •'i//' r �..1 ter,,, 1., ►.�� 1 ' 1t . .,14.1./.1.y.' .a _`i♦ c.:•0 4 r♦ -----.V44;1-.7,41.)t. �. ,. 4i 25-05 2S-1301 ♦ ■.!rr. (,-, A f Sr ii s'L 4i41h�a 2 .•� ,..441,0p�P � � t • ♦� �. � ..,. � ♦obi ,ate 2S-13 1.-4 0-�, �‘kAir'•t rte; t., '1�t►'% �'�'��� ' \J/f T� '',,�U, ��,0 2S-02 90) 0 vis'-. ; tt,,k1, ->Fiii""°<:„;.: �,,., ,�,- `r--a �„= 90 �-a,®r- , i1,fop. 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ViiTi i Ad 2S-14w 10.1 h. •' �� ►� 1 �G's�.'i'�. � ,.....��•,:;,1 75 •• p [W ��� �-,Li��44vi of;7%q, .��.,,:..+.�" ;pikk. 2S-06wp10 [Salmon] . 1� f o0 ® '�Gl,����r, s i% ,�i�� mug �,.��'o::� �s �., 120 •v spm .� lik 014 :.�rwr+'r/.Isar. i r/ ',1ii%/moi I -150/210 210 .,�a,1 s �� 150 2S-07 IIIII -180/180 w Northing (3000 usft/in) ^) N I I ! 1 1 1 i I i 1 I 1 ! 1 i 1 1 ! 1 1 1 1 I 1 i 1 1 I 1 1 1 1 I 1 I 1 1 I 1 i 1 1 I 1 1 1 1 I i i 1 1 ! 1 1 1 1 ! 1 1 1 1 I 1 1 I 1 I 1 1 1 I c - - V1 :, 0 pP^— - ^, ppA��M-- 1 CO) - C — "I - +r 1 1 h 1 _ NJ N j C - N 7) ,,,,--°4 'a ®5 cn N O U - m o co 3 N P d `4 I co I W — _ 7 N So \ \,c( A 4:2 _ x co\°% ` IQ _ OO \ C � A -O - ' O _. ci, _. .._. - I i(: N ` 4111P.41111k co W O N O _ N cri _ co 10 N O _ N I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I (u!msn 000£) 6u!4poN Pool Report o s . South(-)/North(+) (3000 usft/in)W W 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 N N 0_..._....... _... ......... ......... _..........._._ _ __. ......... ...._—_--_ ____ ____. _.........- -....-.._ O 0O) 0 00 IV 0 C -, so i) �, ' 0) •Y O .I 0 " O Oy I 0 FJW CO o C 0 co5CD 04�\ N 4 m � ' + o .I \ W Al O W y WA . 0 0 0co o W N � C O il ` N N N N E NJ ..i $$ $ 6) Nmmmo, a N y i3 I Wm m N ''.. Ommmrnl A Nocb 01 0000 0 m O . noon N O m m A .T1.x , CJ m d g A O 0000i m N O— O O --_ 40 • al South(_,)/North(+) (1500 usft/i.a) rn cn cn o cn o = 0 0 0 0 o N 0 0 0 0 0 0 o oi O 1 Niift IS 1 11111111111111111%114044 -pN Ov CD -4 ruk N ihr mug CP Wo '/ CQ 0 CC G CD il _• •� �` I5 111 N MOOt? �, —• • C 0 vI1 CD C 0 CO4 CD ql' AO! y m _ v► j ' 0 01 AlL A (71 O N N ON V N Z ja NN NNC:' Ca'441140/ I o R_o o O W of m O cu 9!o 06- 0 '" ID rn 1 1Iem.O m0 iv 88888 0 a Vn i .. 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'-'•-•.,..I , i :-....„ . . . . --..,. . . . , . . / GO . , . . . i i / l . . . . . -... . ., . . -. . -.... _,..- . 1 Cl . ..... . ,.. : , • .. , . . • . . : . • . , i , . . . . . . . . . . . . . , • .! . ; -• . , . . . . . . . . . . ..... i i , I CD . . • ---- ...._. . . . . • i . • . . i . . . . . . . . • . • . . . , , . i , . . . . . ! ..... . / . . . . . . : . . ... . , . : , . . • . . .. . . . . , . : . . . . . . . : -..4... . , ! • . . . . . . . . . . . . . A . . . . , . . r . .......„.„....._ / , .. .:. i . . . . . . . i • 2S-09 Drilling Hazards Summary 13-1/2" Hole/10-3/4"Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Anti-collision Low Run Gyro as needed for magnetic interference.Third well on pad,so no real anti-collision risk,only with future plans. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections. Hole Swabbing/Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill(use of trip sheets), Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate. 9-7/8"x 11"Hole/7-5/8"Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with higher Low Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of 12.5 ppg in Tarn formations crossed in intermediate. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight,PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4"Hole/4-1/2"Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. 2S-09 Schlumberger CemCADE* Preliminary Job Design 10-3/4"' Surface Casing (Initial) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 142 Volumes are based on 200% excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2,392' MD. Client: CPAI Revision Date: Aug 4, 2015 Prepared by: Britton Schlotz Location:Anchorage, AK Phone: (314)600-1987 Lead Slurry Minimum pump time: -257 min. (pump time plus 120 min.) Email: bschlotz@slb.com DeepCRETE @ 11 ppg- 1.91 ft3/sk 0.6832 ft3/ft x(100') x 1.00 (no excess) = 69 ft3 < TOC at surface 0.3637 ft3/ft x(1456- 100') x 3.00 (200% excess) = 1480 ft3 0.3637 ft3/ft x(2392- 1456')x 1.50 (50% excess) = 511 ft3 69 ft3+ 1480 ft3+ 511 ft3= 2060 ft3 2060 ft3/ 1.91 ft3/sk= 1079 sks (-1,089 sks) Please have extra DeepCRETE on location for top out, previous csg. Tail Slurry Minimum pump time: - 195 min. (pump time plus 120 min.) < 16"casing Class G +adds @ 15.8 ppg- 1.16 ft3/sk at 100'MD 0.3637 ft3/ft x(2892-2392) x 1.50 (50% excess) = 273 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/ 1.16 ft3/sk= 274 sks Round up to 284 sks BHST= 62 °F, Estimated BHCT= 75 °F. (based on Kuparuk temperature survey) < base of permafrost at 1,456'MD(-1,424'TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 7.00 50.0 7.0 7.1 MUDPUSH H I 7.00 75.0 11.0 17.9 < top of tail at Pause 0.00 0.0 10.0 27.9 2,392'MD 11ppg DeepCRETE 7.00 365.9 52.0 Lead 80.1 Pause 0.00 0.0 10.0 90.1 15.8ppg UniSLURRY 7.00 56.3 8.0 98.2 Tail Pause 0.00 0.0 10.0 108.2 Fresh Water 7.00 10.0 1.0 109.6 Pause 0.00 0.0 10.0 119.6 < 10-3/4",45.5#casing Mud 8.00 250.4 31.3 150.9 in 13.5"OH Mud 3.00 10.0 3.3 154.2 MUD REMOVAL TD at 2,892'MD (-2,661 ND) Expected Mud Properties: 10 ppg, Pv<20, TY<20 Spacer Properties: 10.5 ppg MudPUSH* II, Pv= 17-21, TY nu 20-25 Centralizers: per CPAi program *Mark of Schlumberger 2S_09 Schlumberger CemCADE* Preliminary Job Design 7-5/8" Intermediate Stage 1 (initial) Preliminary Job Design based on limited input data.For estimate purposes only. Client: CPAI Volume Calculations and Cement Systems Revision Date: Aug 3, 2016 Prepared by: Britton Schlotz Location:Anchorage,AK Volumes are based on 30% excess. Phone: (907)263-4207 Mobile: (314)600-1987 Email: bschlotz@slb.com Cement slurry Minimum thickening time: - 215 min (pump time plus 120 min) 15.8 ppg Class G +adds - 1.16 ft3/sk Annular Volume: 0.3429 ft3/ft x(7637'-6076') x 1.3 (30% excess) = 696 ft3 0.2148 ft3/ft x(7742'-7637') x 1.3 (30% excess) = 30 ft3 Shoe Volume: 0.2578 ft3/ft x 80'x 1.00 (no excess) = 21 ft3 Totals: 696 ft3+30 ft3+21 ft3= 747 ft3 10-3/4",45.5#casing 747 ft3/1.16 ft3/sk = 644 sks (-654 sks) at 2,892'MD BHST= 166 °F, Estimated BHCT= 113 °F. (BHST calculated using Kuparuk temperature gradient from permafrost base) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 7.0 40.0 5.7 5.7 Stage collar Pause 0.0 0.0 10.0 15.7 at 5,399 15.8 Shark Tooth 7.0 132.8 19.0 34.7 Pause 0.0 0.0 10.0 44.7 Fresh Water 7.0 10.0 1.0 46.1 Pause 0.0 0.0 10.0 56.1 Top slurry at end of pumping Mud 8.0 326.8 40.9 97.0 < 6,076'MD Mud 3.0 10.0 3.3 100.3 MUD REMOVAL < 7-5/8",29.7#casing Recommended Mud Properties: 10.5 ppg, Pv<20, Ty<20. As thin and light as in 11"under possible to aid in mud removal during cementing. reamed hole Spacer Properties: 12.5 ppg MudPUSH* II, Pv 25- 30, Ty 30-40 Centralizers: per CPAI program TD at--7,742'MD Mark of Schlumberger 2S-09 Schlumberger CemCADE* Preliminary Job Design 7-5/8" Intermediate Sta•e2 (initial) Preliminary Job Design based on limited input data.For estimate purposes only. Client: CPAI Volume Calculations and Cement Systems Revision Date: Aug 3, 2016 Prepared by: Britton Schlotz Location:Anchorage, AK Volumes are based on 30% excess. Phone: (907)263-4207 Mobile: (314)600-1987 Email: bschlotz@slb.com Cement slurry Minimum thickening time: - 190 min. (pump time plus 120 min.) 15.8 ppg Class G +adds - 1.16 ft3/sk Annular Volume: 0.3429 ft3/ft x(5399'-4799')x 1.3 (30% excess) = 268 ft3 Shoe Volume: n/a Totals: 268 ft3+ 0 = 268 ft3 268 ft3/ 1.16 ft3/sk = 232 sks(- 242 sks) 10-3/4",45.5#casing at 2,892'MD BHST= 128 °F, Estimated BHCT= 86 °F. (BHST calculated using Kuparuk temperature gradient from permafrost base) PUMP SCHEDULE PumpRate Stage Cumulative Stage Top slurry at end Stage Time Volume Time of pumping (bpm) min ((bbl) ) min < 4,799'MD DP MU USH II 7.0 40.0 5.7 5.7 Pause 0.0 0.0 10.0 15.7 15.8 Shark Tooth 7.0 47.6 7.0 22.5 Pause 0.0 0.0 10.0 32.5 Fresh Water 7.0 10.0 1.0 33.9 Pause 0.0 0.0 10.0 43.9 Stage collar at 5,399' Mud 8.0 222.9 27.9 71.8 Mud 3.0 10.0 3.3 75.1 MUD REMOVAL Recommended Mud Properties: 10.5 ppg, Pv<20, Tv<20. As thin and light as < 7-5/8",29.7#casing possible to aid in mud removal during cementing. in 11"under reamed hole Spacer Properties: 12.5 ppg MudPUSH* II, Pv 25- 30, Tv 30-40 Centralizers: per CPAi program TD at-7,742'MD *Mark of Schlumberger Well: KRU 2S-09 <==Data Input Name: V Loepp <==Data Input Mud Weight(ppg) 10.50 <==Data Input Weak point or LOT-Measured depth(ft) 2,892' <==Data Input Weak point or LOT True vertical depth(ft) 2,661' <_=Data Input Weak point or LOT-Hole angle(deg) 31.0° <==Data Input Weak point or LOT-Hole size(in) 13.500" <==Data Input Weak point pressure or LOT-EMW(ppg) 12.50 <==Data Input Zone of interest-Measured depth(ft) 13,757' <==Data Input Zone of interest-True vertical depth (ft) 6,349' <==Data Input Zone of interest-Hole angle(deg) 90.0° <==Data Input Zone of interest-Hole size(in) 9.875" <==Data Input Zone of interest-Pore pressure EMW(ppg) 11.00 <==Data Input Gas gradient(psi/ft) 0.10 <==Data Input Bottom hole assembly OD(in) 8.0" <==Data Input Bottom hole assembly length(ft) 200' <==Data Input Drill pipe OD(in) 5.500" <==Data Input BHA annular vol.@ zone of interest(bbl/ft) 0.0326 DP annular vol.@ zone of interest (bbl/ft) 0.0653 DP annular vol. •"weak .oint bbl/ft 0.1477 Additional safety margin(psi) 0.00 <==Data Input Weak point pressure(psi): Plo 1,730 psi Weak point pressure-Safety margin: Pmax 1,730 psi Pmax EMW 12.50 ppg Max anticipated formation pressure(psi): Pf 3,632 psi Weak Pt to Zone of Interest distance(ND ft): OH {TVD} 3,688' Weak Pt to Zone of Interest distance(MD ft): OH {MD} 10,865' Maximum influx height at the bit (TVD ft): H{TVD) 250' Maximum influx height at the bit (MD ft): H{MD} ################ Calc.volume of{H}around BHA: Vlbha 6.5 bbl Calc.volume of{H}around drill pipe: Vldp Calc.volume that H equals @ initial shut in: V1 ################ Calc.vol.that H equals©weak point(MD ft): Vwp 43.1 bbl Calc.volume of vwp @ initial shut in: V2 20.5 bbl Kick Tolerance: V2 20.5 bbl NOTE: • • TRANSMITTAL LETTER CHECKLIST WELL NAME: X(AfrAikxk2 t AT ( .,i- 02S - O� PTD: `a I Co O rj /Development _Service Exploratory _Stratigraphic Test Non-Conventional FIELD: / Il/ POOL: ct K ' "S1/ I) / R.V ©�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 existing well Permit LATERAL No. , API No. 50- - - - (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, Y composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 • ❑❑ , , , , , a) 0 a) a , w N al uh, , , _a m c , =a) � c , a: ,:Q , , , a , I o, , , , , ,, , O o, z, ,• r• o% W, 4 E 0 J, Z o 3 o, a), co 0) a (1)' a, , o , , , ,, o, oa , , � ) .0, °, : � E o w, w -§do '3, o c v: a 0. � v'o 4:74y: t a: o o: w, •1- oO. U -o: E -6, o , , a, ._ EZp > ,, Oa): a 0co y: U)' O, c? CCa 4-, : coym : : a a: °, D. 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