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DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2151520 Well Name/No. KUPARUK RIV UNIT 2S-131-1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20720-60-00 MD 16957 TVD 6208 Completion Date 2/5/2016 Completion Status 1WINJ Current Status P&A UIC No REQUIRED INFORMATION Mud Log No / / Samples No r/ Directional Survey Yes ✓ DATA INFORMATION Types Electric or Other Logs Run: Gr/Res/Dens/Neut (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log C 26849 Log Header Scans 0 0 2151520 KUPARUK RIV UNIT 2S-131-1 LOG HEADERS ED C 26849 Digital Data 4/11/2016 Electronic File: CPAI_2S- P 131-1_MicroSope_Resistivity_lmage_5in_MD_RM .pdf ED C 26849 Digital Data 4/11/2016 Electronic File: CPA12S- 131-1 _MicroScope_Data_RM_DLIS.dlis ED C 26849 Digital Data 4/11/2016 Electronic File: CPAI_2S- 131-1_MicroScope_Data_RM_DLIS.html ED C 26849 Digital Data 2850 9338 9/13/2016 Electronic Data Set, Filename: CPAI_2S- 13L1 VISION RM LAS Intermediate .las ED C 26849 Digital Data 9338 10180 9/13/2016 Electronic Data Set, Filename: CPAI_2S- 13L1 VISION RM LAS Intermediate 2.1as ED C 26849 Digital Data 10180 16866 9/13/2016 Electronic Data Set, Filename: CPAI_2S- 13L1 VISION Service Production RM LAS.las ED C 26849 Digital Data 221 2850 9/13/2016 Electronic Data Set, Filename: CPAI_2S- 13L1 VISION Service Surface RM LAS.Ias ED C 26849 Digital Data 136 16866 9/13/2016 Electronic Data Set, Filename: CPAI_2S- S- 13L1—VISION—Service—RM—LAS.Ias 13L1VISIONServiceRMLAS.Ias G� ED C 26849 Digital Data 174 16866 9/13/2016 Electronic Data Set, Filename: CPAI_2S- 131-1 Custom LAS.Ias ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1_VISION Service RM_DLIS_Intermediate_ 1.dlis ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 131-1_VISION_Service_RM_DLIS_Intermediate_ , 2.dlis AOGCC Page I of 3 Wednesday, April 26, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2151520 Well Name/No. KUPARUK RIV UNIT 2S-131-1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20720-60-00 MD 16957 TVD 6208 Completion Date 2/5/2016 Completion Status 1WINJ Current Status P&A UIC No ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1_VISION_Service_RM_DLIS_Production.dlis . ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1 VISION Service RM DLIS.dlis ' ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1 VISION Service DLIS RM.dlis - ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- P 13L1_VISION_Service_2in_MD_RM.PDF ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1 VISION Service tin MD RM.tif . ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- P 13L1_VISION_Service_2in_TVDSS_RM.PDF ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1 VISION Service tin TVDSS RM.tif ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1_VISION_Service_2in_TVD_RM.PDF ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1 VISION Service 2in TVD RM.tif - ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- P 13L1_VISION_Service_5in_MD_RM.PDF ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1 VISION Service 5in MD RM.tif ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 9 13L1_VISION_Service_5in_TVDSS_RM. PDF ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1 VISION Service 5in TVDSS_RM.tif ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- P 13L1_VISION_Service_5in_TVD_RM.pdf ED C 26849 Digital Data 9/13/2016 Electronic File: CPAI_2S- 13L1 VISION Service 5in TVD RM.tif . ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad27 EOW CompassSurveys.pdf ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad27 [Canvas].txt . ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad27 [Macro].txt ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad27 [Petrel].txt AOGCC Page 2 of 3 Wednesday, April 26, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2151520 Well Name/No. KUPARUK RIV UNIT 2S-131-1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20720-60-00 MD 16957 TVD 6208 Completion Date 2/5/2016 Completion Status 1WINJ Current Status P&A UIC No ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad27 [Surveys].txt ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad83 EOW CompassSurveys.pdf ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad83 [Canvas].txt ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad83 [Macro].txt. ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad83 [Petrel].txt ED C 26849 Digital Data 9/13/2016 Electronic File: 2S-131-1 Nad83 [Surveys].txt Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report O Production Test Information YY & Geologic Markers/Tops ( Y ) COMPLIANCE HISTORY Completion Date: 2/5/2016 Release Date: 10/23/2015 Description Comments: Compliance Reviewed By: Directional / Inclination Data 0y Mechanical Integrity Test Information YY Daily Operations Summary Date Comments Mud Logs, Image Files, Digital Data Y /� Core Chips Y Composite Logs, Image, Data Files c1� Core Photographs Y(!!)Cuttings Samples ��Y & Laboratory Analyses Y� Date: AOGCC \-- --1/ Page 3 of 3 Wednesday, April 26, 2017 RECEIVED STATE OF ALASKA JAN 2 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 2 Suspended ❑ 1 b. Well Class: 20AAC 25.105 20AAc 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: Service 0 Stratigraphic Test ❑ 14. Permit to Drill Number/ Sundry: 2. Operator Name: 6. Date Cop., Susp., or ConocoPhillips Alaska, Inc. ban .- t( /q fi(, 1 215-152/316-073/316-431 / 15. API Number: 3. Address: 7. Date Spudded: P.O. Box 100360 Anchorage, AK 99510-0360 I h o ho 50-103-20720-60-00 4a. Location of Well (Governmental Section): Surface: 3099' FNL, 1672.2' FEL, Sec 17, T10N, R8E, UM 8. Date TD Reached: 2141 to 16. Well Name and Number: KRU 2S -13L1 ' Top of Productive Interval: 9. Ref Elevations: KB:147.5 17. Field / Pool(s): N/A GL: 120 BF: Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1965'FNL, 715' FEL, Sec 7, T1 ON, R8E, UM 9704/6185 ADL 25603, ADL 25590 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 480898 y- 5929949 Zone- 4 16867/6205 ALK 2677, ALK 2678, ALK 2675 TPI: x- N/A y- N/A Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 476573 y- 5936375 Zone- 4 N/A 1436/1412 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) 9929/6253 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/Dens/Neut 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 20 78.7 H-40 28 106 28 106 42 Pre-installed & cemented 133/8 68 L-80 28 2835.6 28 2548 16 1460 sx 11 ppg & 278 sx 12 ppg litcret 103/4 45.5 L-80 2694 9318 2501 6018 12.25 x 13.5 1535 sx 15.8 ppg class G 75/8 29.7 L-80 26 10434 26 6320 19.875 348 sx 15.8 class G 24. Open to production or injection? Yes ❑ No F/] 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): None in 2S-131_1 Retainer 9811 6220 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ - ci r _piFiF n -�' Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Retainer @ 9811 16.8 bbls squeezed below & 4.9 bbls laid above retainer 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: 7I Ratio: Test Period Flow Tubing Casinq Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API (corr): Press. 24 -Hour Rate "'k_" `� 1 zS( Form 10-407 Revised 11/ 015 �L g/Z9/ {� Y� E D ON PAGE 2 RBDMS b u FEB - 2 20'13 Submit ORIGINIAL o ly 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1436 1412 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Kuparuk C 9921 6252 Kuparuk A4 9959 6261 Kuparuk A3 14345 6238 Kuparuk C 14634 6263 Kuparuk A4 14700 6263 TD (A4) 16867 6207 Formation at total depth: Kuparuk A4 31. List of Attachments: Daily Operations Summary, Cement Report, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, i)aleontoloaical r roduc i n or well test results, r 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Brunswick (� 263-4249 Email: Scott.A.Brunswick co .com Printed Name: G.L. Alvord Title: Alaska Drilling Manager /} Si nature: v& Phone: 265-6120 Date: I°1 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only -134 & A Ll Dual Lat Grassroots Horizontal A -Sand Injector Final Wellbore Schematic ConocoPhillips D142 RKB Last Edited: SAB -1/12117 20" Conductor to — 117.5' 16" Surface Hole 4-%" 1BTM Tbing Surface Casino 13-318" 68# L-80 HYD 563 2,847.1' MD / 2,559.3' TVD KBGM GLM w/DV 3521.03" MID 3010' ND 10-3/4" Planned TOC: 5,491.5' (at minimum 12-1/4" X 13-1/2" Intermediate #1 Hole 500' MD above C37) C- .3 ....... "M �V. Muls s2bt5?:.)V- ........... KBGM GLM WIDCK-2 SOV 8797.2' MD 5761' ND 10 %"WhipstocktWindow 8,845'MD HRZ: 9,248'MD 5,978'TVD i-- 10-3/4^ 45;5# L-80 Hyd521 9,329.5' MD 6,029.6 TVQ LowerKatubik.(k 1idl-1arker):9,70U131 17VTVD: M6 2S-13 DTTMSTF JOBTYP SUMMARYOPS 11/8/16 DRILLING R/D E -line, N/D dutch riser ring, N/U MPD RCD head and air valve, R/U and Test SIDETRACK BOPE w/ 5" TJ and test MPD, Slip/cut drill line, M/U whipstock assembly, RIH on 5" DP and set whipstock 11/9/16 DRILLING Mill Window and new hole for FIT. CBU. FIT. OWFF, POOH. Lay down BHA. SIDETRACK 11/10/16 DRILLING Wash stack. MU BHA. RIH and Drill Sidetrack. SIDETRACK 11/11/16 DRILLING Drill Sidetrack to 10,414,. Circulate and weight up for POOH. SIDETRACK 11/12/16 DRILLING Circulate raise MW to 11 PPG. OWFF, POOH Stripping out, Lay down BHA. Change SIDETRACK and test Rams. RU to run casing. Run Liner. 11/13/16 DRILLING Finish Change Rams. Pulled Wear Bushing and set Test Plug. Tested Casing Rams. SIDETRACK Pulled Test Plug and Reset Wear Bushing. RU and Run Liner. 11/14/16 DRILLING Run Liner to 10,403', Circulate BU, Pick up Baker Cement Head, Circulate and lower SIDETRACK Mud Wt to 10.5 PPG. Cement Liner. Release and set Packer. CBU. POOH laying down 5" DP. 11/15/16 DRILLING Lay down DP and Running Tool. Clear Floor. Work on Top Drive. Pull Wear Bushing. SIDETRACK RU and Run Tie Back Casing. Stab in Seals and test. Space out and Dummy run string with Hanger. Tested annulus. Freeze protected well. 11/16/16 DRILLING Finish Pumping Freeze Protect. Landed Casing. Drained Stack, Install Packoff and SIDETRACK test. PT Annulus. Change Rams. Test BOP. PU DP and stand back. MU BHA and single in the hole. 11/17/16 DRILLING PU BHA and RIH single in. Log pass. Test Casing. Drill out Shoetrack. Drill 20' of SIDETRACK new hole. CBU. FIT. Drill Lat 1. 11/18/16 DRILLING Clean out Shoetrack and Rat hole. Drill ahead 20' of new hole. CBU. FIT. Install SIDETRACK RCD. Change Mud to FloPro. OWFF. Drill Lat 1. 11/19/16 DRILLING Directional Drill Production 1 Lat. to 13912'. Serviced Rig. Changed seal in HP Hose. SIDETRACK Directional Drill Production 1 Lat. to 14100'. Changed RCD Bearing. Directional Drill Production 1 Lat. to 14384'. 11/20/16 DRILLING Directional Drill Production 1 Lat to 16,917' TD. CBU. Draw down test. OWFF. SIDETRACK 11/21/16 DRILLING OWFF. Backream Out of the Hole. Freed up Packoff. Continue Backream Out of the SIDETRACK Hole. 11/22/16 DRILLING Backream OOH to Casing Shoe. Circulate to 10ppg KWF, Slip/Cut drill line. SIDETRACK Backream OOH to 8700'. Note: Unable to strip out inside casing due to floats not holding 11/23/16 DRILLING Backream OOH to 400 INC, Circulate 2 x bottoms up. Pump OOH to top of HWDP SIDETRACK and circulate hole clean. Pull MPD bearing, Install trip nipple, Pull OOH and L/D BHA. Rig up to run 4-1/2" liner. 11/24/16 DRILLING Rig up and run 4-1/2" liner per tally, M/U liner hanger and RIH on 4" DP stands to SIDETRACK shoe. Obtain parameters and RIH on 4" DP stands to 13690'. 11/25/16 DRILLING RIH liner on 4" DP and 4" HWDP to 16905'. Set hanger/packer as per Baker. SIDETRACK Pressure test packer, Spot Corrosion Inhibited brine, OWFF, POOH to 6547'. 11/26/16 DRILLING SIDETRACK 11/27/16 DRILLING SIDETRACK 11/28/16 DRILLING SIDETRACK 11/29/16 DRILLING SIDETRACK POOH, Test BOPE, Change out saver sub, Make up whipstock assembly and space out. RIH whipstock assembly on 4" DP, Tag top of liner and set whipstock on depth, Mill window. Mill window, Circulate clean, Perform FIT, Strip OOH, L/D BHA, M/U motor BHA. M/U motor BHA and RIH to above whipstock, Install MPD bearing, Drill to 10181', displacing to 9.8 MW on the fly. Troubleshoot / Repair top drive. j Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/7/2016 1/7/2016 1.25 COMPZI WELLPR BHAH P PJSM; lay down liner running tools as 46.0 0.0 20:30 21:45 per Baker Rep. Clear & clean rig floor. 1/7/2016 1/7/2016 1.00 PROD2 WHPST BHAH P PJSM; mobilize whipstock & mill 0.0 0.0 21:45 22:45 assembly BHA to rig floor. 1/7/2016 1/8/2016 1.25 PROD2 WHPST BHAH P PJSM; make up mill assembly, 0.0 0.0 22:45 00:00 window mill, lower watermelon mill, flex joint, & upper watermelon mill. Lay mill assembly down in shed. Pick up & make up Gen 2 whipstock, debris cup, drain sub, safety disconnect, bottom trip anchor, blank sub, & string magnet. 1/8/2016 1/8/2016 2.75 PROD2 WHPST BHAH P PJSM; continue making up whipstock 0.0 428.0 00:00 02:45 assembly as per MWD & Baker Rep f/ 0'- 428' MD. 1/8/2016 1/8/2016 1.25 PROD2 WHPST TRIP P PJSM; TIH f/ 428'- 1560' MD at 2700 428.0 1,560.0 02:45 04:00 fph. 1/8/2016 1/8/2016 0.25 PROD2 WHPST DHEQ P Shallow hole test MWD @ 200 gpm, 1,560.0 1,560.0 04:00 04:15 550 psi, FO 34%. 1/8/2016 1/8/2016 5.75 PROD2 WHPST TRIP P TIH f/ 1560'- 9912' MD, fill every 20 1,560.0 9,912.0 04:15 10:00 stands, PU 135K, SO 100K, calculated displacement 60.14, actual 48.3 bbls. 1/8/2016 1/8/2016 0.50 PROD2 WHPST SRVY P Orient assembly to 54° left @ 250 9,912.0 9,912.0 10:00 10:30 gpm, 1450 psi, FO 43%. 1/8/2016 1/8/2016 0.25 PROD2 WHPST HOSO T TIH to tag nogo @ 9969' MD, liner top 9,912.0 9,969.0 10:30 10:45 1 VMD deep. 1/8/2016 1/8/2016 1.75 PROD2 WHPST WAIT T Double check all tallies & numbers. 9,969.0 9,969.0 10:45 12:30 Confer with town. Decision made to TOH & lengthen assembly below the whipstock. SIMOPS monitor well, obtain slow pump rates, & blow down TD. SPR's @ 9958' MD, 6234' TVD, MW 12.0 ppg, 12:00 hrs. #1 @ 20 = 80; @ 30 = 300 psi #2 @ 20 = 80; @ 30 = 250 psi 1/8/2016 1/8/2016 6.50 PROD2 WHPST TRIP T PJSM; TOH f/ 6966'- 480' MD, 9,969.0 480.0 12:30 19:00 calculated fill 61, actual 63 bbls. 1/8/2016 1/8/2016 0.25 PROD2 WHPST OWFF T Monitor well, static. 480.0 480.0 19:00 19:15 1/8/2016 1/8/2016 2.25 PROD2 WHPST BHAH T PJSM; rack back HWDP, change out 480.0 480.0 19:15 21:30 shear screws on anchor, add magnet below whipstock, replace debris cup, orient whipstock w/ MWD, and install new 45K shear out lug. 1/8/2016 1/8/2016 1.00 PROD2 WHPST TRIP T PJSM; TIH f/ 480'- 1550' MD. 480.0 1,550.0 21:30 22:30 1/8/2016 1/8/2016 0.25 PROD2 WHPST DHEQ T Shallow hole test MWD @ 200 gpm, 1,550.0 1,550.0 22:30 22:45 625 psi, FO 33%, PU 55K, SO 53K, blow down TD. 1/8/2016 1/9/2016 1.25 PROD2 WHPST TRIP T TIH f/ 1550'- 3271' MD, fill every 20 1,550.0 3,271.0 22:45 00:00 stands, calculated displacement 22, actual 21 bbls. 1/9/2016 1/9/2016 5.75 PROD2 WHPST TRIP T TIH f/ 3271'- 9924' MD, fill every 20 3,271.0 9,924.0 00:00 05:45 stands, PU 135K, SO 100K, calculated displacement 37.8, actual 43.8 bbls. Page 40/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time 1/9/2016 End Time 1/9/2016 Dur (hr) 2.25 Phase PROD2 Op Code WHPST Activity Code RGRP Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 05:45 08:00 T PJSM; change out upper IBOP due to 9,924.0 9,924.0 it leaking. 1/9/2016 1/9/2016 1.75 PROD2 WHPST SRVY T Obtain parameters, attempt to orient, 9,924.0 9,924.0 08:00 09:45 MWD would not turn on. Try multiple flow rates 250-300 gpm, 1250-1850 psi. Troubleshoot MWD. Decision made to trip out for MWD. Spill Drill CRT = 120 sec @ 09:00 hrs. 1/9/2016 1/9/2016 0.50 PROD2 WHPST PULD T Lay down single of drill pipe f/ 9924'- 9,924.0 9,892.0 09:45 10:15 9892' MD. Obtain SPR's & blow down TD. SPR's @ 9924' MD, 6234' TVD, MW 11.9+ ppg, 09:30 hrs. #1 @20=120;@30=310 psi #2 @ 20 = 150; @ 30 = 320 psi 1/9/2016 1/9/2016 0.50 PROD2 WHPST OWFF T Monitor well, static. 9,892.0 9,892.0 10:15 10:45 1/9/2016 1/9/2016 5.75 PROD2 WHPST TRIP T PJSM; TOH f/ 9892' - 470' MD, 9,892.0 470.0 10:45 16:30 calculated fill 60.1, actual 65.15 bbls. 1/9/2016 1/9/2016 0.25 PROD2 WHPST OWFF T Monitor well, static. 470.0 470.0 16:30 16:45 1/9/2016 1/9/2016 2.50 PROD2 WHPST BHAH T PJSM; rack back HWDP, change out 470.0 470.0 16:45 19:15 MWD, anchor shear screws, debris cup, & whipstock lug, TIH w/ HWDP. 1/9/2016 1/9/2016 1.00 PROD2 WHPST TRIP T PJSM; TIH w/ whipstock assembly f/ 470.0 1,560.0 19:15 20:15 470'- 1560' MD. 1/9/2016 1/9/2016 0.25 PROD2 WHPST DHEQ T Shallow hole test MWD, 200 gpm, 575 1,560.0 1,560.0 20:15 20:30 psi. 1/9/2016 1/10/2016 3.50 PROD2 WHPST TRIP T PJSM; TIH f/ 1560'- 6579' MD, 1,560.0 6,579.0 20:30 00:00 calculated displacement 42, actual 44 bbls. 1/10/2016 1/10/2016 2.50 PROD2 WHPST TRIP T PJSM; TIH f/ 6579'- 9924' MD, 6,579.0 9,924.0 00:00 02:30 calculated displacement18.9, actual 21.7 bbls. 1/10/2016 1/10/2016 1.50 PROD2 WHPST RGRP T PJSM; change out swivel packing & 9,924.0 9,924.0 02:30 04:00 test to 3500 psi. 1/10/2016 1/10/2016 0.50 PROD2 WHPST SRVY T Obtain parameters & orient assembly 9,924.0 9,924.0 04:00 04:30 to 52° left, 204 gpm, 980 psi, FO 34%, PU 131 K, SO 105K. 1/10/2016 1/10/2016 0.50 PROD2 WHPST HOSO P PJSM; set whipstock at 52° left as 9,924.0 9,915.0 04:30 05:00 follows. Set down on No Go @ 9969' MD with 80K to observe screws shear on anchor. PU to 140K to confirm anchor set. Work string 2X setting down to 40K each time. Observe lug shear on 2nd time. PU to observe milling assembly free w/ PU130K, SO 104K. Top of window @ 9915' MD, bottom of window @ 9929' MD. SPR's @ 9914' MD, 6250' TVD, MW 11.9+ ppg, 04:45 hrs. #1 @20= 110; @30=280 psi #2 @ 20 = 100; @ 30 = 280 psi Page 41/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/10/2016 1/10/2016 7.00 PROD2 WHPST MILL P PJSM; mill window per Baker Rep. f/ 9,915.0 9,923.0 05:00 12:00 9915'- 9923' MD, PU 130K, SO 104K, ROT 120K, Tq on 7-8K, off 5-6K, FO 46%, WOB 1-5K, 100 rpm, 300 gpm, 2000 psi, Max Gas 0. Fire Drill CRT 98 sec @ 07:00 hrs. 1/10/2016 1/10/2016 6.00 PROD2 WHPST MILL P PJSM; mill window per Baker Rep. f/ 9,923.0 9,931.0 12:00 18:00 9923' - 9931' MD, PU 135K, SO 93K, ROT 115K, Tq on 7-9K, off 5-6K, FO 45%, WOB 10-15K, 70-100 rpm, 300 gpm, 1950 psi, Max Gas 0. 1/10/2016 1/10/2016 1.25 PROD2 WHPST CIRC T Milling continued to slow down to less 9,931.0 9,869.0 18:00 19:15 than 1 fph. Geology confirmed a Siderite stringer outside of window. Confer with Baker Rep & town to decide to pull out of hole for bit. CBU f/ 9931'- 9869' MD, 300 gpm, 1850 psi, 30 rpm, Tq 5-6K, FO 45%. Obtain SPR's. SPR's @ 9914' MD, 6250' TVD, MW 12.0 ppg, 19:00 hrs. #1 @ 20 = 165; @ 30 = 320 psi #2@20=160;@30=315 psi 1/10/2016 1/10/2016 0.50 PROD2 WHPST OWFF T Monitor well, static. 9,869.0 9,869.0 19:15 19:45 1/10/2016 1/10/2016 3.25 PROD2 WHPST TRIP T PJSM; lay down single & TOH f/ 9869' 9,869.0 415.0 19:45 23:00 - 415' MD. Kick w/ Tripping Drill CRT 81 sec @ 22:00 hrs. 1/10/2016 1/10/2016 0.25 PROD2 WHPST OWFF T Monitor well, static. 415.0 415.0 23:00 23:15 1/10/2016 1/11/2016 0.75 PROD2 WHPST BHAH T PJSM; lay down magnet & rack back 3 415.0 92.0 23:15 00:00 stands of HWDP. Calculated fill 54, actual 58 bbis. 1/11/2016 1/11/2016 0.50 PROD2 WHPST BHAH T PJSM; lay down milling assembly as 92.0 0.0 00:00 00:30 per Baker Rep. 1/11/2016 1/11/2016 0.75 PROD2 WHPST SHAH T PJSM; clear & clean floor. Mobilize 0.0 0.0 00:30 01:15 new milling assembly to the rig floor. 1/11/2016 1/11/2016 0.50 PROD2 WHPST BHAH T PJSM; make up milling BHA as per 0.0 347.0 01:15 01:45 Baker Rep. f/ 0 - 347' MD. 1/11/2016 1/11/2016 3.75 PROD2 WHPST TRIP T PJSM; TIH f/ 347'- 9895' MD, fill 347.0 9,895.0 01:45 05:30 every 20 stands, calculated displacement 60.1, actual 55.3 bbls. 1/11/2016 1/11/2016 0.25 PROD2 WHPST CIRC T Obtain milling parameters @ 300 gpm, 9,895.0 9,895.0 05:30 05:45 1400 psi, 100 rpm, Tq 7K, PU 131 K, SO 100K, ROT 113K, 1/11/2016 1/11/2016 0.25 PROD2 WHPST REAM T Wash & ream f/ 9895' - 9922' MD, 300 9,895.0 9,922.0 05:45 06:00 gpm, 1400 psi, 100 rpm, Tq 7K. 1/11/2016 1/11/2016 0.75 PROD2 WHPST MILL T Dress window f/ 9922'- 9931' MD, 300 9,922.0 9,931.0 06:00 06:45 gpm, 1400 psi, FO 45%, 100 rpm, Tq 6-9K. 1/11/2016 1/11/2016 2.00 PROD2 WHPST MILL P Mill window f/ 9931' - 9947' MD, PU 9,931.0 9,947.0 06:45 08:45 145K, SO 75K, ROT 120K, Tq on 8k, off 6-7K, FO 52%, WOB 5-1 OK, 100 rpm, 425 gpm, 2500 psi, Max gas 290 1/11/2016 1/11/2016 1.00 PROD2 WHPST CIRC P Circulate & condition brine, pump 9,947.0 9,947.0 08:45 09:45 super sweep then circulate @ 426 gpm, 2450 psi, FO 52%, 70 rpm, Tq 7K. Page 42/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/11/2016 1/11/2016 0.50 PROD2 WHPST TRIP P PJSM, TOH f/ 9947'- 9892' MD, 9,947.0 9,892.0 09:45 10:15 obtain SPR's, blow down TD. SPR's @ 9947' MD, 6249' TVD, MW 12.0 ppg, 10:00 hrs. #1 @ 20 = 170; @ 30 = 310 psi #2 @ 20 = 170; @ 30 = 290 psi 1/11/2016 1/11/2016 0.50 PROD2 WHPST OWFF P Monitor well, static. 9,892.0 9,892.0 10:15 10:45 1/11/2016 1/11/2016 4.00 PROD2 WHPST TRIP P PJSM; TOH f/ 9892'- 370' MD, 9,892.0 370.0 10:45 14:45 calculated fill 54.1, actual 57.48 bbls. 1/11/2016 1/11/2016 0.25 PROD2 WHPST OWFF P Monitor well, static. 370.0 370.0 14:45 15:00 1/11/2016 1/11/2016 1.00 PROD2 WHPST BHAH P PJSM; stand back HWDP, lay down 370.0 0.0 15:00 16:00 milling BHA per Baker Rep. 1/11/2016 1/11/2016 0.25 PROD2 WHPST BHAH P Clear & clean rig floor. 0.0 0.0 16:00 16:15 1/11/2016 1/11/2016 0.50 PROD2 WHPST RURD P PJSM; pull wear bushing, blow down 0.0 0.0 16:15 16:45 kill & choke lines. 1/11/2016 1/11/2016 0.50 PROD2 WHPST WWWH P PJSM; make up stack washer, flush 0.0 0.0 16:45 17:15 stack, lay down stack washer. 1/11/2016 1/11/2016 0.75 PROD2 WHDBOP RURD P PJSM; rig up test equipment. 0.0 0.0 17:15 18:00 1/11/2016 1/11/2016 5.00 PROD2 WHDBOP BOPE P PJSM; test BOPE w/ 4" test joint to 0.0 0.0 18:00 23:00 250/3500 psi for 5 min each. #1: Top pipe rams, CV 1, 12,13, 14 & manual kill valve. #2: Upper IBOP, HCR kill, CV 9, & 11. #3: Lower IBOP, CV 5,8 & 10. #4: Dart, CV 4,6 & 7. #5: FOSV and CV 2. #6: Manual choke valve & 4" kill line Demco valve,(Demco valve failed, seat replaced) # 7: Manual choke valve & HCR kill. #8: Annular preventer tested to 250/2500 psi. 1/11/2016 1/12/2016 1.00 PROD2 WHDBOP BOPE T Attempt to test / trouble shoot lower 0.0 0.0 23:00 00:00 pipe rams w/ 4" & 4.5" test joint. 1/12/2016 1/12/2016 1.50 PROD2 WHDBOP BOPE T Attempt to test / trouble shoot lower 0.0 0.0 00:00 01:30 pipe rams w/ 4" & 4.5" test joint. 1/12/2016 1/12/2016 2.50 PROD2 WHDBOP BOPE P PJSM; test annular w/ 4/5" joint to 0.0 0.0 01:30 04:00 250 / 2500 psi for 5 minutes each. Test 3.5"X6" VBR's w/ 4/5" test joint & blind rams to 250 / 3500 psi for 5 minutes each. Accumulator Draw Down - Initial system pressure 3000 psi, pressure after closure 1900 psi, 200 psi attained in 43 sec, full pressure attained in 171 sec, 5 nitrogen bottles averaged 1950 psi. Tested pit level sensors & gas alarms. 1/12/2016 1/12/2016 0.50 PROD2 WHDBOP BOPE T PJSM; remove test plug & install 10.5" 0.0 0.0 04:00 04:30 wear bushing. 1/12/2016 1/12/2016 0.25 PROD2 WHDBOP MPSP T PJSM; mobilize storm packer & tools 0.0 0.0 04:30 04:45 to rig floor. 1/12/2016 1/12/2016 1.00 PROD2 WHDBOP TRIP T PJSM; TIH w/ mule shoe, 3 stands of 0.0 1,036.0 04:45 05:45 HWDP & 8 stands of 4" DP f/ 0 - 1036' MD. Page 43/69 Report Printed: 1/23/2017 Rig: DOYON 141 Operations Summary (with Timelog Depths) 2S-13 i.,n- nQu i stir- nairrIKIAI Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/12/2016 1/12/2016 0.75 PROD2 WHDBOP MPSP T PJSM; make up storm packer as per 1,036.0 0.0 05:45 06:30 Baker Rep. TIH & set storm packer @ 89' MD below RKB per Baker Rep. Test to 450 psi for 5 min. Rack back stand. 1/12/2016 1/12/2016 0.25 PROD2 WHDBOP BOPE T PJSM; drain stack, remove wear 0.0 0.0 06:30 06:45 bushing & install test plug. 1/12/2016 1/12/2016 0.75 PROD2 WHDBOP BOPE T PJSM; remove 2-7/8" X 5" VBR's & 0.0 0.0 06:45 07:30 install new 2-7/8" X 5" VBR's. 1/12/2016 1/12/2016 1.75 PROD2 WHDBOP BOPE T PJSM; RU & pretest lower VBR's. Find 0.0 0.0 07:30 09:15 & repair additional surface equipment leak. 1/12/2016 1/12/2016 1.75 PROD2 WHDBOP BOPE T Test lower VBR's w/ 4" & 4.5" test 0.0 0.0 09:15 11:00 joints to 250 / 3500 psi for 5 min each. Retest inline 4" kill line Demco valve. Perform draw down on chokes. 1/12/2016 1/12/2016 0.50 PROD2 WHDBOP RURD T PJSM; rig down test equipment & blow 0.0 0.0 11:00 11:30 down all lines. SIMOPS remove test plug and install 10.5" wear bushing. 1/12/2016 1/12/2016 0.75 PROD2 WHDBOP MPSP T PJSM; TIH to 89'& check for pressure 0.0 1,036.0 11:30 12:15 under storm packer. Release storm packer, pull to surface & lay down per Baker Rep. 1/12/2016 1/12/2016 0.75 PROD2 WHDBOP TRIP T PJSM; TOH w/ 8 stands of 4" DP, 3 1,036.0 0.0 12:15 13:00 stands of HWDP & mule shoe f/1036' 0' MD. 1/12/2016 1/12/2016 0.50 PROD2 WHPST BHAH P PJSM; mobilize tools for motor kick off 0.0 0.0 13:00 13:30 BHA. Clear & clean rig floor. 1/12/2016 1/12/2016 3.00 PROD2 WHPST BHAH P PJSM; pick up BHA 13 as per SLB, 0.0 468.0 13:30 16:30 load sources & change bend in motor f/ 1.5 to 1.15°. 1/12/2016 1/12/2016 0.25 PROD2 WHPST TRIP P PJSM; TIH f/ 468'- 1500' MD. 468.0 1,500.0 16:30 16:45 1/12/2016 1/12/2016 0.50 PROD2 WHPST DHEQ P Shallow test MWD @ 210 gpm, 900 1,500.0 1,500.0 16:45 17:15 psi, good. 1/12/2016 1/12/2016 3.50 PROD2 WHPST TRIP P TIH f/ 1500'- 9921' MD, calculated 1,500.0 9,921.0 17:15 20:45 displacement 60 bbls, actual 59 bbls. 1/12/2016 1/12/2016 1.25 PROD2 WHPST SLPC P PJSM; slip & cut 65' of drill line. 9,921.0 9,921.0 20:45 22:00 1/12/2016 1/12/2016 0.50 PROD2 WHPST SVRG P Service rig. 9,921.0 9,921.0 22:00 22:30 1/12/2016 1/13/2016 1.50 PROD2 WHPST CIRC P CBU @ 210 gpm, 1250 psi, PU 148K, 9,921.0 9,897.0 22:30 00:00 SO 95K, f/ 9921'- 9897' MD, tag bottom @ 9943' MD. Verify pipe tally. 1/13/2016 1/13/2016 0.75 PROD2 WHPST CIRC P Circulate at 200 gpm, 1200 psi with no 9,897.0 9,886.0 00:00 00:45 rotation. 36% flow. P/U = 145 kips, S/O = 95 kips 1/13/2016 1/13/2016 0.50 PROD2 WHPST RURD P Lay down on joint. Blow down top 9,886.0 9,886.0 00:45 01:15 drive and rig up for FIT test 1/13/2016 1/13/2016 0.25 PROD2 WHPST LOT P Perform LOT. Pumped 2 bbl. Bled 9,886.0 9,886.0 01:15 01:30 back .35 bbl. Fluid leaked of at 450 psi with 12.0 ppg brine @ 6258' TVD. LOT = 13.4 ppg EMW 1/13/2016 1/13/2016 0.25 PROD2 WHPST RURD P Rig down test equipment. Blow down 9,886.0 9,886.0 01:30 01:45 1 kill line. Pick up single Page 44/69 Report Printed: 1/23/2017 Rig: DOYON 141 Operations Summary (with Timelog Depths) 2S-13 inh- nPII I INtr. C1RIr:1NAl Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X operation Start Depth(ftKB) End Depth (ftKB) 1/13/2016 1/13/2016 0.50 PROD2 DRILL SRVY P Orient tool face to high -side. Wash 9,886.0 9,900.0 01:45 02:15 down from 9886' to 9900' with no rotation @ 198 gpm, 1210 psi, 35% flow. 1/13/2016 1/13/2016 0.50 PROD2 DRILL TRIP P Slide with no pumps from 9900' to 9,900.0 9,947.0 02:15 02:45 9947' MD. 1/13/2016 1/13/2016 1.00 PROD2 DRILL DDRL P Drill from 9947' to 9968'. TVD = 9,934.0 9,968.0 02:45 03:45 6263;. AST = .87, ART = 0, Bit hours = .87 hrs, Total jars hours = .87 hrs. P/U = 145 kips, S/O = 95 kips, Flow = 26%, WOB = 3-7 kips, RPM = o, 198 gpm @ 1250 psi, 47 spm, 1/13/2016 1/13/2016 0.50 PROD2 DRILL TRIP P POOH from 9968'to 9850'. Blow 9,968.0 9,850.0 03:45 04:15 down Top Drive 1/13/2016 1/13/2016 0.25 PROD2 DRILL OWFF P Monitor well- static 9,850.0 9,850.0 04:15 04:30 1/13/2016 1/13/2016 0.75 PROD2 DRILL MPDA P Pull trip nipple and install RCD bearing 9,850.0 9,850.0 04:30 05:15 1/13/2016 1/13/2016 1.75 PROD2 DRILL DISP P Displace well to 10.5 ppg flo-thru mud 9,850.0 9,900.0 05:15 07:00 at 200 gpm, 1525 psi, 41 % flow w/o rotation. Work pipe from 9826' to 9900'. FCP = 1900 psi 1/13/2016 1/13/2016 0.75 PROD2 DRILL SRVY P Obtain parameters and SPR's. 9,900.0 9,900.0 07:00 07:45 Oriental tool face to high side and shut down pumps. SPR's @ 9915' MD, 6237' TVD, MW 10.7 ppg, 07:00 hrs. #1 @ 20 = 610; @ 30 = 860 psi #2 @ 20 = 600; @ 30 = 880 psi 1/13/2016 1/13/2016 4.25 PROD2 DRILL DDRL T Attempt to slide through window w/o 9,900.0 9,918.0 07:45 12:00 success. Couldn't get past 9918'. Orient 30 deg, 40 deg and 60 deg. deg left of high -side and attempt to slide through setting 10-15 k down without success. Pick up and check torque. Slack off 10-15 k while rotating 3 rpm with no increase in torque. Set down while pumping 1 bpm without success. 1/13/2016 1/13/2016 1.75 PROD2 DRILL DDRL T PJSM; attempt to work through 9,918.0 9,918.0 12:00 13:45 window as follows, orient 20° left & tag up at 9918' MD w/ 20K WOB. Continue to work pipe 360° & tagging up at 9918' MD, no success. Decision made to TOH for milling assembly. 1/13/2016 1/13/2016 4.25 PROD2 DRILL CIRC T CBU working pipe f/ 9910'- 9890' MD, 9,918.0 9,910.0 13:45 18:00 200 gpm, 1950 psi, PU 145K, SO 81 K. Waiting on truck to bring KW brine. 1/13/2016 1/13/2016 2.50 PROD2 DRILL DISP T PJSM; displace well to 12.0 ppg KW 9,910.0 9,910.0 18:00 20:30 brine @ 200 gpm, 1900 psi. 1/13/2016 1/13/2016 0.50 PROD2 DRILL OWFF T Monitor well, static. 9,910.0 9,910.0 20:30 21:00 1/13/2016 1/13/2016 1.50 PROD2 DRILL MPDA T PJSM; blow down MPD choke skid & 9,910.0 9,910.0 21:00 22:30 lines. Remove RCD & install trip nipple. Replace leaking air boot. Page 45/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 r- • • ' r Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operabon Start Depth (ftKB) End Depth (WEI) 1/13/2016 1/14/2016 1.50 PROD2 DRILL TRIP T PJSM; TOH f/ 9910'- 7183' MD, PU 9,910.0 7,183.0 22:30 00:00 125K, SO 88K, calculated fill 14.7, actual 15 bbls. 1/14/2016 1/14/2016 2.50 PROD2 DRILL TRIP T POOH from 7183' to 468' 7,183.0 468.0 00:00 02:30 1/14/2016 1/14/2016 0.25 PROD2 DRILL OWFF T Monitor well at top of BHA 468.0 468.0 02:30 02:45 1/14/2016 1/14/2016 1.50 PROD2 DRILL BHAH T Rack back 3 stand of HWDP and one 468.0 60.0 02:45 04:15 stand of flex collars 1/14/2016 1/14/2016 1.00 PROD2 DRILL BHAH T Download sources and lay down 60.0 0.0 04:15 05:15 motor and MWD tools 1/14/2016 1/14/2016 0.25 PROD2 DRILL BHAH T Clear rig floor 0.0 0.0 05:15 05:30 1/14/2016 1/14/2016 0.25 PROD2 DRILL SFTY T Pre -job safety meeting on picking up 0.0 0.0 05:30 05:45 milling BHA 1/14/2016 1/14/2016 0.50 PROD2 DRILL BHAH T Bring milling tools to the rig floor. 0.0 0.0 05:45 06:15 1/14/2016 1/14/2016 1.00 PROD2 DRILL BHAH T Make up milling BHA 0.0 325.0 06:15 07:15 1/14/2016 1/14/2016 4.00 PROD2 DRILL TRIP T RIH from 325' to 9875' filling every 20 325.0 9,875.0 07:15 11:15 stands. 1/14/2016 1/14/2016 0.25 PROD2 DRILL CIRC T Break circulation and fill pipe. Collect 9,875.0 9,875.0 11:15 11:30 parameters PU 138K, SO 91 K, ROT 115K, 90 rpm, Tq 7K. SPR's @ 9872' MD, 6243' TVD, MW 12.0 ppg,11:00 hrs. #1 @ 20 = 180; @ 30 = 330 psi #2 @ 20 = 180; @ 30 = 340 psi 1/14/2016 1/14/2016 0.50 PROD2 DRILL MILL T Wash from 9875 and set down at 9,875.0 9,915.0 11:30 12:00 9915'. Mill with 90 rpm, and 1-3k WOB. Pump at 350 gpm, 1875 psi and 50% flow. 1/14/2016 1/14/2016 9.00 PROD2 DRILL MILL T PJSM; mill whipstock & window f/ 9,915.0 9,928.0 12:00 21:00 9915' -9928' MD, 6244' TVD, PU 138K, SO 92K, ROT 115K, 100 rpm, Tq on 7-9K, off 5-6K, FO 48%, WOB 1 -7K, 300-350 gpm, 1750 psi. 1/14/2016 1/14/2016 1.25 PROD2 DRILL CIRC T CBU w/ super sweep @ 310 gpm, 9,928.0 9,878.0 21:00 22:15 1750 psi. Decide to TOH to recover possible junk in milling assembly. Blow down TD. SPR's @ 9878' MD, 6240' TVD, MW 12.0 ppg, 22:00 hrs. #1 @ 20 = 130; @ 30 = 300 psi #2 @ 20 = 130; @ 30 = 280 psi 1/14/2016 1/14/2016 0.50 PROD2 DRILL OWFF T Monitor well, static. 9,878.0 9,878.0 22:15 22:45 . 1/14/2016 1/15/2016 1.25 PROD2 DRILL TRIP T PJSM; TOH f/ 9878'-8900' MD, 3000 9,878.0 8,900.0 22:45 00:00 fph, calculated fill 5.4, actual 5.6 bbls. 1/15/2016 1/15/2016 5.00 PROD2 DRILL TRIP T PJSM; continue to TOH f/ 8900'- 325' 8,900.0 325.0 00:00 05:00 MD, 3000 fph, calculated fill 54.54, actual 55.42 bbls. 1/15/2016 1/15/2016 0.25 PROD2 DRILL OWFF T Monitor well, static. 325.0 325.0 05:00 05:15 1/15/2016 1/15/2016 0.50 PROD2 DRILL BHAH T Rack back 3 stands of HWDP. 325.0 48.0 05:15 05:45 Page 46/69 Report Printed: 1/23/2017 Rig: DOYON 141 Operations Summary (with Timelog Depths) 2S-13 inhd nRii i iufn Hair-iuei Time Log ---•-•-•--••-- -..._...,._ Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/15/2016 1/15/2016 0.25 PROD2 DRILL BHAH T Drain stack & pull milling BHA to 48.0 0.0 05:45 06:00 surface looking for any junk or debris. 1/15/2016 1/15/2016 0.25 PROD2 DRILL BHAH T PJSM; lay down milling BHA per 0.0 0.0 06:00 06:15 Baker Rep. 1/15/2016 1/15/2016 0.75 PROD2 DRILL BHAH T PJSM; pick up new 6-1/8" mill bit, new 0.0 336.0 06:15 07:00 lower water melon mill, magent, w/ 3 stands of HWDP. 1/15/2016 1/15/2016 5.00 PROD2 DRILL TRIP T PJSM; TIH f/ 336'- 9900' MD, filling 336.0 9,900.0 07:00 12:00 every 20 stands, calculated displacement 59, actual 61 bbls. 1/15/2016 1/15/2016 1.00 PROD2 DRILL REAM T Wash & ream f/ 9900'- 9928' MD, tag 9,900.0 9,928.0 12:00 13:00 up & clean out fill 9923'-9928', PU 128K, SO 98K, ROT 110K, 300 gpm, 1400 psi, FO 52%, 90 rpm, Tq 8K. 1/15/2016 1/15/2016 2.00 PROD2 DRILL MILL T Mill & dress window f/ 9928' - 9948' 9,928.0 9,938.0 13:00 15:00 MD, 300 gpm, 1500 psi, 90-100 rpm, Tq 6K, FO 47%, PU 128K, SO 98K, ROT 110K. 1/15/2016 1/15/2016 0.25 PROD2 DRILL REAM T Wash & ream f/ 9938'- 9968' MD, to 9,938.0 9,968.0 15:00 15:15 bottom exposing lower mills out of window, PU 138K, SO 98K, ROT 115K, 350 gpm, 1750 psi, FO 47%, 100 rpm, Tq 6-8K. 1/15/2016 1/15/2016 0.50 PROD2 DRILL CIRC T Pump super sweep, pulling up into 9,968.0 9,900.0 15:15 15:45 casing f/ 9968'-9900' MD. Pump at 350 gpm, 2000 psi, 100 rpm, Tq 8k. 1/15/2016 1/15/2016 0.75 PROD2 DRILL MILL T Work mills through window (TOW 9,900.0 9,900.0 15:45 16:30 9915'& BOW 9929') several times until clean. PU 138, SO 92, ROT 115K, 350 gpm, 1750 psi, 100 rpm, Tq 7-9K. Obtain SPR's & blow down TD. SPR's @ 9909' MD, 6242' TVD, MW 12.0 ppg, 16:00 hrs. #1 @ 20 = 190; @ 30 = 300 psi #2 @ 20 = 200; @ 30 = 290 psi 1/15/2016 1/15/2016 0.25 PROM DRILL OWFF T Monitor well, static. 9,900.0 9,900.0 16:30 16:45 1/15/2016 1/15/2016 5.00 PROD2 DRILL TRIP T PJSM; TOH f/ 9909'- 336' MD, 9,900.0 336.0 16:45 21:45 calculated fill 54.5, actual 55.4 bbls. Kick w/ Tripping Drill CRT 77 sec @ 20:00 hrs. 1/15/2016 1/15/2016 0.25 PROD2 DRILL OWFF T Monitor well, static. 336.0 336.0 21:45 22:00 1/15/2016 1/15/2016 1.00 PROD2 DRILL BHAH T PJSM; rack back 3 stands of HWDP & 336.0 0.0 22:00 23:00 lay down milling assembly per Baker Rep. Mill bit 1/4" out of gauge. Lower mill showed wear on carbides. Upper mill small amount of wear. Extreme magnet had slots filled with metal shaving & larger debris. 1/15/2016 1/15/2016 0.25 PROD2 DRILL BHAH T PJSM; clear & clean rig floor. 0.0 0.0 23:00 23:15 1/15/2016 1/16/2016 0.75 PROD2 DRILL BHAH T PJSM; pick up kick off BHA # 16 per 0.0 0.0 23:15 00:00 SLB DD. 1/16/2016 1/16/2016 2.00 PROD2 DRILL BHAH T PJSM; continue making up kick off 0.0 352.0 00:00 02:00 BHA #16 f/ 0 - 352' MD, Page 47/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/16/2016 1/16/2016 0.50 PROD2 DRILL TRIP T PJSM; TIH f/ 352'- 1286' MD, 352.0 1,286.0 02:00 02:30 1/16/2016 1/16/2016 0.25 PROD2 DRILL DHEQ T Shallow test MWD, 200 gpm, 750 psi, 1,286.0 1,286.0 02:30 02:45 FO 39%. Tested good. Blow down TD. 1/16/2016 1/16/2016 4.50 PROD2 DRILL TRIP T PJSM; TIH f/ 1286'- 9864' MD, fill 1,286.0 9,864.0 02:45 07:15 every 20 stands, calculated displacement 60.2, actual 60.2 bbls. 1/16/2016 1/16/2016 1.25 PROD2 DRILL MPDA T PJSM; remove trip nipple & install 9,864.0 9,864.0 07:15 08:30 RCD bearing. 1/16/2016 1/16/2016 2.50 PROD2 DRILL DISP T PJSM; displace KW brine to 10.7 ppg 9,864.0 9,864.0 08:30 11:00 FloThru mud system @ 5 bpm, 2050 psi, PU 135K, SO 85K, orient motor to 52' L. SPR's @ 9864' MD, 6236' TVD, MW 10.7 ppg, 11:00 hrs. #1 @ 20 = 710; @ 30 = 1000 psi #2 @ 20 = 720; @ 30 = 1000 psi 1/16/2016 1/16/2016 1.00 PROM DRILL WASH T Begin to trip in hole & tag up at 9908' 9,864.0 9,908.0 11:00 12:00 MD, wash down @ 30 gpm, 850 psi, 30-50 fph, PU 145K, SO 87K. 1/16/2016 1/16/2016 3.50 PROD2 DRILL WASH T PJSM; wash down f/ 9908'- 9930' MD 9,908.0 9,930.0 12:00 15:30 as follows. Work through window @ 30 gpm, 850 psi, 52' L, push through w/ 7K WOB to 9922' MD. Stall motor at 9922', pick up & orient to 52° L, washing back to 9922'. Increase pumps to 215 gpm, 1975 psi & slowly wash down to 9930' MD. 1/16/2016 1/16/2016 0.50 PROD2 DRILL WASH T Wash to bottom f/ 9930'- 9964' MD, 9,930.0 9,964.0 15:30 16:00 215 gpm, 1975 psi. 1/16/2016 1/16/2016 0.50 PROD2 DRILL WASH T Attempt to work through window w/ no 9,964.0 9,968.0 16:00 16:30 pumps. Tag up at 9919' MD on the way back in. Wash back down to 9968' MD @ 60 gpm, 900 psi. 1/16/2016 1/16/2016 3.50 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 9,968.0 10,085.0 16:30 20:00 f/ 9968'- 10085' MD, 6272' TVD, AST 1.58, ART 1. 10, ADT 2.68, BIT 2.68, JARS 3.55, PU 135K, SO 87K, ROT 11 OK, Tq on 7-8K, off 6-7K, FO 41 %, WOB 10-30K, 250 gpm, 2550 psi, Max gas 432. 1/16/2016 1/16/2016 3.25 PROD2 DRILL REAM T Ream last stand to lessen dog leg per 10,085.0 10,085.0 20:00 23:15 DD, 250 gpm, 2300 psi, 60 rpm, Tq 8- 9K. 1/16/2016 1/17/2016 0.75 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 10,085.0 10,123.0 23:15 00:00 f/ 10085'- 10123' MD, 6274' TVD, AST 0, ART .59, ADT .59, BIT 3.0, JARS 3.87, PU 135K, SO 87K, ROT 11 OK, Tq on 7-81K, off 6-7K, FO 41 %, WOB 10-15K, 250 gpm, 2550 psi, Max gas 432. Fire Drill CRT115 sec @ 23:45 hrs. 1/17/2016 1/17/2016 1.50 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 10,123.0 10,180.0 00:00 01:30 f/ 10123'- 10180' MD, 6269' TVD, AST .68, ART .59, ADT 1.27, BIT 4.27, JARS 5.14, PU 135K, SO 85K, ROT 11 OK, Tq on 8K, off 7-8K, FO 47%, WOB 15-20K, 60 rpm, 250 gpm, 2520 psi, Max gas 336. Page 48/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time ;03:15 Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/17/2016 7/2016 1.75 PROD2 DRILL CIRC P Pump high -vis sweep to surface with 10,180.0 10,180.0 01:30 100% increase in cutting @ 250 gpm, 2425 psi, 60 rpm, Tq 7-8K, FO 44%. SPR's @ 10178' MD, 6268' TVD, MW 10.7 ppg, 03:15 hrs. #1 @ 20 = 680; @ 30 = 940 psi #2 @ 20 = 680; @ 30 = 900 psi 1/17/2016 1/17/2016 1.00 PROD2 DRILL BKRM P PJSM; BROOH f/ 10180'- 9945' MD, 10,180.0 9,945.0 03:15 04:15 250 gpm, 2350 psi, 60 rpm, Tq 7-8K. Orient motor 60° L. 1/17/2016 1/17/2016 0.25 PROD2 DRILL SMPD P Pull BHA through window 9945'- 9,945.0 9,900.0 04:15 04:30 9900' MD, motor @ 60° L, PU 140K (Co. Man, DD & Baker Rep witness). 1/17/2016 1/17/2016 0.50 PROD2 DRILL OWFF P Monitor well & verify 11.7 ppg pore 9,900.0 9,900.0 04:30 05:00 pressure. 1/1712C',6 1/17/2016 3.50 PROD2 DRILL DISP P PJSM; displace to 12.0 ppg KW brine 9,900.0 9,900.0 05:00 08:30 @ 5 bpm, 1290 psi, FO 32%. SPR's @ 9893' MD, 6244' TVD, BW 12.0 ppg, 08:15 hrs. #1 @ 20 = 225; @ 30 = 420 psi #2 @ 20 = 225; @ 30 = 420 psi 1/17/2016 1/17/2016 1.50 PROD2 DRILL OWFF P Monitor well, slight flow to static. 9,900.0 9,900.0 08:30 10:00 1/17/2016 1/17/2016 1.25 PROD2 DRILL MPDA P Remove RCD bearing & install trip 9,900.0 9,900.0 10:00 11:15 nipple. Blow down MPD choke skid & lines. 1/17/2016 1/17/2016 5.00 PROD2 DRILL TRIP P PJSM; TOH f/ 9900'- 380' MD, SLM 9,900.0 380.0 11:15 16:15 out, calculated fill 60.1, actual 63.1 bbls. 1/17/2016 1/17/2016 0.25 PROD2 DRILL OWFF P Monitor well, static. 380.0 380.0 16:15 16:30 1/17/2016 1/17/2016 1.25 PROD2 DRILL BHAH P PJSM; lay down BHA as per SLB. 380.0 0.0 16:30 17:45 1/17/2016 1/17/2016 0.50 PROD2 DRILL BHAH P PJSM; clear & clean rig floor. 0.0 0.0 17:45 18:15 1/17/2016 1/17/2016 1.25 PROD2 DRILL BHAH P PJSM; make up 6-3/4" rotary 0.0 125.0 18:15 19:30 steerable BHA # 17 per SLB DD to 125' MD. 1/17/2016 1/17/2016 1.25 PROD2 DRILL BHAH T PJSM; trouble shoot source 125.0 125.0 19:30 20:45 installation problem, in adnVISION tool. Install source. 1/17/2016 1/17/2016 1.25 PROD2 DRILL BHAH P Continue picking up BHA per SLB DD 125.0 414.0 20:45 22:00 f/ 125'-414' MD. 1/17/2016 1/17/2016 0.25 PROD2 DRILL TRIP P PJSM; TIH f/ 414'-1540' MD. 414.0 1,540.0 22:00 22:15 1/17/2016 1/17/2016 0.25 PROD2 DRILL DHEQ P Shallow hole test MWD @ 200 gpm, 1,540.0 1,540.0 22:15 22:30 950 psi, FO 41 %. 1/17/2016 1/18/2016 1.50 PROD2 DRILL TRIP P TIH f/ 1540'-4959' MD, fill every 20 1,540.0 4,959.0 22:30 00:00 stands, calculated displacement 28, actual 31 bbls. 1/18/2016 1/18/2016 4.25 PROD2 DRILL TRIP P TIH f/ 4959'-9866' MD, fill every 20 4,959.0 9,866.0 00:00 04:15 stands, 5000 fph, calculated displacement 58.1, actual 56.7 bbls. 1/18/2016 1/18/2016 1.50 PROD2 DRILL SLPC P PJSM; cut & slip 65' of drill line, 9,866.0 9,866.0 04:15 05:45 service TD. 1/18/2016 1/18/2016 1.50 PROD2 DRILL MPDA P PJSM; remove trip nipple, install RCD 9,866.0 9,866.0 05:45 07:15 bearing & hook up lines. Page 49/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/18/2016 1/18/2016 3.00 PROD2 DRILL DISP P PJSM; displace well f/ 12.0 ppg KW 9,866.0 9,866.0 07:15 10:15 brine to 10.7 ppg Flo-Thru mud system. Obtain SPR's. SPR's @ 9863' MD, 6245' TVD, MW 10.7 ppg, 10:00 hrs. #1 @ 20 = 760; @ 30 = 990 psi #2 @ 20 = 770, @ 30 = 1044 psi 1/18/2016 1/18/2016 3.00 PROD2 DRILL WASH P PJSM; wash & work through window 9,866.0 10,180.0 10:15 13:15 to bottom f/ 9866'- 10180' MD, PU 145K, SO 90K, ROT 11 OK, 210-250 gpm, 2110-2475 psi. 1/18/2016 1/18/2016 4.75 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 10,180.0 10,526.0 13:15 18:00 f/ 10180'- 10526' MD, 6273' TVD, ADT 3.6, BIT 3.6, JARS 8.74, PU 140K, SO 80K, ROT 105K, Tq on 11 K, off 11 K, ECD 12.17, FO 44%, WOB 9- 12K, 150 rpm, 250 gpm, 2600 psi, Max gas 210. Total Footage 346' Table Top Man Down Drill 18:00 hrs. 1/18/2016 1/19/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 10,526.0 11,028.0 18:00 00:00 f/ 10526'- 11028' MD, 6270' TVD, ADT 3.87, BIT 7.47, JARS 12.61, PU 143K, SO 77K, ROT 108K, Tq on 12- 13K, off 11 K, ECD 12.27, FO 50%, WOB 10-13K, 150 rpm, 250 gpm, 2725 psi, Max gas 1476. Total Footage 502' SPR's @ 10996' MD, 6270' TVD, MW 10.6+ ppg, 23:15 hrs. #1 @ 20 = 840; @ 30 = 1080 psi #2 @ 20 = 770; @ 30 = 1080 psi 1/19/2016 1/19/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 11,028.0 11,571.0 00:00 06:00 f/ 11028'- 11571' MD, 6264' TVD, ADT 4.71, BIT 12.18, JARS 17.32, PU 143K, SO 77K, ROT 105K, Tq on 12K, off 11 K, ECD 12.31, FO 50%, WOB 4- 10K, 140 rpm, 250 gpm, 2810 psi, Max gas 1468. Total Footage 543' SPR's @ 11561' MD, 6264' TVD, MW 10.6+ ppg, 05:51 hrs. #1 @ 20 = 790; @ 30 = 1115 psi #2 @ 20 = 785; @ 30 = 1080 psi 1/19/2016 1/19/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 11,571.0 12,136.0 06:00 12:00 f/ 11571'- 12136' MD, 6259' TVD, ADT 3.67, BIT 15.85, JARS 20.99, PU 145K, SO 75K, ROT 105K, Tq on 13K, off 11-12K, ECD 12.37, FO 52%, WOB 9-13K, 140 rpm, 260 gpm, 3040 psi, Max gas 1665. Total Footage 565' SPR's @ 12042' MD, 6260' TVD, MW 10.5+ ppg, 10:45 hrs. #1 @ 20 = 830; @ 30 = 1130 psi #2 @ 20 = 810; @ 30 = 1020 psi Page 50/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 .... Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -LX Operation Start Depth (ftKB) End Depth (MB) 1/19/2016 1/19/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 12,136.0 12,800.0 12:00 18:00 f/ 12136'- 12800' MD, 6251' TVD, ADT 4.91, BIT 20.76, JARS 25.90, PU 160K, SO 67K, ROT 105K, Tq on 13- 14K, off 11 K, ECD 12.35, FO 52%, WOB 10-13K, 140 rpm, 250 gpm, 2900 psi, Max gas 1007. Total Footage 664' SPR's @ 12800' MD, 6251' TVD, MW 10.5+ ppg, 17:45 hrs. #1 @ 20 = 800; @ 30 = 1115 psi #2 @ 20 = 800; @ 30 = 1145 psi 1/19/2016 1/20/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 12,800.0 13,271.0 18:00 00:00 f/ 12800'- 13271' MD, 6238' TVD, ADT 3.59, BIT 24.35, JARS 29.49, PU 160K, SO 65K, ROT 105K, Tq on 14K, off 13K, ECD 12.30, FO 51 %, WOB 7- 12K, 140 rpm, 251 gpm, 2950 psi, Max gas 2487. Total Footage 471' SPR's @ 13268' MD, 6238' TVD, MW 10.6 ppg, 23:45 hrs. #1 @ 20 = 900; @ 30 = 1150 psi #2 @ 20 = 990; @ 30 = 1220 psi 1/20/2016 1/20/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 13,271.0 13,760.0 00:00 06:00 f/ 13271'- 13760' MD, 6228' TVD, ADT 4.33, BIT 28.68, JARS 33.82, PU 160K, SO 62K, ROT 103K, Tq on 14- 15K, off 13K, ECD 12.35, FO 51 %, WOB 5-13K, 140 rpm, 250 gpm, 2910 psi, Max gas 581. Total Footage 489' 1/20/2016 1/20/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 13,760.0 14,122.0 06:00 12:00 f/ 13760'- 14122' MD, 6220' TVD, ADT 4.24, BIT 32.92, JARS 38.06, PU 160K, SO 62K, ROT 101 K, Tq on 14- 15K, off 13K, ECD 12.39, FO 52%, WOB 6-11 K, 140 rpm, 250 gpm, 3000 psi, Max gas 2523. Total Footage 362' SPR's @ 13837' MD, 6226' TVD, MW 10.5+ ppg, 08:15 hrs. #1 @ 20 = 850; @ 30 = 1185 psi #2 @ 20 = 850, @ 30 = 1175 psi 1/20/2016 1/20/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 14,122.0 14,665.0 12:00 18:00 f/ 14122'- 14665' MD, 6264' TVD, ADT 4.42, BIT 37.34, JARS 42.48, PU 171 K, SO 66K, ROT 104K, Tq on 15K, off 13K, ECD 12.42, FO 50%, WOB 8- 11 K, 140 rpm, 250 gpm, 3050 psi, Max gas 3213. Total Footage 543' SPR's @ 14592' MD, 6264' TVD, MW 10.5+ ppg, 17:30 hrs. #1 @ 20 = 860; @ 30 = 1280 psi #2 @ 20 = 850; @ 30 = 1290 psi Page 51/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 • ♦ f � r Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) EndDepth (ftKB) 1/20/2016 1/21/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 14,665.0 15,152.0 18:00 00:00 f/ 14665'- 15152' MD, 6257' TVD, ADT 3.97, BIT 41.31, JARS 46.45, PU 171 K, SO 64K, ROT 104K, Tq on 15.5K, off 13.5K, ECD 12.45, FO 50%, WOB 8-15K, 140 rpm, 250 gpm, 3150 psi, Max gas 6050. Total Footage 487' SPR's @ 15068' MD, 6259' TVD, MW 10.5 ppg, 23:00 hrs. #1 @ 20 = 900; @ 30 = 1220 psi #2 @ 20 = 880, @ 30 = 1240 psi 1/21/2016 1/21/2016 5.75 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 15,152.0 15,613.0 00:00 05:45 f/ 15152'- 15613' MD, 6244' TVD, ADT 4.16, BIT 45.47, JARS 50.61, PU 165K, SO 52K, ROT 102K, Tq on 15K, off 13K, ECD 12.41, FO 50%, WOB 4- 9K, 140 rpm, 250 gpm, 3110 psi, Max gas 6024. Total Footage 461' SPR's @ 15542' MD, 6245' TVD, MW 10.5+ ppg, 04:30 hrs. #1 @ 20 = 965; @ 30 = 1255 psi #2 @ 20 = 940; @ 30 = 1275 psi 1/21/2016 1/21/2016 3.25 PROD2 DRILL CIRC T Circulate out gas cut mud. 140 rpm, 15,613.0 15,613 0 05:45 09:00 13K tq, 250 gpm, 3120 psi. Non pressurized mud weights of 10 ppg in/9.9 ppg out observed. 1/21/2016 1/21/2016 0.25 PROD2 DRILL OWFF T Perform draw down test. Shut in with 15,613.0 15,613.0 09:00 09:15 380 psi. Pressure built to 440 psi/15 mins. Bleed to 380 psi. Pressure built to 444 psi/10 mins. Suspect gas migration and expansion. 1/21/2016 1/21/2016 2.00 PROD2 DRILL CIRC T CBU. 140 rpm, 13K tq, 250 gpm, 3120 15,613.0 15,613.0 09:15 11:15 psi. 1/21/2016 1/21/2016 0.75 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 15,613.0 15,637.0 11:15 12:00 f/ 15613'- 15637' MD, 6241' TVD, ADT .34, BIT 45.8 1, JARS 50.95, PU 165K, SO 52K, ROT 102K, Tq on 15K, off 13K, ECD 12.54, FO 50%, WOB 5- 10K, 140 rpm, 250 gpm, 3190 psi, Max gas 2882. Total Footage 24' 1/21/2016 1/21/2016 2.50 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 15,637.0 15,829.0 12:00 14:30 f/ 15637'- 15829' MD, 6235' TVD, ADT 2.24, BIT 48.05, JARS 52.19, PU 165K, SO 48K, ROT 103K, Tq on 15K, off 13K, ECD 12.45, FO 50%, WOB 6- 9K, 140 rpm, 250 gpm, 3150 psi, Max gas 1992. Total Footage 192' 1/21/2016 1/21/2016 1.25 PROD2 DRILL MPDA T PJSM. RCD element leaking. Blow 15,829.0 15,829.0 14:30 15:45 down TD. Change out RCD bearing assy. Page 52/69 Report Printed: 1/23/2017 7 Operations Summary (with Timelog Depths) 2S-13 f i fids 'i Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/21/2016 1/21/2016 3.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 15,829.0 16,018.0 15:45 18:45 f/ 15829'- 16018' MD, 6232' TVD, ADT 2.03, BIT 50.08, JARS 55.22, PU 165K, SO 50K, ROT 103K, Tq on 15- 16K, off 13K, ECD 12.53, FO 50%, WOB 6-10K, 140 rpm, 250 gpm, 3200 psi, Max gas 2159. Total Footage 189' 1/21/2016 1/21/2016 1.25 PROD2 DRILL MPDA T PJSM. RCD element leaking. Blow 16,018.0 16,018.0 18:45 20:00 down TD. Change out RCD bearing assy. Upon inspecting failed element it was determined to be a 5" element rather than 4". 1/21/2016 1/22/2016 4.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 16,018.0 16,280.0 20:00 00:00 f/ 16018'- 16280' MD, 6280' TVD, ADT 2.82, BIT 52.90, JARS 58.04, PU 169K, SO 38K, ROT 102K, Tq on 15- 16K, off 13K, ECD 12.67, FO 51%, WOB 7-10K, 140 rpm, 250 gpm, 3225 psi, Max gas 3557. Total Footage 262' SPR's @ 16019' MD, 6230' TVD, MW 10.5+ ppg, 20:00 hrs. #1 @ 20 = 970; @ 30 = 1290 psi #2 @ 20 = 980; @ 30 = 1335 psi 1/22/2016 1/22/2016 8.50 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 16,280.0 16,867.0 00:00 08:30 f/ 16280'- 16867' MD, 6207' TVD, ADT 5.98, BIT 58.88, JARS 64.02, PU 170K, SO 35K, ROT 102K, Tq on 16K, off 15K, ECD 12.74, FO 52%, WOB 6- 9K, 140 rpm, 250 gpm, 3250 psi, Max gas 2815. Total Footage 587' SPR's @ 16586' MD, 6215' TVD, MW 10.5+ ppg, 04:15 hrs. #1 @ 20 = 990; @ 30 = 1314 psi #2 @ 20 = 970; @ 30 = 1335 psi 1/22/2016 1/22/2016 4.00 PROD2 CASING CIRC P Circulate and condition mud. 140 rpm, 16,867.0 16,867.0 . 08:30 12:30 250 gpm, 3240 psi, 51% FO Max gas=3340 1/22/2016 1/22/2016 0.50 PROD2 CASING OWFF P Perform draw down test. Shut in 289 16,867.0 16,867.0 12:30 13:00 psi. Built to 419 psi/5 min. Bleed to 310 psi. Built to 416 psi/5 min. Bleed to 300 psi. Built to 415 psi/5 min. Bleed to 300 psi. Built to 414 psi/5 min. 11.85 ppg EMW observed. 1/22/2016 1/22/2016 3.50 PROD2 CASING CIRC P Circulate and condition mud. 140 rpm, 16,867.0 16,867.0 13:00 16:30 250 gpm, 3250 psi. 52% FO. 1/22/2016 1/22/2016 0.25 PROD2 CASING CIRC P Obtain SPR's and survey as per 16,867.0 16,867.0 16:30 16:45 MWD. SPR's @ 16867' MD, 6207' TVD, MW 10.5+ ppg, 16:30 hrs. #1 @ 20 = 1050; @ 30 = 1375 psi #2 @ 20 = 1050; @ 30 = 1385 psi 1/22/2016 1/23/2016 7.25 PROD2 CASING BKRM P BROOH from 16867' MD to 14788' 16,867.0 14,788.0 16:45 00:00 MD. 250 gpm, 3250 psi, 140 rpm 13K tq, 12.51 ECD. Calc disp=10.8 bbis Act disp=31.3 bbls Page 53/69 Report Printed: 1/23/2017 ® ti Operations Summary (with Timelog Depths) 2S-13 • i • " r Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/23/2016 1/23/2016 6.00 PROD2 CASING BKRM P BROOH from 14788' MD to 12708' 14,788.0 12,708.0 00:00 06:00 MD. 250 gpm, 2750 psi, 140 rpm 9K tq, Rot wt 105K, FO 50%, 12.23 ECD. Calc disp=13.5 bbls Act disp=31.5 bbls 1/23/2016 1/23/2016 6.50 PROD2 CASING BKRM P BROOH from 12708' MD to 10440' 12,708.0 10,440.0 06:00 12:30 MD. 250 gpm, 2750 psi, 140 rpm 7K tq, Rot wt 105K, FO 49%, 12.17 ECD. Calc disp=11.88 bbls Act disp=19.8 bbls 1/23/2016 1/23/2016 2.50 PROD2 CASING PMPO P Pump OOH from 10440' MD to 9866' 10,440.0 9,866.0 12:30 15:00 MD. 250 gpm, 2600 psi, PU 130K. Hold 150 psi back pressure. Calc disp=4.32 Act disp=9.22 Pinhole washout observed on stand #103 1/23/2016 1/23/2016 2.00 PROD2 CASING CIRC P Pick up working single. CBU @ 9895' 9,866.0 9,866.0 15:00 17:00 MD. 250 gpm, 2600 psi, 100 rpm, 6K tq, 12.11 ECD. Lay down working single. 1/23/2016 1/23/2016 1.25 PROD2 CASING DISP P Pump and spot at bit 32 bbl 12.2 ppg 9,866.0 9,393.0 17:00 18:15 viscous brine spacer. Lay in spacer from 9866' MD to 9393' MD. 63 gpm, 175 psi. Hold 280 psi back pressure. 1/23/2016 1/23/2016 1.25 PROD2 CASING DISP P Displace 10.5 ppg FLOTHRU mud to 9,393.0 9,393.0 18:15 19:30 12.2 ppg KCI/NaBr brine. 205 gpm, 1450 psi, 80 rpm, 6K tq. 1/23/2016 1/23/2016 1.00 PROD2 CASING OWFF P Blow down TD. Monitor well by 9,393.0 9,393.0 19:30 20:30 pumping across top of hole. Lost .7 bbl/30 min. 1/23/2016 1/23/2016 1.25 PROD2 CASING MPDA P Blow down MPD choke skid and lines. 9,393.0 9,393.0 20:30 21:45 Pull RCD bearing assy. Install trip nipple. 1/23/2016 1/23/2016 0.50 PROD2 CASING SVRG P Service rig 9,393.0 9,393.0 21:45 22:15 1/23/2016 1/24/2016 1.75 PROD2 CASING TRIP P POOH on elevators from 9393' MD to 9,393.0 7,030.0 22:15 00:00 7030' MD PU 125K. Drop 2" rabbit on stand #94. Calc disp=13.5 Act disp=17.34 SPR's @ 8927' MD, 5825' TVD, MW 12.1+ ppg, 22:30 hrs. #1 @ 20 = 220; @ 30 = 480 psi #2 @ 20 = 230; @ 30 = 520 psi 1/24/2016 1/24/2016 4.00 PROD2 CASING TRIP P POOH on elevators from 7030' MD to 7,030.0 414.0 00:00 04:00 414' MD. Calc disp=51.3 bbls Act disp=62.7 bbls 1/24/2016 1/24/2016 0.25 PROD2 CASING OWFF P Monitor well. Static. 414.0 414.0 04:00 04:15 1/24/2016 1/24/2016 3.00 PROD2 CASING BHAH P Lay down jars. Pick up 1 jt HWDP and 414.0 0.0 04:15 07:15 stand back 2 stds HWDP. Lay down BHA # 17. Calc disp=56.6 bbls Act disp=70.5 bbls for trip. 1/24/2016 1/24/2016 1.00 PROD2 CASING BHAH P Clean and clear rig floor. 0.0 0.0 07:15 08:15 Page 54/69 Report Printed: 1/23/2017 s Operations Summary (with Timelog Depths) 2S-13 • i • Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/24/2016 1/24/2016 1.50 COMPZ2 FISH BHAH P Pick up whip stock retrieval BHA. 0.0 366.0 08:15 09:45 Orient MWD 1/24/2016 1/24/2016 0.25 COMPZ2 FISH TRIP P RIH to 1379' MD. 366.0 1,379.0 09:45 10:00 1/24/2016 1/24/2016 0.25 COMPZ2 FISH DHEQ P Shallow test MWD. 200 gpm, 1100 1,379.0 1,379.0 10:00 10:15 psi, 33% FO 1/24/2016 1/24/2016 5.50 COMPZ2 FISH TRIP P RIH from 1379' MD to 9818' MD. Fill 1,379.0 9,818.0 10:15 15:45 pipe every 20 stds. 1/24/2016 1/24/2016 1.25 COMPZ2 FISH CIRC P Break circ. Orient whip stock retrieval 9,818.0 9,917.0 15:45 17:00 hook to 131'R. Wash down to 9927' MD. Wash retrieval slot from 9917' MD to 9927' MD. PU 130K, SO 100K, 250 gpm, 2200 psi. 1/24/2016 1/24/2016 0.75 COMPZ2 FISH FISH T Orient retrieval hook to 50°L. Slack off 9,917.0 9,917.0 17:00 17:45 to 9919' MD. PU and attempt to hook whip stock. No overpull observed. After two attempts turn string to right and set 10K down on bottom of retrieval slot at 9919' MD. PU and attempt to engage whip stock multiple times. No overpull observed. 1/24/2016 1/24/2016 1.00 COMPZ2 FISH CIRC T Orient to 130°R. Wash retrieval slot 9,917.0 9,917.0 17:45 18:45 from 9917' MD to 9927' MD .250 gpm, 2200 psi. 1/24/2016 1/24/2016 1.50 COMPZ2 FISH FISH T Orient to 40°L and attempt to hook 9,917.0 9,917.0 18:45 20:15 whip stock. Set down 5-15K on bottom of retrieval slot @ 9919' MD.Vary flow rates from 180 gpm to 250 gpm/1700 psi to 2200 psi. Able to set down on slot from 40°L to 19°L orientation. 1/24/2016 1/24/2016 0.25 COMPZ2 FISH CIRC T Orient to 130°R. Wash retrieval slot 9,917.0 9,915.0 20:15 20:30 from 9915' MD to 9927' MD. 290 gpm,3100 psi. Partial packoffs observed when passing top of whip stock. 1/24/2016 1/24/2016 1.50 COMPZ2 FISH FISH T Orient to 40°L and attempt to hook 9,915.0 9,915.0 20:30 22:00 whip stock. Set down 5-15K on bottom of retrieval slot @ 9919' MD.Vary flow rates from 180 gpm to 250 gpm/1700 psi to 2200 psi. Able to set down on slot from 58°L to 7°L orientation. 1/24/2016 1/24/2016 1.50 COMPZ2 FISH FISH T Consult with Rig Engineer and Drilling 9,915.0 9,913.0 22:00 23:30 Superintedent. Work hook 360° while attempting to engage whip stock.. No overpull observed. Observe set down weight on bottom of slot from 54°L to 13°L orientation. 180 gpm, 1300 psi with intermittent pack offs. 1/24/2016 1/25/2016 0.50 COMPZ2 FISH CIRC T Lay down single jt DP. Pump and spot 9,913.0 9,913.0 23:30 00:00 32 bbl 12.2 ppg viscous pill. 1/25/2016 1/25/2016 0.50 COMPZ2 FISH CIRC T Spot 32 bbls 12.2 ppg viscous brine 9,913.0 9,913.0 00:00 00:30 pill 1/25/2016 1/25/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static. 9,913.0 9,913.0 00:30 01:00 1/25/2016 1/25/2016 4.75 COMPZ2 FISH TRIP T POOH from 9913' MD to 3009' MD. 9,913.0 3,009.0 01:00 05:45 I Page 55169 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time I End Time I Our thr) Phase nn Cnda n ry w 1�, . I Ti- o_T v Sfart Depth 1/25/2016 1/25/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static. 3,009.0 3,009.0 05:45 06:15 1/25/2016 1/25/2016 2.00 COMPZ2 FISH TRIP T POOH from 3009' MD to 366' MD. 3,009.0 366.0 06:15 08:15 Calc disp=54.5 bbls Act disp=62.1 bbls 1/25/2016 1/25/2016 0.25 COMPZ2 FISH OWFF T Monitor well. 366.0 366.0 08:15 08:30 1/25/2016 1/25/2016 1.25 COMPZ2 FISH BHAH T Stand back 3 stands HWDP. Lay 366.0 0.0 08:30 09:45 down BHA as per Baker rep. Calc disp=57 bbis Act disp=66.2 bbls for trip. 1/25/2016 1/25/2016 0.25 COMPZ2 WHDBOP RURD T Pull wear bushing 0.0 0.0 09:45 10:00 1/25/2016 1/25/2016 0.75 COMPZ2 WHDBOP WWWH T Make up stack washer. Flush BOPE. 0.0 0.0 10:00 10:45 Lay down stack washer 1/25/2016 1/25/2016 2.25 COMPZ2 WHDBOP RURD T Rig up to test BOPS. 0.0 0.0 10:45 13:00 1/25/2016 1/25/2016 7.00 COMPZ2 WHDBOP BOPE T PJSM; test BOPE w/ 4" test joint to 0.0 0.0 13:00 20:00 250/3500 psi for 5 min each. #1: Top pipe rams, CV 1, 12,13, 14 & manual kill valve. #2: Upper IBOP, HCR kill, CV 9, & 11. #3: Lower IBOP (Lower IBOP failed initial test was cycled and passed retest), CV 5,8 & 10. #4: Dart, CV 4,6 & 7. #5: FOSV and CV 2. #6: HCR choke, 4" kill line Demco valve. # 7: Manual choke valve & HCR kill. #8: Annular preventer tested to 250/2500 psi. #9 Lower VBR's. #10 Blind rams, CV 3 #11 Upper VBR's w/ 4 1/2" test jt. #12 Annular preventer tested to 250/2500 psi. w/ 4 1/2" test jt. Perform draw down on chokes.Accumulator Draw Down - Initial system pressure 3000 psi, pressure after closure 1800 psi, 200 psi attained in 39 sec, full pressure attained in 177 sec, 5 nitrogen bottles averaged 1910 psi. Tested pit level sensors & gas alarms. Test witness waived by AOGCC rep Brian Bixby. 1/25/2016 1/25/2016 1.50 COMPZ2 WHDBOP RURD T Rig down test equipment. Set 12.32" 0.0 0.0 20:00 21:30 ID wear bushing. Blow down choke and kill lines. Reposition trip nipple. 1/25/2016 1/25/2016 1.25 COMPZ2 FISH BHAH T Pick up whip stock retrieval BHA. 0.0 366.0 21:30 22:45 Orient MWD 1/25/2016 1/25/2016 0.25 COMPZ2 FISH TRIP T RIH to 1498' MD. 366.0 1,498.0 22:45 23:00 1/25/2016 1/25/2016 0.25 COMPZ2 FISH DHEQ T Shallow test MWD. 200 gpm, 2000 1,498.0 1,498.0 23:00 23:15 psi. Blow down TD. 1/25/2016 1/26/2016 0.75 COMPZ2 FISH TRIP T RIH from 1498' MD to 3197' MD. Fill 1,498.0 3,197.0 23:15 00:00 pipe 1/26/2016 1/26/2016 3.50 COMPZ2 FISH TRIP T PJSM. RIH from 3197' MD to 8872' 3,197.0 8,872.0 00:00 03:30 MD. Fill every 20 stands. Calc disp=52.8 bbls Act disp=50.1 bbls 1/26/2016 1/26/2016 1.50 COMPZ2 FISH SLPC T PJSM. Slip and cut 78' drilling line. 8,872.0 8,872.0 03:30 05:00 Service top drive. Page 56/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) .t* X41 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/26/2016 1/26/2016 1.00 COMPZ2 FISH TRIP T RIH from 8872' MD to 9913' MD. 8,872.0 9,913.0 05:00 06:00 Calc disp=58.2 bbls Act disp=55.1 bbls 1/26/2016 1/26/2016 0.50 COMPZ2 FISH CIRC T Break circ. Orient whip stock retrieval 8,913.0 8,919.0 06:00 06:30 hook to 130°R. Wash down to 9927' MD. Wash retrieval slot from 9917' MD to 9926' MD. PU 160K, SO 90K, 200 gpm, 1000 psi. 1/26/2016 1/26/2016 2.00 COMPZ2 FISH FISH T Orient retrieval hook to 51°L. Attempt 8,919.0 8,919.0 06:30 08:30 to hook whip stock. No overpull observed. Orient to 44°L,31 °L, 38°L, 48°L attempting to hook whipstock. No overpull observed. At 60°L set down 1 OK wt. on bottom of retrieval slot. PU and observe 75K overpull and fire jar. PU 90K overpull. Work pipe between 250K hoist wt and 120K slack wt. 1/26/2016 1/26/2016 0.75 COMPZ2 FISH FISH T Pick up 290K hoist wt. Observe hoist 8,919.0 8,919.0 08:30 09:15 wt drop to 265K. Continue to pull to 300K hoist wt. Work drill string between 300K and 120K. 1/26/2016 1/26/2016 1.75 COMPZ2 FISH JAR T Cock and fire jar w/100K overpull. Pull 8,919.0 8,919.0 09:15 11:00 to 300K. Observe 8' travel up and down. Anchor is 8" below whipstock. Suspect anchor hanging up on bottom of window. Anchor OD is 6 1/8". Fire jar 13 X. 1/26/2016 1/26/2016 0.50 COMPZ2 FISH SFTY T Perform derrick inspection 8,919.0 8,919.0 11:00 11:30 1/26/2016 1/26/2016 1.50 COMPZ2 FISH JAR T Jar on whip stock w/100K overpull. 8,919.0 8,919.0 11:30 13:00 Pull up to 320K. Fire jar 7 X. 1/26/2016 1/26/2016 0.25 COMPZ2 FISH SFTY T Perform derrick inspection 8,919.0 8,919.0 13:00 13:15 1/26/2016 1/26/2016 1.25 COMPZ2 FISH JAR T Jar on whip stock w/100K overpull. 8,919.0 8,919.0 13:15 14:30 Pull up to 350K. Fire jar 20 X. 1/26/2016 1/26/2016 1.00 COMPZ2 FISH JAR T Cock jar. Pick up to neutral weight. 8,919.0 8,908.0 14:30 15:30 Turn on MWD. MWD showing whip stock oriented to 44°L. Turn drill string and orient whip stock to 14°L. Jar on whip stock w/100K overpull. Pull up to 350K. Move whip stock up 3'. Cock jar. Lost free travel of fish. Fire jar 32 X. 1/26/2016 1/26/2016 0.25 COMPZ2 FISH SFTY T Inspect top drive. 8,908.0 8,908.0 15:30 15:45 1/26/2016 1/26/2016 2.00 COMPZ2 FISH JAR T Jar on whip stock w/100K overpull. 8,908.0 8,919.0 15:45 17:45 Pull up to 350K. Recover free travel of 8'. Fire jar 27 X. Hook slipping out of slot while cocking jar. 1/26/2016 1/26/2016 1.00 COMPZ2 FISH OWFF T Monitor well. Static. Inspect top drive 8,919.0 9,908.0 17:45 18:45 and derrick. Lay down single jt DP. 1/26/2016 1/26/2016 5.00 COMPZ2 FISH TRIP T POOH from 9908' MD to 366' MD. PU 9,908.0 366.0 18:45 23:45 160K. Calc disp=54.54 bbls Act disp=57.22 bbls 1/26/2016 1/27/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 366.0 366.0 23:45 00:00 1/27/2016 1/27/2016 0.25 COMPZ2 FISH OWFF T OWFF, static. 366.0 366.0 00:00 00:15 Page 57/69 Report Printed: 1/23/2017 s Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time indTjme Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/27/2016 1/26 1.00 COMPZ2 FISH BHAH T PJSM, UD whipstock fishing BHA. UD 366.0 0.0 00:15 01:15 9 joints of HWDP, XO, Pump out sub, Float sub, Oil Jars and Bent hook. Observed hook missing the jet. Actual displacement= 3.4 bbis, Calculated displacement= 3.4 bbis 1/27/2016 1/27/2016 0.25 COMPZ2 FISH BHAH T Mobilize fishing tools to rig floor. 0.0 0.0 01:15 01:30 1/27/2016 1/27/2016 1.50 COMPZ2 FISH BHAH T PJSM, M/U BHA as per Baker rep. 0.0 322.0 01:30 03:00 Bull noise, 6.75' OD string mill, Oil jars and 4-3/4" DC. Actual displacement= 4.2 bbis. Calculated displacement= 5.5 bbls. 1/27/2016 1/27/2016 4.00 COMPZ2 FISH TRIP T RIH w/ string mill on 4" DP f/ 322' MD 322.0 9,869.0 03:00 07:00 to 9869' MD, filling every 20 stands. Actual displacement= 58.1 bbls, Calculated displacement = 60 bbis. 1/27/2016 1/27/2016 0.50 COMPZ2 FISH WASH T Wash down to 9914.79' MD, no 9,869.0 9,914.8 07:00 07:30 obstruction in casing observed. P/U= 153K, S/0= 90K, ROT= 115K w/ 7K tq, Pump @ 6 bpm=910 psi w/ 40% F0. Obtain SPR's @ 9882' MD TVD= 6237', MW=12.1+ 7:00 hours MP#1: 20 spm=110 psi, 30 spm=230 psi MP #2: 20 spm= 90 psi, 30 spm= 220 psi. 1/27/2016 1/27/2016 1.00 COMPZ2 FISH CIRC T Circaulte and condtion fluid, add 1 % 9,914.8 9,914.8 07:30 08:30 v/v of SafeLube to system. Pump @ 6 bpm=910 psi, 40% FO. 1/27/2016 1/27/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static. 9,914.8 9,914.0 08:30 09:00 1/27/2016 1/27/2016 5.25 COMPZ2 FISH TRIP T POOH from 9914' MD to 385' MD. 9,914.0 385.0 09:00 14:15 1/27/2016 1/27/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 385.0 385.0 14:15 14:30 1/27/2016 1/27/2016 0.50 COMPZ2 FISH BHAH T Stand back 4 3/4" DC's. Lay down mill 385.0 0.0 14:30 15:00 and bullnose. Calc disp=60 bbis Act disp=65.76 bbis for trip. 1/27/2016 1/27/2016 0.25 COMPZ2 FISH BHAH T Clear rig floor. Mobilize fishing tools to 0.0 0.0 15:00 15:15 floor. 1/27/2016 1/27/2016 1.25 COMPZ2 FISH BHAH T Make up bent retrieval tool BHA. Bent 0.0 373.0 15:15 16:30 hook, oil jar, float sub, MWD, 4 3/4" DC's, intensifier, pump out sub. 1/27/2016 1/27/2016 0.50 COMPZ2 FISH TRIP T RIH with fishing BHA to 1316' MD. 373.0 1,316.0 16:30 17:00 1/27/2016 1/27/2016 0.25 COMPZ2 FISH DHEQ T Shallow test MWD. 200 gpm, 775 psi. 1,316.0 1,316.0 17:00 17:15 1/27/2016 1/27/2016 3.50 COMPZ2 FISH TRIP T RIH with fishing BHA from 1316' MD 1,316.0 8,219.0 17:15 20:45 to 8219' MD Fill pipe every 20 stds. Calc disp=51.08 bbis Act disp=50 bbis Page 58/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/27/2016 1/27/2016 0.75 COMPZ2 FISH CIRC T Observed no returns to surface. 8,219.0 8,219.0 20:45 21:30 Monitor well. Fluid level dropping in annulus. Fluid u -tubing up drillstring. Circulate drill pipe volume. 250 gpm, 1700 psi. No losses, no gains. Monitor well. Static 1/27/2016 1/27/2016 0.75 COMPZ2 FISH TRIP T RIH from 8219' MD to 9815'MD. 8,219.0 9,815.0 21:30 22:15 Calc disp=59.72 Act disp=59.45 bbls 1/27/2016 1/27/2016 1.25 COMPZ2 FISH CIRC T Break circ. Wash down from 9815' MD 9,815.0 9,926.0 22:15 23:30 to 9926' MD. Orient to 155°R. Wash retrieval slot. PU 140K SO 95K 1/27/2016 1/28/2016 0.50 COMPZ2 FISH FISH T Orient to 20°L. Attempt to hook whip 9,926.0 9,905.0 23:30 00:00 stock. Orient to 60°L. Hook whip stock at 9915' MD. Pick up to 175K. Fire jar. 1/28/2016 1/28/2016 3.50 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K, 9,905.0 9,915.0 00:00 03:30 24 gpm, 80 psi. Warm up jar w/50K over pull/ pull to 100K over. Work up to jar at 100K over pull/pulling to 200K over. Fire jar 70X. 1/28/2016 1/28/2016 0.50 COMPZ2 FISH SFTY T Inspect derrick and top drive. 9,915.0 9,915.0 03:30 04:00 1/28/2016 1/28/2016 4.00 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K. 9,915.0 9,905.0 04:00 08:00 24 gpm, 80 ps. Jar at 100K over pull/pulling to 200K over. Move whip stock up hole to 9905' MD. MWD indicates fish rotating as it is worked through free travel. Fire jar 64X. 1/28/2016 1/28/2016 1.25 COMPZ2 FISH SFTY T Inspect derrick and top drive. Consult 9,905.0 9,905.0 08:00 09:15 with Drilling Engineer. 1/28/2016 1/28/2016 2.75 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K. 9,905.0 9,895.0 09:15 12:00 24 gpm, 80 ps. Jar at 100K over pull/pulling to 200K over. Move whip stock up hole to 9895' MD. Fire jar 32X. 1/28/2016 1/28/2016 5.75 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K. 9,895.0 9,883.0 12:00 17:45 48 gpm, 200 psi. Jar at 100K over pull/pulling to 200K over. Move whip stock up hole to 9883' MD. Free travel down to 9923' MD. Fire jar 79 X. 1/28/2016 1/28/2016 0.75 COMPZ2 FISH SFTY T Inspect derrick and top drive. 9,883.0 9,883.0 17:45 18:30 1/28/2016 1/29/2016 5.50 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K. 9,883.0 9,881.0 18:30 00:00 48 gpm, 200 psi. Jar at 100K over pull/pulling to 215K over. Move whip stock up hole to 9881' MD. Free travel down to 9923' MD. Fire jar 90 X. 1/29/2016 1/29/2016 0.50 COMPZ2 FISH JAR T Jar on whip stock @ 9881' MD. PU 9,881.0 9,115.0 00:00 00:30 150K SO 95K. 180 gpm, 1100 psi. Jar at 100K over pull/pulling to 215K over. Free travel down to 9923' MD. Fire jar 4 X. Set whip stock back down to 9115' MD. Page 59/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/29/2016 1/29/2016 3.00 COMPZ2 FISH FISH T Attempt to release hook. Orient whip 9,115.0 9,115.0 00:30 03:30 stock to 32°L. Slack off to 55K 3X. On third attempt observed hook jump out of retrieval slot. Slack off to 9928' MD. Wash fill 200 gpm, 1150 psi. Orient hook to 45° R. PU and observe overpull at 9907' MD. Slack off and orient hook to 60°R. Shut down pump. PU and observe overpull @ 9907' MD. Slack off and orient hook 130°R. PU and observe overpull @ 9907' MD. 1/29/2016 1/29/2016 1.25 COMPZ2 FISH SFTY T Inspect derrick and TD. 9,115.0 9,115.0 03:30 04:45 1/29/2016 1/29/2016 2.50 COMPZ2 FISH FISH T Orient hook 561. Wash down to 9934' 9,115.0 9,857.0 04:45 07:15 MD. Orient hook to 150°R. PU and observe overpull @ 9907' MD. Slack off and orient hook to 45°L working drill string from 9907' MD to 9916' MD. PU and encounter overpull @ 9881' MD. Pull 100K over. Orient hook to 120°L. PU to 9857' MD. No overpull observed. SPR's @ 9857' MD TVD= 6231', MW=12.23 07:00 hours MP #1: 20 spm=180 psi, 30 spm=400 psi MP #2: 20 spm=170 psi, 30 spm=390 psi. 1/29/2016 1/29/2016 0.75 COMPZ2 FISH OWFF T Monitor well. Gas breaking out at 9,857.0 9,857.0 07:15 08:00 surface. 1/29/2016 1/29/2016 1.00 COMPZ2 FISH CIRC T CBU. 290 gpm, 2340 psi. 9,857.0 9,857.0 08:00 09:00 1/29/2016 1/29/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static. 9,857.0 9,857.0 09:00 09:30 1/29/2016 1/29/2016 6.50 COMPZ2 FISH TRIP T Blow down TD. POOH from 9857' MD 9,857.0 373.0 09:30 16:00 to 373' MD. Observed 22K overpull @ 8250' MD. 1/29/2016 1/29/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 373.0 373.0 16:00 16:15 1/29/2016 1/29/2016 1.00 COMPZ2 FISH BHAH T Lay down pump out sub and 373.0 0.0 16:15 17:15 intensifier. Stand back 3 stands 4 3/4" drill collars. Lay down MWD, jar, one joint 3 1/2" HWDP and bent retrieval tool. No fish. Calc disp=58.55 bbls Act disp=66.34 bbls for trip 1/29/2016 1/29/2016 0.75 COMPZ2 FISH BHAH T Clean and clear rig floor. 0.0 0.0 17:15 18:00 1/29/2016 1/29/2016 1.75 COMPZ2 FISH ELOG T PJSM- Rig up wireline. Make up 0.0 0.0 18:00 19:45 wireline tools. 1/29/2016 1/29/2016 3.00 COMPZ2 FISH ELOG T RIH with wireline tools to 9915' MD. 40 0.0 0.0 19:45 22:45 arm caliper/GR/CCI/tractor. Run caliper log from 9915' MD to 9600' MD. 1/29/2016 1/30/2016 1.25 COMPZ2 FISH ELOG T POOH with wire line. 0.0 0.0 22:45 00:00 Total losses for tour=3.24 bbls 1/30/2016 1/30/2016 0.50 COMPZ2 FISH ELOG T POOH w/wireline 0.0 0.0 00:00 00:30 1/30/2016 1/30/2016 0.50 COMPZ2 FISH ELOG T Change out 40 arm caliper tool 0.0 0.0 00:30 01:00 Page 60/69 Report Printed: 1/23/2017 i . "y. Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/30/2016 1/30/2016 2.50 COMPZ2 FISH ELOG T RIH with wireline tools to 9915' MD. 40 0.0 0.0 01:00 03:30 arm caliper/GR/CCI/tractor. Run caliper log from 9915' MD to 9600' MD. 1/30/2016 1/30/2016 2.00 COMPZ2 FISH ELOG T POOH w/wireline 0.0 0.0 03:30 05:30 1/30/2016 1/30/2016 1.00 COMPZ2 FISH ELOG T Lay down wireline tools. Rig down 0.0 05:30 06:30 wireline equipment. 1/30/2016 1/30/2016 1.25 COMPZ2 FISH BHAH T Mobilize Baker fishing tools to rig floor. 0.0 0.0 06:30 07:45 1/30/2016 1/30/2016 1.75 COMPZ2 FISH BHAH T Make up clean out BHA. PU bullnose, 0.0 369.0 07:45 09:30 flex jt, string mill, 3 1/2" HWDP jt, string magnet, x -o, boot basket x2, bit sub, float sub, jar, x -o. 4 3/4" DC's x9, x -o, intensifier, pump out sub, x -o. 1/30/2016 1/30/2016 4.25 COMPZ2 FISH TRIP T RIH to 9822' MD. Fill every 20 stds. 369.0 9,822.0 09:30 13:45 PU 140K SO 95K Calc disp=60.27 bbls Act disp=56.85 bbls 1/30/2016 1/30/2016 1.75 COMPZ2 FISH MILL T Break circ. Wash down and tag up at 9,822.0 9,912.0 13:45 15:30 9888' MD (mill depth). Ream f/9888' MD t/9900' MD (mill depth) 80 rpm, 350 gpm, 1800 psi, 5-8K WOB.. Work pipe f/9900' MD U9888' MD (mill depth) x2. No excessive drag up or down. Ream (/9900' MD t/9910' MD (mill depth) x5. Torque @ 6.5-7K. After 5th ream observed erratic torque @ 6.5-1 OK. Ream f/9910' MD t/9921' MD (mill depth). Bull nose @ 9931' MD. WOB 1-21K. Experiencing 500- 800 psi pump pressure spikes and steady torque @ 8.5-9K. Appear to be cutting new window. Pump viscous SuperSweep. Ream up to 9912' MD (bull nose depth). Shut down rotary and stage pump up to 400 gpm, 2290 psi. 1/30/2016 1/30/2016 0.75 COMPZ2 FISH CIRC T Circulate sweep out of hole. 400 gpm, 9,912.0 9,912.0 15:30 16:15 2290 psi. Did not observe any debris at shakers with sweep. 1/30/2016 1/30/2016 0.50 COMPZ2 FISH OWFF T Lay down working single DP. Blow 9,902.0 9,916.0 16:15 16:45 down TD. Monitor well. Static. 1/30/2016 1/30/2016 2.25 COMPZ2 FISH TRIP T POOH from 9916' MD to 6986' MD. 9,916.0 6,986.0 16:45 19:00 PU 150K. Observed 20K drag pulling mill through stage collar @ 8920' MD. 1/30/2016 1/30/2016 1.00 COMPZ2 FISH SVRG T Service rig. 6,986.0 6,986.0 19:00 20:00 1/30/2016 1/30/2016 2.75 COMPZ2 FISH TRIP T POOH from 6986' MD to 369' MD. 6,986.0 369.0 20:00 22:45 1/30/2016 1/30/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 369.0 369.0 22:45 23:00 1/30/2016 1/31/2016 1.00 COMPZ2 FISH BHAH T Lay down string mill BHA as per Baker 369.0 56.0 23:00 00:00 fishing hand. Stand back 3 stds 4 3/4" DC's. Calc disp=60.82 bbls Act disp=64 bbls for trip. 1/31/2016 1/31/2016 0.50 COMPZ2 FISH BHAH T PJSM-Lay down string mill BHA as 56.0 0.0 00:00 00:30 1 per Baker fishing hand. Page 61/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/31/2016 1/31/2016 0.75 COMPZ2 FISH BHAH T Clean and clear rig floor. 0.0 0.0 00:30 01:15 1/31/2016 1/31/2016 1.75 COMPZ2 FISH SLPC T PJSM-Slip and cut 65' drilling line. 0.0 0.0 01:15 03:00 1/31/2016 1/31/2016 1.75 COMPZ2 FISH BHAH T PJSM-Make up bent retrieval tool BHA 0.0 290.0 03:00 04:45 as per Baker fishing hand. PU bent retrieval tool, 3 1/2" HWDP jt, bumper sub, jar, float sub, MWD, x -o, 4 3/4" DC's x6, x -o, intensifier, pump out sub, x -o. 1/31/2016 1/31/2016 0.25 COMPZ2 FISH TRIP T RIH from 290' MD to 1706' MD. 290.0 1,706.0 04.45 05:00 1/31/2016 1/31/2016 0.25 COMPZ2 FISH DHEQ T Shallow test MWD. 1,706.0 1,706.0 05:00 05:15 1/31/2016 1/31/2016 2.75 COMPZ2 FISH TRIP T RIH from 1706' MD to 9838' MD. Fill 1,706.0 9,838.0 05:15 08:00 every 20 stds. Calc disp=59.62 bbls Act disp=56.29 bbls 1/31/2016 1/31/2016 0.50 COMPZ2 FISH FISH T Break circ. Obtain SPR's and 9,838.0 9,838.0 08:00 08:30 parameters. PU 140K SO 95K, 204 gpm, 1440 psi. Orient jet to138°R. SPR's @ 9838' MD TVD= 6231', MW= 12.23 08:15 hours MP #1: 20 spm=240 psi, 30 spm=520 psi MP #2: 20 spm=240 psi, 30 spm=520 psi. 1/31/2016 1/31/2016 1.00 COMPZ2 FISH FISH T Wash down to 9919' MD. Observed 9,838.0 9,840.0 08:30 09:30 slight tag up @ 9917' MD. Set 5K down wt @ 991 9'MD. Down wt. fell off set 5K down @ 9921' MD. Wash fill down to 9931' MD. Wash retrieval slot 3x working drillstring from 9930' MD to 9920' MD. Observed 3K drag while pulling up. No drag while slacking off. Pull up to orient hook. Observed 15K overpull @ 9905' MD.Slack off and turn drill string 90° to the right. Pull up to 9840' MD. No overpull observed. 1/31/2016 1/31/2016 1.00 COMPZ2 FISH FISH T Orient to 41°L. RIH Wash down to 9,840.0 9,920.0 09:30 10:30 9914' MD. PU to 9877' MD to confirm hook not in retrieval slot. Did not see any overpull or tool face changes. RIH to 9929' MD. Work drill string attempting to locate retrieval slot. Pull up to 9900' MD. Slack off and tag @ 9917' MD. Pull up to 9875' MD. Slack off and tag @ 9917' MD. Maintain 10K down wt and wash down to 9920' MD. Page 62/69 Report Printed: 1/23/2017 e Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/31/2016 1/31/2016 3.50 COMPZ2 FISH FISH T Pick up to 9840' MD and orient to 140° 9,920.0 9,830.0 10:30 14:00 R. RIH to 9930' MD and wash retrieval slot. No set down wt or overpull observed. Reorient and attempt to locate retrieval slot. Working pipe from 15°L to 65°L. Did not observe indications of locating slot. PU to 9875' MD. Slack off and tag up @ 9917' MD. Orient to 140°R. Slack off and wash retrieval slot. Reorient and attempt to locate retrieval slot, working pipe from 30°R to 125°L.No indications of retrieval slot observed. PU to 9830' MD. 1/31/2016 1/31/2016 1.25 COMPZ2 FISH FISH T Orient to 41°L. Slack off and attempt 9,830.0 9,838.0 14:00 15:15 to locate retrieval slot without circulating. No indications of slot. Start pumping and jet plugged. 170 gpm,3500 psi.Work pump on and off to unplug jet. Continue to work pipe to locate retrieval slot. Tag up @ 9919' MD 3x. Pick up to 9910' MD and observed tool face shift to right, from 40°L to 20°L, 30°L to 15°L and 20°L to 9°L. Pull up and observe 20K overpull @ 9906' MD. Continue to pull up and observe 20K overpull @ 9900' MD. While pulling up tool face shifted to 30°R. PU to 9838' MD with no overpull. Stand back one stand DP. Blow down TD. 1/31/2016 1/31/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 9,838.0 9,838.0 15:15 15:30 1/31/2016 1/31/2016 0.50 COMPZ2 FISH TRIP T POOH from 9838' MD to 9648' MD 9,838.0 9,648.0 15:30 16:00 monitoring for swab and overpull. No swab or overpull observed. Fluid level dropping in BOPE as drill string is hoisted. 1/31/2016 1/31/2016 5.75 COMPZ2 FISH TRIP T POOH from 9648' MD to 290' MD. 9,648.0 290.0 16:00 21:45 1/31/2016 1/31/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 290.0 290.0 21:45 22:00 1/31/2016 1/31/2016 1.00 COMPZ2 FISH BHAH T Lay down BHA as per Baker fishing 290.0 0.0 22:00 23:00 hand. Lay down intensifier. Stand back 2 stds 4 3/4" DC's, Lay down MWD and bumper sub. Lay down retrieval tool. No fish. Calc disp=56.34 bbls Act disp=63 bbls 1/31/2016 1/31/2016 0.50 COMPZ2 FISH BHAH T Clean and clear rig floor. 0.0 0.0 23:00 23:30 1/31/2016 2/1/2016 0.50 COMPZ2 FISH SVRG T Service rig. Lube drawworks, TD and 0.0 0.0 23:30 00:00 traveling blocks. 2/1/2016 2/1/2016 0.75 COMPZ2 FISH BHAH T PJSM, M/U Baker box tap as per 0.0 237.0 00:00 00:45 Baker rep. 2/1/2016 2/1/2016 4.00 COMPZ2 FISH TRIP T RIH f/ 237' MD t/ 9784' MD filling pipe 237.0 9,784.0 00:45 04:45 every 20 stands. Actual displacement= 55.3 bbls, Calculated displacement=58.5 bbls. Page 63/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 AA 41 • Rig: DOYON 141 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) 2/1/2016 2/1/2016 0.25 COMPZ2 FISH FISH T Break circ. Obtain SPR's and 9,784.0 9,784.0 04:45 05:00 parameters. PU 143K SO 90K Rot 115K 168 gpm, 450 psi. 20 rpm, 5K tq, SPR's @ 9784' MD TVD= 6215', MW=12.22 05:00 hours MP #1: 20 spm=200 psi, 30 spm=420 psi MP #2: 20 spm=220 psi, 30 spm=400 psi. 2/1/2016 2/1/2016 3.25 COMPZ2 FISH FISH T Wash down from 9784' MD to 9811' 9,784.0 9,920.0 05:00 08:15 MD. 168 gpm, 520 psi. Shut down pump, attempt to engage whip stock to 9919' MD (20 rpm, 5K tq). Slight down drag @ 9914' MD. PU to 9910' MD and slack off to 9921' MD. Did not observe any torque increase. PU to 9910' MD. Pump @ 84 gpm, 500 psi. Slack off without rotary to 9920' MD. Work box tap between 9910' MD and 9922' MD with rotary on/rotary off, pump on/pump off. Work two turns lefthand torque to box tap . Unable to engage fish. 2/1/2016 2/1/2016 0.25 COMPZ2 FISH TRIP T Consult with Drilling Engineer. 9,920.0 9,879.0 08:15 08:30 Decision made to POOH. POOH from 9920' MD to 9879' MD. Blow down TD 2/1/2016 2/1/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static 9,879.0 9,879.0 08:30 09:00 2/1/2016 2/1/2016 3.50 COMPZ2 FISH TRIP T POOH from 9879' MD to 237' MD. 9,879.0 237.0 09:00 12:30 Calc disp=59.04 bbls Act disp=64.79 bbls 2/1/2016 2/1/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 237.0 237.0 12:30 12:45 2/1/2016 2/1/2016 0.25 COMPZ2 FISH BHAH T Lay down box tap BHA as per Baker 237.0 0.0 12:45 13:00 fishing hand. Stand back 2 std's 4 3/4" DC's. Lay down pumo out sub and box tap. 2/1/2016 2/1/2016 0.50 COMPZ2 FISH BHAH T Clean and clear rig floor. 0.0 0.0 13:00 13:30 2/1/2016 2/1/2016 1.50 COMPZ2 FISH BHAH T PJSM-Make up bent retrieval tool BHA 0.0 290.0 13:30 15:00 as per Baker fishing hand. PU bent retrieval tool, 3 1/2" HWDP jt, bumper sub, jar, float sub, MWD, x -o, 4 3/4" DC's x6, x -o, intensifier, pump out sub, x -o. 2/1/2016 2/1/2016 0.25 COMPZ2 FISH TRIP T RIH to 1234' MD 290.0 1,234.0 15:00 15:15 2/1/2016 2/1/2016 0.25 COMPZ2 FISH DHEQ T Shallow test MWD. 200 gpm, 700 psi. 1,234.0 1,234.0 15:15 15:30 Blow down TD 2/1/2016 2/1/2016 3.50 COMPZ2 FISH TRIP T RIH from 1234' MD to 9838' MD. PU 1,234.0 9,838.0 15:30 19:00 140K SO 93K. PU 140K SO 94K w/pumps on. Calc disp=59.21 bbls Act disp=56.35 bbls Page 64/69 Report Printed: 1/23/2017 { Operations Summa with Timelog Depths) 2S-13 Rig: DOYON 141 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) 2/1/2016 2/1/2016 2.50 COMPZ2 FISH FISH T Wash down from 9838' MD to 9924' 9,838.0 9,831.0 19:00 21:30 MD oriented 60°R. Work pipe between 9924' MD and 9917' MD orienting to 43°L. Slack off 10K at 9920' MD. Pick up to 9981' MD. Observed 15K overpull. Slack off drillstring and orient to 150°R to wash retrieval slot. Wash slot from 9925' MD to 9928' MD.275 gpm, 2200 psi. Orient hook to 43°L. Set down 15K at 9920' MD. Weight abruptly fell off.Pick up drillstring to 9870' MD. Did not see any overpull at 9881' MD. Turn off pump and pull up to 9931' MD monitoring for swab. No swab and fluid level dropping in BOPE. 2/1/2016 2/2/2016 2.50 COMPZ2 FISH FISH T Slack off drill string to 9922' MD. Pick 9,831.0 9,915.0 21:30 00:00 up and orient to 150°R to wash slot. Wash down to 9925' MD with 25K. Orient to 43°L. Set down 20K at 9920' MD. Pick up drill string, did not see overpull. Work drill string between 9922' MD and 9906' MD. Set down 15K twice more at 9920' MD. No overpull observed while picking up drill string after setting down at 9920' MD. 2/2/2016 2/2/2016 2.75 COMPZ2 FISH FISH T PJSM; continue to fish whipstock. Try 9,915.0 9,838.0 00:00 02:45 numerous time to find bottom of slot, 275 gpm, 1800 psi. Pick up to 9983'& observe tool face shift to left with over pull, indicating hook dragging up split casing. Slack of to 9915' them pick up to 9890' & orient to 150° right. Slack off to 9921' setting 1 OK down. Reorient hook to 43° left. Work string f/ 9921'-9912'. Slack off to 9921' set 1 OK down. Pick up & observe 10K overpull @ 9916', continuing to pick up to 9838' without tool face changing & no overpull. (Decision made to TOH) 2/2/2016 2/2/2016 0.75 COMPZ2 FISH OWFF T Monitor well, observe gas bubbles 9,838.0 9,838.0 02:45 03:30 breaking out at surface. 2/2/2016 2/2/2016 0.75 COMPZ2 FISH CIRC T CBU at 300 gpm, 2000 psi, FO 46%. 9,838.0 9,838.0 03:30 04:15 2/2/2016 2/2/2016 0.50 COMPZ2 FISH OWFF T Monitor well, static. 9,838.0 9,838.0 04:15 04:45 2/2/2016 2/2/2016 6.50 COMPZ2 FISH TRIP T PJSM; TOH f/ 9838'-290' MD, 9,838.0 290.0 04:45 11:15 observed overpull at 8917' (stage collar), calculated fill 57.4, actual 62.6 bbls. 2/2/2016 2/2/2016 0.50 COMPZ2 FISH BHAH T PJSM; rack back 2 stands of collars & 290.0 0.0 11:15 11:45 pull BHA to floor w/ no fish. 2/2/2016 2/2/2016 2.00 COMPZ2 FISH WAIT T Clear & clean rig floor, perform derrick 0.0 0.0 11:45 13:45 inspection, & unload 4-1/2" liner from shed while waiting for a decision from town. 2/2/2016 2/2/2016 0.25 COMPZ2 FISH BHAH T Lay down Baker hook assembly. 0.0 0.0 13:45 14:00 2/2/2016 2/2/2016 0.50 COMPZ2 FISH BHAH T PJSM; mobilize BHA to rig floor. 0.0 0.0 14:00 14:30 1 Page 65/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (WS) End Depth MKS) 2/2/2016 2/2/2016 1.25 COMPZ2 FISH BHAH T PJSM; pick up clean out BHA per 0.0 286.0 14:30 15:45 Baker Rep. to 286' MD. 2/2/2016 2/2/2016 3.75 COMPZ2 FISH TRIP T PJSM; TIH f/ 286'-9834' MD, PU 286.0 9,834.0 15:45 19:30 142K, SO 90K, calculated displacement 59.5, actual 59.2 bbls. 2/2/2016 2/2/2016 1.25 COMPZ2 FISH WASH T Break circulation & wash down f/ 9,834.0 9,915.0 19:30 20:45 9834'-9918' two times at 200 gpm, 700 psi. Could not wash past 9918'. Rotate 40 rpm w/ same parameters to 9926' MD & stall out w/ 9K Tq. Shut off rotary & attempt to wash down working the pipe several times from 9915'-9926'@ 300 gpm, 1500 psi, FO 44%. SPR's @ 9905' MD TVD= 6228', MW=12.3+ 19:30 hours MP #1: 20 spm=120 psi, 30 spm=280 psi MP #2: 20 spm=130 psi, 30 spm=260 psi. 2/2/2016 2/2/2016 1.00 COMPZ2 FISH CIRC T Pump high -vis super sweep around @ 9,915.0 9,915.0 20:45 21:45 300 gpm, 1500 psi, FO 44%. Observe minimal increase in returns. 2/2/2016 2/2/2016 0.25 COMPZ2 FISH PMPO T PJSM; pump out of hole from 9915'- 9,915.0 9,834.0 21:45 22:00 9834' MD, 210 gpm, 800 psi, PU 150K. 2/2/2016 2/2/2016 0.75 COMPZ2 FISH CIRC T CBU @ 400 gpm, 2000 psi, FO 52 %. 9,834.0 9,834.0 22:00 22:45 2/2/2016 2/2/2016 0.50 COMPZ2 FISH OWFF T Monitor well, static. 9,834.0 9,834.0 22:45 23:15 2/2/2016 2/3/2016 0.75 COMPZ2 FISH PULD X PJSM; pull out of the hole laying down 9,834.0 9,361.0 23:15 00:00 4" DP f/ 9834'-9361- MD, PU 150K, calculated fill 2.7, actual 3.4 bbls. 2/3/2016 2/3/2016 5.75 COMPZ2 FISH PULD X PJSM; continue laying down 4" DP 9,361.0 286.0 00:00 05:45 while pulling out of the hole f/ 9361'- 286' MD. Calculated fill 60, actual 64.9 bbls. 2/3/2016 2/3/2016 0.25 COMPZ2 FISH OWFF X Monitor well, static. 286.0 286.0 05:45 06:00 2/3/2016 2/3/2016 1.75 COMPZ2 FISH BHAH X PJSM; lay down 6 drill collars & BHA 286.0 0.0 06:00 07:45 as per Baker Rep. 2/3/2016 2/3/2016 1.00 COMPZ2 FISH BHAH X PJSM; clear & clean rig floor. 0.0 0.0 07:45 08:45 2/3/2016 2/3/2016 0.75 COMPZ2 RPCOMP WWWH X PJSM; remove wear bushing & flush 0.0 0.0 08:45 09:30 stack. SIMOPS unload 4" DP from pipe shed. 2/3/2016 2/3/2016 1.00 COMPZ2 RPCOMP RURD X PJSM; mobilize casing tools & rig up 0.0 0.0 09:30 10:30 to run tubing. 2/3/2016 2/3/2016 0.50 COMPZ2 RPCOMP SVRG X PJSM; service rig. 0.0 0.0 10:30 11:00 Page 66/69 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation ^B) End Depth (ftKB) 2/3/2016 2/3/2016 11.25 COMPZ2 RPCOMP PUTB X PJSM; Make up suspension string 3.5" 0.0 9,773.0 11:00 22:15 WLEG, 3.5" tubing jt, 2.75" D nipple w/ RHC installed, 3.5" tubing jt, Baker 47D2 FHL retrievable packer (60K shear release), 4-1/2" 12.6 # L-80 IBTM tubing from 0-9773' MD. Calculated displacement 44.8, actual 40 bbls. Ran 334 joints of 4-1/2" tubing with no remakes or rejects. 2/3/2016 2/3/2016 0.50 COMPZ2 RPCOMP THGR X Make up tubing hanger & landing joint. 9,773.0 9,773.0 22:15 22:45 2/3/2016 2/3/2016 0.50 COMPZ2 RPCOMP RURD X PJSM; flush mud pumps & kill line w/ 9,773.0 9,773.0 22:45 23:15 fresh H2O. Blow down kill & choke lines. 2/3/2016 2/4/2016 0.75 COMPZ2 RPCOMP THGR X PJSM; land hanger, WLEG set at 9,773.0 9,801.0 23:15 00:00 9802' MD. PU 115K, SO 75K. RILDS. 2/4/2016 2/4/2016 0.75 COMPZ2 RPCOMP THGR X PJSM; continue RILDS. Test hanger 9,801.0 0.0 00:00 00:45 seals to 5000 psi for 10 minutes, witnessed good. 2/4/2016 2/4/2016 0.50 COMPZ2 RPCOMP RURD X PJSM; drop ball & rod, rig up to test 0.0 0.0 00:45 01:15 tubing & IA. 2/4/2016 2/4/2016 0.75 COMPZ2 RPCOMP PACK X PJSM; pressure up & test tubing to 0.0 0.0 01:15 02:00 3500 psi for 30 minutes, charted (packer pinned at 1680 psi & sets at 2500 psi). Bleed down tubing to 2000 psi & shut in. Attempt to pressure test IA to 3500 psi with no success. 2/4/2016 2/4/2016 2.00 COMPZ2 RPCOMP RGRP XT Trouble shoot surface test equipment. 0.0 0.0 02:00 04:00 Change out multiple pressure sensators & pressure sensor lines. 2/4/2016 2/4/2016 0.50 COMPZ2 RPCOMP SEQP XT Pressure test surface equipment & 0.0 0.0 04:00 04:30 test equipment, good. 2/4/2016 2/4/2016 1.50 COMPZ2 RPCOMP PRTS XT Attempt to test IA several more times 0.0 0.0 04:30 06:00 with no success. 2/4/2016 2/4/2016 2.00 COMPZ2 RPCOMP PRTS XT Pressure up tubing to 4200 psi 0.0 0.0 06:00 08:00 ( applying more pressure to the packer) holding for -10 minutes. Bleed pressure to 2000 psi on tubing. Retest surface equipment, good. Attempt to pressure test IA to 3500 psi, no success. Bleed pressure from IA & tubing. Pressure up IA to 1000 psi for 10 minutes, observing 100 psi loss. 2/4/2016 2/4/2016 8.50 COMPZ2 RPCOMP WAIT XT Wait on orders. SIMOPS rig down 0.0 0.0 08:00 16:30 MPD unit, clean brine residue from rig, remove Katch Kan, remove MPD lines, clean drip pans, & change out liners / swabs on #1 mud pump. Fire Drill CRT 75 sec @ 09:00 hrs. 2/4/2016 2/4/2016 0.50 COMPZ2 RPCOMP CIRC X PJSM; pump down IA & shear SOV 0.0 0.0 16:30 17:00 AT 3000 PSI. Pump 2 bbls through SOV at 2 bpm, 500 psi. 2/4/2016 2/4/2016 0.50 COMPZ2 RPCOMP RURD X Rig down circulating lines & lay down 0.0 0.0 17:00 17:30 landing joint. 2/4/2016 2/4/2016 0.50 COMPZ2 WHDBOP MPSP X PJSM; set BPV & test to 1000 psi for 0.0 0.0 17:30 18:00 1 I 10 minutes, charted. Rig down lines. Page 67/69 Report Printed: 1/23/2017 = Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 2/4/2016 2/4/2016 2.50 COMPZ2 WHDBOP MPDA X PJSM, rig down MPD equipment from 0.0 0.0 18:00 20:30 BOPE. 2/4/2016 2/4/2016 0.50 COMPZ2 WHDBOP OTHR X PJSM; rig down scaffolding around 0.0 0.0 20:30 21:00 BOPE. 2/4/2016 2/4/2016 2.00 COMPZ2 WHDBOP NUND X PJSM; nipple down BOPE, remove 0.0 0.0 21:00 23:00 adapter spools. 2/4/2016 2/5/2016 1.00 COMPZ2 WHDBOP NUND X PJSM; nipple up tree adapter flange 0.0 0.0 23:00 00:00 per CIW Rep. 2/5/2016 2/5/2016 0.50 COMPZ2 WHDBOP NUND X PJSM; continue nipple up of adapter 0.0 0.0 00:00 00:30 flange. 2/5/2016 2/5/2016 0.50 COMPZ2 WHDBOP PRTS X Test SRL seals to 5000 psi for 10 0.0 0.0 00:30 01:00 minutes, witnessed good. 2/5/2016 2/5/2016 0.75 COMPZ2 WHDBOP PRTS X Test hanger seals to 250 psi for 5 min 0.0 0.0 01:00 01:45 & 5000 psi for 10 minutes, witnessed good. 2/5/2016 2/5/2016 0.75 COMPZ2 WHDBOP NUND X PJSM; nipple up CIW tree as per 0.0 0.0 01:45 02:30 Cameron Rep. 2/5/2016 2/5/2016 1.25 COMPZ2 WHDBOP OTHR X PJSM; scaffold crew set up scaffolding 0.0 0.0 02:30 03:45 around tree. 2/5/2016 2/5/2016 0.50 COMPZ2 WHDBOP NUND X Install pump in flange on tree & rig up 0.0 0.0 03:45 04:15 to test. 2/5/2016 2/5/2016 0.75 COMPZ2 WHDBOP PRTS X Pressure test tree to 250 / 5000 psi for 0.0 0.0 04:15 05:00 15 minutes, witnessed good. Remove test dart. 2/5/2016 2/5/2016 1.25 COMPZ2 WHDBOP FRZP X Rig up to freeze protect. SIMOPS 0.0 0.0 05:00 06:15 mobilize lubricator to rig floor. 2/5/2016 2/5/2016 2.00 COMPZ2 WHDBOP FRZP X PJSM; freeze protect well, pump 85 0.0 0.0 06:15 08:15 bbls of diesel down the IA taking returns from the tubing, 1.5 bpm, ICP 680 psi, FCP 1300 psi. 2/5/2016 2/5/2016 1.25 COMPZ2 WHDBOP FRZP X U-tube freeze protect, starting tubing 0.0 0.0 08:15 09:30 pressure 500 psi, ending tubing pressure 450 psi. SIMOPS Lay down 1 stand of drill collars & 30 joints of 4" DP. 2/5/2016 2/5/2016 1.00 COMPZ2 WHDBOP MPSP X PJSM; rig up & set Type H BPV as per 0.0 0.0 09:30 10:30 Cameron Rep. 2/5/2016 2/5/2016 1.00 COMPZ2 WHDBOP MPSP X PJSM; rig up & test BPV pumping 0.0 0.0 . 10:30 11:30 down the IA, test to 1000 psi for 10 minutes. Tubing pressure 0 psi, IA pressure 400 psi. 2/5/2016 2/5/2016 0.50 DEMOB MOVE RURD X PJSM; blow down & rig down freeze 0.0 0.0 11:30 12:00 protect lines. Spill Drill CRT 87 sec @ 11:45 hrs. 2/5/2016 2/5/2016 1.75 DEMOB MOVE RURD X PJSM; secure well, install gauges on 0.0 0.0 12:00 13:45 IA & tubing. SIMOPS rig down scaffolding. 2/5/2016 2/5/2016 4.50 DEMOB MOVE PULD X PJSM; lay down 204 joints of 4" DP 0.0 0.0 13:45 18:15 from derrick. 2/5/2016 2/5/2016 0.50 DEMOB MOVE RURD X Clean & clear rig floor. Lay down 0.0 0.0 18:15 18:45 mouse hole. 2/5/2016 2/5/2016 1.25 DEMOB MOVE SLPC X PJSM; slip & cut 130' of drill line. 0.0 0.0 18:45 20:00 2/5/2016 2/5/2016 0.50 DEMOB MOVE SVRG X PJSM; service rig. 0.0 0.0 20:00 20:30 2/5/2016 2/5/2016 2.00 DEMOB MOVE RURD X PJSM; change out saver sub f/ XT39 0.0 0.0 20:30 22:30 to 4-1/2 IF. Page 68/69 Report Printed: 1/23/2017 i Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/5/2016 2/6/2016 1.50 DEMOB MOVE RURD X PJSM; clean cellar & prep for rig 0.0 0.0 22:30 00:00 move. 2/6/2016 2/6/2016 6.00 DEMOB MOVE RURD X PJSM; continue cleaning around the 0.0 0.0 00:00 06:00 rig. Prep for rig move. 2/6/2016 2/6/2016 6.00 DEMOB MOVE RURD X PJSM; blow down steam & water 0.0 0.0 06:00 12:00 lines. Unhook interconnects between modules. Slide skate ramp to pipe shed. Prep for trucks to hook up to modules. Rig Release at 12:00 hrs. Page 69/69 Report Printed: 1/23/2017 ter: Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/28/2016 10/28/2016 3.00 MIRU MOVE MOB X Move pipe shed, motor module, pump 0.0 0.0 00:00 03:00 module, pit module, and rock washer and stage at end of location. 10/28/2016 10/28/2016 2.50 MIRU MOVE RURD X Install tongue on sub, skid rig floor, 0.0 0.0 03:00 05:30 and raise stompers. SIMOPS Spot rig mats for moving sub to 2S-13 10/28/2016 10/28/2016 3.00 MIRU MOVE RURD X Continue spotting mats for moving sub 0.0 0.0 05:30 08:30 to 2S-13. SIMOPS Change out plumbing for steam lines throughout rig 10/28/2016 10/28/2016 3.75 MIRU MOVE MOB X Move sub off 2S-09 and spot over 2S- 0.0 0.0 08:30 12:15 13. 10/28/2016 10/28/2016 1.00 MIRU MOVE MOB X Set sub stompers. 0.0 0.0 12:15 13:15 10/28/2016 10/28/2016 0.75 MIRU MOVE RURD X Skid rig floor into drilling position. 0.0 0.0 13:15 14:00 10/28/2016 10/28/2016 2.00 MIRU MOVE MOB X Spot pit module. SIMOPS Remove 0.0 0.0 14:00 16:00 tongue from sub. 10/28/2016 10/28/2016 0.50 MIRU MOVE MOB X Spot pump module. 0.0 0.0 16:00 16:30 10/28/2016 10/28/2016 0.75 MIRU MOVE MOB X Spot motor complex 0.0 0.0 16:30 17:15 10/28/2016 10/28/2016 1.75 MIRU MOVE MOB X Spot rockwasher and pipeshed. 0.0 0.0 17:15 19:00 10/28/2016 10/28/2016 2.50 MIRU MOVE MOB X Lay herculite and spot cuttings tank. 0.0 0.0 19:00 21:30 Install hand -i -berm around cuttings tank and cellar area. Start heating rig with steam. 10/28/2016 10/29/2016 2.50 MIRU MOVE RURD X Rig up interconnect lines between 0.0 0.0 21:30 00:00 modules and sub. Install plugs in pumps. Position pipe skate rail. Rig accept at 24:00 hrs. 10/29/2016 10/29/2016 2.50 MIRU WELCTL RURD X Open IA to atmosphere and monitor 0.0 0.0 00:00 02:30 for flow - observe small amount of air coming out at first decreasing to static. SIMOPS finish rigging up and take on 12.2 ppg mud to pits. Mobilize lubricator to cellar. Obtain measurements for elevation: RKB to upper LDS 35.55'. RKB to lower LDS 36.46'. 10/29/2016 10/29/2016 1.00 MIRU WELCTL MPSP X R/U lubricator and pressure test to 0.0 0.0 02:30 03:30 2000 psi. Pull H -type BPV and observe 950 psi on tubing, 0 psi on IA. R/D lubricator. Note: Prior to rigging up lubricator, cycled master / swab valve 3 x times on tree and observed pressure bleeding off through tree cap each time. 10/29/2016 10/29/2016 2.50 MIRU WELCTL OWFF X R/U 1/2" line off wing valve to bleed 0.0 0.0 03:30 06:00 trailer and bleed air from tubing, initial pressure of 950 psi decreasing to 250 psi. IA at 0 psi. SIMOPS Rig up to pump IA. Page 1/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time I Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/29/2016 10/29/2016 1.50 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 06:00 07:30 pressure buildup. Observed pressure remain at 250 psi for initial 25 minutes, and then slowly build up to 310 psi. IA at 0 psi with slight vacuum. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0.0 07:30 08:00 initial pressure of 310 psi decreasing to 150 psi. IA at 0 psi. 10/29/2016 10/29/2016 1.75 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 08:00 09:45 pressure buildup. Observed pressure slowly build up from 150 psi to 190 psi. IA at 0 psi. 10/29/2016 10/29/2016 0.25 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0.0 09:45 10:00 initial pressure of 190 psi decreasing to 100 psi. IA at 0 psi. 10/29/2016 10/29/2016 2.50 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 10:00 12:30 pressure buildup. Observed pressure slowly build up from 100 psi to 147 psi. IA at 0 psi. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0.0 12:30 13:00 initial pressure of 147 psi decreasing to 20 psi. IA at 0 psi. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 13:00 13:30 pressure buildup. Observed pressure slowly build up from 20 psi to 35 psi. IA at 0 psi. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0.0 13:30 14:00 initial pressure of 35 psi decreasing to 0 psi. IA at 0 psi. 10/29/2016 10/29/2016 2.50 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 14:00 16:30 pressure buildup. Observed pressure slowly build up from 0 psi to 36 psi. IA at 0 psi. 10/29/2016 10/29/2016 0.50 MIRU WELCTL OWFF X Bleed air from tubing to bleed trailer, 0.0 0.0 16:30 17:00 initial pressure of 36 psi decreasing to 0 psi. IA at 0 psi. 10/29/2016 10/29/2016 2.00 MIRU WELCTL OWFF X Shut in tubing and monitor for 0.0 0.0 17:00 19:00 pressure buildup. Observed pressure slowly build up from 0 psi to 25 psi. IA at 0 psi. SIMOPS Rig up hardline to 400 bbl kill tank to circulate KWF. 10/29/2016 10/29/2016 0.25 MIRU WELCTL SFTY X Hold PJSM for killing well with 0.0 0.0 19:00 19:15 j 12.2ppg KWF, taking returns to kill tank. Page 2/55 Report Printed: 112312017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/29/2016 10/29/2016 1.75 MIRU WELCTL KLWL X Line up and flood lines from rig to kill 0.0 0.0 19:15 21:00 tank. Pressure test to 2000 psi and confirm no leaks - good test. Line up to pump down IA, taking returns through tubing to kill tank. Stage up to 2 bpm and pump 44 bbls of 12.2 ppg KWF before seeing returns at kill tank, initial pressure of 45 psi increasing to 236 psi. Continue pumping 168 bbls of 12.2ppg KWF, staging up to 3 bpm, 470 psi. Observe initial returns containing large amount of air and mud weight out fluctuate between 11.7 -12.0+ for first 130 bbls pumped and then steadily increase to 12.2 ppg in/out. Shut in well and blow down lines to kill tank. Total volume pumped 212 bbls. Final volume in kill tank 136 bbls. Total losses downhole 76 bbls 10/29/2016 10/29/2016 0.75 MIRU WELCTL OWFF X Monitor for pressure buildup on tubing 0.0 0.0 21:00 21:45 and IA - well static at 0 psi on tubing and 0 psi on IA. Open up tubing and IA to atmosphere and observe both on a vacuum. 10/29/2016 10/29/2016 1.25 MIRU WHDBOP MPSP X Rig up lubricator and test to 2000 psi - 0.0 0.0 21:45 23:00 good test. Install HP-type BPV. R/D lubricator. 10/29/2016 10/30/2016 1.00 MIRU WHDBOP MPSP X Fill tree with water and line up to pump 0.0 0.0 23:00 00:00 down IA to pressure test BPV in direction of flow, monitoring for leaks past BPV through the wing valve. Stage up to 2 bpm and pump 15 bbls 12.2ppg KWF before seeing any pressure increase. Continue pumping total of 24 bbls at 2 bpm, initial pressure of 45 psi increase to 700 psi and level out. Shut in well and observe IA pressure fall to 100 psi. Remove tree cap and open swab valve. Pump down IA at 2 bpm, 620 psi for total of 10 bbls, monitoring for any leaks past BPV - no leaks observed. Shut in and blow down lines. 10/30/2016 10/30/2016 1.00 MIRU WHDBOP OTHR X Blow down lines and clean up cellar 0.0 0.0 00:00 01:00 area. 10/30/2016 10/30/2016 2.50 MIRU WHDBOP NUND X Nipple down production tree. Make up 0.0 0.0 01:00 03:30 4-1/2" IBT to top of hanger and confirm it will swallow BPV. Convert HP-type BPV into 2-way check. 10/30/2016 10/30/2016 4.50 MIRU WHDBOP NUND X Nipple up BOPE and dutch riser ring. 0.0 0.0 03:30 08:00 Note: MPD RCD head will not be rigged up until after 7-5/8" casing is cut/pulled to surface. 10/30/2016 10/30/2016 1.00 MIRU WHDBOP RURD X Make up 4-1/2" test joint and rig up to 0.0 0.0 08:00 09:00 test BOPE. Page 3/55 ReportPrinted: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 10/30/2016 10/30/2016 6.50 MIRU WHDBOP BOPE X Perform shell test. Test witnessed by 0.0 0.0 09:00 15:30 AOGCC Rep. Matt Herrera and Guy Cook. Tested BOPE with 4-1/2" test joint. 250/3500 psi, charted for 5 minutes each. Test #1 with 4-1/2" test joint, testing Annular, CV#1, #12, #13, #14, 4" kill line valve on mud manifold, and 4"Dart valve. Test #2 - Upper 3-1/2" x 6" VBR's, CV # 9, #11, mezzanine kill valve, and 4" FOSV Test #3- CV #5, #8, #10, and HCR Kill. Test #4 - CV #4, #6, #7. Test #5 - Super choke to 1500 psi Test #6 - Manual choke to 1500 psi Test #7 - CV #2, #5, and manual kill Test #8 - HCR choke. Test #9 - Upper IBOP Test #10 - Manual choke, lower IBOP Test #11 - Lower 3-1/2" x 6" VBR's Test #12 -Blind rams, CV #3. Perform Koomey draw down test. Observed initial system pressure at ACC- 3040 PSI, MAN - 1500 PSI, and annular - 1425 PSI. After Closure observed ACC - 1900 PSI, 200 PSI increase in 15 seconds with 1 x electric motor, and full pressures at 85 seconds w/ 1 x electric motor and 2 x air pumps. Perform CPAI performance test, function 2 x rams and 1 x HCR and observe 2 x electric pumps attain full system pressure in 20 sec and 2 x air pumps attain full system pressure in 72 sec. 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. Tested primary and remote BOP controls. Note that the upper IBOP failed initial test - aftern functioning and greasing, it re- tested good. 10/30/2016 10/30/2016 0.25 MIRU WHDBOP RURD X Rig down test equipment and blow 0.0 0.0 15:30 15:45 down lines. 10/30/2016 10/30/2016 0.50 MIRU WHDBOP OTHR X Service top drive. 0.0 0.0 15:45 16:15 10/30/2016 10/30/2016 3.00 MIRU WHDBOP MPSP X Remove 2 -way check adapter from 0.0 0.0 16:15 19:15 HP -type BPV and attempt to pull BPV. Drain stack to assist with stabbing BPV. Pull with dry rod and observe tubing on a vacuum. Fill hole, observe returns after 40 bbls pumped. 10/30/2016 10/30/2016 1.00 SLOT RPCOMP SLKL X Rig up dutch riser. Fill pipe every 30 0.0 0.0 19:15 20:15 minutes to ensure fluid to surface. 10/30/2016 2.50 SLOT RPCOMP SLKL X Rig up to run slickline. Fill pipe every 0.0 0.0 20:15 110/30/2016 2: 1 30 minutes to ensure fluid to surface. Page 4155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start TimeEnd Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 0.0 0.0 10/30/2016 10/30/2016 0.25 SLOT RPCOMP SLKL X Pressure test slickline lubricator and 22:45 23:00 1 dutch riser to 500 psi - good test. 10/30/2016 10/31/2016 1.00 SLOT RPCOMP SLKL XT Run in hole w/ "F" type collar catcher 0.0 0.0 23:00 00:00 and tag up on top of tubing hanger. Work twice, unable to get through. Pull to surface and re -pin catcher with stronger brass. Run in hole and make 15 x attempts to run through tubing - unsuccessful. Pull to surface and inspect tool - observe pin sheared on catcher tool and the wires were bent. SIMOPS - Mobilize 4-112" slip -stop catcher with bullnose on bottom from 1-Y pad Note: Total losses since pulling BPV = 88 bbis. Loss rate has slowed to —8 bbl/hr. 10/31/2016 10/31/2016 1.00 SLOT RPCOMP SLKL XT Re -pin F -style collar catcher and work 0.0 0.0 00:00 01:00 through tubing hanger to 40' prior to making up lubricator. Make up lubricator and run in hole to 530' - unable to work tool any further. Pull OOH and inspect tool - observe wires bent. Continue topping off fluid in well, observe loss rate decrease to —6 bbl/hr SIMOPS - Mobilize 4-112" slip -stop catcher with bullnose on bottom from 1-Y pad 10/31/2016 10/31/2016 4.00 SLOT RPCOMP SLKL X RIH w/ slip -stop catcher tool with 0.0 0.0 01:00 05:00 bullnose and set catcher below GLM. POOH and lay out running tool. RIH w/ dummy valve and seat in GLM at 3479'. POOH and lay out running tool. Pressure test IA to 1000 psi to confirm valve seated ok - good test, no sign of return flow through tubing. RIH w/ catcher pulling tool, retrieve catcher, and POOH. Continue topping off fluid in well, observe loss rate of —6 bbl/hr. 10/31/2016 10/31/2016 1.50 SLOT RPCOMP SLKL X Rig down slickline, laying out 0.0 0.0 05:00 06:30 lubricator and dutch riser. 10/31/2016 10/31/2016 1.00 SLOT RPCOMP PRTS X Rig up to pump down IA and pressure 0.0 0.0 06:30 07:30 test packer to 2000 psi, 15 min - good test. Rig down lines and blow down. SIMOPS Rig up casing tongs for pulling kill string. 10/31/2016 10/31/2016 3.00 SLOT RPCOMP PULL X Make up landing joint 9,814.0 9,772.0 07:30 10:30 monitor IA pressure - LDS and pull hanger /r. 7210k Observe packer releahookload. PUW 127k.hanger, remove bail extensons,an change out elevators. Page 5/55 Report Printed: 1 /2 312 01 7 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 10/31/2016 10/31/2016 1.50 SLOT RPCOMP CIRC X Shut in tubing and line up to pump 9,772.0 9,772.0 10:30 12:00 down IA. Bullhead 187 bbls 12.2ppg KWF down IA, staging up to 4.5 bpm, 828 psi. 10/31/2016 10/31/2016 4.50 SLOT RPCOMP CIRC X Line up to circulate down tubing and 9,772.0 9,772.0 12:00 16:30 circulate / condition mud for 4 x BU, staging up from 4 bpm, 547 psi, 5% F/O to 5 bpm, 600 psi, 8% F/O. Observe 620 units gas on first bottoms up. Initial MW 12.2 in / 12.1 out. After 1.5 BU, observe MW 12.1 in / 11.9 out. Final MW 12.2 in/out. Losses while circulating = 63 bbls. 10/31/2016 10/31/2016 0.75 SLOT RPCOMP OWFF X Monitor well for flow - observe fluid 9,772.0 9,772.0 16:30 17:15 level drop 2 ft in 30 minutes. 10/31/2016 10/31/2016 0.50 SLOT RPCOMP PULL X Lay down top 4-1/2" IBTm single and 9,772.0 9,745.0 17:15 17:45 blow down kill line and top drive. 10/31/2016 10/31/2016 0.75 SLOT RPCOMP PULL XT Line up hole fill on trip tank, pull 1 x 9,745.0 9,745.0 17:45 18:30 stand 4-1/2" tubing (85 ft long), and attempt to rack back in derrick on raised wooden platform - unable to rack back. Decision made to lay out 4- 1/2" sidways. 10/31/2016 11/1/2016 5.50 SLOT RPCOMP PULL X Pull OOH sideways with 4-1/2" IBTm 9,745.0 7,696.0 18:30 00:00 kill string f/ 9745'- 7696', PUW 115k, SOW 86k. Observe 1-2 bbl/hr loss rate. Note: Attempt to monitor hole fill on trip tank, but mud continued to aerate badly and was not filling hole correctly. Swap to pit #5 while troubleshooting issue. Total losses for 24 hr = 123 bbls (not including the 187 bbls bullheaded away) OA pressure = 260 psi 11/1/2016 11/1/2016 6.00 SLOT RPCOMP PULL X Pull OOH sideways with 4-1/2" IBTm 7,696.0 3,250.0 00:00 06:00 kill string fl 7696'- 3250', PUW 74k, SOW 60k. Observe -1.5 bbl/hr loss rate. Monitor displacement on pit #5. Note: Attempted to swap over to trip tank after investigation but observe similar issue with trip tank pump not able to keep up with hole fill. Rig will inspect pump. 11/1/2016 11/1/2016 5.00 SLOT RPCOMP PULL X Pull OOH sideways with 4-1/2" IBTm 3,250.0 115.0 06:00 11:00 kill string f/ 3250' - 115'. Observe -1 bbl/hr loss rate. Monitor displacement on pit #5. 11/1/2016 11/1/2016 0.50 SLOT RPCOMP PULL X Pull OOH and lay down Baker 115.0 0.0 11:00 11:30 retrievable packer, 3-1/2" tubing, D - Nipple, and WLEG. 11/1/2016 11/1/2016 0.75 SLOT RPCOMP RURD X Clean and clear rig floor. 0.0 0.0 11:30 12:15 11/1/2016 11/1/2016 0.50 SLOT PLUG BOPE T Install test plug and R/U to test BOPE. 0.0 0.0 12:15 12:45 Page 6/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -x Operation (ftKB) End Depth (ftKB) 11/1/2016 11/1/2016 1.75 SLOT PLUG BOPE T Test BOP upper and lower VBR's and 0.0 0.0 12:45 14:30 the annular with 3-1/2" test joint. 250/3500 psi, charted for 5 minutes each. 11/1/2016 11/1/2016 0.75 SLOT PLUG BOPE T R/D test equipment and install 12.5" 0.0 0.0 14:30 15:15 ID wearbushing. 11/1/2016 11/1/2016 0.75 SLOT PLUG RURD T Rig up to run 3-1/2" tubing. 0.0 0.0 15:15 16:00 11/1/2016 11/1/2016 1.00 SLOT PLUG SFTY T Hold 3rd Quarter HSE/Performance 0.0 0.0 16:00 17:00 Review with all crews and management. 11/1/2016 11/1/2016 1.50 SLOT PLUG PULD T Hold PJSM for running retainer. Make 0.0 229.0 17:00 18:30 up cement retainer and RIH w/ 7 x joints 3-1/2" EUE cement stinger to 229'. 11/1/2016 11/1/2016 4.25 SLOT PLUG TRIP T RIH w/ 4" DP stands from derrick f/ 229.0 6,389.0 18:30 22:45 229' - 6389', PUW 119k, SOW 87k, run speed 75-90 ft/min, monitoring displacement on pit #5. Observe -1.5 bbl/hr loss rate. 11/1/2016 11/2/2016 1.25 SLOT PLUG PULD T RIH w/ 4" DP singles from pipe shed f/ 6,389.0 7,272.0 22:45 00:00 6389'- 7272', PUW 128k, SOW 90k, run speed 75 ft/min, monitoring displacement on pit #5. Observe --1 bbl/hr loss rate. Total losses for 24 hr = 25.5 bbl OA pressure = 220 psi 11/2/2016 11/2/2016 3.75 SLOT PLUG PULD T RIH w/ 4" DP singles from pipe shed f/ 7,272.0 9,811.0 00:00 03:45 7272' - 9811', PUW 167k, SOW 100k, run speed 75 ft/min, monitoring displacement on pit #5. Total losses for trip in hole = 19 bbls 11/2/2016 11/2/2016 0.50 SLOT PLUG MPSP T Set cement retainer with top at 9811' 9,811.0 9,795.0 03:45 04:15 MD as per Baker and release from retainer, PUW 167k, SOW 100k. 11/2/2016 11/2/2016 0.25 SLOT PLUG RURD T Rig up cement hose and test 9,795.0 9,795.0 04:15 04.30 equipment. 11/2/2016 11/2/2016 1.00 SLOT PLUG MPSP T Line up to pump down DP and IA. 9,795.0 9,795.0 04:30 05:30 Pressure test cement retainer from above. Although lines were flooded beforehand, took 2.5 bbls pumped before seeing any increase in pressure. Pressured up to 3625 psi, shut in and observed pressure drop from 3575 psi to 3430 psi over 15 minutes. Bumped up pressure to 3650psi, shut in, and observed pressure hold at 3580 psi for 10 min. 11/2/2016 11/2/2016 0.25 SLOT PLUG SQEZ T Sting into retainer and perform 9,795.0 9,811.0 05:30 05:45 injectivity test, staging up to 3bpm and monitoring annulus for returns - static. 1.5 bpm @ 890 psi 2.0 bpm @ 900 psi 2.5 bpm @ 980 psi 3.0 bpm @ 1085 psi 11/2/2016 11/2/2016 0.25 SLOT PLUG SFTY T Sting out of retainer and hold PJSM 9,811.0 9,806.0 05:45 06:00 for cement job. Page 7/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/2/2016 11/2/2016 0.75 SLOT PLUG RURD T Line up SLB to cement line, batch mix 9,806.0 9,806.0 06:00 06:45 mudpush and cement, line up to take returns through rig choke, and fill choke lines / gas buster. 11/2/2016 11/2/2016 0.75 SLOT PLUG CMNT T SLB pump 2 bbls 12.5 ppg mudpush. 9,806.0 9,806.0 06:45 07:30 Shut in and pressure test cement lines to 4000 psi - good test. Continue pumping 8 bbls 12.5 ppg mudpush at 2.5 bpm, 1308 psi, 21.7 bbls 15.8ppg cement at 2.8 bpm, 1217 psi, and 3.1 bbls 12.5 ppg mudpush at 2.2 bpm, 994 psi. Clear lines to rig floor with 1.5 bbls water. Swap over to rig and pump 65.2 bbls at 3.5 bpm, 1470 psi. Hold 800 psi backpressure with rig choke throughout job. 11/2/2016 11/2/2016 0.50 SLOT PLUG SQEZ T Strip down and sting into retainer. 9,806.0 9,811.0 07:30 08:00 Bleed off IA pressure and open annular - monitor for leaks throughout job. Pump 27.8 bbls w/ rig at 3 bpm, ICP 955 psi, FCP 1177 psi, squeezing total of 16.8 bbls of 15.8ppg Cement below cement retainer. 11/2/2016 11/2/2016 0.50 SLOT PLUG TRIP T Sting out of retainer, lay out single, 9,811.0 9,609.0 08:00 08:30 and POOH 2 x stands at 1000 ft/hr to 9609'. Note: 4.9 bbls of 15.8ppg cement left in hole above retainer. Estimated TOC @ 9704'. 11/2/2016 11/2/2016 1.00 SLOT PLUG CIRC T Drop wiper ball and circulate 2 x BU at 9,609.0 9,609.0 08:30 09:30 12 bpm, 2607 psi 11/2/2016 11/2/2016 4.50 SLOT PLUG PRTS T Rig up to pressure test down DP and 9,609.0 9,609.0 09:30 14:00 IA, close annular. Pressure test top of cement retainer / casing / cement to 3500 psi / 30 min - unable to obtain good test. Observe pressure bleeding off at 7 psi/min. Troubleshoot surface equipment and try various lineups - still unable to obtain good test. Note: Observe OA pressure at 1000 psi. 11/2/2016 11/2/2016 1.00 SLOT PLUG CIRC T Circulate 1 x BU at 6 bpm, 996 psi, 9,609.0 9,609.0 14:00 15:00 10% F/O, MW in 12.2ppg, MW out 12.1 ppg. Note: Started seeing small amount of diesel in returns at surface right after kicking on the pumps. OA pressure decrease to 810 psi. 11/2/2016 11/2/2016 1.00 SLOT PLUG PRTS T Line up and attempt to pressure test 9,609.0 9,609.0 15:00 16:00 retainer / casing / cement to 3500 psi for 30 min - unable to obtain good test. Observe OA pressure increase from 810 psi to 1100 psi. 11/2/2016 11/2/2016 0.75 SLOT PLUG OWFF T Monitor well for flow - observe slight 9,609.0 9,609.0 16:00 16:45 flow with small amounts of diesel in mud. Flow out at 85 sec for vis cup. F- Page 8155 Report Printed: 1/23/2017 V. {'* Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/2/2016 11/2/2016 0.75 SLOT PLUG OWFF T Continue monitoring well for flow. 9,609.0 9,609.0 16:45 17:30 Observe flow out slowly increase to 52 sec for vis cup and OA pressure decrease to 620 psi. 11/2/2016 11/2/2016 1.00 SLOT PLUG OWFF T Continue monitoring well for flow. 9,609.0 9,609.0 17:30 18:30 Observe flow out slowly decrease to 65 sec for vis cup and OA pressure decrease to 380 psi. 11/2/2016 11/2/2016 0.50 SLOT PLUG OWFF T Continue monitoring well for flow. Line 9,609.0 9,609.0 18:30 19:00 up to bleed off OA pressure to kill tank. Bleed off to 270 psi and observe flow out decrease to 105 sec for vis cup. OA pressure fall to 250 psi. Bleed down to 200 psi and observe flow out decrease to 303 sec for vis cup. OA pressure fall to 190 psi. Bleed off to 100 psi and observe pressure climb to 150 psi within 5 minutes and flow our increased to 190 sec for vis cup. 11/2/2016 11/2/2016 2.00 SLOT PLUG OWFF T Continue monitoring well for flow. 9,609.0 9,609.0 19:00 21:00 Observe flow out continue to decrease to static. Leave OA shut in and monitor pressure, fall from 150 to 130 psi. 11/2/2016 11/3/2016 3.00 SLOT PLUG TRIP T Pull OOH and rack back 4" DP f/ 9609' 9,609.0 6,863.0 21:00 00:00 - 6863', monitoring displacement on trip tank. OA pressure = Decrease from 143 psi to 120 psi. 11/3/2016 11/3/2016 3.00 SLOT PLUG TRIP T Pull OOH and rack back 4" DP f/ 6863' 6,863.0 229.0 00:00 03:00 - 229', monitoring displacement on pit #5. SIMOPS troubleshoot trip tank pump. OA pressure continue to decrease from 120 psi to 110 psi. 11/3/2016 11/3/2016 1.00 SLOT PLUG PULD T L/D 7 xjoints 3-1/2" EUE and retainer 229.0 0.0 03:00 04:00 running tool. 11/3/2016 11/3/2016 2.00 SLOT PLUG TRIP T P/U Baker test packer and RIH on 4" 0.0 2,760.0 04:00 06:00 DP stands from derrick to 2760', monitoring displacement on pit #5. 11/3/2016 11/3/2016 0.25 SLOT PLUG MPSP T Set test packer and rig up test 2,760.0 2,760.0 06:00 06:15 equipment. 11/3/2016 11/3/2016 1.00 SLOT PLUG PRTS T Line up and pressure test down DP 2,760.0 2,760.0 06:15 07:15 against cement retainer/ casing / cement plug from 2760' downward to 3500 psi / 30 min - good test. 11/3/2016 11/3/2016 0.75 SLOT PLUG PRTS T Line up and attempt to pressure test 2,760.0 2,760.0 07:15 08:00 IA (from 2760' to surface) to 3500 psi / 30 min - unable to get a good test, observe 200 psi drop over 30 min. 11/3/2016 11/3/2016 0.50 SLOT PLUG MPSP T Rig down test equipment and release 2,760.0 2,760.0 08:00 08:30 test packer. 11/3/2016 11/3/2016 0.25 SLOT PLUG OWFF T Monitor well for flow - well static. 2,760.0 2,760.0 08:30 08:45 11/3/2016 11/3/2016 1.50 SLOT PLUG TRIP T Pull OOH f/ 2760' to surface, racking 2,760.0 0.0 08:45 10:15 back 4" DP in derrick and laying out Baker test packer, monitoring displacement on pit #5 Page 9155 Report Printed: 1/23/2017 - " Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/3/2016 11/3/2016 0.75 SLOT PLUG RURD T Clean / clear rig floor. 0.0 0.0 10:15 11:00 11/3/2016 11/3/2016 0.50 SLOT PLUG SVRG T Service top drive. 0.0 0.0 11:00 11:30 11/3/2016 11/3/2016 5.25 SLOT PLUG TRIP T Make up Baker MSC cutter assembly 0.0 9,186.5 11:30 16:45 and RIH on 4" DP stands from derrick to 9186.5'. PUW 170k, SOW 97k, monitoring displacement on pit #5 Note: Cameron hand pressure tested packoff to confirm it was still holding, 5000 psi for 15 min - good test. 11/3/2016 11/3/2016 1.25 SLOT PLUG CPBO T Spot cutter at 9186.5'. Perform casing 9,186.5 9,186.5 16:45 18:00 cut w/ 8 bpm, 1992 psi, 12% F/O, 80 rpm, 9k Tq. Saw pressure gradually drop to 1512 psi. Slacked off into cut w/ pumps on and no rotary and saw it take 5k weight. Pick up and observe pressure increase, confirming cut. OA pressure = 95 psi - did not see any increase to indicate communication w/ IA. 11/3/2016 11/3/2016 0.50 SLOT PLUG CIRC T Close annular, line up to circulate 9,186.5 9,186.5 18:00 18:30 down DP/IA taking returns through OA to kill tank. Pressure up to 1000 psi - no circulation observed at OA w/ pressure at 0 psi. Note: Small amount of diesel bled back to surface when OA was initially opened to kill tank. With 12.2ppg mud in hole and 1000 psi on pumps, we should have —2000 psi differential to OA 11/3/2016 11/3/2016 1.00 SLOT PLUG CPBO T Pull up to 9125', PUW 163k, SOW 9,186.5 9,125.0 18:30 19:30 99k. Spot cutter at 9125' and perform 2nd casing cut w/ 6 bpm, 1550 psi, 10% F/O, 80 rpm, 9k Tq. Saw pressure gradually drop to 1049 psi. Slaccked off into cut w/ pumps on and no rotary and saw it take 5k weight. Pick up and observe pressure increase, confirming cut. 11/3/2016 11/3/2016 0.25 SLOT PLUG CIRC T Close annular, line up to circulate 9,125.0 9,125.0 19:30 19:45 down DP/IA taking returns through OA to kill tank. Pressure up to 1000 psi - no circulation observed at OA w/ pressure at 0 psi. Note: With 12.2ppg mud in hole and 1000 psi on pumps, we should have —2000 psi differential to OA 11/3/2016 11/3/2016 1.25 SLOT PLUG CIRC T Discuss path forward with town. Drop 9,125.0 9,125.0 19:45 21:00 ball and pump down to open circ sub above cutters. Circulate 1 x BU at 8 bpm, 1400 psi, 12% F/O, 12.1+ppg in/out. 11/3/2016 11/3/2016 0.50 SLOT PLUG T Monitor well for flow - static. SIMOPS 9,125.0 9,125.0 21:00 21:30 �OVVFF bring on mud and prep for displacement. B/D kill line. Page 10/55 Repor Printed: 1/23/2017 ` Operations Summary (with Timelog Depths) y 2S-13 • WE Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/3/2016 11/3/2016 0.25 SLOT PLUG SFTY T Hold PJSM for displacing to 10.5ppg 9,125.0 9,125.0 21:30 21:45 LSND 11/3/2016 11/3/2016 1.25 SLOT PLUG DISP T Displace well from 12.2ppg Warp 9,125.0 9,125.0 21:45 23:00 WBM to 10.5ppg LSND w/ 8.4 bpm, 1570 psi dropping to 1280 psi, 14% F/O. Shut down as LSND was starting to come back to allow for moving mud in pits / rockwasher. 11/3/2016 11/3/2016 0.25 SLOT PLUG OWFF T Monitor well for flow -observe slight 9,125.0 9,125.0 23:00 23:15 flow out and small amount of diesel breaking out at surface. SIMOPS offload mud to vac truck. OA pressure = 420 psi. 11/3/2016 11/3/2016 0.25 SLOT PLUG CIRC T Circulate / condition mud w/ 8 bpm, 9,125.0 9,125.0 23:15 23:30 1148 psi, 12% F/O, observe 10.5ppg in/out. OA pressure = drop to 380 psi 11/3/2016 11/4/2016 0.50 SLOT PLUG OWFF T Monitor well for flow -observe slight 9,125.0 9,125.0 23:30 00:00 flow out. Bleed off OA pressure from 380 psi to 200 psi and continue to monitor. Observe flow out stop - well static. Note: Observe small amount of diesel breaking out in mud at surface. 11/4/2016 11/4/2016 4.50 SLOT PLUG TRIP T Pull OOH racking back 4" DP f/ 9125' 9,125.0 0.0 00:00 04:30 to surface, monitoring displacement on trip tank. 11/4/2016 11/4/2016 1.00 SLOT PLUG BHAH T Inspect cutters - observe good 0.0 0.0 04:30 05:30 indication that casing was successfully cut. UD circ sub and re -dress cutters. 11/4/2016 11/4/2016 4.00 SLOT PLUG TRIP T RIH w/ MSC cutter assembly on 4" DP 0.0 8,880.0 05:30 09:30 stands to 8880' MD, monitoring displacement on trip tank. 11/4/2016 11/4/2016 0.50 SLOT PLUG CPBO T Spot cutter at 8880' MD. PUW 152k, 8,880.0 8,880.0 09:30 10:00 SOW 101 k, ROT 118k, 7kTq. Perform casing cut w/ 8 bpm, ICP 1910 psi, 13% F/O, 80 rpm, 7k Tq. Saw pressure drop to 1595 psi over 1 minute and then quickly fall to 1276 psi. Observed OA pressure increase from 0 psi to 950 psi. 11/4/2016 11/4/2016 0.50 SLOT PLUG CIRC T Hold PJSM for displacing OA to kill 8,880.0 8,880.0 10:00 10:30 tank. Close annular, line up to circulate down DP taking returns through OA to kill tank. Circulate 10 bbls to kill tank, holding 950 psi on choke manifold, to confirm communication with OA. Page 11/55 Report Printed: 1/23/2017 . Sn Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/4/2016 11/4/2016 3.75 SLOT PLUG DISP T Displace OA to 10.5ppg LSND, 8,880.0 8,880.0 10:30 14:15 maintaining 950-450 psi backpressure throughout displacement, staging pumps up to 5 bpm, 1386 psi. Pump 35 bbls Hi-Vis Deepclean pill followed by 274 bbls 10.5ppg LSND. Shut down and suck diesel mixture out of kill tank. Continue pumping 279 bbls 10.5ppg LSND at 5 bpm, 1122 psi until MW 10.5ppg coming out at tank. 11/4/2016 11/4/2016 1.25 SLOT PLUG OWFF T Monitor well for flow-observe slight 8,880.0 8,815.0 14:15 15:30 flow back and slow u-tubing of fluid up drill string. Rack back stand, blow down topdrive, and continue monitoring well for flow. Observe flow back out of OA continually decrease to static and u-tube up drill string stop. 11/4/2016 11/4/2016 3.00 SLOT PLUG TRIP T Pull OOH racking back 4" DP f/ 8815'- 8,815.0 3,880.0 15:30 18:30 3880', PUW 150k, SOW 111 k, monitoring displacement on trip tank. Total of 61 x stands racked in derrick. 11/4/2016 11/4/2016 3.00 SLOT PLUG PULD T Pull OOH laying down 4" DP f/ 3880'- 3,880.0 40.0 18:30 21:30 40', monitoring displacement on trip tank. 11/4/2016 11/4/2016 0.25 SLOT PLUG BHAH T Lay out MSC cutter and stablizer and 40.0 0.0 21:30 21:45 clear floor. 11/4/2016 11/4/2016 1.00 SLOT PLUG WWWH T Make up stack washer and jet stack 0.0 0.0 21:45 22:45 clean w/ 450 gpm, 45 psi, 16% F/O, 50 rpm, 0.3k Tq. LID same, blow down top drive, kill and choke lines. 11/4/2016 11/4/2016 0.50 SLOT PLUG RURD T Change out elevators for 5", pull 0.0 0.0 22:45 23:15 wearbushing and lay out same. 11/4/2016 11/5/2016 0.75 SLOT PLUG BOPE T Change out upper 3-112" x 6" VBR's to 0.0 0.0 23:15 00:00 7-5/8" solid body casing rams. SIMOPS Change out saver sub from XT39 to 4-1/2" IF. 11/5/2016 11/5/2016 2.00 SLOT PLUG BOPE T Change out upper 3-1/2" x 6" VBR's to 0.0 0.0 00:00 02:00 7-5/8" solid body casing rams. SIMOPS Change out saver sub from XT39 to 4-1/2" IF. 11/5/2016 11/5/2016 1.00 SLOT PLUG BOPE T Drain stack, Make up 7-5/8" test joint, 0.0 0.0 02:00 03:00 R/U test assembly, and perform body test. 11/5/2016 11/5/2016 0.50 SLOT PLUG BOPE T Test annular and casing rams w/ 7- 0.0 0.0 03:00 03:30 5/8" test joint and 5" dart valve to 250/3500 psi 5/5 min - good test. Note: 4-1/2" IF TIW unable to test - make up XO on tested XT39 TIW 11/5/2016 11/5/2016 0.50 SLOT PLUG BOPE T RID test equipment and pull test plug. 0.0 0.0 03:30 04:00 11/5/2016 11/5/2016 2.50 SLOT PLUG WWSP T C/O elevators, pick up 5" DP double 0.0 0.0 04:00 06:30 and pack off retrieval tool. RIH and pull packoff, 35k over block weight to pull free. LID packoff and running tool. SIMOPS: Rig up casing pulling equipment. Page 12/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (W]3) 11/5/2016 11/5/2016 0.50 SLOT PLUG PULL T RIH wl Baker spear on 5" DP and 0.0 8,875.0 06:30 07:00 spear casing below hanger. Pull hanger free, 248k PUW. Pick up 5'. 11/5/2016 11/5/2016 2.00 SLOT PLUG CIRC T Line up and circulate 1 x surface -to- 8,875.0 8,875.0 07:00 09:00 surface volume at 489 gpm, 419 psi until even 10.5ppg in/out 11/5/2016 11/5/2016 1.50 SLOT PLUG PULL T Pull hanger to floor. Observed hanger 8,875.0 8,843.0 09:00 10:30 catching up in BOP stack - rig up tuggers to help keep it centered. 11/5/2016 11/5/2016 0.50 SLOT PLUG PULL T Release spear and L/D 5" DP, spear, 8,843.0 8,843.0 10:30 11:00 and hanger. 11/5/2016 11/5/2016 5.00 SLOT PLUG PULL T Pull OOH w/ 7 5/8" 29.7# L-80 8,843.0 5,268.0 11:00 16:00 Dopeless Hyd 563 casing f/ 8843'- 5268', PUW 240k, SOW 155k, monitoring displacement on trip tank and strapping joints in pipe shed. 11/5/2016 11/5/2016 1.00 SLOT PLUG CIRC T Observe well u -tubing up the 7-5/8" 5,268.0 5,268.0 16:00 17:00 casing. Stab floor valve, make up top drive and circulate string volume at 510 gpm, 250 psi, 16% F/0. Observe even 10.5ppg in/out. R/D floor valve and B/D topdrive. 11/5/2016 11/5/2016 1.75 SLOT PLUG PULL T Pull OOH w/ 7 5/8" 29.7# L-80 5,268.0 3,272.0 17:00 18:45 Dopeless Hyd 563 casing f/ 5268'- 3272', PUW 133k, SOW 115k, monitoring displacement on trip tank and strapping joints in pipe shed. 11/5/2016 11/5/2016 0.75 SLOT PLUG CIRC T Observe well u -tubing up the 7-5/8" 3,272.0 3,272.0 18:45 19:30 casing. Stab floor valve, make up top drive and circulate string volume at 510 gpm, 137 psi, 16% F/0. Observe even 10.5ppg in/out. R/D floor valve and B/D topdrive. 11/5/2016 11/5/2016 0.75 SLOT PLUG PULL T Pull OOH w/ 7 5/8" 29.7# L-80 3,272.0 2,040.0 19:30 20:15 Dopeless Hyd 563 casing f/ 3272'- 2040', PUW 90k, SOW 80k, monitoring displacement on trip tank and strapping joints in pipe shed. 11/5/2016 11/5/2016 0.75 SLOT PLUG CIRC T Observe well u -tubing up the 7-5/8" 2,040.0 2,040.0 20:15 21:00 casing. Stab floor valve, make up top drive and circulate surface-to-surface volume at 510 gpm, 93 psi, 16% F/O. Observe even 10.5ppg in/out. R/D floor valve and B/D topdrive. 11/5/2016 11/5/2016 2.25 SLOT PLUG PULL T Pull OOH w/ 7 5/8" 29.7# L-80 2,040.0 0.0 21:00 23:15 Dopeless Hyd 563 casing f/ 2040' to surface, monitoring displacement on trip tank and strapping joints in pipe shed. Total of 215 x joints, 1 x cut joint, and 3 x hydroform centralizers laid out. Cut joint = 35.25'. Cement residue observed on last 3 xjoints and on cut joint. 11/5/2016 11/6/2016 0.75 SLOT PLUG RURD T Rig down casing tools and stage to 0.0 0.0 23:15 00:00 side on rig floor. Clean/clear rig floor. 11/6/2016 11/6/2016 1.50 SLOT PLUG BOPE T Flush stack and CIO upper rams to 3- 0.0 0.0 00:00 01:30 1/2" X 6" VBRs. 11/6/2016 11/6/2016 0.25 SLOT PLUG BOPE T R/U to test rams and annular with 5" 0.0 0.0 01:30 01:45 test joint. Page 113155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/6/2016 11/6/2016 0.75 SLOT PLUG BOPE T Test lower rams, upper rams and 0.0 0.0 01:45 02:30 annular with 5" test joint. Test rams and 5" floor valve to 250/3500 psi and annular to 250/2500 psi. 11/6/2016 11/6/2016 0.50 SLOT PLUG RURD T Install 12.5" ID wear bushing. 0.0 0.0 02:30 03:00 11/6/2016 11/6/2016 1.50 SLOT PLUG BHAH T M/U Baker fishing BHA as per Baker 0.0 235.0 03:00 04:30 rep, Spear, Bumper sub, Oil jar, Circ sub, 6 x 6-1/4" spiral DC's, and Accelerator jar. 11/6/2016 11/6/2016 7.75 SLOT PLUG PULD T RIH picking up 5" DP singles from 235.0 8,855.0 04:30 12:15 shed f/ 235'-8760' MD, monitoring displacement on trip tank. Total of 91 x stands and 2 x singles 5" DP picked up. 11/6/2016 11/6/2016 1.50 SLOT PLUG CIRC T Circulate hole clean w/ 676 gpm, ICP 8,855.0 8,855.0 12:15 13:45 1450psi, FCP 1371 psi, 18% F/O, MW 10.5ppg in/out, total 1120 bbls circulated. Note: observed a heavy spot of 10.7+ppg at bottoms up. 11/6/2016 11/6/2016 2.25 SLOT PLUG JAR T RIH and confirm depth offish - no-go 8,855.0 8,880.0 13:45 16:00 out at 8880'. PUW 211 k, SOW 135k. Engage spear and attempt to jar free 7 -518" fish. Jar at 280k and then P/U to 425k. Stage up to jarring at 410k and continue picking up to 425k after each fire. Fire jars total of 60 x times. Unable to jar fish free. 11/6/2016 11/6/2016 0.25 SLOT PLUG PULD T Disengage spear and L/D 2 x 5" DP 8,880.0 8,855.0 16:00 16:15 singles, PUW 211 k. 11/6/2016 11/6/2016 1.25 SLOT PLUG SFTY T Perform post -jarring derrick 8,855.0 8,855.0 16:15 17:30 inspection. SIMOPS L/D casing power tongs off rig floor. 11/6/2016 11/6/2016 4.00 SLOT PLUG TRIP T POOH racking back 5" DP stands ft 8,855.0 235.0 17:30 21:30 8855'- 235' MD, monitoring displacement on trip tank. 11/6/2016 11/6/2016 1.00 SLOT PLUG BHAH T UD fishing BHA as per Baker rep f/ 235.0 0.0 21:30 22:30 235' to surface. Observe damage to packoff element on spear 11/6/2016 11/6/2016 1.00 SLOT PLUG BHAH T Clean and clear rig floor and mobilize 0.0 0.0 22:30 23:30 1 clean out BHA to rig floor. 11/6/2016 11/7/2016 0.50 SLOT PLUG BHAH T P/U cleanout BHA as per Baker rep. 0.0 46.0 23:30 00:00 M/U junk mill, watermelon mill, casing scraper, float, bumper sub, oil jar, and circ sub. 11/7/2016 11/7/2016 0.75 SLOT PLUG BHAH T Finish M/U cleanout BHA as per Baker 46.0 46.0 00:00 00:45 rep, M/U junk mill, watermelon mill, casing scraper, float, bumper sub, oil jar, and circ sub. 11/7/2016 11/7/2016 0.75 SLOT PLUG PULD T RIH w/ cleanout BHA picking up 18 x 46.0 605.0 00:45 01:30 4" HWDP jts from shed f/ 46'-605' MD, monitoring displacement on pit #5. 11/7/2016 11/7/2016 1.25 SLOT PLUG PULD T RIH w! cleanout BHA picking up 42 x 605.0 1,933.0 01:30 02:45 4" DP jts from shed f/ 605'-1933' MD, monitoring displacement on pit #5. Fill pipe and B/D topdrive. Page 14/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK13) End Depth (ftK6) 11/7/2016 11/7/2016 0.50 SLOT PLUG SVRG T Service rig, grease crown, top drive, 1,933.0 1,933.0 02:45 03:15 and blocks. 11/7/2016 11/7/2016 2.75 SLOT PLUG TRIP T RIH w/ cleanout BHA on 4" DP stands 1,933.0 6,448.0 03:15 06:00 f/ 1933'-6448' MD, filling pipe every 20 x stands and monitoring displacement on pit #5 11/7/2016 11/7/2016 1.00 SLOT PLUG REAM T Tag up at 6448' MD w/ 10k 6,448.0 6,475.0 06:00 07:00 downweight, observe 8k overpull. Obtain parameters PUW 167k, SOW 120k, ROT 143k, 30 rpm, 7k Tq. Stage up pumps to 6 bpm, 330 psi, 8% F/O and stage up rotary to 30 rpm, 8-12k Tq. Ream across section f/ 6445-6551' several times then continue down to 6475'. Note: Watermelon mill 12.8' above junk mill on btm 11/7/2016 11/7/2016 1.50 SLOT PLUG TRIP T RIH w/ cleanout BHA on 4" DP stands 6,475.0 8,846.0 07:00 08:30 f/ 6475'-8846' MD, monitoring displacement on pit #5. 11/7/2016 11/7/2016 0.50 SLOT PLUG CIRC T Fill pipe, obtain parameters PUW 8,846.0 8,880.0 08:30 09:00 220k, SOW 138k. Stage up pumps to 5 bpm, 344 psi, 7% F/0, wash down and tag top of 7-5/8" fish @ 8880' MD w/ 5k. 11/7/2016 11/7/2016 1.75 SLOT PLUG CIRC T R/B stand and PIU single to allow for 8,880.0 8,846.0 09:00 10:45 reciprocating full stand. Stage up to 6 bpm, 400 psi, 8% F/0, 40 rpm, 10-12k Tq and work section from 8845'-8875'. Kill rotary, continue staging up pumps to 12 bpm, 930 psi, 16% F/O and reciprocate f/ 8800' - 8875'. Circulate 1 x surface-to-surface volume. 11/7/2016 11/7/2016 1.00 SLOT PLUG OWFF T Monitor well for flow - static. UD 8,846.0 8,846.0 10:45 11:45 single, pump dry job, and B/D top drive. 11/7/2016 11/7/2016 2.75 SLOT PLUG TRIP T POOH racking back 5" DP f/ 8846'- 8,846.0 605.0 11:45 14:30 605' MD, monitoring displacement on trip tank. 11/7/2016 11/7/2016 0.50 SLOT PLUG TRIP T POOH racking back 5" HWDP f/ 605'- 605.0 46.0 14:30 15:00 46' MD, monitoring displacement on trip tank. 11/7/2016 11/7/2016 1.25 SLOT PLUG BHAH T Lay down cleanout BHA as per Baker, 46.0 0.0 15:00 16:15 monitoring displacement on trip tank. Clean/clear rig floor of BHA tools. 11/7/2016 2.00 SLOT PLUG ELOG T Mobilize E -line tools to rig floor and 0.0 0.0 16:15 1111/7/2016 18:15 1 R/U for running E -line. Page 15/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Stag Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth (RKB) 11/7/2016 11/7/2016 5.25 SLOT PLUG ELOG T RIH w/ E-Line EMIT tool and tag up on 0.0 0.0 18:15 23:30 7-5/8" stump. Log section at various frequencies and running speeds as per SLB E-line to obtain correct data for EMIT analysis. POOH and L/D tools. Note: No clear indications observed to show centralizer placement behind pipe. However, SLB E-Line confirmed 10-3/4" collars are at 8836.75', 8797.75', & 8758.75' MD w/ D142's RKB. Unable to clearly indicate depth of lowest collar w/ EM tool, but using joint length from tally, it is at 8873.55' MD w/ D142's RKB. 11/7/2016 11/8/2016 0.50 SLOT PLUG ELOG T R/D E-line and clear rig floor. 0.0 0.0 23:30 00:00 11/8/2016 11/8/2016 2.50 SLOT PLUG ELOG T Remove bell nipple,nipple down dutch 0.0 0.0 00:00 02:30 riser system and remove mouse hole. 11/8/2016 11/8/2016 1.50 SLOT PLUG MPDA T Nipple up RCD on top of annular. 0.0 0.0 02:30 04:00 Obtain measurements needed to modify trip nipple and send over to shop. Install mouse hole. 11/8/2016 11/8/2016 1.50 SLOT PLUG SLPC T PJSM, Slip and cut 102' of drilling line. 0.0 0.0 04:00 05:30 11/8/2016 11/8/2016 0.25 SLOT WHDBOP RURD T Pull wear bushing and install test plug. 0.0 0.0 05:30 05:45 11/8/2016 11/8/2016 0.75 SLOT WHDBOP MPDA T Install test cap on RCD and purge air 0.0 0.0 05:45 06:30 from BOP stack. Pressure test RCD to 250/1500 psi, good test. Page 16/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 �.. Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (WB) 11/8/2016 11/8/2016 4.00 SLOT WHDBOP BOPE T Test witness waived by AOGCC Rep. 0.0 0.0 06:30 10:30 Chuck Scheve. Tested with 5" test joint. 250/3500 psi, charted for 5 minutes each. Test #1 Blind rams, CV # 12,13 and 14, Kill mud manifolds and 4-1/2" Dart Test #2 - Top Pipe rams, CV # 9, #11, mezzanine kill valve, and 4-1/2" IF Floor valve. Test #3- CV #8, #10 and HCR Kill, Test #4 - CV #6, #7 and Manual kill Test #5 - Super Choke & Manual operated choke to 2000 PSI. Test #6 - CV #2, #5 & Annular Test #7 - Upper pipe rams, CV# 3,4,6 and 1. Test #8 - HCR Choke Test #9 - Manual choke and Upper IBOP Test #10 - Lower pipe rams and lower IBOP Perform Koomey draw down test. Observed initial system pressure at 3000 psi, after closure 1650 psi, 200 psi increase in 8 seconds, and full pressures at 51 seconds. Observed 6 nitrogen bottles with an average PSI of 2350 PSI. Tested pit level sensors & flow out alarms. Gas detection alarms tested w/ low & high level. 11/8/2016 11/8/2016 1.00 SLOT WHDBOP RURD T Remove test plug and install wear 0.0 0.0 10:30 11:30 bushing. Blow down choke,kill and top drive. L/D 5" test joint. 11/8/2016 11/8/2016 1.00 SLOT WHPST BHAH T Picked up BHA componets to Rig 0.0 0.0 11:30 12:30 Floor via Beaver Slide. 11/8/2016 11/8/2016 3.00 SLOT WHPST BHAH T Made up BHA and 18 jts 5" HWDP per 0.0 736.0 12:30 15:30 Baker Rep. 11/8/2016 11/8/2016 0.75 SLOT WHPST TRIP T RIH with Whipstock from 736'to 736.0 1,495.0 15:30 16:15 1,495' 11/8/2016 11/8/2016 0.25 SLOT WHPST DHEQ T Shallow tested MWD. 1,495.0 1,495.0 16:15 16:30 11/8/2016 11/8/2016 5.50 SLOT WHPST TRIP T RIH with Whipstock from 1495'to 1,495.0 8,880.0 16:30 22:00 8,880' filling DP every 20 stands. 11/8/2016 11/8/2016 0.75 SLOT WHPST SRVY T Survey and orient Whipstock to 19 8,880.0 8,845.0 22:00 22:45 Deg left of High Side. Set anchor and pull test. Sheared bolt. 11/8/2016 11/9/2016 1.25 SLOT WHPST MILL T Milled Window from 8,845' to 8,846'. 8,845.0 8,846.0 22:45 00:00 655 GPM, 1640 PSI, 2 K WOB,100 RPM, 18 K torque. Up Wt 215K DW 135K Rot Wt 170K. 11/9/2016 11/9/2016 5.50 SLOT WHPST MILL T Milled Window from 8,846'to 8,861'. 8,846.0 8,861.0 00:00 05:30 553 GPM, 1215 PSI, 6 K WOB, 90 RPM, 20 K torque. Up Wt 215K DW 135K Rot Wt 170K. Page 17155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) r 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/9/2016 11/9/2016 4.00 SLOT WHPST MILL T Milled Window from 8,861'to 8,889'. 8,861.0 8,889.0 05:30 09:30 550-746 GPM, 1215-2013 PSI, 15 K WOB, 90 RPM, 17 K torque. Up Wt 215K DW 135K Rot Wt 170K. Upper Mill out into open hole @ 8889' MD. Top of window @ 8847' MD, Bottom of window @ 8867' MD 11/9/2016 11/9/2016 4.00 SLOT WHPST DDRL T Milled 15' of gauge 9-7/8" open hole 8,889.0 8,904.0 09:30 13:30 from 8,889' to 8,904'. 500GPM, 1138 PSI, 13% FO, 15 K WOB, 130 RPM, 17 K torque. Up Wt 215K DW 135K Rot Wt 170K. 11/9/2016 11/9/2016 1.00 SLOT WHPST REAM T Worked Mills through window and 8,904.0 8,847.0 13:30 14:30 Dressed window with and without pumps.750 GPM @ 2,085 PSI, 90 RPM. 11/9/2016 11/9/2016 0.75 SLOT WHPST CIRC T Pulled from top of window @ 8847' to 8,847.0 8,823.0 14:30 15:15 8823' and CBU 800 GPM 2282 PSI. 11/9/2016 11/9/2016 1.00 SLOT WHPST FIT T RU and FIT 14.7 PPG EMW. 8,823.0 8,823.0 15:15 16:15 11/9/2016 11/9/2016 0.50 SLOT WHPST OWFF T Observed well Static. 8,823.0 8,823.0 16:15 16:45 11/9/2016 11/9/2016 3.75 SLOT WHPST TRIP T POOH from 8,823' to 181'. 8,823.0 181.0 16:45 20:30 11/9/2016 11/9/2016 1.00 SLOT WHPST BHAH T POOH cleaning Magnets from 181' to 181.0 120.0 20:30 21:30 120'. Slots were full of metal shavings. 11/9/2016 11/9/2016 1.50 SLOT WHPST BHAH T Laid down BHA. 120.0 0.0 21:30 23:00 11/9/2016 11/10/2016 1.00 SLOT WHPST BHAH T Cleared BHA componets off Rig Floor. 0.0 0.0 23:00 00:00 11/10/2016 11/10/2016 1.00 SLOT WHPST WWWH T M/U stack washer on MI Swaco 0.0 0.0 00:00 01:00 magnets. Wash BOP stack to clean metal cuttings out of stack from milling casing. UD assembly. 11/10/2016 11/10/2016 2.00 SLOT WHPST BHAH T M/U drilling BHA and HWDP to 760' 0.0 0.0 01:00 03:00 MD 11/10/2016 11/10/2016 0.75 SLOT WHPST TRIP T RIH w/ 5" DP f/ 760' MD to 1700' MD. 0.0 1,700.0 03:00 03:45 11/10/2016 11/10/2016 0.25 SLOT WHPST DHEQ T Shallow hole test MWD as per SLB, 1,700.0 1,700.0 03:45 04:00 good test. 11/10/2016 11/10/2016 3.00 SLOT WHPST TRIP T RIH w/ 5" DP f/ 1700' MD to 8814' MD, 1,700.0 8,814.0 04:00 07:00 fill pipe every 20 stands. Observed proper hole fill. 11/10/2016 11/10/2016 0.75 SLOT WHPST MPDA T Remove trip nipple and install MPD 8,814.0 8,814.0 07:00 07:45 bearing as per MPD personal. 11/10/2016 11/10/2016 1.25 SLOT WHPST MPDA T Establish circulation @ 750 gpm=2480 8,814.0 8,814.0 07:45 09:00 psi. Calibrate MPD chokes as per rig engineer. Break in MPD element @ 40 rpm's. Sent downlink to ensure tool is in neutral. P/U= 220K, S/0=143K. 11/10/2016 11/10/2016 0.75 SLOT WHPST CIRC T Obtain slow pump rates @ 8814' MD, 8,814.0 8,814.0 09:00 09:45 5786' TVD, MW=10.5 ppg MP #1: 30 spm=260 psi, 40 spm= 330 psi MP#2: 30 spm= 260 psi, 40 spm= 330 psi Page 18155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK6) End Depth (ftKB) 11/10/2016 11/10/2016 0.75 SLOT WHPST TRIP T Trip BHA though window, Top @ 8,814.0 8,838.0 09:45 10:30 8847' MD, Bottom @ 8867' MD. Set down 1 OK on under gauge hole @ 8880' MD. P/U though window to 8840' MD, observed 15K over pull when pulling bit though bottom of window. RIH back to 8880' MD, set down 1 OK. Lower stabilizer still on the bottom of slide, decision made to P/U and get the stabilizer higher on slide before reaming down to open up under gauge hole. 11/10/2016 11/10/2016 0.50 SLOT WHPST REAM T Shut off Pump and Rotation and 8,838.0 8,887.0 10:30 11:00 pulled up to TOW @ 8,845'5K overpull. Ran back in to 8,887'. 11/10/2016 11/10/2016 1.00 INTRM5 DRILL REAM T Ream from 8,887'to 8,904'50 RPM 8,887.0 8,904.0 11:00 12:00 Torq 15K 551 GPM PP 1586 PSI WOB 2 - 4 K. 11/10/2016 11/10/2016 6.00 INTRM1 DRILL DDRL T Directional Drilled from 8,904'to 8,904.0 9,025.0 12:00 18:00 9,025' MD, 5,874' TVD, GPM 600, PP 1900 PSI, RPM 50 - 100,TQ on Btm 15 - 17K, Off 14K, WOB 5-7K, UW 225K, DW 141K, RW 167K, ECD 11.3, Max Gas 39 units MPD 400 psi, ADT 5.4 Hrs 11/10/2016 11/11/2016 6.00 INTRM1 DRILL DDRL T Directional Drilled from 9,025'to 9,025.0 9,314.0 18:00 00:00 9,314' MD, 5,999' TVD, GPM 650, PP 2355 PSI, RPM 100,TQ on Btm 15 - 18K, Off 14K, WOB 12-17K, UW 215K, DW 141 K, RW 167K, ECD 11.2 - 11.8, Max Gas 39 units MPD 400 psi, ADT 4.69 Hrs 11/11/2016 11/11/2016 6.50 INTRM1 DRILL DDRL T Directional Drilled from 9,314' to 9,314.0 9,712.0 00:00 06:30 9,712' MD, 6,156' TVD, GPM 650, PP 2350 PSI, RPM 130,TQ on Btm 16 - 18K, Off 14K, WOB 18K, UW 213K, DW 140K, RW 172K, ECD 11.75, Max Gas 30 units MPD 400 psi, ADT 4.81 Hrs 11/11/2016 11/11/2016 3.00 INTRM1 DRILL WAIT T Circulated while waiting for survey 9,712.0 9,712.0 06:30 09:30 corrections from Schlumberger, 653 GPM 2400 psi 80 RPM Tq 12K. 11/11/2016 11/11/2016 2.50 INTRM1 DRILL DDRL T Directional Drilled from 9,712'to 9,712.0 9,854.0 09:30 12:00 9,854' MD, 6,225' TVD, GPM 650, PP 2460 PSI, RPM 130,TQ on Btm 16 - 18K, Off 14K, WOB 18K, UW 219K, DW 145K, RW 170K, ECD 11.7 to 11.9, Max Gas 183 units MPD 400 psi, ADT 1.35 Hrs mud lost for 12 Hrs 0 Bbls. 11/11/2016 11/11/2016 7.50 INTRM1 DRILL DDRL T Directional Drilled from 9,854' to 9,854.0 10,414.0 12:00 19:30 10414' MD, 6,351' TVD, GPM 650 to 700, PP 2800 PSI, RPM 130,TQ on Btm 16 - 24K, Off 15 to 18K, WOB 15 to 18K, UW 242K, DW 122K, RW 168K, ECD 11.7 to 11.9, Max Gas 537 units MPD 300 psi, ADT 5.81 Hrs 11/11/2016 11/11/2016 1.50 INTRM1 CASING CIRC T CBU 700 GPM, 2785 PSI, 130 RPM, 10,414.0 10,414.0 19:30 21:00 20K Tq, Took Survey and SPR. Page 19/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/11/2016 11/11/2016 0.75 INTRM1 CASING OWFF T Finger Print Test. Closed choke 10,414.0 10,414.0 21:00 21:45 (MPD) for 5 Min build up 0 PSI, opened for 5 Min No flow 1 PSI. Closed for final build 0 PSI 5 Min. Opened for 10 Min no flow. 11/11/2016 11/12/2016 2.25 INTRM1 CASING CIRC T Circulate and increase MW from 10.7 10,414.0 10,414.0 21:45 00:00 PPG to 11 PPG for Trip Margin. 655 GPM, 2610 PSI, 60 RPM, Tq 13 to 16K, Up 242 Dn 122, Rt 170, ECD 11.6 to 11.9. total mud loss for 12 Hrs 87 Bbl. 11/12/2016 11/12/2016 1.00 INTRM1 CASING CIRC T Circulate and increase MW from 10.7 10,414.0 10,414.0 00:00 01:00 PPG to 11 PPG for Trip Margin. 655 GPM, 2610 PSI, 60 RPM, Tq 13 to 16K, Up 242 Dn 122, Rt 170, ECD 11.6 to 11.9 11/12/2016 11/12/2016 0.50 INTRM1 CASING OWFF T Observed well for 30 min. No Flow. 10,414.0 10,414.0 01:00 01:30 11/12/2016 11/12/2016 2.00 INTRM1 CASING SMPD T POOH Strip out from 10,414'to 9,854' 10,414.0 9,854.0 01:30 03:30 100 psi Back pressure with MPD. Over pull to 30K. Worked tight spots. 11/12/2016 11/12/2016 5.25 INTRM1 CASING BKRM T Backreamed out of the hole From 9,854.0 8,783.0 03:30 08:45 9,854' to 8,783'. 550 GPM 1875 psi Slowed GPM to 366 with 945 psi to come through window, 5-10 K overpull. UW 240K DW 138K, 60 RPM. 11/12/2016 11/12/2016 2.00 INTRM1 CASING CIRC T CBU X 2 650 GPM 2445 psi, 140 8,783.0 8,783.0 08:45 10:45 RPM, 11/12/2016 11/12/2016 0.50 INTRM1 CASING OWFF T OWFF for 30 Min. Lost .5 Bbl. 8,783.0 8,783.0 10:45 11:15 11/12/2016 11/12/2016 1.25 INTRM1 CASING MPDA T Pulled RCD and nipple. Installed Trip 8,783.0 8,783.0 11:15 12:30 nipple. 11/12/2016 11/12/2016 2.00 INTRM1 CASING TRIP T POOH from 8,387to 7,295' UW 205K 8,783.0 7,295.0 12:30 14:30 DW 130K. Dropped 2 7/8" Rabbit on Stand 83. 11/12/2016 11/12/2016 0.50 INTRM1 CASING CIRC T Pumped 20 Bbl Dry Job 5 BPM 340 7,295.0 7,295.0 14:30 15:00 psi. 11/12/2016 11/12/2016 4.25 INTRMI CASING TRIP T POOH from 7,295' to 760'. UW 82K 7,295.0 760.0 15:00 19:15 DW 80K. Recovered Rabbit at HWDP. 11/12/2016 11/12/2016 0.50 INTRMI CASING RURD T Recovered Stripping Rubber and RU 760.0 760.0 19:15 19:45 to LD HWDP. 11/12/2016 11/12/2016 2.75 INTRM1 CASING BHAH T POOH Laying Down BHA from 760'to 760.0 0.0 19:45 22:30 0' 11/12/2016 11/13/2016 1.50 INTRMI CASING BOPE T PJSM and Changed Upper Rams to 7 0.0 0.0 22:30 00:00 5/8". 11/13/2016 11/13/2016 0.50 INTRMI CASING BOPE T PJSM, Cont to change upper rams to 0.0 0.0 00:00 00:30 7-5/8" soild body rams. 11/13/2016 11/13/2016 1.00 INTRM1 CASING BOPE T Pull wear bushing and set test plug. 0.0 0.0' 00:30 01:30 Rig up to test BOPE. 11/13/2016 11/13/2016 0.75 INTRM1 CASING BOPE T Test upper 7-5/8" pipe rams to 0.0 0.01, 01:30 02:15 250/3500 psi and annular to 250/2500 psi with 7-5/8" test joint. Test replacement 4-1/2" IF floor valve to 250/3500 psi. 11/13/2016 11/13/2016 1.00 INTRM1 CASING BOPE Rig down testing equipment and blow 0.0 0.0 02:15 03:15 IT down. Remove test plug and set 12- 1/2" ID wear bushing. Page 20/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/13/2016 11/13/2016 0.76 INTRMI CASING RURD T Rig up to run 7-5/8" liner. C/O to long 0.0 0.0 03:15 04:00 bails, casing elevators and R/U power tongs. 11/13/2016 11/13/2016 3.00 INTRM1 CASING PUTB T M/U Topco shoe, 2 joints, WFT float 0.0 1,684.0 04:00 07:00 collar, 1 joint and BHI landing collar. Test floats, good. RIH w/ 7-5/8', 29.7#, L-80 Hydril 563 casing t/ surface to 1684' MD. P/U= 87K, S/0=87K 11/13/2016 11/13/2016 0.50 INTRM1 CASING OTHR T Changed Handling tools and made up 1,684.0 1,717.0 07:00 07:30 Liner Hanger. 11/13/2016 11/13/2016 0.75 INTRM1 CASING CIRC T Made up 1 stand DP and Broke 1,717.0 1,810.0 07:30 08:15 Circulatinon staging up to 6 BPM. 148 psi with 9% Flow. 11/13/2016 11/13/2016 6.25 INTRM1 CASING RUNL T RIH with Liner on DP from 1,810'to 1,810.0 8,369.0 08:15 14:30 8,369'. UW 240K DW 135K. Fill DP on the fly and top off every 10 Stands. 11/13/2016 11/13/2016 3.00 INTRM1 CASING CIRC T Circulate and condition mud staging 8,369.0 8,369.0 14:30 17:30 pump up to 6 BPH 449 psi. MW in 11.1 MW out 11.2. UW 214K DW 133K. FO 9-10%. 7263 total strokes pumped. 11/13/2016 11/14/2016 6.50 INTRM1 CASING RUNL T RIH with Liner on DP from 8,369' to 8,369.0 10,325.0 17:30 00:00 10,325'. UW 242K DW 132K. Fill DP on the fly and top off every 10 Stands.From 9,600' took 20 to 40K to push in. Running speed adjusted from 250' PH to 100 FPH to keep from stacking weight. Loss for tour 22 Bbls. 11/14/2016 11/14/2016 1.00 INTRM1 CASING RUNL T RIH with Liner on DP from 10,325' to 10,325.0 10,345.0 00:00 01:00 10,345'. UW 242K DW 132K. Fill DP on the fly and top off every 10 Stands.From 9,600' took 20 to 40K to push in. Running speed adjusted from 250' PH to 100 FPH to keep from stacking weight. 11/14/2016 11/14/2016 0.50 INTRM1 CASING RUNL T Washed down from 10,345'to 10,414'. 10,345.0 10,414.0 01:00 01:30 Staged pump up to 4 BPM 520 psi UW 240k DW 130K tagged w 5K. 11/14/2016 11/14/2016 2.75 INTRMI CASING CIRC T CBU staging pump to 7BPM. 615 psi. 10,414.0 10,403.0 01:30 04:15 with 10% FO. Attempted to recipricate but packed off while pulling up. Put pipe @ 10,403' and were able to increase rate to 7 BPM without packing off. Max Gas 397 units. 11/14/2016 11/14/2016 0.50 INTRM1 CEMENT RURD T Laid down Single and made up Baker 10,403.0 10,403.0 04:15 04:45 Plug Dropping Head. 11/14/2016 11/14/2016 6.75 INTRM1 CEMENT CIRC T Circulate and condition mud lowering 10,403.0 10,403.0 04:45 11:30 MW from 11.1 PPG to 10.5 PPG. Staged pump up to 7 BPM 690 PSI. 11/14/2016 11/14/2016 0.50 INTRM1 CEMENT SFTY T PJSM on Cementing. 10,403.0 10,403.0 11:30 12:00 Page 21/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 11/14/2016 11/14/2016 1.00 INTRMI CEMENT CMNT T Schlumberger pumped 5 Bbls water. 10,403.0 8,687.1 12:00 13:00 Tested lines to 4000 psi. Batched up and pumped 40 Bbls of 12.5 PPG Mudpush Followed by 97.6 Bbls Class G cement 15.8 PPG with 1.5 PPG Simnet. 4.4 to 6 BPM. Dart launch confirmed for both Darts. Pumped 10 BUS Water and displaced 2019 Stks with rig pump @ 5 BPM slowing to 3 BPM for last 32 Bbls. Bumped plug with 838 psi held for 5 min. CIP 1304 Hrs. 11/14/2016 11/14/2016 0.50 INTRMI CEMENT PACK T Pressured up to 3800 psi held 5 min 8,687.1 8,687.0 13:00 13:30 to set liner. Set down 60K and bled pressure. Checked floats good. Released from liner and set ZXP packer Disengaged from PBR pumpiong 2 BPM. Top of Liner @ 8687.08'. 11/14/2016 11/14/2016 1.50 INTRM1 CEMENT CIRC T PU 30' to 8657'. Circulated at 7 BPM 8,687.1 8,657.0 13:30 15:00 600 psi staging up to 15 BPM 1196 psi total of 7800 Stks. 11/14/2016 11/14/2016 0.50 INTRM1 CEMENT RURD T Laid down 1 single and cement head. 8,657.0 8,595.0 15:00 15:30 11/14/2016 11/14/2016 1.00 INTRM1 CEMENT CIRC T Circulated staging up to 15 BPM 1190 8,595.0 8,595.0 15:30 16:30 psi total of 8900 Stks. Recip pipe 30'. 11/14/2016 11/14/2016 0.50 INTRM1 CEMENT OWFF T POOH 2 Stands and observe well for 8,595.0 8,433.0 16:30 17:00 10 min. No Flow. 11/14/2016 11/14/2016 0.75 INTRMI CEMENT PRTS T RU and Test Liner Top 1000 psi for 10 8,433.0 8,433.0 17:00 17:45 Min. Good Test. RD test equipment. 11/14/2016 11/14/2016 0.75 INTRM1 CEMENT CIRC T Broke Circulation and pumped Dry 8,433.0 8,433.0 17:45 18:30 Job. 11/14/2016 11/15/2016 5.50 INTRM1 CEMENT PULD T POOH laying down 5" DP from 8,433' 8,433.0 3,000.0 18:30 00:00 to 3,000'. 11/15/2016 11/15/2016 3.50 INTRM1 CEMENT PULD T POOH laying down 5" DP and Baker 3,000.0 0.0 00:00 03:30 Running Tool from 3,000' to Surface. 11/15/2016 11/15/2016 1.50 INTRM1 CEMENT PULD T Laid down 15 Stands 5" DP from the 0.0 0.0 03:30 05:00 Derreck via mousehole. 11/15/2016 11/15/2016 0.50 INTRM1 CEMENT WWWH T Made up Stack wash tool and washed 0.0 0.0 05:00 05:30 stack. 11/15/2016 11/15/2016 0.50 INTRMI CEMENT RURD T Cleared Rig floor and PU Casing 0.0 0.0 05:30 06:00 tools. 11/15/2016 11/15/2016 0.50 INTRM1 CEMENT SVRG T MP2 work on Topdrive and 0.0 0.0 06:00 06:30 Drawworks. 11/15/2016 11/15/2016 0.50 INTRM1 CEMENT RURD T Pulled Wearbushing. 0.0 0.0 06:30 07:00 11/15/2016 11/15/2016 0.50 INTRM1 CEMENT RURD T RU to run casing. 0.0 0.0 07:00 07:30 11/15/2016 11/15/2016 0.50 INTRM1 CEMENT HOSO T Made Dummy run with casing Hanger. 0.0 0.0 07:30 08:00 11/15/2016 11/15/2016 10.00 INTRM1 CEMENT PUTB T Ran 7 5/8" 29.7# L-80 HYD 563 0.0 8,658.0 08:00 18:00 Casing with Tieback seals from Surface to 8,658'. UW 261K DW 141 K. Page 22/55 Report Printed: 112312017 Operations Summary (with Timelog Depths) r� 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/15/2016 11/15/2016 2.00 INTRM1 CEMENT HOSO T RU to circulate. RIH to locate Seals in 8,658.0 8,703.0 18:00 20:00 the PBR. Detected Seal engagment @ 8,694'. Picked up Jt 213 and located on no-go at 8,703'. Tally difference 6.89' Deep. 11/15/2016 11/15/2016 0.50 INTRM1 CEMENT PRTS T Closed Annulur and Tested 7 5/8" X 8,703.0 8,703.0 20:00 20:30 10 3/4" Annulus to 2,000 PSI for 10 Min. 11/15/2016 11/15/2016 1.00 INTRMI CEMENT HOSO T Space out Casing with 2 Pups total 8,703.0 8,703.0 20:30 21:30 2.12' below the first full A. Landed Hanger and confirmed seal engagment with 200 PSI PT on annulus. Bled off after 10 Min on chart. 11/15/2016 11/15/2016 1.00 INTRM1 CEMENT HOSO T Picked up 10' and Made Dummy run 8,703.0 8,703.0 21:30 22:30 with Annular closed stripping and landed out Hanger. 11/15/2016 11/16/2016 1.50 INTRMI CEMENT CRIH T Picked up to 8,693'. Closed annular 8,703.0 8,693.0 22:30 00:00 and Reverse circulated 30 BUS spacer pill followed by 175 BUS of 300 BUS of Inhibited Water @ 3 BPM. ICP 400 PSI FCP 565 PSI. 11/16/2016 11/16/2016 0.75 INTRMI CEMENT CRIH T Circulated 125 Bbls of of Inhibited 8,693.0 8,693.0 00:00 00:45 Water @ 3.5 BPM. ICP 565 PSI FCP 670 PSI. 11/16/2016 11/16/2016 1.00 INTRM1 CEMENT FRZP T Switched over to LRS and pumped 8,693.0 8,693.0 00:45 01:45 200 Bbls Isotherm 3 BPM 1200 PSI. SIP 700 PSI. 11/16/2016 11/16/2016 0.25 INTRM1 CEMENT HOSO T Slacked off and landed casing while 8,693.0 8,703.0 01:45 02:00 bleeding off annulus. 11/16/2016 11/16/2016 2.00 INTRM1 CEMENT RURD T Evacuate Isotherm from Stack and 8,703.0 8,703.0 02:00 04:00 drained and laid down Landing Jt. 11/16/2016 11/16/2016 3.00 INTRM1 CEMENT WWSP T Set Packoff and filled void per 8,703.0 8,703.0 04:00 07:00 Cameron Rep. 11/16/2016 11/16/2016 0.50 INTRMI CEMENT WWSP T Tested Packoff to 5,000 PSI for 10 8,703.0 0.0 07:00 07:30 Min Wittnessed by CPAI Rep. 11/16/2016 11/16/2016 3.00 INTRM1 CEMENT PRTS T Pressured Annulus to 2,000 PSI for 30 0.0 0.0 07:30 10:30 Min. Chart and Gauge were not reading the same. Repeated the Test 2,000 PSI for 30 Min. Test was done pumping Isotherm. Bled off and left 150 PSI on the OA. 11/16/2016 11/16/2016 0.50 INTRM1 CEMENT RURD T Rigged down and blew down test 0.0 0.0 10:30 11:00 equiment. 11/16/2016 11/16/2016 1.00 INTRM1 CEMENT BOPE T Changed Top Rams from 7 5/8" to 3.5 0.0 0.0 11:00 12:00 to 6" VBR. 11/16/2016 11/16/2016 1.50 INTRM1 WHDBOP RURD T Set Test Plug with 4" Test Jt and filled 0.0 0.0 12:00 13:30 Stack with water. Body tested to 3500 PSI Page 23/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (WB) 11/16/2016 11/16/2016 4.50 INTRM1 WHDBOP BOPE T Test witness waived by AOGCC Rep. 0.0 0.0 13:30 18:00 Brian Bixby. Tested with 4" and 4.5" test joints. 250/3500 psi, charted for 5 minutes each. Test #1 Blind rams, CV # 12,13 and 14, Kill mud manifolds and 4-1/2" Dart Test #2 - Top Pipe rams, CV # 9, #11, mezzanine kill valve, and 4-1/2" IF Floor valve. Test #3- CV #8, #10 and HCR Kill, Test #4 - CV #6, #7 and Manual kill Test #5 - Super Choke & Manual operated choke to 2000 PSI. Test #6 - CV #2, #5 & Annular Test #7 - Upper pipe rams, CV# 3,4,6 and 1. Test #8 - HCR Choke Test #9 - Manual choke and Upper IBOP Test #10 - Lower pipe rams and lower IBOP Perform Koomey draw down test. Observed initial system pressure at 3000 psi, after closure 1650 psi, 200 psi increase in 8 seconds, and full pressures at 51 seconds. 11/16/2016 11/16/2016 1.00 INTRM1 WHDBOP RURD T Pulled and Laid down test plug and 0.0 0.0 18:00 19:00 test Jt. Installed Long Wearbushing with 12.5" ID. 11/16/2016 11/16/2016 0.50 INTRM1 CEMENT RURD T Cleared off and cleaned Rig Floor. 0.0 0.0 19:00 19:30 11/16/2016 11/16/2016 4.00 INTRMI CEMENT PULD T PU and stood back in Derreck 60 Jts 0.0 0.0 19:30 23:30 (20 Stands) of 4" HWDP. Then PU and stood back in Derreck 30 Jts (10 Stands) of 4" DP. 11/16/2016 11/17/2016 0.50 INTRM1 CEMENT BHAH T PU BHA per Slumberger Reps to 21' 0.0 21.0 23:30 00:00 11/17/2016 11/17/2016 1.75 INTRM1 CEMENT BHAH T Finish PU BHA per Schlumberger to 21.0 367.0 00:00 01:45 367". 11/17/2016 11/17/2016 1.75 INTRM1 CEMENT PULD T RIH with BHA single in DP from the 367.0 1,784.0 01:45 03:30 Pipeshed from 367'to 1,784'. UW 76K DW 72K. Filled pipe every 20 stands. 11/17/2016 11/17/2016 0.50 INTRM1 CEMENT SVRG T Serviced Rig. 1,784.0 1,784.0 03:30 04:00 11/17/2016 11/17/2016 0.50 INTRM1 CEMENT DHEQ T Shallow tested MWD. 1,784.0 1,784.0 04:00 04:30 11/17/2016 11/17/2016 8.25 INTRM1 CEMENT PULD T RIH with BHA single in DP from the 1,784.0 8,512.0 04:30 12:45 Pipeshed from 1,784' to 8,512'. UW 180K DW 102K. Filled pipe every 20 stands. 11/17/2016 11/17/2016 7.00 INTRM1 CEMENT QEVL T RIH 8,500' to 10,218' Logging with 8,512.0 10,218.0 12:45 19:45 MWD/LWD @ 450 FPH. UW 196K DW 100K. 230 GPM ICP 1,570 psi FCP 1,718 psi. Page 24/55 Report Printed: 1/23/2017 _- Operations Summary (with Timelog Depths) B 2S-13 MW Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time I Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 11/17/2016 11/17/2016 2.00 INTRM1 CEMENT CIRC T Circulated and conditioned Mud for 10,218.0 10,218.0 19:45 21:45 Casing Test. Reduced MW from 10.7 PPG to 10.5 PPG. 40 RPM Tq 11 K 230 GPM 1767 psi. Recip full stand. UW 214K DW 102K RtW 129K Total Stk pumped 6090. 11/17/2016 11/17/2016 1.25 INTRM1 CEMENT PRTS T RU and Tested Casing 3,650 psi for 10,218.0 10,218.0 21:45 23:00 30 Min on chart. RD test hose. 11/17/2016 11/18/2016 1.00 INTRM1 CEMENT COCF T Cleaned out down from 10,218' to 10,218.0 10,279.0 23:00 00:00 Landing collar @ 10,276'. Drilled LC and cement down to 10,279'. GPM 230, PP 1730 psi, RPM 40, Tq 11 K, UW 214K, DW 101 K, RTW 132K WOB 8 - 1 OK. Tagged Cement and Plug @ 10,266'. 11/18/2016 11/18/2016 3.25 INTRM1 CEMENT DRLG T Continue to Clean out Shoetrack and 10,279.0 10,414.0 00:00 03:15 Rathole. From 10,279' to 10,414'. FC and Shoe came in 5' low. FC @ 10,360' and Shoe @ 10,406'. 230 GPM, 1825 psi, 5 - 1 O WOB, 60 RPM. 11/18/2016 11/18/2016 0.50 INTRM1 CEMENT DDRL T Directional Drilled from 10,414'to 10,414.0 10,434.0 03:15 03:45 10434' MD, 6,360' TVD, GPM 230, PP 1905 PSI, RPM 60,TQ on Btm 11.5K, WOB 5 to 10K, UW 174K, DW 104K, RW 133K, ECD 11 i, ADT .40 Hrs 11/18/2016 11/18/2016 1.00 INTRM1 CEMENT CIRC T Circulated and conditioned Mud for 10,434.0 10,434.0 03:45 04:45 Casing Test. MW 10.5 PPG. 60 RPM Tq 11 K 230 GPM 1914 psi. Recip full stand. UW 177K DW 105K RtW 133K Total Stk pumped 3265. 11/18/2016 11/18/2016 0.75 INTRM1 CEMENT FIT T Pulled into casing shoe @ 10,406'. 10,434.0 10,404.0 04:45 05:30 Did FIT to 13.5 PPG EMW. 11/18/2016 11/18/2016 1.50 PROD1 DRILL MPDA T Pulled Flow Nipple and Installed RCD 10,404.0 10,404.0 05:30 07:00 Bearing and Nipple. Calibrated MPD Chokes. 11/18/2016 11/18/2016 1.75 PROD1 DRILL DISP T Pumped 20 Bbl Spacer. Displaced 10,404.0 10,404.0 07:00 08:45 well to 9.8 PPG FloPro system. 230 GPM, 1930 psi, 60 RPM, 8 to 9K Tq. UW 174K DW 104K RW 133K. Total Stks 4805. Took SPR. 11/18/2016 11/18/2016 0.75 PROD1 DRILL OWFF T Took SPR through MPD Choke. Did 10,404.0 10,404.0 08:45 09:30 Drawdown test with MPD Choke. 11/18/2016 11/18/2016 1.00 PROD1 DRILL CIRC T Circulated and conditioned Mud MW 10,404.0 10,404.0 09:30 10:30 9.8 PPG. 60 RPM Tq 11 K 230 GPM 1874 psi. Recip full stand. UW 177K DW 105K RtW 133K Total Stk pumped 3300. MPD BP 15 psi 11/18/2016 11/18/2016 0.50 PROD1 DRILL SVRG T Serviced Rig. 10,404.0 10,404.0 10:30 11:00 11/18/2016 11/18/2016 0.25 PROD1 DRILL REAM T Circulated and Washed from 10404'to 10,404.0 10,434.0 11:00 11:15 10434'. MW 9.8 PPG. 60 RPM Tq 11 K 230 GPM 1874 psi. UW 177K DW 105K RtW 133K 11/18/2016 11/18/2016 6.75 PROD1 DRILL DDRL T Directional Drilled from 10,434'to 10,434.0 10,879.0 11:15 18:00 10879' MD, 6,340' TVD, GPM 263, PP 2310 PSI, RPM 150,TQ on Btm 11.5K, WOB 15K, UW 177K, DW 101 K, RW 130K, ECD 10.97, ADT 4.52 Hrs Max Gas 190 units. MPD BP 15 psi. Page 25155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/18/2016 11/19/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 10,879'to 10,879.0 11,542.0 18:00 00:00 11,542' MD, 6,315' TVD, GPM 271, PP 2435 PSI, RPM 150,TQ on Btm 11.5K, WOB 7K, UW 173K, DW 98K, RW 130K, ECD 11.27, ADT 4.01 Hrs Max Gas 209 units MPD BP 15 psi. 11/19/2016 11/19/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 11,542' to 11,542.0 12,207.0 00:00 06:00 12,207' MD, 6,312' TVD, GPM 272, PP 2460 PSI, RPM 150,TQ on Btm 11.5K, WOB 13K to 15K, UW 177K, DW 100K, RW 128K, ECD 11.21, ADT 4.17 Hrs Max Gas 140 units MPD BP 15 psi. 11/19/2016 11/19/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 12,207' to 12,207.0 13,154.0 06:00 12:00 13,154' MD, 6,290' TVD, GPM 272, PP 2530 PSI, RPM 150,TQ on Btm 15K, WOB 15K to 16K, UW 195K, DW 90K, RW 132K, ECD 11.36, ADT 3.94 Hrs Max Gas 120 units MPD BP 15 psi. 11/19/2016 11/19/2016 4.75 PROD1 DRILL DDRL T Directional Drilled from 13,154' to 13,154.0 13,912.0 12:00 16:45 13,912' MD, 6,272' TVD, GPM 272, PP 2695 PSI, RPM 160,TQ on Btm 15K, WOB 15K to 16K, UW 189K, DW 86K, RW 132K, ECD 11.45, ADT 2.93 Hrs Max Gas 286 units MPD BP 15 psi. 11/19/2016 11/19/2016 0.50 PROD1 DRILL SVRG T Serviced Rig. 13,912.0 13,912.0 16:45 17:15 11/19/2016 11/19/2016 0.50 PROD1 DRILL RGRP T Changed seal in Union on HP Mud 13,912.0 13,912.0 17:15 17:45 Hose between the Pump Module and Rig. 11/19/2016 11/19/2016 2.75 PROD1 DRILL DDRL T Directional Drilled from 13,912' to 13,912.0 14,100.0 17:45 20:30 14,100' MD, 6,276' TVD, GPM 272, PP 2540 PSI, RPM 160,TQ on Btm 16K, WOB 15K to 14.5K, UW 189K, DW 86K, RW 132K, ECD 11.45, ADT 2.93 Hrs Max Gas 0 units MPD BP 15 psi. 11/19/2016 11/19/2016 1.00 PROD1 DRILL MPDA T Changed RCD Bearing. Maintained 14,100.0 14,100.0 20:30 21:30 150 PSI with Bag. Warmed up bearing. 11/19/2016 11/20/2016 2.50 PROD1 DRILL DDRL T Directional Drilled from 14,100' to 14,100.0 14,384.0 21:30 00:00 14,384' MD, 6,294' TVD, GPM 272, PP 2690 PSI, RPM 160,TQ on Btm 15K, WOB 14.5K, UW 193K, DW 86K, RW 132K, ECD 10.91, ADT 1.56 Hrs Max Gas 253 units MPD BP 15 psi. 11/20/2016 11/20/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 14,384'to 14,384.0 15,237.0 00:00 06:00 15,237' MD, 6,298' TVD, GPM 272, PP 2675 PSI, RPM 160,TQ on Btm 15.5K, WOB 15.5K, UW 207K, DW 68K, RW 127K, ECD 11.52, ADT 4.22 Hrs Max Gas 225 units MPD BP 15 psi. 11/20/2016 11/20/2016 6.00 PROD1 DRILL DDRL T Directional Drilled from 15,237'to 15,237.0 15,978.0 06:00 12:00 15,978' MD, 6,298' TVD, GPM 272, PP 2865 PSI, RPM 160,TQ on Btm 15K, WOB 14K, UW 206K, DW 82K, RW 129K, ECD 11.61, ADT 3.31 Hrs Max Gas 240 units MPD BP 15 psi. Page 26/55 Report Printed: 1/23/2017 - Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/20/2016 11/20/2016 8.25 PROD1 DRILL DDRL T Directional Drilled from 15,978'to 15,978.0 16,917.0 12:00 20:15 16,917' MD, 6,250' TVD, GPM 272, PP 3165 PSI, RPM 160,TQ on Btm 15K, WOB 14.5 to 6.5K, UW 220K, DW 84K, RW 145K, ECD 11.71, ADT 6.03 Hrs Max Gas 204 units MPD BP 15 psi. 11/20/2016 11/20/2016 1.25 PROD1 CASING CIRC T CBU 279 GPM 3120 psi, 160 RPM, 16,917.0 16,917.0 20:15 21:30 13K Tq, 11.54 ECD, Max Gas 120 units, RW 137K 11/20/2016 11/20/2016 1.00 PROD1 CASING OWFF T Did Drawdown test w MPD. Build up 16,917.0 16,917.0 21:30 22:30 pressuer declined each cycle indicating Well Bore Breathing. 11/20/2016 11/21/2016 1.50 PROD1 CASING OWFF T OWFF to confirm Breathing. 16,917.0 16,917.0 22:30 00:00 11/21/2016 11/21/2016 1.00 PROD1 CASING OWFF T OWFF to confirm Breathing. Breathing 16,917.0 16,917.0 00:00 01:00 confirmed. 11/21/2016 11/21/2016 0.25 PROD1 CASING PULD T Lay down single and drop rabbit. 16,917.0 16,888.0 01:00 01:15 11/21/2016 11/21/2016 7.25 PROD1 CASING BKRM T Back Reamed from 16,888' to 14,767' 16,888.0 14,767.0 01:15 08:30 GPM 272 PP 2650 psi, RPM 150 with Tq 11-13K ECD 11.51, Max Gas 711 units. 11/21/2016 11/21/2016 6.50 PROD1 CASING REAM T Well packed off @ 14,767'. Worked 14,767.0 14,873.0 08:30 15:00 Tight Spots 14,861' establishing pump and rotation. Stood back one stand and PU a single to have room to work. Established circulation and rotation at 14,873'. Recipicated and rotated while staging pump up to 5 BPM with 1920 psi, 140 RPM with 12K Tq, ECD 11.17. Laid down single. 11/21/2016 11/21/2016 1.50 PROD1 CASING BKRM T Backreamed from 14,873' to 14,665' 14,873.0 14,665.0 15:00 16:30 Worked pump up to 6 BPM 2440 psi, 140 RPM 12K Tq, Continue to adjust pump rate for packoff. 11/21/2016 11/21/2016 1.00 PROD1 CASING SMPD T RIH from 14,665'to 15,046'to check 14,665.0 15,046.0 16:30 17:30 hole condition. DW 60 to 75K. 11/21/2016 11/21/2016 1.50 PROD1 CASING SMPD T POOH from 15,046'to 14,665' Strip 15,046.0 14,665.0 17:30 19:00 out with 175 psi BP. UW 209K. 11/21/2016 11/22/2016 5.00 PROD1 CASING BKRM T Backreamed from 14,665' to 13,915' 14,665.0 13,903.3 19:00 00:00 GPM 254 2375 psi, 140 RPM 14.3K Tq, Started @ 250 FPH and increased to 500 FPH. Minor packoff @ 14,880'. 11/22/2016 11/22/2016 6.00 PROD1 CASING BKRM T Backream OOH f/ 13915'- 12210'w/ 13,903.3 12,198.3 00:00 06:00 265 gpm, 2320 psi, 9% F/0, 11.16 ECD, 140 rpm, 10-12k Tq, pulling at 700 ft/hr as hole conditions allow. 11/22/2016 11/22/2016 5.25 PROD1 CASING BKRM T Backream OOH f/ 12210' - 11504' wl 12,198.3 11,492.3 06:00 11:15 265 gpm, 2155 psi, 9% F/0, 11.01 ECD, 140 rpm, 8-10k Tq, pulling at 700 ft/hr as hole conditions allow. Page 27/55 Report Printed: 1/23/2017 a# Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/22/2016 11/22/2016 0.75 PROD1 CASING PMPO T Pump OOH f/ 11504'- 10414'w/ 265 11,492.3 10,488.3 11:15 12:00 gpm, 2090 psi, 9% F/O. Observe pressure increase to 2400 psi at 10414' MD. RIH to 10420', bleed off pressure, and pull up into shoe to 10402'w/ no pumps, PUW 177k. Establish rate inside casing w/ 265 gpm, 2125 psi, 10% F/O, 100 rpm, 8- 9k Tq. Kill pumps and rotary and trip in hole to 10500'. 11/22/2016 11/22/2016 1.00 PROD1 CASING REAM T Attempt to pull back into shoe w/ 200 10,488.3 10,392.3 12:00 13:00 gpm, 1375 psi - observe pack off wl bit at the 7-5/8" shoe. Kill pump and drop down below shoe. Pull bit inside shoe, observing slight overpull, and stage up pumps to 3.5 bpm. Observe hole start to pack off at 3.5 bpm, drop rate to 3 bpm, 787 psi, and stage up rotary to 80 rpm, 7k Tq, ROT 133k and ream through shoe. Kill pumps and rotary and trip through shoe, no issues, PUW 173k, SOW 112k. 11/22/2016 11/22/2016 3.25 PROD1 CASING DISP T Circulate cased hole to Kill weight Flo- 10,392.3 10,392.3 13:00 16:15 Pro. Pump 30 bbl low -vis sweep followed by 30 bbl hi -vis sweep. Continue circulating and weighting up system from 9.8ppg to 10.Oppg Flo - Pro, total 940 bbls pumped. 11/22/2016 11/22/2016 0.75 PROD1 CASING OWFF T Perform MPD drawdown, observing 10,392.3 10,392.3 16:15 17:00 pressure drop f/ 58 psi to 28 psi on continuous decreasing trend, indiciating slight breathing - well deemed static. 11/22/2016 11/22/2016 2.50 PROD1 CASING SLPC T Slip / cut 117' drill line and calibrate 10,392.3 10,392.3 17:00 19:30 top drive / amphion system. SIMOPS - Continue to OWFF observing flow decrease to static. Open up MPD chokes and inspect - large amount of aluminum and rubber found in choke #1 11/22/2016 11/23/2016 4.50 PROD1 CASING BKRM T Backream OOH fl 10404'- 8700'w/ 10,392.3 8,688.3 19:30 00:00 200 gpm, 1300 psi, 7% F/O 10.61 ECD, 50 rpm, 7k Tq, ROT 130k. Note: Unable to strip OOH due to floats not holding OA pressure = 1050 psi 11/23/2016 11/23/2016 6.00 PROD1 CASING BKRM T Backream OOH f/ 8700'- 5667'w/ 200 8,688.3 5,655.3 00:00 06:00 gpm, 1100 psi, 8% F/O, 50 rpm, 6.5k Tq, ROT 119k. Note: 2.38" rabbit was stuck in stand #74. Racked by itself on drillers side and re -drifted stand #75 to confirm it was ok. Page 28/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) off; 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/23/2016 11/23/2016 6.00 PROD1 CASING BKRM T Backream OOH f/ 5667'- 2546'w/ 200 5,655.3 2,534.3 06:00 12:00 gpm, 865 psi, 8% F/O, 50 rpm, 2k Tq, ROT 79k. Note: 2.38" rabbit was stuck in stand #45. Racked by itself on drillers side. Found rabbit stuck again in stand #41. Removed 2.38" rabbit and dropped 1.9" (1 29/32") rabbit from stand #41 onwards. 11/23/2016 11/23/2016 1.50 PROD1 CASING CIRC T Circulate / condition hole clean, 2,534.3 2,534.3 12:00 13:30 pumping 25 bbl hi -vis sweep followed with 10.Oppg Flo -Pro at 241 gpm, 1152 psi, 11% F/O, 50 rpm, 1.5k Tq, 10.87 ppg ECD. Note: Observed large amount of cuttings coming over shakers after first bottoms up. 11/23/2016 11/23/2016 4.00 PROD1 CASING PMPO T Pumped OOH to top of HWDP f/ 2546' 2,534.3 355.3 13:30 17:30 - 367'w/ 240 gpm, 1120 psi, 7% F/O. 11/23/2016 11/23/2016 1.00 PROD1 CASING CIRC T Pumped hi -vis sweep and chased with 355.3 355.3 17:30 18:30 10.Oppg Flo -Pro w/ 240 gpm, 940 psi, 12% F/O, 50 rpm, 1 k Tq. Note: Observed metal shavings coming over the shakers at bottoms up, large majority being aluminum and small portion being steel. 11/23/2016 11/23/2016 0.25 PROD1 CASING OWFF T Monitor well for flow - static. Blow 355.3 355.3 18:30 18:45 down top drive. 11/23/2016 11/23/2016 1.50 PROD1 CASING MPDA T Pull MPD bearing assembly and drain 355.3 355.3 18:45 20:15 nipple. Install trip nipple. Clean / clear rig floor. 11/23/2016 11/23/2016 2.25 PROD1 CASING BHAH T Pull OOH racking back HWDP and 355.3 -11.8 20:15 22:30 jars and laying down BHA. Observed both flapper and plunger floats plugged open with debris. Bit graded 3 -2 -BT -N -X -2 -CT -TD. SI MOPS - Blow down MPD lines. 11/23/2016 11/23/2016 0.50 PROD1 CASING BHAH T Clean / clear rig floor -11.8 -11.8 22:30 23:00 11/23/2016 11/24/2016 1.00 COMPZ1 CASING RURD T Rig up to run 4-1/2" liner. -11.8 -11.8 23:00 00:00 OA pressure = 360 psi 11/24/2016 11/24/2016 1.00 COMPZ1 CASING RURD T Rig up to run liner, change out -11.8 -11.8 00:00 01:00 elevators and rig up power tongs. Confirm pipe count in shed. 11/24/2016 11/24/2016 0.25 COMPZ1 CASING SFTY T Hold PJSM for running 4-1/2" liner. -11.8 -11.8 01:00 01:15 11/24/2016 11/24/2016 4.75 COMPZ1 CASING PUTB T Run 4-1/2" 12.6# L-80 IBT-m liner as -11.8 2,369.3 01:15 06:00 per tally to 2381', allowing liner to self - fill and monitoring displacement on pit #5. 11/24/2016 11/24/2016 6.00 COMPZ1 CASING PUTB T Run 4-1/2" 12.6# L-80 IBT-m liner as 2,369.3 5,763.3 06:00 12:00 per tally f/ 2381'- 5775', allowing liner to self -fill and monitoring displacement on pit #5. PUW 95k, SOW 82k. Page 29155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/24/2016 11/24/2016 1.75 COMPZ1 CASING PUTB T Run 4-1/2" 12.6# L-80 IBT-m liner as 5,763.3 6,593.3 12:00 13:45 per tally f/ 5775'- 6605', allowing liner to self-fill and monitoring displacement on pit #5. SOW 85k. 11/24/2016 11/24/2016 2.25 COMPZ1 CASING OTHR T Make up sealbore extension, Liner 6,593.3 6,763.3 13:45 16:00 hanger / packer assembly, and running tool. Fill liner sleeve with Pal mix. Make up float sub w/ flapper-style float, XO, and 1 x stand 4" DP to 6775'. 11/24/2016 11/24/2016 0.25 COMPZ1 CASING CIRC T Stage up pumps to 2 bpm, 100 psi 6,763.3 6,763.3 16:00 16:15 and confirm circulation. Blow down top drive. PUW 105k, SOW 88k. 11/24/2016 11/24/2016 3.25 COMPZ1 CASING RUNL T Run liner in on 4" DP stands f/ 6775'- 6,763.3 10,363.3 16:15 19:30 10375' just above shoe, filling pipe on the fly and topping off every 5 x stands with fill-up hose, monitoring displacement on pit #5. SOW 105k. Note: Rabbited stand 45 & 74 from derrick w/ 2" OD drift 11/24/2016 11/24/2016 0.75 COMPZ1 CASING CIRC T Stage up to 5 bpm, 528 psi, 8% F/O 10,363.3 10,363.3 19:30 20:15 and circulate 1 x DP volume. Drop rate to 3 bpm, 312 psi, 5% F/O and rotate string at 30 rpm, 7k tq, ROT 124k. Kill pump / rotary, work torque out, and obtain PUW 145k, SOW 107k. Total 45 bbls pumped. Blow down top drive. Cased hole FF = 0.15 11/24/2016 11/25/2016 3.75 COMPZ1 CASING RUNL T Run liner in on 4" DP stands f/ 10375' 10,363.3 13,678.3 20:15 00:00 - 13690', filling pipe on the fly and topping off every 5 x stands with fill-up hose, monitoring displacement on pit #5. Observe open hole FF increase to 0.25-0.30. OA pressure = 100 psi 11/25/2016 11/25/2016 6.75 COMPZ1 CASING RUNL T Run liner in on total of 88 x 4" DP 13,678.3 16,854.3 00:00 06:45 stands and 20 x 4" HWDP stands f/ 13690'- 16866', filling pipe on the fly and topping off every 5 x stands with fill-up hose, monitoring displacement on pit #5. PUW 200k, SOW 80k. Make up 5' spaceout pup on top of HWDP. Note: Rabbited HWDP stands 19 & 20 from derrick w/ 2" OD drift 11/25/2016 11/25/2016 1.00 COMPZ1 CASING RUNL T RIH to 16905' and obtain parameters, 16,854.3 16,893.3 06:45 07:45 PUW 200k, SOW 80k. Stage up pumps to 5 bpm, 1055 psi, 8% F/O and circulate 1 x DP volume. Page 30/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) X17 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/25/2016 11/25/2016 1.25 COMPZ1 CASING PACK T Drop 1.5" phenolic ball and pump 16,893.3 16,893.3 07:45 09:00 down @ 3 bpm, 650 psi, 6% F/0, reducing to 2 bpm, 490 psi, 5% F/0 after 470 strokes. Ball on seat @ 770 strokes. Pressure up to 2500 psi and slack off to block weight to set hanger. Pressure up to 3500 psi to release from hanger and observe pressure falling off and flow returns at surface. Pick up to 200k and confirm not released yet. Slack off to block weight and pressure up to 2500 psi, observing pressure fall off and flow returns at surface. Pick up to 208k and confirm not released yet. 11/25/2016 11/25/2016 1.00 COMPZ1 CASING PACK T Drop 2nd 1.5" ball and pump down at 16,893.3 16,893.3 09:00 10.00 3 bpm, ICP 1215 psi, FCP 970 psi, 7% F/0, reducing to 2.5 bpm, 780 psi, 6% F/O after 700 strokes. Total of 1002 strokes pumped, no pressure increase observed to indicate ball seated. 11/25/2016 11/25/2016 1.50 COMPZI CASING PACK T Work down left-hand torque and 16,893.3 16,893.3 10:00 11:30 perform left-hand release from liner as per Baker rep. Pick up and release dogs, PUW 175k, SOW 135k. 11/25/2016 11/25/2016 0.50 COMPZ1 CASING PACK T Set liner top packer as per Baker w/ 16,893.3 10,220.3 11:30 12:00 30rpm, 1 Ok Tq, slacking off to block weight to confirm set. PUW 175k, SOW 135k. Liner top packer set at 10,232.11' MD. 11/25/2016 11/25/2016 1.25 COMPZ1 CASING PRTS T Rig up and pressure test liner top 10,220.3 10,220.3 12:00 13:15 packer to 3500 psi, 30 min, charted - good test. Blow down lines. 11/25/2016 11/25/2016 0.50 COMPZ1 WELLPR TRIP T Pull OOH f/ 10230'- 10171', racking 10,220.3 10,159.3 13:15 13:45 back 4" DP stand and laying down 4" pup joint. 11/25/2016 11/25/2016 2.25 COMPZ1 WELLPR CIRC T Circulate / condition mud while 10,159.3 10,159.3 13:45 16:00 reciprocating w/ 300 gpm, 1290 psi. PUW 184k, SOW 133k. No gas observed at bottoms up but observed 9.8+-9.9 ppg returns. Continue circulating until I Oppg in/out observed. 11/25/2016 11/25/2016 0.50 COMPZ1 WELLPR CRIH T Pump 10 bbis hi -vis spacer followed 10,159.3 10,159.3 16:00 16:30 by 9 bbls Corrosion Inhibited brine, followed by 20 bbls hi -vis spacer. Chase with 10.Oppg mud to spot. 11/25/2016 11/25/2016 1.00 COMPZ1 WELLPR PMPO T Pull up above Cl pill f/ 10171'- 10025'. 10,159.3 9,624.3 16:30 17:30 Pump OOH laying in hi -vis spacer ft 10025'- 9636'w/ 2 bpm, 375 psi, PUW 178k. 11/25/2016 11/25/2016 1.00 COMPZ1 WELLPR OWFF T Monitor well for flow - observe well 9,624.3 9,624.3 17:30 18:30 breathing back slowly on decreasing trend. Continue to monitor, initial rate of 62 sec/quart decrease to 97 sec/quart. Page 31/55 Report Printed: 112312017 . Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/25/2016 11/25/2016 1.50 COMPZ1 WELLPR TRIP T Pull OOH on elevators f/ 9636'- 8805', 9,624.3 8,793.3 18:30 20:00 racking back 4" HWDP, monitoring displacement on pit #5. pulling speed 15-20 ft/min, PUW 157k, SOW 117k. Observe incorrect hole fill. 11/25/2016 11/25/2016 0.25 COMPZ1 WELLPR OWFF T Monitor well for flow - static. 8,793.3 8,793.3 20:00 20:15 11/25/2016 11/25/2016 2.75 COMPZ1 WELLPR PMPO T Pump OOH f/ 8805'- 7018' w/ 3.5 8,793.3 7,006.3 20:15 23:00 bpm, 415 psi, 5% F/O, monitoring displacement on pit #5. PUW 132k. 11/25/2016 11/25/2016 0.25 COMPZ1 WELLPR OWFF T Blowdown topdrive and monitor well 7,006.3 7,006.3 23:00 23:15 for flow - well static. 11/25/2016 11/26/2016 0.75 COMPZ1 WELLPR TRIP T Pull OOH f/ 7018'- 6547', monitoring 7,006.3 6,535.3 23:15 00:00 displacement on pit #5. PUW 124k. 11/26/2016 11/26/2016 0.75 COMPZ1 WELLPR TRIP T Pull OOH f/ 6547'- 6156' at 1080 ft/hr 6,535.3 6,144.3 00:00 00:45 pulling speed, monitoring displacement on pit #5. Observe incorrect hole fill. 11/26/2016 11/26/2016 0.25 COMPZ1 WELLPR OWFF T Monitor well for flow - static. 6,144.3 6,144.3 00:45 01:00 11/26/2016 11/26/2016 3.00 COMPZ1 WELLPR PMPO T Pump OOH f/ 6156'- 4260' at 4000 6,144.3 4,248.3 01:00 04:00 ft/hr pulling speed w/ 4 bpm, 320 psi to offset swab, monitoring displacement on pit #5. Blow down top drive and confirm well static. 11/26/2016 11/26/2016 3.50 COMPZ1 WELLPR TRIP T Pull OOH f/ 4260'- 65 at 3000 ft/hr 4,248.3 53.3 04:00 07:30 pulling speed, monitoring displacement on trip tank. 11/26/2016 11/26/2016 1.00 COMPZ1 WELLPR BHAH T Lay down liner running tools, 53.3 -11.8 07:30 08:30 monitoring displacement on trip tank - observe good indication of shear. Recovered both 1.5" balls. 1st ball had signs of washout on it. 2nd ball was not damaged. 61.9 bbls calculated displacement. 58.1 bbl actual displacement 11/26/2016 11/26/2016 0.50 COMPZ1 WELLPR RURD T Clean / clear rig floor. -11.8 -11.8 08:30 09:00 11/26/2016 11/26/2016 1.00 COMPZ1 WHDBOP RURD T Pull wear bushing and install test plug. -11.8 -11.8 09:00 10:00 Rig up test assembly, purge air from BOP stack and choke manifold w/ water, and perform body test. Page 32155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code WHDBOP Activity Code BOPE Time P -T -X T Operation Tested BOPE with 4" and 4-1/2" test (ftK8) -11.8 End Depth (WB) -11.8 11/26/2016 11/26/2016 6.25 COMPZ1 joint. 250/3500 psi, charted for 5 10:00 16:15 minutes each. Witness waived by AOGCC Rep. Louis Grimaldi. Install 4" Test Joint and test: Test #1 -Annular, CV#1, #12, #13, #14, 4" kill line valve on mud manifold, and 4" FOSV. Test #2 - Upper 3-1/2" x 6" VBR's, CV # 9, #11, mezzanine kill valve, and 4" dart valve. Test #3 - CV #8, #10, and HCR Kill. Test #4 - CV #6, #7, and manual kill. Test #5 - Super choke to 1500 psi Test #6 - Manual choke to 1500 psi Test #7 - CV #2 and #5. Test #8 - Lower 3-1/2" x 6" VBR's. Install 4-1/2" Test joint and test: Test #9 - Annular, CV #3, #4, and #6 Test #10 - Upper 3-1/2" x 6" VBR's, Lower IBOP, and HCR choke. Test #11 - Manual choke and Upper IBOP Test #12 - Lower 3-1/2" x 6" VBR's Test #13 - Blind rams Perform Koomey draw down test. Observed initial system pressure at ACC - 2950 PSI, MAN - 1525 PSI. After Closure observed ACC - 1800 PSI, 200 PSI increase in 7 seconds, full pressure at 49 seconds. Drawdown test performed w/ 2 electric pumps and 2 x air pumps. Observed 6 nitrogen bottles with an average PSI of 2658 PSI. Tested all gas and PVT alarms, both audio and visual - good tests. Note that the upper IBOP failed initial test - after functioning and greasing once, it re -tested good. 11/26/2016 11/26/2016 0.75 COMPZ1 WHDBOP RURD T Pull test plug, install 12.5" ID wear -11.8 -11.8 16:15 17:00 bushing, and lay down test joint. 11/26/2016 11/26/2016 1.25 PROD2 WHPST SVRG T Change out saver sub. SIMOPS -11.8 11.8 17:00 18:15 mobilize whipstock BHA to rig floor. 11/26/2016 11/26/2016 0.50 PROD2 WHPST RURD T Clear rig floor and verify whipstock -11.8 -11.8 18:15 18:45 BHA assembly. 11/26/2016 11/26/2016 0.25 PROD2 WHPST SFTY T Hold PJSM for picking up whipstock 11.8 11.8 18:45 19:00 assembly. 11/26/2016 11/26/2016 2.00 PROD2 W HPST BHAH T Make up window mill, lower window 11.8 11.8 19:00 21:00 mill, flex joint, upper string mill, XO, 1 xjt4" HWDP, XO, and Impulse MWD assembly. Scribe MWD assembly as per SLB / Baker and rack back in derrick. Note: Window mill and upper string mill gauged at 6-3/4". Lower window mill gauged at 6-5/8" 11/26/2016 11/26/2016 0.75 PROD2 WHPST BHAH T Make up seal assembly, no-go locater, -11.8 146.3 21:00 21:45 unloader, XO, 4 x joints 4" DP, and 2 x pups 4" DP to 158'. Page 33155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 11/26/2016 11/26/2016 1.00 PROD2 WHPST BHAH T Make up 7-5/8" Gen 2 Whipstock, 146.3 275.3 21:45 22:45 debris sub, drain sub, safety disconnect, 7-5/8" bottom trip anchor, Baker Xtreme Magnet, and XO. RIH to 196'. Pin window mill to whipstock w/ 45k shear bolt and install snap ring. RIH to 287'. Note: Bottom anchor pinned w/ 6 x 3650 Ib shear bolts and transport bolt removed prior to RIH. 11/26/2016 11/27/2016 1.25 PROD2 WHPST BHAH T Make up 2 x float subs w/ non -ported 275.3 549.3 22:45 00:00 flapper -style floats, XO, 2 x stands 4" HWDP, XO, 4 x MI Swaco Magnostar magnets, XO, and 1 x joint 4" DP and RIH to 561'. OA pressure = 120 psi. 11/27/2016 11/27/2016 1.25 PROD2 WHPST TRIP T RIH w/ 7-5/8" whipstock aseembly on 549.3 1,495.3 00:00 01:15 4" DP stands to 1507', monitoring displacement on pit #1. 11/27/2016 11/27/2016 0.25 PROD2 WHPST DHEQ T Shallow test MWD tools w/ 236 gpm, 1,495.3 1,495.3 01:15 01:30 716 psi, 8% F/0 - good test. Blow down top drive. 11/27/2016 11/27/2016 8.50 PROD2 WHPST TRIP T RIH w/ 7-5/8" whipstock assembly on 1,495.3 10,022.3 01:30 10:00 4" DP stands f/ 1507'- 10034', increasing running speed to 60 ft/min, monitoring displacement on pit #1, and filling pipe every 20 x stands, PUW 166k, SOW 11ok. 11/27/2016 11/27/2016 1.75 PROD2 WHPST SRVY T Wash down stand #101 & #102 f/ 10,022.3 10,180.3 10:00 11:45 10034'- 10192' and orient whipstock to 20° left of high side w/ 230 gpm, 1317 psi, 8% F/O. Note: Laid out top single of stand #102. 11/27/2016 11/27/2016 1.00 PROD2 WHPST SRVY T Wash down stand #103 w/ 226 gpm, 10,180.3 10,221.3 11:45 12:45 1295 psi, 8% F/0 and orient whipstock to 23° left of high side. Tag top of liner at 10233.69'w/ no-go (bottom of seals at 10237.66'). PUW 170k, SOW 110k Note: Top of Liner found 1.58' deeper than calculated. 11/27/2016 11/27/2016 0.25 PROD2 WHPST WPST T Set whipstock as per Baker rep. Set 10,221.3 10,029.3 12:45 13:00 down 19k weight to shear / set bottom anchor. Pull up to 185k to confirm set. Work string to 190k up and 60k down w/ pumps on at 226 gpm, 1290 psi. Kill pump and set down 60k weight to shear bolt and release from whipstock. Confirm released with PUW 178k, SOW 113k. Top of window @ 10,041.54' MD Bottom of window @ 10,055.20' MD Page 34155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) a 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/27/2016 11/27/2016 0.75 PROD2 WHPST CUTP T Obtain parameters at 200 gpm, 1135 10,029.3 10,029.3 13:00 13:45 psi, 7% F/O, 80 rpm, 7k Tq, ROT 135k and take SPRs. SPRs@10041' MD 6289' TVD, MW=10.Oppg,13:05 hours MP#1: 20 spm=540 psi, 30 spm=700 psi. MP #2: 20 spm=520 psi, 30 spm=670 psi. 11/27/2016 11/27/2016 7.00 PROD2 WHPST MILL T Tag top of whipstock and mill window 10,029.3 10,043.3 13:45 20:45 f/ 10041.54'- 10055.20'w/ 212 gpm, 1300 psi, 7% F/O, 80 rpm, 8-10k Tq, 1 -2k WOB. 11/27/2016 11/28/2016 3.25 PROD2 WHPST MILL T Continue milling f/ 10055'- 10064'w/ 10,043.3 10,052.3 20:45 00:00 212 gpm, 1355 psi, 7% F/O, 110 rpm, 9.5k Tq, 10k WOB. Pump 23 bbl hi -vis sweep at bottom of window - observe slight increase in fine shavings as sweep came back over shakers. 11/28/2016 11/28/2016 5.50 PROD2 WHPST DDRL T Mill f/ 10064'- 10080'w/ 212 gpm, 10,052.3 10,068.3 00:00 05:30 1390 psi, 7% F/O, 110 rpm, 9.5k Tq, 10-11 k WOB. Pump 25 bbl hi -vis sweep at bottom - observe slight increase in fine shavings as sweep came back over shakers. 11/28/2016 11/28/2016 0.50 PROD2 WHPST BKRM T Backream slowly through window f/ 10,068.3 9,982.3 05:30 06:00 10080'- 10023' w/ 212 gpm, 1373 psi, 6% F/O, 100 rpm, 8k Tq, 10.1 ppg MW in / out. 11/28/2016 11/28/2016 0.75 PROD2 WHPST TRIP T Kill pumps / rotary and obtain 9,982.3 9,982.3 06:00 06:45 parameters - PUW 161 k, SOW 117k. Trip down through window to bottom, seeing 2-3k drag across whipstock. Trip up through window to 10' above whipstock, seeing 1-2k drag across whipstock. Trip back down through window to bottom, seeing 1-2k drag across whipstock. Trip back up through window to 9994', seeing 1-2k drag across whipstock. Rack back stand, and blow down top drive. 11/28/2016 11/28/2016 1.50 PROD2 WHPST LOT T Rig up and perform LOT to 13.4ppg 9,982.3 9,982.3 06:45 08:15 EMW w/ 10.1 ppg Flo -Pro at 6289.5' TVD. 2.1 bbls pumped, 1.3 bbls returned. Rig down and blow down lines. 11/28/2016 11/28/2016 0.75 PROD2 WHPST MPDA T Pull trip nipple, install MPD bearing 9,982.3 9,982.3 08:15 09:00 and drain nipple, and line up for stripping OOH. SIMOPS - Make up top single back onto stand #102. 11/28/2016 11/28/2016 7.00 PROD2 WHPST SMPD T Strip OOH f/ 9994'- 8200' at 3000 ft/hr 9,982.3 633.3 09:00 16:00 w/ 250 psi pulling, 50 psi in slips, f/ 8200'- 4200' at 5000 ft/hr w/ 250 psi pulling, 50 psi in slips, and f/ 4200' - 645' at 4000 ft/hr w/ 175 psi pulling, 50 psi in slips. Maintain 200 gpm through MPD system. Monitor displacement on pit #1. Page 35/55 Report Printed: 1/23/2017 p Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time I our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK8) End Depth (ftKB) 11/28/2016 11/28/2016 0.50 PROD2 WHPST OWFF T Close chokes and monitor for 633.3 633.3 16:00 16:30 pressure buildup - no pressure. Open up and monitor well for flow - static. 11/28/2016 11/28/2016 0.75 PROD2 WHPST MPDA T Pull MPD bearing and drain nipple. 633.3 633.3 16:30 17:15 Install trip nipple. 11/28/2016 11/28/2016 0.50 PROD2 WHPST TRIP T Pull OOH f/ 645'- 365', monitoring 633.3 353.3 17:15 17:45 displacement on pit #1. 11/28/2016 11/28/2016 1.75 PROD2 WHPST BHAH T Pull OOH f/ 365'- 283', cleaning metal 353.3 271.3 17:45 - 19:30 off magnets and laying down magnet assembly, monitoring displacement on pit #1. Observe each magnet full w/ fine metal shavings to the OD of the pockets. 11/28/2016 11/28/2016 1.25 PROD2 WHPST BHAH T Pull OOH ft 283' to surface, laying 271.3 -11.8 19:30 20:45 down milling assembly as per Baker/ SLB. Window mill = 6-5/8" (1/8" Under gauge) Lower string mill = 6-5/8" (In gauge) Upper string mill = 6-3/4" (In gauge) 11/28/2016 11/28/2016 1.75 PROD2 WHPST WWWH T Rig up stack washer wl 1 x string -11.8 -11.8 20:45 22:30 magnet, and 4" DP w/ pup joint. RIH and jet stack, functioning annular and upper/lower VBR's. Flush stack w/ 700 gpm, 120 psi, 18% F/O, 15 rpm. Pull OOH, clean metal off magnets (observed small amount of metal on magnet), and lay out assembly. 11/28/2016 11/28/2016 0.50 PROD2 WHPST RURD T Clean / clear rig floor. -11.8 -11.8 22:30 23:00 11/28/2016 11/28/2016 0.25 PROM WHPST SFTY T Hold PJSM for picking up motor BHA. -11.8 -11.8 23:00 23:15 11/28/2016 11/29/2016 0.75 PROD2 WHPST BHAH T Make up BHA # 12 as per SLB w/ 1.5° -11.8 -11.8 23:15 00:00 motor. 11/29/2016 11/29/2016 1.00 PROD2 WHPST BHAH T Finish making up BHA #12 as per SLB -11.8 324.3 00:00 01:00 to 336', monitoring displacement on pit #1. 11/29/2016 11/29/2016 1.00 PROD2 WHPST TRIP T Trip in hole on 4" DP stands f/ 336'- 324.3 1,773.3 01:00 02:00 1785', monitoring displacement on pit #1. 11/29/2016 11/29/2016 0.25 PROD2 WHPST DHEQ T Fill pipe and shallow hole test MWD w/ 1,773.3 1,773.3 02:00 02:15 205 gpm, 835 psi, 8% F/O - good test. 11/29/2016 11/29/2016 4.75 PROD2 WHPST TRIP T Trip in hole on 4" DP stands f/ 1785'- 1,773.3 9,873.3 02:15 07:00 9885', filling pipe every 20 x stands, monitoring displacement on pit #1. 11/29/2016 11/29/2016 0.75 PROD2 WHPST MPDA T Pull trip nipple and install MPD 9,873.3 9,873.3 07:00 07:45 bearing and drain nipple. 11/29/2016 11/29/2016 1.00 PROD2 WHPST CIRC T Establish circulation at 205 gpm, 1495 9,873.3 9,968.3 07:45 08:45 psi, 8% F/O and orient bit to 23° left of high side f/ 9885'- 9980'. Page 36/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) �A °. 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/29/2016 11/29/2016 0.25 PROD2 WHPST TRIP T Trip in hole slowly across window and 9,968.3 10,054.3 08:45 09:00 into open hole f/ 9980'- 10066', observing 1-2k consistent drag across the slide and in open hole. PUW 163k, SOW 110k. Note: See additional 3-5k drag each time tool joint passes through MPD bearing 11/29/2016 11/29/2016 0.50 PROD2 DRILL REAM T Wash down to through undergauge 10,054.3 10,068.3 09:00 09:30 hole to bottom f/ 10066'- 10080'w/ 243 gpm, 1810 psi, 11% F/O. 11/29/2016 11/29/2016 2.50 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 10080'- 10111' 10,068.3 10,099.3 09:30 12:00 MD w/ 250 gpm, 1841 psi, 9% F/O, 40 rpm, 8.5k Tq, 3-5k WOB. Off btm SPP 1750 psi, PUW 162k, SOW 112k, ROT 135k wl 8k Tq, AST 1.36, ART 0.08, ADT 1.44, Bit hrs 1.44, Jar hrs 71.45. Note: Displace well to 9.8 ppg Flo -Pro WBM on the fly on first stand. 11/29/2016 11/29/2016 3.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 10111'- 10181' 10,099.3 10,169.3 12:00 15:00 MD w/ 230 gpm, 1915 psi, 6% F/O, 40 rpm, 8.5k Tq, 5.8k WOB, ECD 10.74,Off btm SPP 1650 psi, PUW 167k, SOW 116k, ROT 136k w/ 7.8k Tq, MW 9.8ppg, Max gas 12 units, AST 1.34, ART 0.68, ADT 2.02, Bit hrs 3.46, Jar hrs 73.47. 11/29/2016 11/29/2016 1.00 PROD2 DRILL SVRG T Service top drive. 10,169.3 10,169.3 15:00 16:00 11/29/2016 11/29/2016 2.75 PROD2 DRILL RGRP T Trouble shoot top drive - hydraulic 10,169.3 10,169.3 16:00 18:45 pump failed. Maintain circulation at 2 bpm, 520 psi, 5% F/O. 11/29/2016 11/29/2016 0.25 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 10181'- 10186' 10,169.3 10,174.3 18:45 19:00 MD w/ 228 gpm, 1645 psi, 6% F/O, 3.5k WOB, ECD 10.64,Off btm SPP 1620 psi, PUW 162k, SOW 116k, MW 9.8ppg, AST 0. 1, ART 0, ADT .1, Bit hrs 3.56, Jar hrs 73.57. Note: Needed to get stand down deeper to allow for removal of hydraulic pump. 11/29/2016 11/29/2016 1.00 PROD2 DRILL RGRP T Trouble shoot top drive - hydraulic 10,174.3 10,174.3 19:00 20:00 pump failed. Discover that spare hydraulic pump not correct part. Maintain circulation at 2 bpm, 520 psi, 5% F/O. 11/29/2016 11/29/2016 0.75 PROD2 DRILL SMPD T Strip OOH f/ 10181'- 9996'w/ 35 psi 10,169.3 9,984.3 20:00 20:45 in slips, 130 psi pulling, PUW 172k. Pull BHA slowly across window, observing 1-2 k drag. 11/29/2016 11/30/2016 3.25 PROD2 DRILL RGRP T Remove broken hydraulic pump. Prep 9,984.3 9,984.3 20:45 00:00 for installation of new pump while mobilizing parts from deadhorse. Begin installing new pump at change out. OA pressure = 150 psi Page 37/55 Report Printed: 1/23/2017 - Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 11/30/2016 11/30/2016 2.25 PROD2 DRILL RGRP T Replace hydraulic pump on top drive, 9,984.3 9,984.3 00:00 02:15 fill reservoir, and calibrate system. 11/30/2016 11/30/2016 0.75 PROD2 DRILL TRIP T Trip in hole through window to bottom 9,984.3 10,174.3 02:15 03:00 f/ 9996'- 10186', seeing 1 k drag across window. PUW 164k, SOW 120k. 11/30/2016 11/30/2016 3.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 10186'- 10250' 10,174.3 10,238.3 03:00 06:00 MD w/ 240 gpm, 1800 psi, 9% F/O, 40 rpm, 8.5k Tq, 3-8k WOB, ECD 10.89,Off btm SPP 1750 psi, PUW 165k, SOW 120k, ROT 135k w/ 8k Tq, MW 9.8ppg, Max gas 349 units, AST 1.46, ART 0.33, ADT 1.79, Bit hrs 5.23, Jar hrs 75.24. 11/30/2016 11/30/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 10250'- 10435' 10,238.3 10,423.3 06:00 12:00 MD w/ 240 gpm, 2000 psi, 7% F/O, 40 rpm, 8.5k Tq, 3-8k WOB, ECD 11.04, Off btm SPP 1800 psi, PUW 165k, SOW 115k, ROT 135k w/ 8k Tq, MW 9.95ppg, Max gas 225 units, AST 2.94, ART 0.75, ADT 3.69, Bit hrs 8.92, Jar hrs 78.93. SPRs @ 10275' MD 6353' TVD, MW=9.95 ppg, 07:00 hours MP#1: 20 spm=540 psi, 30 spm=760 psi. MP #2: 20 spm=540 psi, 30 spm=700 psi. 11/30/2016 11/30/2016 1.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 10250'- 10490' 10,423.3 10,478.3 12:00 13:00 MD w/ 247 gpm, 2110 psi, 8% F/O, 40 rpm, 8.5k Tq, 5.5k WOB, ECD 11.11,Off btm SPP 1888 psi, PUW 158k, SOW 112k, ROT 136k w/ 7k Tq, MW 10.0 ppg, Max gas 200 units, AST 0, ART 0.84, ADT 0.84, Bit hrs 9.78, Jar hrs 79.77. SPRs @ 10490' MD 6328' TVD, MW=10.0 ppg, 14:30 hours MP#1: 20 spm=500 psi, 30 spm=720 psi. MP #2: 20 spm=470 psi, 30 spm=690 psi. 11/30/2016 11/30/2016 1.75 PROD2 DRILL CIRC T Circulate bottoms up at TD w/ 247 10,478.3 10,478.3 13:00 14:45 gpm, 1920 psi, 7% F/O, 40 rpm, 6.8k Tq, ECD 10.96. Orient drill string to 23° left of high side. Blow down top drive. 11/30/2016 11/30/2016 0.75 PROD2 DRILL OWFF T Close MPD chokes and monitor for 10 10,478.3 10,478.3 14:45 15:30 minutes - no pressure buildup. Open up and monitor well for flow for 30 minutes w/ 5 rpm, 6k tq, ROT 130k - well static 11/30/2016 11/30/2016 1.00 PROD2 DRILL SMPD T Strip OOH f/ 10490'- 9992', holding 10,478.3 9,980.3 15:30 16:30 50 psi in slips and 150 psi pulling, Pull slowly through window, observing no drag. PUW 164k 11/30/2016 11/30/2016 0.50 PROD2 DRILL OWFF T Monitor well for flow - static. 9,980.3 9,980.3 16:30 17:00 Page 38155 Report Printed: 112312017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/30/2016 12/1/2016 7.00 PROD2 DRILL SMPD T Strip OOH f/ 9992 - 640', holding 50 9,980.3 608.3 17:00 00:00 psi in slips and 175 psi pulling, increasing running speed to 5000 ft/hr. Monitor displacement on pit #5. OA pressure = 325 psi 12/1/2016 12/1/2016 0.50 PROD2 DRILL SMPD T Strip OOH f/ 620'- 336', holding 50 psi 608.3 324.3 00:00 00:30 in slips and 175 psi pulling, monitoring displacement on pit #5. 12/1/2016 12/1/2016 0.25 PROD2 DRILL OWFF T Monitor well for flow - static. 324.3 324.3 00:30 00:45 12/1/2016 12/1/2016 0.75 PROD2 DRILL MPDA T Hold PJSM. Pull MPD bearing and 324.3 324.3 00:45 01:30 drain nipple. Install trip nipple. 12/1/2016 12/1/2016 1.50 PROD2 DRILL BHAH T Hold PJSM. Rack back HWDP, jars, 324.3 -11.8 01:30 03:00 and Flex NMDC's. UD Impulse, Periscope, mud motor, and bit. Observed each outer cutter chipped on the leading edge. Bit graded 1 -3 - CT -G -X -2 -BT -TD. Spring on the top non -ported flapper valve was broken and the valve stuck in open position. 12/1/2016 12/1/2016 1.50 PROD2 DRILL BHAH T Hold PJSM. Make up BHA#13 as per -11.8 325.3 03:00 04:30 SLB to 337', installing 2 x non -ported flapper valves and 1 x non -ported plunger valve floats for MPD. 12/1/2016 12/1/2016 0.75 PROD2 DRILL TRIP T Trip in hole w/ 4" DP stands f/ 337'- 325.3 1,788.3 04:30 05:15 1800', monitoring displacement on pit #5. 12/1/2016 12/1/2016 0.25 PROD2 DRILL DHEQ T Shallow hole test MWD tools w/ 202 1,788.3 1,788.3 05:15 05:30 gpm, 870 psi, 8% F/0, 10.77 ppg ECD - good test. 12/1/2016 12/1/2016 1.50 PROD2 DRILL TRIP T Trip in hole w/ 4" DP stands f/ 1800' - 1,788.3 5,534.3 05:30 07:00 5536', filling pipe every 20 x stands, monitoring displacement on pit #5. 12/1/2016 12/1/2016 0.50 PROD2 DRILL SVRG T Service rig, grease crown and top 5,534.3 5,534.3 07:00 07:30 drive and adjust top drive hydraulics. 12/1/2016 12/1/2016 2.75 PROD2 DRILL TRIP T Trip in hole w/ 4" DP stands f/ 5536'- 5,534.3 9,893.3 07:30 10:15 9905', filling pipe every 20 x stands, monitoring displacement on pit #5. PUW 160k, SOW 114k. 12/1/2016 12/1/2016 0.75 PROD2 DRILL MPDA T Pull trip nipple. Install MPD bearing 9,893.3 9,893.3 10:15 11:00 and drain nipple. 12/1/2016 12/1/2016 0.25 PROD2 DRILL MPDA T Break in new bearing w/ 149 gpm, 932 9,893.3 9,893.3 11:00 11:15 psi, 7% F/O, 30 rpm w/ 7k tq, 60 rpm w/ 7.5k tq. 12/1/2016 12/1/2016 1.00 PROD2 DRILL TRIP T Trip in hole w/ 4" DP stands f/ 9905'- 9,893.3 10,138.3 11:15 12:15 10150', monitoring displacement on pit #5. PUW 161k, SOW 114k. No drag observed while running BHA through window. Note: Observed 10-15k drag @ 9909'. Pick up and work back through section, continue tripping ahead with no issues. Page 39/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) 0.75 Phase PROD2 Op Code DRILL Activity Code WASH Time P -T -X T Operation Wash down f/ 10150'- 10310'w/ 211 (WB) 10,138.3 End Depth (ftKB) 10,298.3 12/1/2016 12:15 12/1/2016 13:00 gpm, 1590 psi, 7% F/O, taking check shot surveys as per SLB, PUW 161 k, SOW 114k. Note: Observed 10-15k drag @ 10310' and 200 psi increase in pump pressure. 12/1/2016 12/1/2016 1.25 PROD2 DRILL REAM T Ream down f/ 10310'- 10490'w/ 211 10,298.3 10,478.3 13:00 14:15 gpm, 1640 psi, 40 rpm, 7.5k Tq, taking check shot surveys as per SLB, ROT 133k. 12/1/2016 12/1/2016 3.75 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 10490 - 10740' 10,478.3 10,728.3 14:15 18:00 MD, 6302' TVD, w/ 240 gpm, 2150 psi, 8% F/O, 140 rpm, 11k Tq, 7.5k WOB, ECD 11.04, Off btm SPP 2170 psi, PUW 164k, SOW 107k, ROT 129k w/ 8.5k Tq, MW 9.8 ppg, Max gas 60 units, ADT 2.71, Bit hrs 2.71, Jar hrs 82.48. Note: Dropped mud weight down to 9.8ppg once on bottom drilling. 12/1/2016 12/2/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 10740 - 11322' 10,728.3 11,310.3 18:00 00:00 MD, 6277' TVD, w/ 260 gpm, 2202 psi, 9% F/O, 160 rpm, 12k Tq, 6k WOB, ECD 11.19, Off btm SPP 2198 psi, PUW 162k, SOW 107k, ROT 133k w/ 9k Tq, MW 9.8 ppg, Max gas 155 units, ADT 4.32, Bit hrs 7.03, Jar hrs 86.80. SPRs @ 11229' MD 6281' TVD, MW=9.80 ppg, 23:00 hours MP#1: 20 spm=540 psi, 30 spm=780 psi. MP #2: 20 spm=520 psi, 30 spm=740 psi. OA pressure = 760 psi 12/2/2016 12/2/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 11332 to 11798' 11,310.3 11,786.3 00:00 06:00 MD, 6242' TVD, w/ 260 gpm, 2202 psi, 9% F/O, 160 rpm, 12k Tq, 6-10k WOB, ECD 11. 19, Off btm SPP 2198 psi, PUW 165k, SOW 105k, ROT 125k w/ 9k Tq, MW 9.8 ppg, Max gas 289 units, ADT 4.41, Bit hrs 11.44, Jar hrs 91.21. SPRs @ 11698' MD 6276' TVD, MW=9.80 ppg, 03:50 hours MP#1: 20 spm=550 psi, 30 spm=770 psi. MP #2: 20 spm=540 psi, 30 spm=750 psi. Page 40155 Report Printed: 1/23/2017 =- Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (f.KB) End Depth (ftKB) 12/2/2016 12/2/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 11798 to 12261' 11,786.3 12,249.3 06:00 12:00 MD, 6257' TVD, w/ 260 gpm, 2258 psi, 9% F/O, 160 rpm, 14k Tq, 6-10k WOB, ECD 11.31, Off btm SPP 2200 psi, PUW 168k, SOW 102k, ROT 133k w/ 13k Tq, MW 9.8 ppg, Max gas 150 units, ADT 4.47, Bit hrs 15.91, Jar hrs 95.68. SPRs @ 12175' MD 6277' TVD, MW=9.80 ppg, 10:51 hours MP#1: 20 spm=630 psi, 30 spm=900 psi. MP #2: 20 spm=630 psi, 30 spm=830 psi. 12/2/2016 12/2/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 12261' to 12790' 12,249.3 12,778.3 12:00 18:00 MD, 6262' TVD, w/ 260 gpm, 2423 psi, 10% F/O, 140 rpm, 14k Tq, 6-10k WOB, ECD 11.36, Off btm SPP 2416 psi, PUW 164k, SOW 100k, ROT 133k w/ 13k Tq, MW 9.8 ppg, Max gas 297 units, ADT 4.16, Bit hrs 20.07, Jar hrs 99.84. SPRs @ 12648' MD 6265' TVD, MW=9.80 ppg, 16:30 hours MP#1: 20 spm=680 psi, 30 spm=940 psi. MP #2: 20 spm=640 psi, 30 spm=880 psi. 12/2/2016 12/3/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 12790' to 13503' 12,778.3 13,491.3 18:00 00:00 MD, 6247' TVD, w/ 260 gpm, 2461 psi, 10% F/O, 140 rpm, 13k Tq, 12k WOB, ECD 11.45, Off btm SPP 2460 psi, PUW 168k, SOW 99k, ROT 134k w/ 8k Tq, MW 9.8 ppg, Max gas 196 units, ADT 4.04, Bit hrs 24.11, Jar hrs 103.88. SPRs @ 13215' MD 6259' TVD, MW=9.85 ppg, 21:45 hours MP#1: 20 spm=700 psi, 30 spm=960 psi. MP #2: 20 spm=680 psi, 30 spm=900 psi. OA pressure= 1100 psi 12/3/2016 12/3/2016 2.75 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 13503' to 13885' 13,491.3 13,873.3 00:00 02:45 MD, 6234' TVD, w/ 264 gpm, 2461 psi, 10% F/O, 160 rpm, 13k Tq, 6-12k WOB, ECD 11.51, Off btm SPP 2460 psi, PUW 172k, SOW 94k, ROT 128k w/ 12k Tq, MW 9.8 ppg, Max gas 282 units, ADT 1.65, Bit hrs 25.74, Jar hrs 105.53. SPRs @ 13783' MD 6240' TVD, MW=9.80 ppg, 02:02 hours MP#1: 20 spm=760 psi, 30 spm=1040 psi. MP #2: 20 spm=730 psi, 30 spm=970 psi. Page 41/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/3/2016 12/3/2016 1.00 PROD2 DRILL SRVY T Pump out of hole 2 x stands f/ 13885'- 13,873.3 13,873.3 02:45 03:45 13695'w/ 262 gpm, 2460 psi, 172k PUW. Re -survey @ 13695' due to bad survey. Cycle pumps to obtain survey and wash down 2 x stands to bottom w/ 262 gpm, 2460 psi, 94k SOW. 12/3/2016 12/3/2016 2.25 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 13885'to 14077' 13,873.3 14,065.3 03:45 06:00 MD, 6227' TVD, w/ 264 gpm, 2500 psi, 10% F/O, 160 rpm, 13k Tq, 8-12k WOB, ECD 11.50, Off btm SPP 2460 psi, PUW 172k, SOW 94k, ROT 128k w/ 8k Tq, MW 9.8 ppg, Max gas 108 units, ADT 1.36, Bit hrs 27.10, Jar hrs 106.89. 12/3/2016 12/3/2016 6.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 14077' to 14790' 14,065.3 14,778.3 06:00 12:00 MD, 6265' TVD, w/ 264 gpm, 2550 psi, 10% F/O, 160 rpm, 14k Tq, 8-12k WOB, ECD 11.52, Off btm SPP 2500 psi, PUW 174k, SOW 90k, ROT 133k w/ 12k Tq, MW 9.8 ppg, Max gas 164 units, ADT 3.99, Bit hrs 31.11, Jar hrs 110.88. SPRs @ 14353' MD 6228' TVD, MW=9.80 ppg, 08:15 hours MP#1: 20 spm=740 psi, 30 spm=980 psi. MP #2: 20 spm=760 psi, 30 spm=1000 psi. 12/3/2016 12/3/2016 5.25 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 14790' to 15390' 14,778.3 15,378.3 12:00 17:15 MD, 6252' TVD, w/ 270 gpm, 2814 psi, 12% F/O, 160 rpm, 14k Tq, 8-12k WOB, ECD 11.70, Off btm SPP 2729 psi, PUW 191 k, SOW 92k, ROT 138k w/ 8k Tq, MW 9.8 ppg, Max gas 164 units, ADT 3.51, Bit hrs 34.62, Jar hrs 114.39. SPRs @ 15110' MD 6270' TVD, MW=9.85 ppg, 14:45 hours MP#1: 20 spm=760 psi, 30 spm=1000 psi. MP #2: 20 spm=770 psi, 30 spm=1020 psi. Start adding in Alpine beads and nut plug fine from 14980' to TD. Increase lube concentration to 2.5%. Observed 46' fault @ 14888' and 10' fault @ 14823' - total of 56' throw down to the north. We dropped out of target zone early to minimize loss of pay on other side of fault. 12/3/2016 12/3/2016 1.75 PROD2 DRILL SRVY T Backream out 2 x stands f/ 15390'- 15,378.3 15,378.3 17:15 19:00 15202' and work section several times where high dogleg, 8.4°, was observed w/ 260 gpm, 2621 psi, 9% F/O, 100 rpm, 8-10k Tq, ECD 11.53, PUW 174k, SOW 90k, ROT 126k. Ream back down to bottom f/ 15202'- 15390'. Page 42155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 416, 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/3/2016 12/4/2016 5.00 PROD2 DRILL DDRL T DDrill 6-3/4" hole f/ 15390' to 15853' 15,378.3 15,841.3 19:00 00:00 MD, 6242' ND, w/ 262 gpm, 2730 psi, 10% F/O, 140 rpm, 11-14k Tq, 10-15k WOB, ECD 11.65, Off btm SPP 2725 psi, PUW 190k, SOW 92k, ROT 136k w/ 9k Tq, MW 9.8 ppg, Max gas 241 units, ADT 3.46, Bit hrs 38.08, Jar hrs 117.85. Note: Observed hard spot of anchorite formation f/ 15417' - 15524'. Pressure continues to build over connections on closed MPD chokes to 70-150 psi, but always builds slower and levels out to lower pressure after cycling chokes, indicating breathing. The 3 x drill string floats started leaking at —15,000' MD. SPRs @ 15668' MD 6251' TVD, MW=9.80 ppg, 22:30 hours MP#1: 20 spm=760 psi, 30 spm=1000 psi. MP #2: 20 spm=760 psi, 30 spm=1000 psi. OA pressure = 1140 psi 12/4/2016 12/4/2016 6.00 PROD2 DRILL DDRL T DDrill 6-314" hole f/ 15853' to 16530' 15,841.3 16,518.3 00:00 06:00 MD, 6218' TVD, w/ 262 gpm, 2730 psi, 10% F/O, 140 rpm, 11-14k Tq, 8-14k WOB, ECD 11.80, Off btm SPP 2725 psi, PUW 192k, SOW 88k, ROT 138k w/ 13k Tq, MW 9.8 ppg, Max gas 277 units, ADT 3.64, Bit hrs 41.72, Jar hrs 121.49. SPRs @ 16220' MD 6231' TVD, MW=9.85 ppg, 02:45 hours MP#1: 20 spm=820 psi, 30 spm=1080 psi. MP #2: 20 spm=830 psi, 30 spm=1080 psi. Note: Observed 1 x fault @ 16395', 2' throw down to the south. Page 43/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/4/2016 12/4/2016 3.50 PROD2 DRILL DDRL T DDrill 6-3/4" hole ft 16530' to 16980' 16,518.3 16,968.3 06:00 09:30 MD, 6208' TVD, w/ 262 gpm, 3018 psi, 10% F/O, 160 rpm, 11-15k Tq, 8-15k WOB, ECD 11.85, Off btm SPP 3000 psi, PUW 197k, SOW 88k, ROT 140k w/ 13k Tq, MW 9.8 ppg, Max gas 522 units, ADT 2.44, Bit hrs 44.16, Jar hrs 123.93. SPRs @ 16771' MD 6213' TVD, MW=9.85 ppg, 07:30 hours MP#1: 20 spm=800 psi, 30 spm=1050 psi. MP #2: 20 spm=810 psi, 30 spm=1060 psi. Final lube concentration = 2.5% Lotorq. Added total of 157 bags of Alpine beads & 200 bags of nut plug fine into system from 14900'- TD. Total seepage losses for interval = 65 bbls. In target A4 zone for 84% of lateral. 12/4/2016 12/4/2016 2.25 PROD2 CASING CIRC T Pump 23 bbl hi -vis sweep and chase 16,968.3 16,850.3 09:30 11:45 w/ 9.8 ppg mud, circulate 1 x surface- to-surface volume wl 262 gpm, 3000 psi, 160 rpm, 13k Tq, ROT 142k, racking back one stand f/ 16908' - 16862'. SPRs @ 16955' MD 6209' TVD, MW=9.85 ppg, 11:38 hours MP#1: 20 spm=790 psi, 30 spm=1070 psi. MP #2: 20 spm=800 psi, 30 spm=1090 psi. 12/4/2016 12/4/2016 1.75 PROD2 CASING OWFF T Perform MPD exhale test w/ 10 rpm, 16,850.3 16,850.3 11:45 13:30 9k Tq, ROT 147k. Cycled chokes and observed pressure buildup on decreasing trend and volume bled back on decreasing trend. Initial shut in pressure of 147 psi decreased to 111 psi with total volume bled back = 5.4 bbls. Confirmed wellbore breathing. 12/4/2016 12/4/2016 4.50 PROD2 CASING BKRM T Backream OOH f/ 16862'- 15207' MD 16,850.3 15,195.3 13:30 18:00 @ 1000 ft/hr pulling speed w/ 260 gpm, ICP 2800 psi, FCP 2550 psi, 9% F/O, ECD 11.42, 150 rpm, 10-12k Tq, PUW 197k, SOW 88k, ROT 147k. 12/4/2016 12/4/2016 4.25 PROD2 CASING BKRM T Backream OOH f/ 15207'- 14070' MD 15,195.3 14,058.3 18:00 22:15 @ 350-500 ft/hr pulling speed w/ 260 gpm, ICP 2550 psi, FCP 2500 psi, 9% F/O, ECD 11.39, 100-150 rpm, 8-11 k Tq, PUW 184k, SOW 95k, ROT 120k. Note: No issues observed pulling BHA through fault. Page 44155 Report Printed: 112 312 01 7 Operations Summary (with Timelog Depths) o 2S-13 - Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code CASING Activity Code BKRM Time P -T -X T Operation Backream OOH f/ 14070'- 13300' MD (ttKB) 14,058.3 End Depth (ftKB) 13,288.3 12/4/2016 12/5/2016 1.75 PROD2 @ 1000 ft/hr pulling speed w/ 262 22:15 00:00 gpm, ICP 2500 psi, FCP 2490 psi, 9% F/O, ECD 11.35, 100 rpm, 10-12k Tq, PUW 170k, SOW 95k, ROT 120k. OA pressure = 1100 psi 12/5/2016 12/5/2016 7.25 PROD2 CASING BKRM T Backream OOH f/ 13300'- 10375' MD 13,288.3 10,363.3 00:00 07:15 @ 1000 ft/hr pulling speed w/ 262 gpm, ICP 2490 psi, FCP 2178 psi, 9% F/O, ECD 11.20, 100-140 rpm, 9-11k Tq, ROT 122k. Note: Start weighting up 9.8ppg Flo - Pro to 9.9 ppg @ 11900' MD. 12/5/2016 12/5/2016 1.25 PROD2 CASING PMPO T Pump OOH f/ 10375'- 9987', pulling 10,363.3 9,975.3 07:15 08:30 BHA through window w/ 179 gpm, 1130 psi, PUW 158k. No drag observed while pulling through window. 12/5/2016 12/5/2016 2.50 PROD2 CASING CIRC T Pump 24 bbl hi -vis sweep followed by 9,975.3 9,975.3 08:30 11:00 733 bbls of mud, weighting up 9.9 ppg Flo -Pro system on the fly to 10.2 ppg in/out, adjusting pump rate from 228 gpm to 200 gpm to maintain ECD no greater than 11.5 ppg, final pump pressure 1586 psi. Rotate @ 60 rpm, 6k Tq, reciprocating stand. Obtain SPR's for new mud: SPRs @ 9899' MD 6267' TVD, MW=10.20 ppg, 11:00 hours MP#1: 20 spm=670 psi, 30 spm=910 psi. MP #2: 20 spm=650 psi, 30 spm=870 psi. 12/5/2016 2016 0.25 PROD2 CASING RURD T Blow down top drive and open up well 9,975.3 9,975.3 11:00 at RCD to monitor for flow. 12/5/2016 E1215/2016 1.00 PROD2 CASING OWFF T Monitor well forflow at RCD head - 9,975.3 9,975.3 11:15 well static. 12/5/2016 12/5/2016 1.50 PROD2 CASING MPDA T Pull MPD bearing and drain nipple. 9,975.3 9,975.3 12:15 13:45 Install trip nipple. Clean/clear rig floor of MPD equipment. 12/5/2016 12/5/2016 1.75 PROD2 CASING TRIP T Pull OOH on elevators f/ 9987'- 8576', 9,975.3 8,564.3 13:45 15:30 monitoring displacement on trip tank, PUW 169k, SOW 120k. Observe incorrect hole fill. Monitor well for flow - well static. 12/5/2016 12/5/2016 5.25 PR0D2 CASING PMPO T Pump OOH to offset swab f/ 8576' 8,564.3 5,266.3 15:30 20:45 5278'w/ 127 gpm, ICP 837 psi, FCP 648 psi, 5% F/O, PUW 147k, SOW 110k, monitoring displacement on pit #5. 12/5/2016 12/5/2016 1.25 PROD2 CASING TRIP T Pull OOH on elevators f/ 5278' - 4448', 5,266.3 4,436.3 20:45 22:00 monitoring displacement on trip tank, PUW 109k, SOW 95k. Observe incorrect hole fill. Monitor well for flow well static. Page 45/55 Report Printed: 1/23/2017 71 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 12/5/2016 12/5/2016 1.75 PROD2 CASING PMPO T Pump OOH to offset swab f/ 4448'- 4,436.3 3,360.3 22:00 23:45 3372 w/ 127 gpm, ICP 630 psi, FCP 551 gpm, 5% F/0, PUW 97k, SOW 94k, monitoring displacement on pit #5. 12/5/2016 12/6/2016 0.25 PROD2 CASING TRIP T Pull OOH on elevators f/ 3372'- 3285', 3,360.3 3,273.3 23:45 00:00 PUW 91k, SOW 88k, monitoring displacement on trip tank. OA pressure = 550 psi 12/6/2016 12/6/2016 2.75 PROD2 CASING TRIP T Cont to POOH f/ 3285' MD to 368' MD 3,273.3 314.3 00:00 02:45 on elevators. Calculated displacement= 103 bbls Actual displacement= 151 bbls. 12/6/2016 12/6/2016 1.75 PROD2 CASING BHAH T L/D 4" 5 joints HWDP, Jars and SLB 314.3 -11.8 02:45 04:30 tools as per SLB. The seal area on the flapper float looked questionable and debris was found in the spring of the plunger float. Smith MDi516 bit grade= 0 -0 -NO -A -X -NO-TD 12/6/2016 12/6/2016 0.50 PROD2 CASING BHAH T Clean and clear rig floor. UD SLB -11.8 -11.8 04:30 05:00 subs and tools. 12/6/2016 12/6/2016 1.50 COMPZ2 FISH BHAH T Make up whipstock retrieval BHA and -11.8 53.3 05:00 06:30 SLB MWD tools. Orient MWD tool face offset to jet on retrieval hook. Observed 292.5 deg tool face offset. 12/6/2016 12/6/2016 0.75 COMPZ2 FISH TRIP T RIH w/ 4" DP f/ 65' MD to 1517' MD. 53.3 1,505.3 06:30 07:15 12/6/2016 12/6/2016 0.25 COMPZ2 FISH DHEQ T Shallow hole test MWD tools @ 215 1,505.3 1,505.3 07:15 07:30 gpm=755 psi, good test. 12/6/2016 12/6/2016 3.50 COMPZ2 FISH TRIP T Cont to RIH w/ 4" DP f/ 1517' MD to 1,505.3 8,134.3 07:30 11:00 8146' MD. 12/6/2016 12/6/2016 1.00 COMPZ2 FISH SLPC T Slip and cut drilling line, cut off 130' of 8,134.3 8,134.3 11:00 12:00 drilling line. SIMOPS: remove ice build up in derrick. OA pressure= 540 psi. 12/6/2016 12/6/2016 1.00 COMPZ2 FISH SLPC T Finish Slip and cut drilling line, cut off 8,134.3 8,134.3 12:00 13:00 130' of drilling line. 12/6/2016 12/6/2016 1.25 COMPZ2 FISH TRIP T Cont to RIH w/ 4" DP f/ 8,146' MD to 8,134.3 9,975.3 13:00 14:15 9,987' MD. 12/6/2016 12/6/2016 1.00 COMPZ2 FISH WASH T Washed down from 9,987' to 10,057'. 9,975.3 10,045.3 14:15 15:15 211 GPM, UW 177K DW 132K. 12/6/2016 12/6/2016 0.25 COMPZ2 FISH FISH P Located and engaged hook. Jarred 10,045.3 9,971.3 15:15 15:30 whipstock free. 12/6/2016 12/6/2016 1.75 COMPZ2 FISH CIRC P CBU X 2 250 GPM 1857 psi. MW in 9,971.3 9,971.3 15:30 17:15 10.2 PPG MW out 10.1+. 12/6/2016 12/6/2016 0.50 COMPZ2 FISH OWFF P OWFF for 30 Min. Small flow did not 9,971.3 9,971.3 17:15 17:45 die off. 12/6/2016 12/6/2016 1.25 COMPZ2 FISH CIRC P CBU to even out MW. 250 GPM 1867 1 9,971.3 9,971.3 17:45 19:00 psi. 12/6/2016 12/6/2016 1.00 COMPZ2 FISH OWFF P OWFF. Well went Static. 9,971.3 9,971.3 19:00 20:00 12/6/2016 12/7/2016 4.00 COMPZ2 FISH PMPO P Attempted to POOH on Elevators Well 9,971.3 8,221.3 20:00 00:00 was swabing. POOH pumping 2.5 to 3 BPM from 9,983' to 8,233'. 105 GPM 605 psi. UW 170K. Page 46155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKa) End Depth (WS) 12/7/2016 12/7/2016 9.25 COMPZ2 FISH PMPO P POOH w/ pump @ 106 gpm= 600 psi, 8,221.3 2,993.3 00:00 09:15 reduce pumps to 82 gpm=420 psi f/ 8233' MD to 3005' MD. P/U= 143K, S/0= 85K. 12/7/2016 12/7/2016 2.75 COMPZ2 FISH TRIP P POOH on elevetors f/ 3005' MD to 2,993.3 838.3 09:15 12:00 850' MD. Monitor hole fill on trip tank. 12/7/2016 12/7/2016 0.75 COMPZ2 FISH TRIP P Continue POOH on elevetors f/ 850' 838.3 81.3 12:00 12:45 MD to 93' MD. 12/7/2016 12/7/2016 0.75 COMPZ2 FISH BHAH P Lay down Baker Hook assembly. 81.3 -11.8 12:45 13:30 12/7/2016 12/7/2016 1.50 COMPZ2 FISH PULL P Laid down Baker Whipstock. Junk -11.8 -11.8 13:30 15:00 Catcher was missing. 12/7/2016 12/7/2016 1.50 COMPZ2 FISH RURD P Cleared and cleaned up Rig Floor. -11.8 -11.8 15:00 16:30 12/7/2016 12/7/2016 1.25 COMPZ2 CASING RURD P RU to run Liner. -11.8 -11.8 16:30 17:45 12/7/2016 12/8/2016 6.25 COMPZ2 CASING PUTB P Ran 4.5" 12.6# L-80 TXP Lower -11.8 4,396.3 17:45 00:00 Completion Liner to 4,408'. UW 85K DW 81 K. 12/8/2016 12/8/2016 3.75 COMPZ2 CASING PUTB P Cont. to run 4.5" 12.6# L-80 TXP 4,396.3 6,880.3 00:00 03:45 Lower Completion Liner f/ 4408' MD to 6892' MD. P/U 102K, S/0= 86K. Ran a total of 168 joints of 4-1/2" TXP w/ zero remakes and zero rejects, 2- 5.75" swell packers, 1- 6.38" swell packer and 78 6-1/2" Hydroforms. 12/8/2016 12/8/2016 1.00 COMPZ2 CASING BHAH P P/U 3-1/8" SLB collar and instal in 6,880.3 6,914.3 03:45 04:45 tubing stump. M/U slim pulse and obtain tool face offset of 74.58deg. M/U to Baker hook hanger and run in the hole to 6926' MD. 12/8/2016 12/8/2016 0.25 COMPZ2 CASING RURD P Change out handling equipment to 4" 6,914.3 6,914.3 04:45 05:00 IXT39. 12/8/2016 12/8/2016 3.00 COMPZ2 CASING RUNL P RIH w/ 4-1/2" TXP liner on 4" DP f/ 6,914.3 9,944.3 05:00 08:00 6926' MD to above window @ 9956' MD. PIU= 149L, S/0= 104K. 12/8/2016 12/8/2016 2.00 COMPZ2 CASING RUNL P Shallow hole test MWD tools @ 120 9,944.3 10,326.3 08:00 10:00 gpm=628 psi, good. RIH and attempt to side liner into open hole, tagged main bore SBE @ 10,245K. POOH to 10,000' MD, put 1/2 a wrap in drill string and worked down. RIH and tagged @ 10,245' MD. POOH to 10,000' MD, worked 1/4" wrap down. RIH, bent joint passed though window @ 10042' MD. Cont to RIH t/ 10338' MD. P/U=149K, S/0=104K 12/8/2016 12/8/2016 2.00 COMPZ2 CASING RUNL P Cont RIH w/ 4-1/2" TXP liner on 4" DP 10,326.3 11,638.3 10:00 12:00 f/ 10,338' MD to 11,650' MD. P/U= 156K, S/0=100K. 12/8/2016 12/8/2016 6.00 COMPZ2 CASING RUNL P Cont RIH w/ 4-1/2" TXP liner on 4" DP 11,638.3 16,909.3 12:00 18:00 f/ 11,650' MD to 16,921' MD. P/U= 21 OK, S/0=1 05K. 12/8/2016 12/8/2016 1.00 COMPZ2 CASING SRVY P Estabilished Circulation for MWD. 16,909.3 16,949.3 18:00 19:00 Aligned Tool Face 180 Deg out and worked down hole past Hang off depth to 16,961' MD. Page 47155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/8/2016 12/8/2016 2.00 COMPZ2 CASING HOSO P Attempted to find hook @ 16,957'. 16,949.3 16,947.3 19:00 21:00 Unable to locate hook Reoriented to 180 out and worked through obstruction down to 16,971'. Reoriented and hooked @ 16,959'(2' deep). 12/8/2016 12/8/2016 0.50 COMPZ2 CASING PACK P Dropped 19132" Ball and pumped 16,947.3 10,063.3 21:00 21:30 down on seat. Released running tool with 3500 psi. Pressured up to 4165 psi to blow ball seat. Confirmed shearout of ball seat. 12/8/2016 12/8/2016 0.50 COMPZ2 WELLPR TRIP P POOH Running Tool from 10,075'to 10,063.3 9,980.3 21:30 22:00 10,035' pumping 1 BPM. Continue POOH to 9,992'. Top of Liner 10,035'. 12/8/2016 12/8/2016 0.25 COMPZ2 WELLPR OWFF P OWFF 10 Min. Static. 9,980.3 9,980.3 22:00 22:15 12/8/2016 12/8/2016 1.50 COMPZ2 WELLPR DISP P Pumped 25 Bbl HV Spacer followed 9,980.3 9,980.3 22:15 23:45 by 10.2 PPG Brine to Surface. 269 GPM ICP 1470 psi FCP 1225 psi. 12/8/2016 12/9/2016 0.25 COMPZ2 WELLPR RURD P Blow Down Top Drive. 9,980.3 9,980.3 23:45 00:00 12/9/2016 12/9/2016 1.75 COMPZ2 WELLPR OWFF P OWFF, slight flow. Perform exhale 9,980.3 9,972.3 00:00 01:45 test, Monitor fluid flowing from well w/ vis cup. Initial flow= 6.3 seconds per quart and slowed to 9.56 seconds per quart over 1-1/2" hours. P/U= 177K. 12/9/2016 12/9/2016 1.50 COMPZ2 WELLPR TRIP P POOH on elevators f/ 9984' MD to 9,972.3 8,414.3 01:45 03:15 8426' MD. Calculated hole fill 15 bbls, Actual hole fill 13 bbls. Displacement 2 bbls off. 12/9/2016 12/9/2016 0.25 COMPZ2 WELLPR OWFF T OWFF, Monitor fluid discharge w/ vis 8,414.3 8,414.3 03:15 03:30 cup and record every 5 min. fluid slowed f/ 9.06 seconds per quart to 10.75 seconds per quart. 12/9/2016 12/9/2016 0.75 COMPZ2 WELLPR TRIP P POOH on elevators f/ 8426' MD to 8,414.3 7,464.3 03:30 04:15 7476' MD. Calculated hole fill 5.6 bbls, Actual hole fill 3.6 bbls. Displacement 2 bbls off. 12/9/2016 12/9/2016 1.25 COMPZ2 WELLPR PMPO P POOH w/ pump 3 stands f/ 7476' MD 7,464.3 7,162.3 04:15 05:30 to 7174' MD. Calculated hole fill= 1.6 bbis. Actual hole fill = 0. 12/9/2016 12/9/2016 1.50 COMPZ2 WELLPR CIRC T Circulate and condition fluid, pump @ 7,162.3 7,162.3 05:30 07:00 200 gpm=380 psi. Observed no gas at bottoms up and circulated to ensure even MW in/out 10.2 ppg. 12/9/2016 12/9/2016 4.75 COMPZ2 WELLPR OWFF T OWFF, Monitor fluid discharge w/ vis 7,162.3 7,162.3 07:00 11:45 cup and record every 5 min . Initial reading at 7:05 am was 6 seconds per quart, discharge slowed to 15.75 seconds per quart @ 10:00 am. After 10:00 am this discharged picked up to 6-10 seconds per quart. The decision was made RIH back above hook hanger and increase MW to 10.4+ ppg• 12/9/2016 12/9/2016 1.00 COMPZ2 WELLPR CIRC T CBU to ensure no gas in wellbore. 7,162.3 7,162.3 11:45 12:45 Pump @ 200 gpm=408 psi w/ 6% flow out. No gas at BU or pit gain observed. Page 48155 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (WEI) End Depth (ftKB) 12/9/2016 12/9/2016 2.25 COMPZ2 WELLPR TRIP T RIH from 7,195'to 9,940'. 7,162.3 9,928.3 12:45 15:00 12/9/2016 12/9/2016 2.00 COMPZ2 WELLPR CIRC T CBU to check for gas or influx. 200 9,928.3 9,928.3 15:00 17:00 GPM 516 psi. No influx noted. 12/9/2016 12/9/2016 2.00 COMPZ2 WELLPR CIRC T Circulated and increased MW to 10.4+ 9,928.3 9,928.3 17:00 19:00 PPG. 200 GPM 471 psi. Lost 13 Bbls while circulating. 12/9/2016 12/9/2016 0.50 COMPZ2 WELLPR OWFF T OWFF slight loss Est 1 BPH. 9,928.3 9,928.3 19:00 19:30 12/9/2016 12/9/2016 1.00 COMPZ2 WELLPR TRIP T POOH from 9,940' to7,174' Good Hole 9,928.3 7,162.3 19:30 20:30 Fill. 12/9/2016 12/9/2016 3.00 COMPZ2 WELLPR TRIP P POOH from 7,174'to 92' Good Hole 7,162.3 80.3 20:30 23:30 Fill. 12/9/2016 12/10/2016 0.50 COMPZ2 WELLPR BHAH P Layed down Baker running tool. 80.3 38.3 23:30 00:00 12/10/2016 12/10/2016 0.50 COMPZ2 WELLPR BHAH P Laid down MWD. 38.3 -11.8 00:00 00:30 12/10/2016 12/10/2016 1.50 COMPZ2 WHDBOP RURD P Pulled Wear Bushing and set Test -11.8 -11.8 00:30 02:00 Plug. RU to test BOP. 12/10/2016 12/10/2016 4.50 COMPZ2 WHDBOP BOPE P Tested BOPE with 4" and 4-1/2" test -11.8 -11.8 02:00 06:30 joint. 250/3500 psi, charted for 5 minutes each. Witness waived by AOGCC Rep. Jeff Jones. Install 4" Test Joint and test: Test #1 - Annular, CV#1, #12, #13, #14, 4" kill line valve on mud manifold, and 4" FOSV. Test #2 - Upper 3-1/2" x 6" VBR's, CV # 9, #11, mezzanine kill valve, and 4" dart valve. Test #3 - CV #8, #10, and HCR Kill. Test #4 - CV #6, #7, and manual kill. Test #5 - Super choke to 1500 psi Test #6 - Manual choke to 1500 psi Test #7 - CV #2 and #5. Test #8 - Lower 3-1/2" x 6" VBR's. Install 4-1/2" Test joint and test: Test #9 - Annular, CV #3, #4, and #6 Test #10 - Upper 3-1/2" x 6" VBR's, Lower IBOP, and HCR choke. Test #11 - Manual choke and Upper IBOP Test #12 - Lower 3-1/2" x 6" VBR's Test #13 - Blind rams Perform Koomey draw down test. Observed initial system pressure at ACC - 2925 PSI, MAN - 1525 PSI. After Closure observed ACC - 1725 PSI, 200 PSI increase in 5 seconds, full pressure at 52 seconds. Drawdown test performed w/ 2 electric pumps and 2 x air pumps. Observed 6 nitrogen bottles with an average PSI of 2600 PSI. Tested all gas and PVT alarms, both audio and visual - good tests. Note that the upper IBOP failed initial test - after functioning and greasing once, it re-tested good. 12/10/2016 1.00 COMPZ2 WHDBOP RURD P RD Test Equipment and reset Wear 11.8 -11.8 112/10/2016 06:30 07:30 1 Bushing. Page 49/55 Report Printed: 1/23/2017 = Operations Summary (with Timelog Depths) 7 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/10/2016 12/10/2016 1.00 COMPZ2 RWRID RURD P Rig up casing Equipment to run LEM. -11.8 -11.8 07:30 08:30 12/10/2016 12/10/2016 2.50 COMPZ2 RWRID PUTB P Made up LEM per Backer Rep and -11.8 302.3 08:30 11:00 oriented with MWD. 12/10/2016 12/10/2016 1.50 COMPZ2 RWRID RCST P RIH from 314' to 2,208' with LEM on 302.3 2,196.3 11:00 12:30 4" DP. 12/10/2016 12/10/2016 0.25 COMPZ2 RWRID DHEQ P Shallow Tested MWD. 2,196.3 2,196.3 12:30 12:45 12/10/2016 12/10/2016 4.00 COMPZ2 RWRID RCST P RIH from 2,208'to 10,209'with LEM 2,196.3 10,197.3 12:45 16:45 on 4" DP. UW 195K DW 127K. 12/10/2016 12/10/2016 0.25 COMPZ2 RWRID WASH P Made up Top Drive and wash down 10,197.3 10,221.3 16:45 17:00 from 10,209' to 10,233' 127 GPM 590 psi. Unable to enter Top of Liner. Set down 15K. UW 205K DW 128K. 12/10/2016 12/10/2016 2.25 COMPZ2 RWRID WASH T Attempted to enter Top of Liner 10,221.3 10,221.3 17:00 19:15 Rotating Tool Face working down torque and taging with 30K. GPM 127 PSI 590. UW 201 K DW 126K. No Success. 12/10/2016 12/10/2016 0.25 COMPZ2 RWRID TRIP T POOH from 10,233'to 10,206'. 10,221.3 10,194.3 19:15 19:30 12/10/2016 12/10/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 10,194.3 10,194.3 19:30 19:45 12/10/2016 12/11/2016 4.25 COMPZ2 RWRID TRIP T POOH from 10,206'to 315'. 10,194.3 303.3 19:45 00:00 12/11/2016 12/11/2016 0.75 COMPZ2 RWRID RURD T PJSM, R/U casing tongs and 303.3 298.3 00:00 00:45 elevators and prep to L/D LEM assembly. 12/11/2016 12/11/2016 1.50 COMPZ2 RWRID BHAH T UD LEM assembly and MWD tools as 298.3 -11.8 00:45 02:15 per Baker rep and SLB MWD rep. 12/11/2016 12/11/2016 1.25 COMPZ2 RWRID BHAH T Clean and clear rig floor. L/D casing -11.8 -11.8 02:15 03:30 tongs and handling equipment via beaver slide. 12/11/2016 12111/2016 1.50 COMPZ2 RWRID SLPC T PJSM, Cut and slip 59' of drilling line, -11.8 -11.8 03:30 05:00 4 wraps. 12/11/2016 12/11/2016 1.00 COMPZ2 RWRID SVRG T Service rig, service top drive, blocks, -11.8 -11.8 05:00 06:00 iron roughneck and draw works. 12/11/2016 12/11/2016 1.50 COMPZ2 RWRID RURD T PJSM, R/U power tongs and dress f/ 3 -11.8 -11.8 06:00 07:30 -1/8". Mobilize Baker fishing tools to rig floor, load pipe shed w/ 2-7/8" PAC pipe and strap. 12/11/2016 12/11/2016 1.25 COMPZ2 RWRID BHAH T M/U clean out BHA as per Baker. 3- -11.8 94.3 07:30 08:45 3/4" Smooth OD convex mill, 1 joint 2- 7/8" PAC, 4-3/4" Smooth OD string mill, 1 joint 2-7/8" PAC pipe and string magnets. 12/11/2016 12/11/2016 4.75 COMPZ2 RWRID TRIP T RIH from 106'to 10,007' UW 180K 94.3 9,995.3 08:45 13:30 DW 130K. 12/11/2016 12/11/2016 4.25 COMPZ2 RWRID REAM T Washed down with mill bha from 9,995.3 10,299.3 13:30 17:45 10,106'to 10,311'. Tagged @ 10,233' and was free below 10,234'. Reamed out from 10,244' to 10,311' with 7-9K WOB 40 - 60 RPM. 171 GPM @ 814 PSI. UW 190K DW 132K RW 152K Tq 6K. 12/11/2016 12/11/2016 0.25 COMPZ2 RWRID PULD T Laid down 2 singles to 10,310'. 10,299.3 10,298.3 17:45 18:00 Page 50/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) �4 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time bur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/11/2016 12/11/2016 3.75 COMPZ2 RWRID CIRC T Circulated Rot and Recip with 213 to 10,298.3 10,298.3 18:00 21:45 256 GPM 1200 psi to 1490 psi. 50 RPM Tq 7-9K. Pumped 3 sweeps to clean hole. 12/11/2016 12/11/2016 0.25 COMPZ2 RWRID PULD T Laid down 1 single. 10,298.3 10,268.3 21:45 22:00 12/11/2016 12/11/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 10,268.3 10,268.3 22:00 22:15 12/11/2016 12/12/2016 1.75 COMPZ2 RWRID TRIP T POOH from 10,280' to 7,304'. UW 10,268.3 7,292.3 22:15 00:00 134K DW 100K. 12/12/2016 12/12/2016 2.75 COMPZ2 RWRID TRIP T POOH frpm 7,304' to 104'. 7,292.3 92.3 00:00 02:45 12/12/2016 12/12/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static 92.3 92.3 02:45 03:00 12/12/2016 12/12/2016 1.00 COMPZ2 RWRID BHAH T Laid down BHA. 92.3 -11.8 03:00 04:00 12/12/2016 12/12/2016 0.75 COMPZ2 RWRID BHAH T Cleaned off Rig Floor. -11.8 -11.8 04:00 04:45 12/12/2016 12/12/2016 1.25 COMPZ2 RWRID BHAH T Made up and ran in LEM Assembly to -11.8 302.3 04:45 06:00 314'. 12/12/2016 12/12/2016 1.00 COMPZ2 RWRID RCST T RIH with LEM on 4" DP from 314' to 302.3 2,193.3 06:00 07:00 2,205'. 12/12/2016 12/12/2016 0.50 COMPZ2 RWRID DHEQ T Shallow tested MWD. Working. 2,193.3 2,193.3 07:00 07:30 12/12/2016 12/12/2016 4.00 COMPZ2 RWRID RCST T RIH with LEM on 4" DP from 2,205' to 2,193.3 10,013.3 07:30 11:30 10,025'. 12/12/2016 12/12/2016 3.00 COMPZ2 RWRID WASH T Washed down orienting LEM from 10,013.3 10,232.3 11:30 14:30 10,025' to 10,244'. Washed and worked pipe from 10,217 to 10,244' tagging with 15K, would not seat. 12/12/2016 12/12/2016 0.25 COMPZ2 RWRID TRIP T POOH 1 stand and blow down top 10,232.3 10,232.3 14:30 14:45 drive. 12/12/2016 12/12/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 10,232.3 10,232.3 14:45 15:00 12/12/2016 12/12/2016 4.50 COMPZ2 RWRID TRIP T POOH from 10,244' to 314'. 10,232.3 302.3 15:00 19:30 12/12/2016 12/12/2016 2.00 COMPZ2 RWRID BHAH T Laid down LEM assembly. 302.3 -11.8 19:30 21:30 12/12/2016 12/12/2016 1.00 COMPZ2 RWRID BHAH T Cleared components off Rig Floor. -11.8 -11.8 21:30 22:30 12/12/2016 12/13/2016 1.50 COMPZ2 RWRID BHAH T Made up Cleanout BHA with -11.8 53.3 22:30 00:00 Reverseing Basket. 12/13/2016 12/13/2016 1.25 COMPZ2 RWRID BHAH T Finish making up Cleanout BHA. 53.3 290.3 00:00 01:15 12/13/2016 12/13/2016 3.75 COMPZ2 RWRID TRIP T RIH with Cleanout BHA from 302' to 290.3 10,001.3 01:15 05:00 10,013'. 12/13/2016 12/13/2016 2.25 COMPZ2 RWRID WASH T Wash down with reverse Basket from 10,001.3 10,282.3 05:00 07:15 10,013' to 10,294'. Took weight at 10,244' and washed through. Remainder took 2 to 5K while washing down. 12/13/2016 12/13/2016 0.50 COMPZ2 RWRID CIRC T Pumped down ball to open Pump Out 10,282.3 10,282.3 07:15 07:45 Sub.3 BPM 560 psi. 12/13/2016 12/13/2016 1.25 COMPZ2 RWRID CIRC T Pumped Viscus Pill and circulated out. 10,282.3 10,282.3 07:45 09:00 8 BPM 2214 psi. 12/13/2016 12/13/2016 0.25 COMPZ2 RWRID OWFF T OWFF well Static. 10,282.3 10,282.3 09:00 09:15 12/13/2016 12/13/2016 4.50 COMPZ2 RWRID TRIP T POOH from 10,294' to 302'. 10,282.3 290.3 09:15 13:45 Page 51/55 Report Printed: 1/2312017 -;-. Operations Summary (with Timelog Depths) x , lb2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/13/2016 12/13/2016 1.25 COMPZ2 RWRID BHAH T Cleaned Magnets and laid down BHA. 290.3 -11.8 13:45 15:00 Emty Reverse Baskit and redress. 12/13/2016 12/13/2016 0.50 COMPZ2 RWRID BHAH T Cleaned Rig Floor. -11.8 -11.8 15:00 15:30 12/13/2016 12/13/2016 0.50 COMPZ2 RWRID SVRG T Serviced Rig. -11.8 -11.8 15:30 16:00 12/13/2016 12/13/2016 1.00 COMPZ2 RWRID BHAH T Made up BHA with Reversre Basket -11.8 290.3 16:00 17:00 and Magnets. 12/13/2016 12/13/2016 4.50 COMPZ2 RWRID TRIP T RIH from 302'to 10,203'. 290.3 10,191.3 17:00 21:30 12/13/2016 12/13/2016 1.50 COMPZ2 RWRID WASH T Washed down from 10,203' to 10,296'. 10,191.3 10,284.3 21:30 23:00 Tagged with 4K at 10,296'. Worked Basket. 6 BPM 2,055 psi. 30 RPM Tq 6-9K. RW 147K. 12/13/2016 12/13/2016 0.25 COMPZ2 RWRID CIRC T Pumped down ball to open Pump Out 10,284.3 10,284.3 23:00 23:15 Sub.3 BPM 575 psi. 12/13/2016 12/14/2016 0.75 COMPZ2 RWRID CIRC T Pumped Viscus Pill and circulated at. 10,284.3 10,284.3 23:15 00:00 8 BPM 2110 psi. 12/14/2016 12/14/2016 0.50 COMPZ2 RWRID CIRC T Circulated Viscous Pill out at. 8 BPM 10,284.3 10,284.3 00:00 00:30 2110 psi. 12/14/2016 12/14/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 10,284.3 10,284.3 00:30 00:45 12/14/2016 12/14/2016 4.00 COMPZ2 RWRID TRIP T POOH from 10,296'to 302'. 10,284.3 290.3 00:45 04:45 12/14/2016 12/14/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 290.3 290.3 04:45 05:00 12/14/2016 12/14/2016 1.50 COMPZ2 RWRID BHAH T Cleaned Magnets and laid down BHA. 290.3 -11.8 05:00 06:30 12/14/2016 12/14/2016 2.00 COMPZ2 RWRID BHAH T Redressed Reverse Basket and made -11.8 290.3 06:30 08:30 up Cleanout BHA. 12/14/2016 12/14/2016 4.00 COMPZ2 RWRID TRIP T RIH with Cleanout BHA from 302' to 290.3 9,998.3 08:30 12:30 10,010'. 12/14/2016 12/14/2016 3.75 COMPZ2 RWRID WASH T Washed down from 10,010' to 9,998.3 10,284.1 12:30 16:15 10,295.87'. Tagged with 5 - 8K WOB at 10,295.87'. Worked Basket. 254 GPM 1,955 psi. 30-60 RPM Tq 5-6K. RW 154K. 12/14/2016 12/14/2016 1.50 COMPZ2 RWRID CIRC T Dropped ball and opened PO sub. 10,284.1 10,284.2 16:15 17:45 Continued circulating 8 BPM 2197 psi. 12/14/2016 12/14/2016 0.25 COMPZ2 RWRID PULD T Laid down single and blow down Top 10,284.2 10,273.3 17:45 18:00 Drive. 12/14/2016 12/14/2016 0.25 COMPZ2 RWRID OWFF T OWFF Well Static. 10,273.3 10,273.3 18:00 18:15 12/14/2016 12/14/2016 3.75 COMPZ2 RWRID TRIP T POOH from 10,285' to 314'. 10,273.3 302.3 18:15 22:00 12/14/2016 12/14/2016 1.50 COMPZ2 RWRID BHAH T Laid down BHA Cleaned Magnets and 302.3 -11.8 22:00 23:30 Junk Basket Jird full. 12/14/2016 12/15/2016 0.50 COMPZ2 RWRID BHAH T Clear componets off Rig Floor. -11.8 -11.8 23:30 00:00 12/15/2016 12/15/2016 0.50 COMPZ2 RWRID BHAH T Finish laying down BHA. -11.8 -11.8 00:00 00:30 12/15/2016 12/15/2016 0.75 COMPZ2 RWRID BHAH T Cleared Rig floor and chamged -11.8 -11.8 00:30 01:15 Equipment. 12/15/2016 12/15/2016 3.50 COMPZ2 RWRID PUTB T Picked up LEM BHA with inner string -11.8 302.3 01:15 04:45 and MWD and made up per Baker Rep and Detail. Page 52/55 Report Printed: 1/23/2017 Operations Summary (with Timelog Depths) 2S-13 Job: DRILLING SIDETRACK 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 (WB) 302.3 2,188.3 12/15/2016 12/15/2016 1.00 COMPZ2 RWRID RCST T RIH with LEM on 4" DP from 314' to 04:45 05:45 2,200'. 12/15/2016 12/15/2016 0.50 COMPZ2 RWRID DHEQ T Shallow tested MWD 120 GPM 260 2,188.3 2,188.3 05:45 06:15 psi. 12/15/2016 12/15/2016 3.50 COMPZ2 RWRID RCST T RIH with LEM on 4" DP from 2,200 to 2,188.3 9,921.3 06:15 09:45 9,933'. 12/15/2016 12/15/2016 3.00 COMPZ2 RWRID WASH T Washed down from 9,933' to 10,285'. 9,921.3 10,273.3 09:45 12:45 120 GPM 516 psi. UW 174K DW 129K. Orient Tool Face andTagged Latch with 20K no movement. 12/15/2016 12/15/2016 0.25 COMPZ2 RWRID TRIP T POOH from 10,285'to 10,045'. UW 10,273.3 10,033.3 12:45 13:00 178K. 12/15/2016 12/15/2016 1.50 COMPZ2 RWRID CIRC T Circulated and oriented Tool Face to 10,033.3 10,008.3 13:00 14:30 Jet Latch. 139 GPM 640 psi. UW 178K DW 135K. 12/15/2016 12/15/2016 0.25 COMPZ2 RWRID TRIP T RIH from 10,020' to 10,209'. 10,008.3 10,197.3 14:30 14:45 12/15/2016 12/15/2016 4.75 COMPZ2 RWRID WASH T Washed Latch and worked pipe to 10,197.3 10,275.3 14:45 19:30 reorint Tool Face. Attempted to Latch 3 times. No success latching in. Continued to wash and orient LEM while regrouped with Anchorage Team. Oriented Tool Face to 17 Left and set down 50K per Baker. 12/15/2016 12/15/2016 1.25 COMPZ2 RWRID PACK P Dropped 1.5" Ball and pumped down 10,275.3 10,275.3 19:30 20:45 to seat. Pressured up to 2,500 psi and set ZXP Packer. Pressured up to 3800 psi and released running tool. 12/15/2016 12/15/2016 0.75 COMPZ2 RWRID PRTS P PU to nuetral weight and Tested IA to 10,275.3 10,273.3 20:45 21:30 3500 psi for 10 Min on Chart. 12/15/2016 12/15/2016 0.25 COMPZ2 RWRID PACK P Picked up and retagged 4' high 10,273.3 10,273.3 21:30 21:45 comfirming LEM set. 12/15/2016 12!15/2016 0.50 COMPZ2 RWRID OWFF P OWFF Well Static. 10,273.3 10,273.3 21:45 22:15 12/15/2016 12/16/2016 1.75 COMPZ2 RWRID PULD P POOH Laying Down DP from 10,285' 10,273.3 8,757.3 22:15 00:00 to 8,769'. 12/16/2016 12/16/2016 7.50 COMPZ2 RWRID PULD P POOH laying down DP from 8,769' to 8,757.3 302.3 00:00 07:30 314'. 12116/2016 12/16/2016 0.25 COMPZ2 RWRID OWFF P OWFF Well Static. 302.3 302.3 07:30 07:45 12/16/2016 12/16/2016 0.50 COMPZ2 RWRID PULD P Laid down 4 Stands of DP from 302.3 302.3 07:45 08:15 Derreck in mousehole. 12/16/2016 12/16/2016 0.25 COMPZ2 RWRID BHAH P RU power tongs for inner string. 302.3 302.3 08:15 08:30 12/16/2016 12/16/2016 1.50 COMPZ2 RWRID BHAH P Laid down Baker running tool and 302.3 -11.8 08:30 10:00 1 inner String with MWD. 12/16/2016 12/16/2016 0.75 COMPZ2 RWRID BHAH P Cleared Rig Floor. -11.8 -11.8 10:00 10:45 12/16/2016 12/16/2016 7.25 COMPZ2 RPCOMP PULD P Laid down 66 Stands of DP from -11.8 -11.8 10:45 18:00 Derreck in mousehole. 12/16/2016 12/16/2016 1.50 COMPZ2 RPCOMP WWWH P Pulled Wear Bushing. RU Stack Wash -11.8 -11.8 18:00 19:30 Tool and Washed Stack. 12/16/2016 12/16/2016 0.75 COMPZ2 RPCOMP RURD P Rigged up to run Upper Completion. -11.8 -11.8 19:30 20:15 12!16/2016 12/17/2016 3.75 COMPZ2 RPCOMP PUTB P Make up and Run 4.5" Upper 11.8 1,765.3 20:15 00:00 Completion per Detail to 1,777'. Page 53155 Report Printed: 1!23/2017 - Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/17/2016 12/17/2016 9.25 COMPZ2 RPCOMP PUTB P Make up and Run 4.5" Upper 1,765.3 10,011.3 00:00 09:15 Completion per Detail from 1,777' to 10,023'. Tagged No Go with 10K. 12/17/2016 12/17/2016 1.75 COMPZ2 RPCOMP HOSO P Laid down 4 Jts of Tubing. PU 3 Jts of 10,011.3 10,008.3 09:15 11:00 Tubing and tagged @ 10,013'. Washed top og Seal Bore 5BPM 447 psi. Entered Seal Bore pumping 2 BPM 60 psi. Confirmed entry with increase to 140 psi. Ran in to 10,020'. 12/17/2016 12/17/2016 0.50 COMPZ2 RPCOMP PRTS P Tested IA to 500 psi for 5 Min on 10,008.3 10,008.3 11:00 11:30 Chart to confirm seals engaged. 12/17/2016 12/17/2016 1.50 COMPZ2 RPCOMP HOSO P Spaced out. Added 2 Pups 7.82'+ 10,008.3 9,962.3 11:30 13:00 3.90'. 12/17/2016 12/17/2016 1.00 COMPZ2 RPCOMP THGR P Made up Tubing Hanger and Landing 9,962.3 9,962.3 13:00 14:00 Joint. 12/17/2016 12/17/2016 1.00 COMPZ2 RPCOMP CRIH P Pumped 69 Bbls Inhibited Brine 9,962.3 9,962.3 14:00 15:00 displaced with 137 Bbls Brine. 5 BPM 500 psi. 12/17/2016 12/17/2016 0.25 COMPZ2 RPCOMP THGR P Drained Stack and Landed Tubing. 9,962.3 10,007.3 15:00 15:15 12/17/2016 12/17/2016 1.00 COMPZ2 RPCOMP THGR P Ran in Lock Down Screws and tested 10,007.3 -11.8 15:15 16:15 Tubing Hanger 5,000 psi for 10 Min. 12/17/2016 12/17/2016 0.25 COMPZ2 RPCOMP PRTS P Dropped Ball and Rod. -11.8 -11.8 16:15 16:30 12/17/2016 12/17/2016 1.75 COMPZ2 RPCOMP PRTS P Pressure tested Tubing 3,500 psi for -11.8 -11.8 16:30 18:15 30 Min on chart. Tested IA 3,500 psi for 30 Min on chart. Both test good. 12/17/2016 12/17/2016 0.75 COMPZ2 RPCOMP CIRC P Pressured up IA to 2,590 psi and -11.8 -11.8 18:15 19:00 Sheared out Valve. Checked circulation both ways. 12/17/2016 12/17/2016 0.25 COMPZ2 RPCOMP OWFF P OWFF Well Static -11.8 -11.8 19:00 19:15 12/17/2016 12/17/2016 0.25 COMPZ2 RPCOMP RURD P RD and laid down Landing Joint. -11.8 -11.8 19:15 19:30 12/17/2016 12/17/2016 0.75 COMPZ2 WHDBOP MPSP P Installed Type H BPV and Tested -11.8 -11.8 19:30 20:15 2,500 psi for 10 Min on chart. 12/17/2016 12/17/2016 0.75 COMPZ2 WHDBOP OWFF P OWFF for 30 Min. Well Static. -11.8 -11.8 20:15 21:00 12/17/2016 12/17/2016 1.25 COMPZ2 WHDBOP OTHR P Cleared Rig Floor and Blow down -11.8 -11.8 21:00 22:15 lines. 12/17/2016 12/17/2016 0.75 COMPZ2 WHDBOP MPDA P Pulled Trip Nipple. -11.8 -11.8 22:15 23:00 12/17/2016 12/18/2016 1.00 COMPZ2 WHDBOP MPDA P Cleaned and removed RCD Clamp -11.8 -11.8 23:00 00:00 and AV valve from Stack. 12/18/2016 12/18/2016 1.00 COMPZ2 WHDBOP MPDA P Removed RCD Clamp and AV valve 0.0 0.0 00:00 01:00 from Stack. 12/18/2016 12/18/2016 3.50 COMPZ2 WHDBOP OTHR T ND Annular and remove from Stack. 0.0 0.0 01:00 04:30 NU new Annular. 12/18/2016 12/18/2016 1.25 COMPZ2 WHDBOP NUND P ND BOP and set back. 0.0 0.0 04:30 05:45 12/18/2016 12/18/2016 2.75 COMPZ2 WHDBOP NUND P Dressed Hanger and NU Adapter 0.0 0.0 05:45 08:30 Flange. Installed Test Dart. 12/18/2016 12/18/2016 0.25 COMPZ2 WHDBOP PRTS P Tested void 250/5000 psi for 5 Min. 0.0 0.0 08:30 08:45 12/18/2016 12/18/2016 2.25 COMPZ2 WHDBOP NUND P NU Tree. 0.0 0.0 08:45 11:00 Page 54/55 Report Printed: 1/23/2017 a - Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 142 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (WS) End Depth (MB) 12/18/2016 12/18/2016 0.25 COMPZ2 WHDBOP PRTS P Tested Tree to 250/5000 psi for 15 0.0 0.0 11:00 11:15 Min. 12/18/2016 12/18/2016 0.75 COMPZ2 WHDBOP MPSP P Pulled Test Dart and BPV. 0.0 0.0 11:15 12:00 12/18/2016 12/18/2016 1.00 COMPZ2 WHDBOP FRZP P Rigged up to Freeze protect well. 0.0 0.0 12:00 13:00 12/18/2016 12/18/2016 0.25 COMPZ2 WHDBOP FRZP P Tested lines 2000 psi. With LRS. 0.0 0.0 13:00 13:15 12/18/2016 12/18/2016 1.25 COMPZ2 WHDBOP FRZP P Pumped 91 BUS Diesel with LRS 0.0 0.0 13:15 14:30 down IA. 12/18/2016 12/18/2016 1.25 COMPZ2 WHDBOP FRZP P Allowed IA and Tubing to U Tube. 0.0 0.0 14:30 15:45 12/18/2016 12/18/2016 1.75 COMPZ2 WHDBOP MPSP P Installed Lubricator tested to 2000 psi 0.0 0.0 15:45 17:30 and Set BPV. Laid down Lubricator. 12/18/2016 12/18/2016 1.00 COMPZ2 MOVE RURD P Rigged down test lines and trimmed 0.0 0.0 17:30 18:30 Tree. Secured Well. Tubing 325 PSI (Before BPV), IA 50 PSI, OA 25 PSI. Rig released to Move @ 1900 Hrs 12/18/16. 12/18/2016 12/18/2016 0.50 DEMOB MOVE RURD P Prep to move to 1 D-37. Rig released 0.0 -11.8 18:30 19:00 @ 1900 hrs 12-18-2016 for'23 mile move. Page 55155 Report Printed: 1/23/2017 NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S -13L1 Definitive Survey Report 09 September, 2016 Company: NADConversion Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-13 Wellbore: 2S-131-1 Design: 2S-131-1 Schlumberger Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2S-13 2S-13: 120+27.5 @ 147.50usft(Doyonl41) 25-13: 120+27.5 @ 147.50usft (Doyonl41) True Minimum Curvature 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-13 Well Position +N/ -S 0.00 usft Northing: 5,929,948.70 usft Latitude: 70° 13'11.187 N +E/ -W 0.00 usft Easting: 480,898.09 usft Longitude: 150° 9' 14.767 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 120.00 usft Wellbore 2S-131-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1 (nT) BG G M 2015 12/15/2015 18.44 80.86 57,486 Design 2S-131-1 Date Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 9,906.60 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,283.58 2S-131361 Srvy #1 - SLB _NSG+Battery+ (usft) (usft) (usft) (I 1,304.79 27.50 0.00 0.00 325.92 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 82.68 1,283.58 2S-131361 Srvy #1 - SLB _NSG+Battery+ GYD-GC-SS Gyrodata gyro single shots 11/30/2015 10:2: 1,304.79 2,775.54 2S-13PB1 Srvy #2 - SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/30/2015 10:21 2,868.21 9,265.50 2S-13PB1 Srvy #3 - SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/6/2015 8:33: 9,288.24 9,288.24 2S-13PB1 Srvy #4 - SLB_Inc+Filler (2S-1 INC+TREND Inclinometer + known azi trend 12/15/2015 9:3E 9,338.00 9,906.60 2S-13 Srvy #1 - SLB_MWD+GMAG (2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/20/2015 11:31 9,942.83 10,132.07 2S-131-1 Srvy #1 -SLB - Inc -Filler (2S -13L INC+TREND Inclinometer+ known azi trend 1/16/2016 8:47: 10,161.27 16,785.89 2S-131-1 Srvy #2 - SLB_MWD+GMAG (2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/18/2016 8:57: Survey 982016 9:34:OOAM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1 -W Northing Easting DLS Section Weft) (1) 0 (usft) (usft) (usft) (usft) (ft) (ft) (°/100•) (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,948.70 480,898.09 0.00 0.00 UNDEFINED 82.68 0.03 287.05 82.68 -64.82 0.00 -0.01 5,929,948.70 480,898.08 0.05 0.01 GYD-GC-SS(1) 107.50 0.04 238.86 107.50 -40.00 0.00 -0.03 5,929,948.70 480,898.06 0.11 0.02 GYD-GC-SS(1) 20" x 42" 174.86 0.10 201.50 174.86 27.36 -0.06 -0.07 5,929,948.64 480,898.02 0.11 -0.02 GYD-GC-SS(1) 266.90 0.54 204.98 266.90 119.40 -0.53 -0.28 5,929,948.17 460,897.81 0.48 -0.28 GYD-GC-SS (1) 358.92 2.63 196.47 358.88 211.38 -2.95 -1.06 5,929,945.75 480,897.02 2.28 -1.85 GYD-GC-SS (1) 450.55 4.08 197.58 450.35 302.85 -8.07 -2.64 5,929,940.63 480,895.43 1.58 -5.21 GYD-GC-SS (1) 542.44 4.84 198.23 541.96 394.46 -14.87 -4.84 5,929,933.84 480,893.21 0.83 -9.60 GYD-GC-SS(1) 982016 9:34:OOAM Page 2 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13:120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 Database: OAKEDMP2 Survey Map Map Vertical MO Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/low) (ft) Survey Tool Name 634.35 5.99 202.27 633.46 485.96 -22.99 -7.87 5,929,925.73 480,890.16 1.32 -14.63 GYD-GC-SS (1) 726.00 6.53 203.78 724.56 577.06 -32.19 -11.79 5,929,916.55 480,886.22 0.62 -20.05 GYD-GC-SS (1) 817.94 8.48 201.86 815.71 668.21 -43.26 -16.42 5,929,905.48 480,881.56 2.14 -26.63 GYD-GC-SS(1) 910.56 9.80 205.54 907.15 759.65 -56.71 -22.36 5,929,892.05 480,875.59 1.56 -34.44 GYD-GC-SS (1) 1,003.86 11.08 208.23 998.91 851.41 -71.78 -30.02 5,929,877.01 480,867.89 1.47 -42.62 GYD-GC-SS (1) 1,096.09 12.93 209.29 1,089.12 941.62 -88.59 -39.27 5,929,860.22 480,858.60 2.02 -51.37 GYD-GC-SS(1) 1,188.56 15.38 208.11 1,178.77 1,031.27 -108.43 -50.11 5,929,840.41 480,847.72 2.67 -61.72 GYD-GC-SS(1) 1,283.58 19.22 206.89 1,269.48 1,121.98 -133.50 163.12 5,929,815.37 480,834.64 4.06 -75.20 GYD-GC-SS (1) 1,304.79 20.60 207.96 1,289.42 1,141.92 -139.91 -66.45 5,929,808.97 480,831.29 6.73 -78.64 MWD+IFR-AK-CAZ-SC (2) 1,396.67 21.80 208.96 1,375.08 1,227.58 -169.12 -82.29 5,929,779.61 480,815.38 1.36 -93.95 MWD+IFR-AK-CAZ-SC (2) 1,491.21 25.56 213.09 1,461.65 1,314.15 -201.58 -101.93 5,929,747.40 480,795.66 4.34 -109.83 MWD+IFR-AK-CAZ-SC (2) 1,585.16 27.45 217.68 1,545.73 1,398.23 -235.70 -126.24 5,929,713.34 480,771.27 2.97 -124.47 MWD+IFR-AK-CAZ-SC (2) 1,677.93 29.30 221.23 1,627.36 1,479.86 -269.70 -154.27 5,929,679.41 480,743.15 2.70 -136.92 MWD+IFR-AK-CAZ-SC (2) 1,771.75 30.21 225.91 1,708.82 1,561.32 -303.40 -186.36 5,929,645.81 480,710.98 2.66 -146.84 MWD+IFR-AK-CAZ-SC (2) 1,863.74 31.06 226.45 1,787.97 1,640.47 -335.85 -220.19 5,929,613.44 480,677.08 0.97 -154.76 MWD+IFR-AK-CAZ-SC (2) 1,956.72 32.83 229.72 1,866.87 1,719.37 -368.68 -256.80 5,929,580.71 480,640.38 2.66 -161.43 MWD+IFR-AK-CAZ-SC (2) 2,050.37 33.68 233.62 1,945.19 1,797.69 -400.50 -297.08 5,929,549.00 480,600.02 2.46 -165.21 MWD+IFR-AK-CAZ-SC (2) 2,143.17 34.26 235.37 2,022.15 1,874.65 1130.60 -339.29 5,929,519.00 480,557.74 1.23 -166.49 MWD+IFR-AK-CAZ-SC (2) 2,237.57 35.48 238.69 2,099.61 1,952.11 -459.94 -384.57 5,929,489.78 480,512.40 2.39 -165.42 MWD+IFR-AK-CAZ-SC (2) 2,330.47 38.90 240.04 2,173.61 2,026.11 1388.53 -432.89 5,929,461.32 480,464.01 3.78 -162.02 MWD+IFR-AK-CAZ-SC (2) 2,423.89 39.45 242.06 2,246.03 2,098.53 -517.09 -484.53 5,929,432.89 480,412.31 1.49 -156.73 MWD+IFR-AK-CAZ-SC (2) 2,515.04 40.79 245.52 2,315.74 2,168.24 -543.00 -537.21 5,929,407.12 480,359.56 2.85 -148.66 MWD+IFR-AK-CAZ-SC (2) 2,609.16 42.70 247.70 2,385.97 2,238.47 -567.85 -594.73 5,929,382.41 480,301.98 2.55 -137.01 MWD+IFR-AK-CAZ-SC (2) 2,701.86 43.56 247.40 2,453.62 2,306.12 -592.05 -653.30 5,929,358.36 460,243.36 0.95 -124.24 MWD+IFR-AK-CAZ-SC (2) 2,775.54 45.32 247.46 2,506.22 2,358.72 -611.85 -700.94 5,929,338.69 480,195.68 2.39 -113.94 MWD+IFR-AK-CAZ-SC (2) 2,835.00 46.00 247.45 2,547.78 2,400.28 -628.16 -740.21 5,929,322.48 480,156.37 1.14 -105.43 MWD+IFR-AK-CAZ-SC (3) 133/8" x 16" 2,868.01 46.37 247.44 2,570.64 2,423.14 337.29 -762.21 5,929,313.40 480,134.35 1.14 -100.67 MWD+IFR-AK-CAZ-SC (3) 2,961.88 45.93 246.36 2,635.67 2,488.17 -663.85 -824.47 5,929,287.01 480,072.02 0.95 -87.77 MWD+IFR-AK-CAZ-SC (3) 3,053.24 45.12 245.87 2,699.67 2,552.17 -690.24 -884.08 5,929,260.77 480,012.35 0.97 -76.23 MWD+IFR-AK-CAZ-SC (3) 3,145.12 45.68 246.79 2,764.19 2,616.69 -716.50 -944.00 5,929,234.66 479,952.38 0.94 164.40 MWD+IFR-AK-CAZ-SC (3) 3,237.98 47.31 247.54 2,828.11 2,680.61 -742.63 -1,006.07 5,929,208.69 479,890.24 1.85 -51.26 MWD+IFR-AK-CAZ-SC (3) 3,332.72 50.46 248.03 2,890.40 2,742.90 -769.61 -1,072.14 5,929,181.88 479,824.11 3.35 -36.57 MWD+IFR-AK-CAZ-SC (3) 3,425.65 51.28 247.93 2,949.05 2,801.55 -796.64 -1,138.97 5,929,155.03 479,757.22 0.89 -21.51 MWD+IFR-AK-CAZ-SC (3) 3,518.99 55.39 247.67 3,004.77 2,857.27 -824.93 -1,208.28 5,929,126.92 479,687.85 4.41 -6.10 MWD+IFR-AK-CAZ-SC (3) 3,609.42 56.46 248.04 3,055.44 2,907.94 -853.16 -1,277.65 5,929,098.86 479,618.41 1.23 9.40 MWD+IFR-AK-CAZ-SC (3) 3,703.27 57.86 248.01 3,106.33 2,958.83 -882.67 -1,350.77 5,929,069.54 479,545.22 1.49 25.94 MWD+IFR-AK-CAZ-SC (3) 3,795.35 58.60 248.24 3,154.81 3,007.31 -911.83 -1,423.42 5,929,040.56 479,472.51 0.83 42.49 MWD+IFR-AK-CAZ-SC (3) 3,888.69 62.00 248.65 3,201.05 3,053.55 -941.61 -1,498.82 5,929,010.98 479,397.04 3.66 60.08 MWD+IFR-AK-CAZ-SC (3) 3,983.02 62.42 248.93 3,245.03 3,097.53 -971.80 -1,576.62 5,928,980.99 479,319.18 0.52 78.68 MWD+IFR-AK-CAZ-SC (3) 9/9/2016 9:34:00AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S +E/ -W Northing Easting DLS Section (usft) 0 (`) (usft) (usft) (usft) (usft) (ft) (ft) (°1700') (ft) Survey Tool Name 4,075.27 61.97 248.44 3,288.06 3,140.56 -1,001.46 -1,652.63 5,928,951.52 479,243.09 0.68 96.71 MWD+IFR-AK-CAZ-SC (3) 4,168.33 61.01 250.91 3,332.49 3,184.99 -1,029.87 -1,729.30 5,928,923.31 479,166.36 2.55 116.15 MWD+IFR-AK-CAZ-SC (3) 4,262.19 60.59 251.46 3,378.28 3,230.78 -1,056.29 -1,806.86 5,928,897.09 479,088.74 0.68 137.73 MWD+IFR-AK-CAZ-SC (3) 4,356.57 60.80 251.48 3,424.47 3,276.97 -1,082.45 -1,884.89 5,928,871.13 479,010.65 0.22 159.80 MWD+IFR-AK-CAZ-SC (3) 4,449.98 61.03 251.32 3,469.88 3,322.38 -1,108.49 -1,962.26 5,928,845.29 478,933.23 0.29 181.59 MWD+IFR-AK-CAZ-SC (3) 4,544.76 61.00 251.15 3,515.81 3,368.31 -1,135.16 -2,040.76 5,928,818.82 478,854.67 0.16 203.49 MWD+IFR-AK-CAZ-SC (3) 4,638.59 61.06 250.63 3,561.26 3,413.76 -1,162.03 -2,118.33 5,928,792.15 478,777.04 0.49 224.70 MWD+IFR-AK-CAZ-SC (3) 4,732.01 60.86 249.57 3,606.61 3,459.11 -1,189.83 -2,195.12 5,928,764.55 478,700.18 1.01 244.71 MWD+IFR-AK-CAZ-SC (3) 4,826.27 60.79 250.20 3,652.56 3,505.06 -1,218.13 -2,272.40 5,928,736.44 478,622.84 0.59 264.58 MWD+IFR-AK-CAZ-SC (3) 4,916.93 61.06 250.33 3,696.61 3,549.11 -1,244.89 -2,346.99 5,928,709.88 478,548.19 0.32 284.22 MWD+IFR-AK-CAZ-SC (3) 5,010.28 61.10 250.12 3,741.76 3,594.26 -1,272.53 -2,423.88 5,928,682.43 478,471.24 0.20 304.41 MWD+IFR-AK-CAZ-SC (3) 5,102.78 60.72 250.05 3,786.73 3,639.23 -1,300.07 -2,499.87 5,928,655.09 478,395.18 0.42 324.20 MWD+IFR-AK-CAZ-SC (3) 5,195.28 60.66 249.61 3,832.01 3,684.51 -1,327.88 -2,575.59 5,928,627.48 478,319.41 0.42 343.59 MWD+IFR-AK-CAZ-SC (3) 5,289.37 60.74 250.17 3,878.06 3,730.56 -1,356.09 -2,652.64 5,928,599.46 478,242.29 0.53 363.41 MWD+IFR-AK-CAZ-SC (3) 5,381.75 60.67 250.09 3,923.26 3,775.76 -1,383.47 -2,728.41 5,928,572.27 478,166.46 0.11 383.19 MWD+IFR-AK-CAZ-SC (3) 5,473.45 60.63 250.62 3,968.20 3,820.70 -1,410.35 -2,803.68 5,928,545.60 478,091.13 0.51 403.12 MWD+IFR-AK-CAZ-SC (3) 5,567.92 60.66 250.87 4,014.51 3,867.01 -1,437.50 -2,881.42 5,928,518.64 478,013.33 0.23 424.19 MWD+IFR-AK-CAZ-SC (3) 5,661.68 60.74 251.47 4,060.40 3,912.90 -1,463.89 -2,958.80 5,928,492.45 477,935.88 0.56 445.70 MWD+IFR-AK-CAZ-SC (3) 5,757.08 60.53 251.29 4,107.18 3,959.68 -1,490.44 -3,037.60 5,928,466.11 477,857.04 0.27 467.87 MWD+IFR-AK-CAZ-SC (3) 5,850.57 60.90 250.91 4,152.91 4,005.41 -1,516.85 -3,114.74 5,928,439.89 477,779.83 0.53 489.23 MWD+IFR-AK-CAZ-SC (3) 5,943.99 60.44 248.47 4,198.68 4,051.18 -1,545.11 -3,191.11 5,928,411.82 477,703.39 2.33 508.62 MWD+IFR-AK-CAZ-SC (3) 6,037.22 60.79 249.67 4,244.43 4,096.93 -1,574.13 -3,266.99 5,928,383.00 477,627.45 1.18 527.11 MWD+IFR-AK-CAZ-SC (3) 6,129.53 60.59 248.07 4,289.62 4,142.12 -1,603.14 -3,342.06 5,928,354.18 477,552.31 1.53 545.15 MWD+IFR-AK-CAZ-SC (3) 6,222.41 60.88 248.38 4,335.02 4,187.52 -1,633.20 -3,417.31 5,928,324.32 477,477.00 0.43 562.43 MWD+IFR-AK-CAZ-SC (3) 6,316.01 60.70 248.15 4,380.70 4,233.20 -1,663.45 -3,493.20 5,928,294.26 477,401.04 0.29 579.90 MWD+IFR-AK-CAZ-SC (3) 6,409.32 60.61 250.20 4,426.43 4,278.93 -1,692.37 -3,569.22 5,928,265.54 477,324.96 1.92 598.55 MWD+IFR-AK-CAZ-SC (3) 6,502.38 58.16 250.88 4,473.82 4,326.32 -1,719.05 -3,644.72 5,928,239.05 477,249.39 2.71 618.76 MWD+IFR-AK-CAZ-SC (3) 6,598.21 58.41 253.51 4,524.20 4,376.70 -1,743.97 -3,722.33 5,928,214.33 477,171.73 2.35 641.61 MWD+IFR-AK-CAZ-SC (3) 6,689.12 58.87 256.33 4,571.52 4,424.02 -1,764.16 -3,797.27 5,928,194.33 477,096.74 2.70 666.89 MWD+IFR-AK-CAZ-SC (3) 6,783.66 59.28 258.89 4,620.11 4,472.61 -1,781.56 -3,876.47 5,928,177.14 477,017.51 2.36 696.87 MWD+IFR-AK-CAZ-SC (3) 6,878.78 58.49 262.31 4,669.28 4,521.78 -1,794.87 -3,956.79 5,928,164.03 476,937.16 3.19 730.86 MWD+IFR-AK-CAZ-SC (3) 6,974.96 57.42 266.31 4,720.32 4,572.82 -1,802.96 -4,037.89 5,928,156.14 476,856.05 3.70 769.60 MWD+IFR-AK-CAZ-SC (3) 7,068.26 56.96 269.00 4,770.88 4,623.38 -1,806.17 -4,116.23 5,928,153.13 476,777.71 2.47 810.84 MWD+IFR-AK-CAZ-SC (3) 7,162.25 56.44 272.56 4,822.50 4,675.00 -1,805.11 -4,194.76 5,928,154.39 476,699.20 3.21 855.73 MWD+IFR-AK-CAZ-SC (3) 7,254.28 55.85 275.87 4,873.78 4,726.28 -1,799.50 -4,270.96 5,928,160.19 476,623.01 3.05 903.08 MWD+IFR-AK-CAZ-SC (3) 7,345.72 55.88 278.70 4,925.10 4,777.60 -1,789.91 -4,346.02 5,928,169.97 476,547.98 2.56 953.09 MWD+IFR-AK-CAZ-SC (3) 7,441.05 55.03 280.27 4,979.15 4,831.65 -1,776.97 -4,423.47 5,928,183.10 476,470.58 1.62 1,007.20 MWD+IFR-AK-CAZ-SC (3) 7,533.25 52.88 282.42 5,033.41 4,885.91 -1,762.33 3,496.55 5,928,197.93 476,397.54 3.00 1,060.29 MWD+IFR-AK-CAZ-SC (3) 7,625.94 51.57 285.38 5,090.19 4,942.69 -1,744.75 -4,567.66 5,928,215.69 476,326.48 2.89 1,114.70 MWD+IFR-AK-CAZ-SC (3) 7,719.41 52.60 289.78 5,147.65 5,000.15 -1,722.47 -4,637.92 5,928,238.14 476,256.29 3.87 1,172.52 MWD+IFR-AK-CAZ-SC (3) 9/9/2016 9:34.00AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 Database: OAKEDM P2 Survey Map Map Vertical MI) Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting OLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,811.71 53.12 292.34 5,203.38 5,055.88 -1,696.03 -4,706.57 5,928,264.76 476,187.71 2.28 1,232.90 MWD+IFR-AK-CAZ-SC (3) 7,903.79 54.45 296.32 5,257.79 5,110.29 -1,665.41 -4,774.23 5,928,295.54 476,120.14 3.77 1,296.17 MWD+IFR-AK-CAZ-SC (3) 7,995.87 55.41 299.86 5,310.71 5,163.21 -1,629.92 -4,840.69 5,928,331.19 476,053.77 3.31 1,362.81 MWD+IFR-AK-CAZ-SC (3) 8,088.89 55.39 303.20 5,363.54 5,216.04 -1,589.89 -4,905.94 5,928,371.39 475,988.63 2.96 1,432.53 MWD+IFR-AK-CAZ-SC (3) 8,181.47 55.44 306.84 5,416.11 5,268.61 -1,546.17 -4,968.34 5,928,415.27 475,926.35 3.24 1,503.71 MWD+IFR-AK-CAZ-SC (3) 8,274.49 55.80 309.81 5,468.64 5,321.14 -1,498.56 -5,028.55 5,928,463.02 475,866.26 2.66 1,576.88 MWD+IFR-AK-CAZ-SC (3) 8,368.67 57.04 309.97 5,520.73 5,373.23 -1,448.24 -5,088.76 5,928,513.48 475,806.19 1.32 1,652.29 MWD+IFR-AK-CAZ-SC (3) 8,461.71 56.71 309.14 5,571.57 5,424.07 -1,398.62 -5,148.83 5,928,563.25 475,746.25 0.83 1,727.06 MWD+IFR-AK-CAZ-SC (3) 8,553.04 55.84 310.08 5,622.28 5,474.78 -1,350.20 -5,207.35 5,928,611.82 475,687.86 1.28 1,799.96 MWD+IFR-AK-CAZ-SC (3) 8,647.67 55.94 311.96 5,675.35 5,527.85 -1,298.78 -5,266.46 5,928,663.38 475,628.88 1.65 1,875.67 MWD+IFR-AK-CAZ-SC (3) 8,741.37 57.18 315.11 5,726.99 5,579.49 -1,244.92 -5,323.12 5,928,717.38 475,572.37 3.10 1,952.03 MWD+IFR-AK-CAZ-SC (3) 8,835.77 58.31 317.50 5,777.38 5,629.88 -1,187.20 -5,378.26 5,928,775.23 475,517.38 2.45 2,030.73 MWD+IFR-AK-CAZ-SC (3) 8,928.24 58.65 321.18 5,825.73 5,678.23 -1,127.42 -5,429.60 5,928,835.14 475,466.20 3.41 2,109.02 MWD+IFR-AK-CAZ-SC (3) 9,021.69 59.42 323.94 5,873.82 5,726.32 -1,063.80 -5,478.30 5,928,898.87 475,417.66 2.66 2,189.00 MWD+IFR-AK-CAZ-SC (3) 9,114.60 60.50 327.49 5,920.34 5,772.84 -997.35 -5,523.58 5,928,965.43 475,372.55 3.51 2,269.41 MWD+IFR-AK-CAZ-SC (3) 9,207.51 61.42 330.83 5,965.45 5,817.95 -927.62 -5,565.21 5,929,035.26 475,331.11 3.30 2,350.49 MWD+IFR-AK-CAZ-SC (3) 9,265.30 61.60 332.19 5,993.02 5,845.52 -882.98 -5,589.43 5,929,079.95 475,307.00 2.09 2,401.04 MWD+IFR-AK-CAZ-SC (3) 9,288.24 61.68 332.70 6,003.92 5,856.42 -865.08 -5,598.77 5,929,097.87 475,297.70 1.99 2,421.09 INC+TREND (4) 9,318.00 61.77 333.08 6,018.01 5,870.51 -841.75 -5,610.72 5,929,121.23 475,285.82 1.17 2,447.11 MWD+IFR-AK-CAZ-SC (5) 10 3/4" x 13-1/2" 9,338.00 61.83 333.34 6,027.47 5,879.97 -826.02 -5,618.66 5,929,136.98 475,277.92 1.17 2,464.59 MWD+IFR-AK-CAZ-SC (5) 9,399.61 61.71 338.01 6,056.62 5,909.12 -776.58 -5,641.01 5,929,186.48 475,255.69 6.68 2,518.07 MWD+IFR-AK-CAZ-SC (5) 9,441.73 62.23 340.89 6,076.42 5,928.92 -741.77 -5,654.06 5,929,221.32 475,242.74 6.16 2,554.21 MWD+IFR-AK-CAZ-SC (5) 9,536.34 64.93 344.27 6,118.52 5,971.02 -660.94 -5,679.39 5,929,302.20 475,217.61 4.29 2,635.35 MWD+IFR-AK-CAZ-SC (5) 9,628.18 66.40 347.72 6,156.37 6,008.87 -579.76 -5,699.62 5,929,383.42 475,197.59 3.78 2,713.92 MWD+IFR-AK-CAZ-SC (5) 9,720.92 69.66 349.31 6,191.07 6,043.57 -495.49 -5,716.73 5,929,467.73 475,180.70 3.86 2,793.30 MWD+IFR-AK-CAZ-SC (5) 9,814.38 72.21 349.35 6,221.59 6,074.09 -408.69 -5,733.08 5,929,554.56 475,164.56 2.73 2,874.35 MWD+IFR-AK-CAZ-SC (5) 9,906.40 74.94 350.60 6,247.61 6,100.11 -321.79 -5,748.44 5,929,641.50 475,149.43 3.24 2,954.94 MWD+IFR-AK-CAZ-SC (5) 9,929.00 76.05 349.23 6,253.27 6,105.77 -300.24 -5,752.27 5,929,663.04 475,145.65 7.66 2,974.93 INC+TREND (6) 7.3/8" x 8-7/8" 9,942.83 76.74 348.40 6,256.52 6,109.02 -287.06 -5,754.88 5,929,676.24 475,143.08 7.66 2,987.31 INC+TREND (6) 10,037.13 87.36 349.00 6,269.55 6,122.05 -195.60 -5,773.15 5,929,767.73 475,125.04 11.28 3,073.29 INC+TREND (6) 10,131.87 92.06 353.76 6,270.03 6,122.53 -101.99 -5,787.34 5,929,861.37 475,111.09 7.06 3,158.78 INC+TREND(6) 10,161.07 90.45 354.51 6,269.39 6,121.89 -72.95 -5,790.32 5,929,890.41 475,108.18 6.08 3,184.50 MWD+IFR-AK-CAZ-SC (7) 10,255.59 90.00 354,23 6,269.02 6,121.52 21.11 -5,799.59 5,929,984.49 475,099.15 0.56 3,267.60 MWD+IFR-AK-CAZ-SC (7) 10,351.16 88.84 354.20 6,269.98 6,122.48 116.19 -5,809.22 5,930,079.58 475,089.76 1.21 3,351.74 MWD+IFR-AK-CAZ-SC (7) 10,445.97 88.53 354.39 6,272.16 6,124.66 210.50 -5,818.65 5,930,173.91 475,080.57 0.38 3,435.14 MWD+IFR-AK-CAZ-SC (7) 10,540.98 89.46 354.41 6,273.82 6,126.32 305.05 -5,827.92 5,930,268.46 475,071.55 0.98 3,518.63 MWD+IFR-AK-CAZ-SC (7) 10,635.74 90.35 357.30 6,273.98 6,126.48 399.55 -5,834.76 5,930,362.97 475,064.94 3.19 3,600.74 MWD+IFR-AK-CAZ-SC (7) 10,700.70 90.69 357.59 6,273.39 6,125.89 464.44 -5,837.66 5,930,427.86 475,062.21 0.69 3,656.11 MWD+IFR-AK-CAZ-SC (7) 9/9/2018 9:34:OOAM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Repoli Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 25-13: 120+27.5 @ 147.50usft (Doyon 141) Site: Kuparuk 2S Pad MD Reference: 2S-13:120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 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) (9/1001) (ft) Survey Tool Name 10,731.14 90.84 0.12 6,272.99 6,125.49 494.87 -5,838.27 5,930,458.29 475,061.67 8.33 3,681.65 MWD+IFR-AK-CAZ-SC (7) 10,824.23 90.48 2.06 6,271.91 6,124.41 587.93 -5,836.50 5,930,551.34 475,063.68 2.12 3,757.73 MWD+IFR-AK-CAZ-SC (7) 10,919.63 90.62 3.55 6,271.00 6,123.50 683.21 -5,831.83 5,930,646.60 475,068.59 1.57 3,834.03 MWD+IFR-AK-CAZ-SC (7) 11,013.21 91.14 3.98 6,269.56 6,122.06 776.58 -5,825.69 5,930,739.94 475,074.97 0.72 3,907.91 MWD+IFR-AK-CAZ-SC (7) 11,109.04 91.07 4.87 6,267.71 6,120.21 872.10 -5,818.29 5,930,835.44 475,082.60 0.93 3,982.89 MWD+IFR-AK-CAZ-SC (7) 11,203.72 90.72 6.20 6,266.23 6,118.73 966.33 -5,809.16 5,930,929.63 475,091.97 1.45 4,055.81 MWD+IFR-AK-CAZ-SC (7) 11,298.73 90.14 6.77 6,265.52 6,118.02 1,060.72 -5,798.43 5,931,023.99 475,102.94 0.86 4,127.98 MWD+IFR-AK-CAZ-SC (7) 11,393.68 90.35 8.91 6,265.11 6,117.61 1,154.78 -5,785.48 5,931,118.00 475,116.13 2.26 4,198.62 MWD+IFR-AK-CAZ-SC (7) 11,487.91 90.24 9.64 6,264.63 6,117.13 1,247.78 -5,770.29 5,931,210.95 475,131.55 0.78 4,267.13 MWD+IFR-AK-CAZ-SC (7) 11,581.57 90.04 10.58 6,264.40 6,116.90 1,339.98 -5,753.85 5,931,303.10 475,148.22 1.03 4,334.28 MWD+IFR-AK-CAZ-SC (7) 11,677.85 89.83 10.96 6,264.51 6,117.01 1,434.57 -5,735.86 5,931,397.63 475,166.45 0.45 4,402.53 MWD+IFR-AK-CAZ-SC (7) 11,773.16 90.48 11.01 6,264.25 6,116.75 1,528.13 -5,717.70 5,931,491.14 475,184.84 0.68 4,469.85 MWD+IFR-AK. CAZ-SC (7) 11,866.04 90.86 12.26 6,263.17 6,115.67 1,619.09 -5,698.97 5,931,582.05 475,203.80 1.41 4,534.69 MWD+IFR-AK-CAZ-SC (7) 11,962.22 90.86 14.79 6,261.72 6,114.22 1,712.59 -5,676.48 5,931,675.48 475,226.53 2.63 4,599.52 MWD+IFR-AK-CAZ-SC (7) 12,056.22 91.10 15.80 6,260.11 6,112.61 1,803.24 -5,651.69 5,931,766.06 475,251.55 1.10 4,660.71 MWD+IFR-AK-CAZ-SC (7) 12,150.60 90.42 15.34 6,258.86 6,111.36 1,894.15 -5,626.36 5,931,856.89 475,277.10 0.87 4,721.80 MWD+IFR-AK-CAZ-SC (7) 12,244.02 89.90 14.92 6,258.60 6,111.10 1,984.33 -5,601.97 5,931,947.00 475,301.71 0.72 4,782.83 MWD+IFR-AK-CAZ-SC (7) 12,339.56 90.52 15.91 6,258.25 6,110.75 2,076.43 -5,576.58 5,932,039.03 475,327.34 1.22 4,844.88 MWD+IFR-AK-CAZ-SC (7) 12,434.41 91.07 16.78 6,256.94 6,109.44 2,167.44 -5,549.89 5,932,129.96 475,354.26 1.09 4,905.29 MWD+IFR-AK-CAZ-SC (7) 12,529.38 90.52 18.61 6,255.62 6,108.12 2,257.90 -5,521.03 5,932,220.34 475,383.34 2.01 4,964.04 MWD+IFR-AK-CAZ-SC (7) 12,624.72 91.07 18.82 6,254.29 6,106.79 2,348.19 -5,490.44 5,932,310.54 475,414.16 0.62 5,021.68 MWD+IFR-AK-CAZ-SC (7) 12,719.84 91.55 17.49 6,252.12 6,104.62 2,438.55 -5,460.81 5,932,400.82 475,444.01 1.49 5,079.91 MWD+IFR-AK-CAZ-SC (7) 12,813.56 91.34 18.34 6,249.76 6,102.26 2,527.70 -5,431.99 5,932,489.88 475,473.05 0.93 5,137.60 MWD+IFR-AK-CAZ-SC (7) 12,907.48 91.44 17.25 6,247.48 6,099.98 2,617.10 -5,403.30 5,932,579.20 475,501.97 1.17 5,195.56 MWD+IFR-AK-CAZ-SC (7) 13,003.04 91.55 15.76 6,244.98 6,097.48 2,708.68 -5,376.16 5,932,670.71 475,529.34 1.56 5,256.21 MWD+IFR-AK-CAZ-SC (7) 13,096.21 91.48 14.64 6,242.52 6,095.02 2,798.56 -5,351.74 5,932,760.52 475,553.98 1.20 5,316.96 MWD+IFR-AK-CAZ-SC (7) 13,191.72 90.89 14.47 6,240.55 6,093.05 2,890.99 -5,327.74 5,932,852.87 475,578.21 0.64 5,380.06 MWD+IFR-AK-CAZ-SC (7) 13,286.00 91.00 13.72 6,238.99 6,091.49 2,982.42 -5,304.79 5,932,944.23 475,601.40 0.80 5,442.92 MWD+IFR-AK-CAZ-SC (7) 13,379.04 90.86 11.12 6,237.48 6,089.98 3,073.26 -5,284.78 5,933,035.02 475,621.63 2.80 5,506.94 MWD+IFR-AK-CAZ-SC (7) 13,475.45 91.55 10.15 6,235.45 6,087.95 3,167.99 -5,266.99 5,933,129.69 475,639.66 1.23 5,575.43 MWD+IFR-AK-CAZ-SC (7) 13,569.02 91.72 8.48 6,232.78 6,085.28 3,260.28 -5,251.85 5,933,221.94 475,655.03 1.79 5,643.39 MWD+IFR-AK-CAZ-SC (7) 13,662.82 91.48 8.11 6,230.16 6,082.66 3,353.07 -5,238.32 5,933,314.68 475,668.79 0.47 5,712.65 MWD+IFR-AK-CAZ-SC (7) 13,757.69 92.58 6.51 6,226.80 6,079.30 3,447.10 -5,226.26 5,933,408.67 475,681.09 2.05 5,783.77 MWD+IFR-AK-CAZ-SC (7) 13,852.49 92.52 7.30 6,222.59 6,075.09 3,541.12 -5,214.88 5,933,502.65 475,692.71 0.83 5,855.26 MWD+IFR-AK-CAZ-SC (7) 13,947.88 90.83 7.50 6,219.80 6,072.30 3,635.67 -5,202.59 5,933,597.16 475,705.23 1.78 5,926.69 MWD+IFR-AK-CAZ-SC (7) 14,042.34 90.00 7.47 6,219.11 6,071.61 3,729.32 -5,190.29 5,933,690.78 475,717.77 0.88 5,997.36 MWD+IFR-AK-CAZ-SC (7) 14,136.63 88.32 9.07 6,220.50 6,073.00 3,822.62 -5,176.73 5,933,784.02 475,731.57 2.46 6,067.03 MWD+IFR-AK-CAZ-SC (7) 14,231.28 85.61 11.73 6,225.51 6,078.01 3,915.57 -5,159.67 5,933,876.92 475,748.86 4.01 6,134.45 MWD+IFR-AK-CAZ-SC (7) 14,326.47 82.79 15.04 6,235.13 6,087.63 4,007.67 -5,137.76 5,933,968.96 475,771.00 4.55 6,198.46 MWD+IFR-AK-CAZ-SC (7) 14,421.97 84.65 17.28 6,245.58 6,098.08 4,098.84 -5,111.34 5,934,060.05 475,797.65 3.04 6,259.16 MWD+IFR-AK-CAZ-SC (7) 9/9/2016 9:34:00AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 25-13 Project: Kuparuk River Unit TVD Reference: 2S-13:120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 25-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 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 14,515.58 86.61 20.50 6,252.71 6,105.21 4,187.13 -5,081.13 5,934,148.26 475,828.08 4.02 6,315.35 MWD+IFR-AK-CAZ-SC (7) 14,610.34 87.98 20.34 6,257.18 6,109.68 4,275.84 -5,048.10 5,934,236.87 475,861.33 1.46 6,370.31 MWD+IFR-AK-CAZ-SC (7) 14,704.49 89.15 19.91 6,259.54 6,112.04 4,364.21 -5,015.72 5,934,325.15 475,893.93 1.32 6,425.35 MWD+IFR-AK-CAZ-SC (7) 14,799.41 89.41 19.22 6,260.73 6,113.23 4,453.64 -4,983.94 5,934,414.50 475,925.94 0.78 6,481.61 MWD+IFR-AK-CAZ-SC (7) 14,895.32 91.25 18.38 6,260.18 6,112.68 4,544.43 -4,953.03 5,934,505.20 475,957.07 2.11 6,539.48 MWD+IFR-AK-CAZSC (7) 14,989.43 91.31 18.21 6,258.08 6,110.58 4,633.76 -4,923.49 5,934,594.44 475,986.83 0.19 6,596.92 MWD+IFR-AK-CAZ-SC (7) 15,083.19 91.41 17.67 6,255.85 6,108.35 4,722.94 -4,894.62 5,934,683.54 476,015.92 0.59 6,654.59 MWD+IFR-AK-CAZ-SC (7) 15,179.49 91.48 17.08 6,253.42 6,105.92 4,814.81 -4,865.87 5,934,775.33 476,044.90 0.62 6,714.58 MWD+IFR-AK-CAZ-SC (7) 15,274.31 91.44 16.03 6,251.01 6,103.51 4,905.67 -4,838.87 5,934,866.11 476,072.14 1.11 6,774.69 MWD+IFR-AK-CAZ-SC (7) 15,367.68 91.51 15.84 6,248.61 6,101.11 4,995.42 4,813.24 5,934,955.79 476,097.99 0.22 6,834.66 MWD+IFR-AK-CAZ-SC (7) 15,462.72 91.58 15.61 6,246.04 6,098.54 5,086.87 -4,787.49 5,935,047.16 476,123.96 0.25 6,895.98 MWD+IFR-AK-CAZ-SC (7) 15,558.50 91.96 15.61 6,243.08 6,095.58 5,179.08 -4,761.73 5,935,139.29 476,149.96 0.40 6,957.90 MWD+IFR-AK-CAZ-SC (7) 15,653.21 91.48 15.24 6,240.24 6,092.74 5,270.33 4,736.55 5,935,230.48 476,175.36 0.64 7,019.37 MWD+IFR-AK-CAZ-SC (7) 15,749.41 91.07 15.44 6,238.10 6,090.60 5,363.08 4,711.11 5,935,323.15 476,201.04 0.47 7,081.93 MWD+IFR-AK-CAZ-SC (7) 15,844.81 91.75 15.94 6,235.75 6,088.25 5,454.90 4,685.32 5,935,414.89 476,227.06 0.88 7,143.52 MWD+IFR-AK-CAZ-SC (7) 15,938.66 92.06 16.67 6,232.63 6,085.13 5,544.92 -4,658.98 5,935,504.84 476,253.62 0.84 7,203.33 MWD+IFR-AK-CAZ-SC (7) 16,031.05 92.51 16.66 6,228.95 6,081.45 5,633.36 4,632.51 5,935,593.21 476,280.31 0.49 7,261.74 MWD+IFR-AK-CAZ-SC (7) 16,123.74 92.10 18.02 6,225.22 6,077.72 5,721.77 -4,604.91 5,935,681.53 476,308.14 1.53 7,319.49 MWD+IFR-AK-CAZ-SC (7) 16,220.59 91.34 19.37 6,222.31 6,074.81 5,813.46 4,573.88 5,935,773.14 476,339.39 1.60 7,378.04 MWD+IFR-AK-CAZ-SC (7) 16,316.73 91.00 20.77 6,220.35 6,072.85 5,903.74 -4,540.89 5,935,863.33 476,372.60 1.50 7,434.33 MWD+IFR-AK-CAZ-SC (7) 16,410.44 91.17 21.14 6,218.58 6,071.08 5,991.24 4,507.39 5,935,950.73 476,406.33 0.43 7,488.02 MWD+IFR-AK-CAZ-SC (7) 16,505.92 91.00 21.15 6,216.77 6,069.27 6,080.27 4,472.95 5,936,039.67 476,440.99 0.18 7,542.46 MWD+IFR-AK-CAZ-SC (7) 16,599.43 91.34 21.04 6,214.86 6,067.36 6,167.50 4,439.30 5,936,126.80 476,474.85 0.38 7,595.84 MWD+IFR-AK-CAZ-SC (7) 16,694.27 91.96 21.19 6,212.13 6,064.63 6,255.93 -4,405.15 5,936,215.14 476,509.22 0.67 7,649.95 MWD+IFR-AK-CAZSC (7) 16,785.89 92.34 21.77 6,208.69 6,061.19 6,341.13 4,371.63 5,936,300.24 476,542.96 0.76 7,701.72 MWD+IFR-AK-CAZ-SC (7) 16,867.00 92.34 21.77 6,205.38 6,057.88 6,416.39 4,341.57 5,936,375.42 476,573.21 0.00 7,747.21 PROJECTED to TD 6-3/4" open hole 9MO16 9:34:OOAM Page 7 COMPASS 5000.1 Build 74 Cement Detail Report 2S-13 String: Conductor Cement Job: DRILLING ORIGINAL, 11/28/201512:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 10/13/2015 09:45 10/13/2015 15:00 2S-13 Comment CH2MHi11 drilled 42" hole to 80' below ground level, set 20" 78.67# APISL Grade B Insulated Conductor. SLB cemented in two stages with 59.8bbl 15.7ppg Arctic Set 1 cement. Sealed Pan Cellar is 5' deep, 6' wide. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... I Top Plug? Btm Plug? Conductor Cement Tack conductor in place i 85.0 107.5 No I 0.01 No No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) I I RotateTT Pipe RPM (rpm) 2 2 2 86.0 1 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 10.3 bbl Arctic Set 1 Cement slurry at 15.7ppg, 70°F slurry temp, 18°F ambient temp, 60°F water temp. CIP @ 10:15 Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Conductor cement 80.0 120.0 60 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 15.70 Additives Additive Type Concentration Conc Unit label Stage # 2 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement Cement to surface 27.5 85.0 No No No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No I I No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 48.5 bbl Arctic Set 1 Cement slurry at 15.7ppg, 70°F slurry temp, 18°F ambient temp, 60°F water temp. Cement in place at 15:00 hrs. TOTAL 59.8bb1 pumped Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Conductor cement O. 80.0 120 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 15.70 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/23/2017 Cement Detail Report 2S-13 qr■■' String: Surface Casing Cement Job: DRILLING ORIGINAL, 11/28/201512:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 12/3/2015 10:15 12/3/2015 15:45 2S-13 Comment Pump 5 bbls of fresh water & PT lines to 3500 psi. Pump 20 bbls 8.3 ppg CW -100 , 4 bpm, 150 psi. Pump 100 bbls of 10.5 ppg MPII w/ red dye at 3.5 bpm, 150 psi. Drop bottom plug & pump 496.5 bbls of 11.0 ppg Lead Cement at 6.5 bpm, 350 psi. Pump 79 bbls of 12.0 ppg Tail Cement at 6 bpm, 450 psi. Drop top plug & kick out with 10 bbls of fresh H2O at 5 bpm, 160 psi. Swap to rig & displace cement with 10.1 ppg mud at 5.5 bpm, 700 psi. Bump plug w/ 3998 stks, pressure up to 1200 psi & hold for 5 min. Check floats, Floats not holding. Shut in and hold 100 psi. CIP at 15:45 hrs. Total of 282 bbls of cement returns to surface. Flow line packed off at 156 bbls of displacement. Take returns to cellar Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 1 29.9 2,850.0 Yes 282.0 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) 6 5 6 700.0 1,200.0 Yes 1 10.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 5 bbls of fresh water & PT lines to 3500 psi. Pump 20 bbls 8.3 ppg CW -100 , 4 bpm, 150 psi. Pump 100 bbls of 10.5 ppg MPII w/ red dye at 3.5 bpm, 150 psi. Drop bottom plug & pump 496.5 bbls of 11.0 ppg Lead Cement at 6.5 bpm, 350 psi. Pump 79 bbls of 12.0 ppg Tail Cement at 6 bpm, 450 psi. Drop top plug & kick out with 10 bbls of fresh H2O at 5 bpm, 160 psi. Swap to rig & displace cement with 10.1 ppg mud at 5.5 bpm, 700 psi. Bump plug w/ 3998 stks, pressure up to 1200 psi & hold for 5 min. Check floats, Floats not holding. Shut in and hold 100 psi. CIP at 15:45 hrs. Total of 282 bbls of cement returns to surface. Flow line packed off at 156 bbls of displacement. Take returns to cellar Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 29.9 1,954.0 1,460 LiteCRETE 496.5 Yield (ffl/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.75 11.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,954.0 2,850.0 278 LiteCRETE 79.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.67 5.01 12.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 BWOB Additive Type Concentration Conc Unit label Dispersant D185 0.06 gal/sx Additive Type Concentration Conc Unit label Acelerator (Calcium Chloride) D186 0.1 gal/sx Additive Type Concentration Conc Unit label Gas Block D500 0.75 gal/sx Page 1/1 Report Printed: 1/23/2017 Cement Detail Report 2S-13 String: Liner Cement Job: DRILLING ORIGINAL, 11/28/201512:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Liner Cement 12/13/2015 12:00 12/13/2015 16:20 2S-13 Comment PJSM for cementing 10.75' liner. Pump 5 bbls of CW -100 & PT lines to 400/4000 psi for 5 min. Pump 35 bbls of CW -100 @ 4 bpm, 500 psi. Batch up mud push. Pump 40 bbls of 11.5 ppg MPII @ 5 bpm, 450 psi. Batch up cement. Pump 320 bbls of 15.8 ppg cement @ 5.5 bpm, 300 psi. Kick out top plug with 10 bbls of H2O. Swap to rig pumping 10.0 ppg mud to displace. Pump 21 bbls to @ 6 bpm = 140 psi, slow to 3 bpm = 75 psi, observe latch up with pressure increase to 650 psi. Continue pumping 6.5 bpm = 400 psi. Observe cement lift with pressure increasing to 1640 psi. Started seeing losses @ 555 bbls into displacement observed losses. Slowed pump to 3 bpm = 1100 psi. Bump the plug with 641 bbls, pressure up to 1700 psi. Hold pressure for 5 min & bleed off. Floats good. CIP @ 16:20 hrs. Cement Stages Stage # 1 Description Objective Top Depth (ftK6) Bottom Depth (ftK6) Full Return? Vol Cement... Top Plug? Btm Plug? Liner Cement 1 1 5,840.0 9,329.0 No Yes No 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) 5 3 6 1,100.0 1,700.0 No No Tagged Depth (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 5,840.0 9,329.0 1,535 G 320.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.17 3.25 15.80 5.60 Additives Additive Type Concentration Cone Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Cone Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Cone Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Acelerator (Calcium Chloride) ID186 0.15 gal/sx Additive Type Concentration Cone Unit label Gas Block D60OG 1.6 gal/sx Page 1/1 Report Printed: 1 /2 312 01 7 Cement Detail Report 2S-13 String: Cement Plug - Abandon 2S-13 PB1 Job: DRILLING ORIGINAL, 11/28/201512:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug - Abandon 2S-13 PB1 12/17/2015 18:15 12/17/2015 19:30 2S-13 Comment Batch up & pump 5 bbls of 13.0 ppg MPII to flood lines. PT lines 400 / 4000 psi. Pump 25 bbls of 13.0 ppg MPII @ 3.4 bpm, 460 psi. Load wiper ball in pipe & batch up cement. Pump 70 bbls of 15.8 ppg cement w/ 1.5 ppb CemNet @ 4.4 bpm, 430-100 psi. Pump 5.3 bbls of 13.7 MPII @ 3.5 bpm, 30 psi. Swap to rig & displace with 156 bbls of 11.9 ppg mud @ 4.5 bpm, 125-780 psi. CIP 19:28 hrs. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? I Btm Plug? Cement Plug 1 9,710.0 10,303.0 No No Yes Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? 1 Stroke (ft) Rotated? I Pipe RPM (rpm) 5 5 5 780.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Plug back Intermediate #2 pilot hole. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Plug Back Cement 9,710.0 10,303.0 338 G 70.0 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.08 15.80 94.3 6.20 Additives Additive Type Concentration Cone Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Cone Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Cone Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Cone Unit label Retarder ID177 0.015 gal/sx Page 111 Report Printed: 1/23/2017 Cement Detail Report 2S-13 String: Cement Plug - Kickoff for 2S-13 intrm s... Job: DRILLING ORIGINAL, 11/28/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug - Kickoff for 2S-13 intrm section 12/17/2015 23:30 12/18/2015 00:40 2S-13 Comment Pump 31 bbls 13.0 ppg MPII @ 4.4 bpm, 575 psi. Shut down to batch up cement, load wiper ball in pipe. Pump 66 bbls of 17.0 ppg cement w/ 1.5 ppb CemNet @ 4 bpm, 475-40 psi. Pump 7 bbls of 13.0 ppg MPII @ 3 bpm, 10 psi. Swap to rig to displace 143 bbls with 11.9 ppg mud @ 4.5 bpm, 120-800 psi. CIP @ 00:40 hrs. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Plug 9,117.0 9,710.0 No No 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) 4 5 5 800.0 1 No I No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 9,131.0 Drill Bit 9,710.0 97/8 Comment KOP for intermediate # 2. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Plug Back Cement 9,117.0 9,710.0 371 G 66.0 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.00 3.86 17.00 175.0 7.40 Additives Additive Type Concentration Cone Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Cone Unit label Dispersant D065 0.9 %BWOC Additive Type Concentration Cone Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Cone Unit label Retarder ID177 1 0.015 gal/sx Page 1/1 Report Printed: 1/23/2017 Cement Detail Report y ?'- 2S-13 String: Intermediate #3 Casing Cement Job: DRILLING ORIGINAL, 11/28/201512:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate #3 Casing Cement 12/27/2015 03:00 12/27/2015 07:30 2S-13 Comment PJSM; line up to cementers & pump 5 bbis of CW -100. Pressure test lines 500 / 3500 psi for 5 min. Pump 5 bbis of CW -100, 3 bpm, 540 psi. Pump 40 bbis of 12.5 ppg MPII at 3 bpm, 540 psi. Load wiper plug in pipe. Pump 72 bbis of 15.8 ppg cement slurry w/ 2 Ib/bbl CemNet at3 bpm, 275 psi. Load shut off plug in pipe. Pump 10 bbis of H2O. Swap to rig & displace with 460 bbis of 11.8+ ppg mud at 3 bpm, 250-600 psi. Bump plug & pressure up to 1200 psi & hold for 5 min. CIP 07:30 hrs. While chasing the plug with the rig pump the pits received an average of 50% returns from 0 to 420 bbis away. Returns steadily increased the last 40 bbis and full returns were achieved the last 20 bbis as the cement came up the annulus. 400 psi lift pressure was observed. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? IntermediateCasing 9,167.0 10,444.0 No Yes Yes Cement Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbi/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 3 3 3 600.0 1,200.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment PJSM; line up to cementers & pump 5 bbis of CW -100. Pressure test lines 500 / 3500 psi for 5 min. Pump 5 bbis of CW -100, 3 bpm, 540 psi. Pump 40 bbls of 12.5 ppg MPII at 3 bpm, 540 psi. Load wiper plug in pipe. Pump 72 bbis of 15.8 ppg cement slurry w/ 2 Ib/bbl CemNet at3 bpm, 275 psi. Load shut off plug in pipe. Pump 10 bbls of H2O. Swap to rig & displace with 460 bbls of 11.8+ ppg mud at 3 bpm, 250-600 psi. Bump plug & pressure up to 1200 psi & hold for 5 min. CIP 07:30 hrs. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 9,167.0 10,444.0 348 G 72.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.09 15.80 97.6 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder ID177 0.02 gal/sx Page 1/1 Report Printed: 1/23/2017 z r 3 Cement Detail Report =` 2S-13 String: Abandonment Cement Plug Job: DRILLING SIDETRACK, 10/28/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Abandonment Cement Plug 11/2/2016 06:45 11/2/2016 08:00 2S-131-1 Comment SLB pump 2 bbls 12.5 ppg mudpush. Shut in and pressure test cement lines to 4000 psi - good test. Continue pumping 8 bbls 12.5 ppg mudpush at 2.5 bpm, 1308 psi, 21.7 bbls 15.8ppg cement at 2.8 bpm, 1217 psi, and 3.1 bbis 12.5 ppg mudpush at 2.2 bpm, 994 psi. Clear lines to rig floor with 1.5 bbls water. Swap over to rig and pump 65.2 bbls at 3.5 bpm, 1470 psi. Hold 800 psi backpressure with rig choke throughout job. Strip down and sting into retainer. Bleed off IA pressure and open annular - monitor for leaks throughout job. Pump 27.8 bbls w/ rig at 3 bpm, ICP 955 psi, FCP 1177 psi, squeezing total of 16.8 bbls of 15.8ppg Cement below cement retainer. Sting out of retainer, lay out single, and POOH 2 x stands at 1000 ft/hr to 9609'. Left 4.9 bbls of 15.8ppg cement in hole above retainer. Estimated TOC @ 9704'. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Abandonment Cement Isolate formation and 9,704.0 10,186.0 No 0.0 No No Plug abandon laterals 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 3 3 1,177.0 11 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Squeezed 16.8 bbls cement below retainer and left 4.9 bbls above. 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 (%) Density (Ib/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: 1/23/2017 Cement Detail Report 2S-13 String: Abandonment Cement Plug Job: DRILLING SIDETRACK, 10/28/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Abandonment Cement Plug 11/2/2016 06:45 11/2/2016 08:00 2S-131-1 Comment SLB pump 2 bbls 12.5 ppg mudpush. Shut in and pressure test cement lines to 4000 psi - good test. Continue pumping 8 bbis 12.5 ppg mudpush at 2.5 bpm, 1308 psi, 21.7 bbls 15.8ppg cement at 2.8 bpm, 1217 psi, and 3.1 bbls 12.5 ppg mudpush at 2.2 bpm, 994 psi. Clear lines to rig floor with 1.5 bbls water. Swap over to rig and pump 65.2 bbls at 3.5 bpm, 1470 psi. Hold 800 psi backpressure with rig choke throughout job. Strip down and sting into retainer. Bleed off IA pressure and open annular - monitor for leaks throughout job. Pump 27.8 bbls w/ rig at 3 bpm, ICP 955 psi, FCP 1177 psi, squeezing total of 16.8 bbls of 15.8ppg Cement below cement retainer. Sting out of retainer, lay out single, and POOH 2 x stands at 1000 ft/hr to 9609'. Left 4.9 bbis of 15.8ppg cement in hole above retainer. Estimated TOC @ 9704'. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Abandonment Cement Isolate formation and 9,704.0 10,186.0 No 0.0 No No Plug abandon laterals bl/m. Q Pump Init (b.. Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 2 3 3 1,177.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Squeezed 16.8 bbls cement below retainer and left 4.9 bbls above. 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 (%) Density (Ib/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: 1/23/2017 4. Cement Detail Report 2S-13 String: 7 5/8 Liner Job: DRILLING SIDETRACK, 10/28/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 7 5/8 Liner 11/14/2016 11:30 11/14/2016 13:00 2S-131-1 Comment Schlumberger pumped 5 Bbls water. Tested lines to 4000 psi. Batched up and pumped 40 Bbls of 12.5 PPG Mudpush Followed by 97.6 Bbls Class G cement 15.8 PPG with 1.5 PPG Simnet. 4.4 to 6 BPM. Dart launch confirmed for both Darts. Pumped 10 Bbls Water and displaced 2019 Stks with rig pump @ 5 BPM slowing to 3 BPM for last 32 Bbls. Bumped plug with 838 psi held for 5 min. CIP 1304 Hrs. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug. Btm Plug? 7 5/8 Liner Cement Liner 8,687.0 10,403.0 Yes 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) 6 3 5 838.0 1,196.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Schlumberger pumped 5 Bbls water. Tested lines to 4000 psi. Batched up and pumped 40 Bbls of 12.5 PPG Mudpush Followed by 97.6 Bbls Class G cement 15.8 PPG with 1.5 PPG Simnet. 4.4 to 6 BPM. Dart launch confirmed for both Darts. Pumped 10 Bbls Water and displaced 2019 Stks with rig pump @ 5 BPM slowing to 3 BPM for last 32 Bbls. Bumped plug with 838 psi held for 5 min. CIP 1304 Hrs. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 8,687.0 10,403.0 G 92.6 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (°/) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.17 5.10 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/23/2017 215152 2(0b4LA E9 Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer: Conoco Phillips Alaska Dispatched To: Well No: 2S-13/L1/PB1 Date Dispatched: Job#: 14AKA0060 Dispatched By: Transmittal #: 13SEP16-SP01 DATA LOGGED °l *W201Cw M.K BENDER AOGCC: Makana Bender 13 -Sep -16 Stephanie Pacillo Well / Product Description Hardcopy Digital Copy E -Delivery Date CD 1 Contents on CD N/A 2S-13 Data: DLIS / ASCII Graphics_: pdf Surveys: pdf / txt ***REVISED*** _ x x x CD 1 Contents on CD N/A 2S -13L1 Data: DLIS/ASCII Graphics: pdf x - x Surveys: pdf/txt ***REVISED*** x CD 1 Contents on CD N/A 2S-13PB1 Data: HIS /ASCII x x x Graphics: pdf Surveys: pdf / txt ***REVISED*** Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(aD-conocophiIIiPs. com Al askaPTSPrintCenterCcDsIb.com Tom Osterkamp Attn: Stephanie Pacillo 907-263-4795 Received By: ...� C•w 2 1 5152 Z -G 6qq REVISED 1:27 pm, Sep 12, 2016 NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S -13L1 Definitive Survey Report 09 September, 2016 NAD 27 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 25-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 25-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S -13L1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 Database: OAKE DM P2 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 25-13 201.50 Map Map From Well Position +N/ -S 0.00 usft Northing: 5,929,948.70 usft Latitude: 70° 13'11.187 N Tool Name +E/ -W 0.00 usft Easting: 480,898.09 usft Longitude: 150° 9' 14.767 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 120.00 usft 11/30/2015 10:21 2,868.21 9,265.50 2S-13PB1 Srvy #3 - SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/6/2015 8:33: Wellbore 2S-131-1 INC+TREND Inclinometer + known azi trend 12/15/2015 9:3E 9,338.00 Magnetics Model Name Sample Date Declination Dip Angle Field Strength INC+TREND Inclinometer+ known azi trend 1/16/2016 8:47: V) (1) (nT) MWD+IFR AK CAZ SCC BGGM2015 12/15/2015 18.44 80.86 57,486 -4.84 5,929,933.84 480,893.21 0.83 -9.60 Design 2S-131-1 Audit Notes: Version: 1.0 Vertical Section: Phase: Depth From (TVD) (usft) 27 50 ACTUAL Tie On Depth: 9,906.60 +N/ -S +E/ -W Direction (usft) (usft) C) 0.00 0 00 325.92 Survey Program Date 201.50 Map Map From To MD Inc Azi TVD TVDSS (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 82.68 1,283.58 2S-13PB1 Srvy #1 - SLB_NSG+Battery+ GYD-GC-SS Gyrodata gyro single shots 11/30/2015 10:2; 1,304.79 2,775.54 2S-13PB1 Srvy #2 - SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/30/2015 10:21 2,868.21 9,265.50 2S-13PB1 Srvy #3 - SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/6/2015 8:33: 9,288.24 9,288.24 2S-13PB1 Srvy #4 - SLB_Inc+Filler (25-1 INC+TREND Inclinometer + known azi trend 12/15/2015 9:3E 9,338.00 9,906.60 2S-13 Srvy #1 - SLB_MWD+GMAG (2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/20/2015 11:31 9,942.83 10,132.07 25-131-1 Srvy #1 - SLB -Inc -Filler (2S -13L INC+TREND Inclinometer+ known azi trend 1/16/2016 8:47: 10,161.27 16,785.89 2S-131-1 Srvy #2 - SLB_MWD+GMAG (2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/18/2016 8:57: Survey 107.50 0.04 238.86 107.50 -40.00 0.00 -0.03 5,929,948.70 480,898.06 0.11 0.02 NOT an Actual Survey 20" x 42" 174.86 0.10 201.50 Map Map -0.06 Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,948.70 480,898.09 0.00 0.00 UNDEFINED 82.68 0.03 287.05 82.68 -64.82 000 -0.01 5,929,948.70 480,898.08 0.05 0.01 GYD-GC-SS (1) 107.50 0.04 238.86 107.50 -40.00 0.00 -0.03 5,929,948.70 480,898.06 0.11 0.02 NOT an Actual Survey 20" x 42" 174.86 0.10 201.50 174.86 27.36 -0.06 -0.07 5,929,948.64 480,898.02 0.11 -0.02 GYU-13D-55(1) 266.90 0.54 204.98 266.90 119.40 -0.53 -0.28 5,929,948.17 480,897.81 0.48 -0.28 GYD-GC-SS (1) 358.92 2.63 196.47 358.88 211.38 -2.95 -1.06 5,929,945.75 480,897.02 2.28 -1.85 GYD-GC-SS (1) 450.55 4.08 197.58 450.35 302.85 -8.07 -2.64 5,929,940.63 480,895.43 1.58 -5.21 GYD-GC-SS (1) 542.44 4.84 198.23 541.96 394.46 -14.87 -4.84 5,929,933.84 480,893.21 0.83 -9.60 GYD-GC-SS (1) 9/9/2016 9:34:OOAM Page 2 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 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 634.35 5.99 202.27 633.46 485.96 -22.99 -7.87 5,929,925.73 480,890.16 1.32 -14.63 GYD-GC-SS(1) 726.00 6.53 203.78 724.56 577.06 -32.19 -11.79 5,929,916.55 480,886.22 0.62 -20.05 GYD-GC-SS (1) 817.94 8.48 201.86 815.71 668.21 -43.26 -16.42 5,929,905.48 480,881.56 2.14 -26.63 GYD-GC-SS(1) 910.56 9.80 205.54 907.15 759.65 -56.71 -22.36 5,929,892.05 480,875.59 1.56 -34.44 GYD-GC-SS(1) 1,003.86 11.08 208.23 998.91 851.41 -71.78 -30.02 5,929,877.01 480,867.89 1.47 -42.62 GYD-GC-SS(1) 1,096.09 12.93 209.29 1,089.12 941.62 -88.59 -39.27 5,929,860.22 480,858.60 2.02 -51.37 GYD-GC-SS (1) 1,188.56 15.38 208.11 1,178.77 1,031.27 -108.43 -50.11 5,929,840.41 480,847.72 2.67 -61.72 GYD-GC-SS(1) 1,283.58 19.22 206.89 1,269.48 1,121.98 -133.50 -63.12 5,929,815.37 480,834.64 4.06 -75.20 GYD-GC-SS(1) 1,304.79 20.60 207.96 1,289.42 1,141.92 -139.91 -66.45 5,929,808.97 480,831.29 6.73 -78.64 MWD+IFR-AK-CAZ-SC (2) 1,396.67 21.80 208.96 1,375.08 1,227.58 -169.12 -82.29 5,929,779.81 480,815.38 1.36 -93.95 MWD+IFR-AK-CAZ-SC (2) 1,491.21 25.56 213.09 1,461.65 1,314.15 -201.58 -101.93 5,929,747.40 480,795.66 4.34 -109.63 MWD+IFR-AK-CAZ-SC (2) 1,585.16 27.45 217.68 1,545.73 1,398.23 -235.70 -126.24 5,929,713.34 480,771.27 2.97 -124.47 MWD+IFR-AK-CAZ-SC (2) 1,677.93 29.30 221.23 1,627.36 1,479.86 -269.70 -154.27 5,929,679.41 480,743.15 2.70 -136.92 MWD+IFR-AK-CAZ-SC (2) 1,771.75 30.21 225.91 1,708.82 1,561.32 -303.40 -186.36 5,929,645.81 480,710.98 2.66 -146.84 MWD+IFR-AK-CAZ-SC (2) 1,863.74 31.06 226.45 1,787.97 1,640.47 -335.85 -220.19 5,929,613.44 480,677.08 0.97 -154.76 MWD+IFR-AK-CAZ-SC (2) 1,956.72 32.83 229.72 1,866.87 1,719.37 -368.68 -256.80 5,929,580.71 480,640.38 2.66 -161.43 MWD+IFR-AK-CAZ-SC (2) 2,050.37 33.68 233.62 1,945.19 1,797.69 -400.50 -297.08 5,929,549.00 480,600.02 2.46 -165.21 MWD+IFR-AK-CAZ-SC (2) 2,143.17 34.26 235.37 2,022.15 1,874.65 -430.60 -339.29 5,929,519.00 480,557.74 1.23 -166.49 MWD+IFR-AK-CAZ-SC (2) 2,237.57 35.48 238.69 2,099.61 1,952.11 -459.94 -384.57 5,929,489.78 480,512.40 2.39 -165.42 MWD+IFR-AK-CAZ-SC (2) 2,330.47 38.90 240.04 2,173.61 2,026.11 -488.53 -432.89 5,929,461.32 480,464.01 3.78 -162.02 MWD+IFR-AK-CAZ-SC (2) 2,423.89 39.45 242.06 2,246.03 2,098.53 -517.09 -484.53 5,929,432.89 480,412.31 1.49 -156.73 MWD+IFR-AK-CAZ-SC (2) 2,515.04 40.79 245.52 2,315.74 2,168.24 -543.00 -537.21 5,929,407.12 480,359.56 2.85 -148.66 MWD+IFR-AK-CAZ-SC (2) 2,609.16 42.70 247.70 2,385.97 2,238.47 -567.85 -594.73 5,929,382.41 480,301.98 2.55 -137.01 MWD+IFR-AK-CAZ-SC (2) 2,701.86 43.56 247.40 2,453.62 2,306.12 -592.05 -653.30 5,929,358.36 480,243.36 0.95 -124.24 MWD+IFR-AK-CAZ-SC (2) 2,775.54 45.32 247.46 2,506.22 2,358.72 -611.85 -700.94 5,929,338.69 480,195.68 2.39 -113.94 MWD+IFR-AK-CAZ-SC (2) 2,835.00 46.00 247.45 2,547.78 2,400.28 -628.16 -740.21 5,929,322.48 480,156.37 1.14 -105.43 NOT an Actual Survey H 1 / 2,868.01 46.37 247.44 2,570.64 2,423.14 -637.29 -762.21 5,929,313.40 480,134.35 1.14 -100.67 MWD+IFR-AK-CAZ-SC (3) 2,961.88 45.93 246.36 2,635.67 2,488.17 -663.85 -824.47 5,929,287.01 480,072.02 0.95 -87.77 MWD+IFR-AK-CAZ-SC (3) 3,053.24 45.12 245.87 2,699.67 2,552.17 -690.24 -884.08 5,929,260.77 480,012.35 0.97 -76.23 MWD+IFR-AK-CAZ-SC (3) 3,145.12 45.68 246.79 2,764.19 2,616.69 -716.50 -944.00 5,929,234.66 479,952.38 0.94 -64.40 MWD+IFR-AK-CAZ-SC (3) 3,237.98 47.31 247.54 2,828.11 2,680.61 -742.63 -1,006.07 5,929,208.69 479,890.24 1.85 -51.26 MWD+IFR-AK-CAZ-SC (3) 3,332.72 50.46 248.03 2,890.40 2,742.90 -769.61 -1,072.14 5,929,181.88 479,824.11 3.35 -36.57 MWD+IFR-AK-CAZ-SC (3) 3,425.65 51.28 247.93 2,949.05 2,801.55 -796.64 -1,138.97 5,929,155.03 479,757.22 0.89 -21.51 MWD+IFR-AK-CAZ-SC (3) 3,518.99 55.39 247.67 3,004.77 2,857.27 -824.93 -1,208.28 5,929,126.92 479,687.85 4.41 -6.10 MWD+IFR-AK-CAZ-SC (3) 3,609.42 56.46 248.04 3,055.44 2,907.94 -853.16 -1,277.65 5,929,098.86 479,618.41 1.23 9.40 MWD+IFR-AK-CAZ-SC (3) 3,703.27 57.86 248.01 3,106.33 2,958.83 -882.67 -1,350.77 5,929,069.54 479,545.22 1.49 25.94 MWD+IFR-AK-CAZ-SC (3) 3,795.35 58.60 248.24 3,154.81 3,007.31 -911.83 -1,423.42 5,929,040.56 479,472.51 0.83 42.49 MWD+IFR-AK-CAZ-SC (3) 3,888.69 62.00 248.65 3,201.05 3;053.55 -941.61 -1,498.82 5,929,010.98 479,397.04 3.66 60.08 MWD+IFR-AK-CAZ-SC (3) 3,983.02 62.42 248.93 3,245.03 3,097.53 -971.80 -1,576.62 5,928,980.99 479,319.18 0.52 78.68 MWD+IFR-AK-CAZ-SC (3) 9/9/2016 9:34:OOAM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 Database: OAKEDMP2 Survey 9/9/2016 9:34:OOAM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi ND TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,075.27 61.97 248.44 3,288.06 3,140.56 -1,001.46 -1,652.63 5,928,951.52 479,243.09 0.68 96.71 MWD+IFR-AK-CAZ-SC (3) 4,168.33 61.01 250.91 3,332.49 3,184.99 -1,029.87 -1,729.30 5,928,923.31 479,166.36 2.55 116.15 MWD+IFR-AK-CAZ-SC (3) 4,262.19 60.59 251.46 3,378.28 3,230.78 -1,056.29 -1,806.86 5,928,897.09 479,088.74 0.68 137.73 MWD+IFR-AK-CAZ-SC (3) 4,356.57 60.80 251.48 3,424.47 3,276.97 -1,082.45 -1,884.89 5,928,871.13 479,010.65 0.22 159.80 MWD+IFR-AK-CAZ-SC (3) 4,449.98 61.03 251.32 3,469.88 3,322.38 -1,108.49 -1,962.26 5,928,845.29 478,933.23 0.29 181.59 MWD+IFR-AK-CAZ-SC (3) 4,544.76 61.00 251.15 3,515.81 3,368.31 -1,135.16 -2,040.76 5,928,818.82 478,854.67 0.16 203.49 MWD+IFR-AK-CAZ-SC (3) 4,638.59 61.06 250.63 3,561.26 3,413.76 -1,162.03 -2,118.33 5,928,792.15 478,777.04 0.49 224.70 MWD+IFR-AK-CAZ-SC (3) 4,732.01 60.86 249.57 3,606.61 3,459.11 -1,189.83 -2,195.12 5,928,764.55 478,700.18 1.01 244.71 MWD+IFR-AK-CAZ-SC (3) 4,826.27 60.79 250.20 3,652.56 3,505.06 -1,218.13 -2,272.40 5,928,736.44 478,622.84 0.59 264.58 MWD+IFR-AK-CAZ-SC (3) 4,916.93 61.06 250.33 3,696.61 3,549.11 -1,244.89 -2,346.99 5,928,709.88 478,548.19 0.32 284.22 MWD+IFR-AK-CAZ-SC (3) 5,010.28 61.10 250.12 3,741.76 3,594.26 -1,272.53 -2,423.88 5,928,682.43 478,471.24 0.20 304.41 MWD+IFR-AK-CAZ-SC (3) 5,102.78 60.72 250.05 3,786.73 3,639.23 -1,300.07 -2,499.87 5,928,655.09 478,395.18 0.42 324.20 MWD+IFR-AK-CAZ-SC (3) 5,195.28 60.66 249.61 3,832.01 3,684.51 -1,327.88 -2,575.59 5,928,627.48 478,319.41 0.42 343.59 MWD+IFR-AK-CAZ-SC (3) 5,289.37 60.74 250.17 3,878.06 3,730.56 -1,356.09 -2,652.64 5,928,599.46 478,242.29 0.53 363.41 MWD+IFR-AK-CAZ-SC (3) 5,381.75 60.67 250.09 3,923.26 3,775.76 -1,383.47 -2,728.41 5,928,572.27 478,166.46 0.11 383.19 MWD+IFR-AK-CAZ-SC (3) 5,473.45 60.63 250.62 3,968.20 3,820.70 -1,410.35 -2,803.68 5,928,545.60 478,091.13 0.51 403.12 MWD+IFR-AK-CAZ-SC (3) 5,567.92 60.66 250.87 4,014.51 3,867.01 -1,437.50 -2,881.42 5,928,518.64 478,013.33 0.23 424.19 MWD+IFR-AK-CAZ-SC (3) 5,661.68 60.74 251.47 4,060.40 3,912.90 -1,463.89 -2,958.80 5,928,492.45 477,935.88 0.56 445.70 MWD+IFR-AK-CAZ-SC (3) 5,757.08 60.53 251.29 4,107.18 3,959.68 -1,490.44 -3,037.60 5,928,466.11 477,857.04 0.27 467.87 MWD+IFR-AK-CAZ-SC (3) 5,850.57 60.90 250.91 4,152.91 4,005.41 -1,516.85 -3,114.74 5,928,439.89 477,779.83 0.53 489.23 MWD+IFR-AK-CAZ-SC (3) 5,943.99 60.44 248.47 4,198.68 4,051.18 -1,545.11 -3,191.11 5,928,411.82 477,703.39 2.33 508.62 MWD+IFR-AK-CAZ-SC (3) 6,037.22 60.79 249.67 4,244.43 4,096.93 -1,574.13 -3,266.99 5,928,383.00 477,627.45 1.18 527.11 MWD+IFR-AK-CAZ-SC (3) 6,129.53 60.59 248.07 4,289.62 4,142.12 -1,603.14 -3,342.06 5,928,354.18 477,552.31. 1.53 545.15 MWD+IFR-AK-CAZ-SC (3) 6,222.41 60.88 248.38 4,335.02 4,187.52 -1,633.20 -3,417.31 5,928,324.32 477,477.00 0.43 562.43 MWD+IFR-AK-CAZ-SC (3) 6,316.01 60.70 248.15 4,380.70 4,233.20 -1,663.45 -3,493.20 5,928,294.26 477,401.04 0.29 579.90 MWD+IFR-AK-CAZ-SC (3) 6,409.32 60.61 250.20 4,426.43 4,278.93 -1,692.37 -3,569.22 5,928,265.54 477,324.96 1.92 598.55 MWD+IFR-AK-CAZ-SC (3) 6,502.38 58.16 250.88 4,473.82 4,326.32 -1,719.05 -3,644.72 5,928,239.05 477,249.39 2.71 618.76 MWD+IFR-AK-CAZ-SC (3) 6,598.21 58.41 253.51 4,524.20 4,376.70 -1,743.97 -3,722.33 5,928,214.33 477,171.73 2.35 641.61 MWD+IFR-AK-CAZ-SC (3) 6,689.12 58.87 256.33 4,571.52 4,424.02 -1,764.16 -3,797.27 5,928,194.33 477,096.74 2.70 666.89 MWD+IFR-AK-CAZ-SC (3) 6,783.66 59.28 258.89 4,620.11 4,472.61 -1,781.56 -3,876.47 5,928,177.14 477,017.51 2.36 696.87 MWD+IFR-AK-CAZ-SC (3) 6,878.78 58.49 262.31 4,669.28 4,521.78 -1,794.87 -3,956.79 5,928,164.03 476,937.16 3.19 730.86 MWD+IFR-AK-CAZ-SC (3) 6,974.96 57.42 266.31 4,720.32 4,572.82 -1,802.96 -4,037.89 5,928,156.14 476,856.05 3.70 769.60 MWD+IFR-AK-CAZ-SC (3) 7,068.26 56.96 269.00 4,770.88 4,623.38 -1,806.17 -4,116.23 5,928,153.13 476,777.71 2.47 810.84 MWD+IFR-AK-CAZ-SC (3) 7,162.25 56.44 272.56 4,822.50 4,675.00 -1,805.11 -4,194.76 5,928,154.39 476,699.20 3.21 855.73 MWD+IFR-AK-CAZ-SC (3) 7,254.28 55.85 275.87 4,873.78 4,726.28 -1,799.50 -4,270.96 5,928,160.19 476,623.01 3.05. 903.08 MWD+IFR-AK-CAZ-SC (3) 7,345.72 55.88 278.70 4,925.10 4,777.60 -1,789.91 -4,346.02 5,928,169.97 476,547.98 2.56 953.09 MWD+IFR-AK-CAZ-SC (3) 7,441.05 55.03 280.27 4,979.15 4,831.65 -1,776.97 -4,423.47 5,928,183.10 476,470.58 1.62 1,007.20 MWD+IFR-AK-CAZ-SC (3) 7,533.25 52.88 282.42 5,033.41 4,885.91 -1,762.33 -4,496.55 5,928,197.93 476,397.54 3.00 1,060.29 MWD+IFR-AK-CAZ-SC (3) 7,625.94 51.57 285.38 5,090.19 4,942.69 -1,744.75 -41567.66 5,928,215.69 476,326.48 2.89 1,114.70 MWD+IFR-AK-CAZ-SC (3) 7,719.41 52.60 289.78 5,147.65 5,000.15 -1,722.47 -4,637.92 5,928,238.14 476,256.29 3.87 1,172.52 MWD+IFR-AK-CAZ-SC (3) 9/9/2016 9:34:OOAM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Axi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,811.71 53.12 292.34 5,203.38 5,055.88 -1,696.03 -4,706.57 5,928,264.76 476,187.71 2.28 1,232.90 MWD+IFR-AK-CAZ-SC (3) 7,903.79 54.45 296.32 5,257.79 5,110.29 -1,665.41 -4,774.23 5,928,295.54 476,120.14 3.77 1,296.17 MWD+IFR-AK-CAZ-SC (3) 7,995.87 55.41 299.86 5,310.71 5,163.21 -1,629.92 -4,840.69 5,928,331.19 476,053.77 3.31 1,362.81 MWD+IFR-AK-CAZ-SC (3) 8,088.89 55.39 303.20 5,363.54 5,216.04 -1,589.89 -4,905.94 5,928,371.39 475,988.63 2.96 1,432.53 MWD+IFR-AK-CAZ-SC (3) 8,181.47 55.44 306.84 5,416.11 5,268.61 -1,546.17 -4,968.34 5,928,415.27 475,926.35 3.24 1,503.71 MWD+IFR-AK-CAZ-SC (3) 8,274.49 55.80 309.81 5,468.64 5,321.14 -1,498.56 -5,028.55 5,928,463.02 475,866.26 2.66 1,576.88 MWD+IFR-AK-CAZ-SC (3) 8,368.67 57.04 309.97 5,520.73 5,373.23 -1,448.24 -5,088.76 5,928,513.48 475,806.19 1.32 1,652.29 MWD+IFR-AK-CAZ-SC (3) 8,461.71 56.71 309.14 5,571.57 5,424.07 -1,398.62 -5,148.83 5,928,563.25 475,746.25 0.83 1,727.06 MWD+IFR-AK-CAZ-SC (3) 8,553.04 55.84 310.08 5,622.28 5,474.78 -1,350.20 -5,207.35 5,928,611.82 475,687.86 1.28 1,799.96 MWD+IFR-AK-CAZ-SC (3) 8,647.67 55.94 311.96 5,675.35 5,527.85 -1,298.78 -5,266.46 5,928,663.38 475,628.88 1.65 1,875.67 MWD+IFR-AK-CAZ-SC (3) 8,741.37 57.18 315.11 5,726.99 5,579.49 -1,244.92 -5,323.12 5,928,717.38 475,572.37 3.10 1,952.03 MWD+IFR-AK-CAZ-SC (3) 8,835.77 58.31 317.50 5,777.38 5,629.88 -1,187.20 -5,378.26 5,928,775.23 475,517.38 2.45 2,030.73 MWD+IFR-AK-CAZ-SC (3) 8,928.24 58.65 321.18 5,825.73 5,678.23 -1,127.42 -5,429.60 5,928,835.14 475,466.20 3.41 2,109.02 MWD+IFR-AK-CAZ-SC (3) 9,021.69 59.42 323.94 5,873.82 5,726.32 -1,063.80 -5,478.30 5,928,898.87 475,417.66 2.66 2,189.00 MWD+IFR-AK-CAZ-SC (3) 9,114.60 60.50 327.49 5,920.34 5,772.84 -997.35 -5,523.58 5,928,965.43 475,372.55 3.51 2,269.41 MWD+IFR-AK-CAZ-SC (3) 9,207.51 61.42 330.83 5,965.45 5,817.95 -927.62 -5,565.21 5,929,035.26 475,331.11 3.30 2,350.49 MWD+IFR-AK-CAZ-SC (3) 9,265.30 61.60 332.19 5,993.02 5,845.52 -882.98 -5,589.43 5,929,079.95 475,307.00 2.09 2,401.04 MWD+IFR-AK-CAZ-SC (3) 9,288.24 61.68 332.70 6,003.92 5,856.42 -865.08 -5,598.77 5,929,097.87 475,297.70 1.99 2,421.09 INC+TREND (4) 9,318.00 61.77 333.08 6,018.01 5,870.51 -841.75 -5,610.72 5,929,121.23 475,285.82 1.17 2,447.11 NOT an Actual Survey') 10 3/4" x 13-1/2" 9,338.00 61.83 333.34 6,027.47 5,879.97 -826.02 -5,618.66 5,929,136.98 475,277.92 1.17 2,464.59 MWD+IFR-AK-CAZ-SC (5) 9,399.61 61.71 338.01 6,056.62 5,909.12 -776.58 -5,641.01 5,929,186.48 475,255.69 6.68 2,518.07 MWD+IFR-AK-CAZ-SC (5) 9,441.73 62.23 340.89 6,076.42 5,928.92 -741.77 -5,654.06 5,929,221.32 475,242.74 6.16 2,554.21 MWD+IFR-AK-CAZ-SC (5) 9,536.34 64.93 344.27 6,118.52 5,971.02 -660.94 -5,679.39 5,929,302.20 475,217.61 4.29 2,635.35 MWD+IFR-AK-CAZ-SC (5) 9,628.18 66.40 347.72 6,156.37 6,008.87 -579.76 -5,699.62 5,929,383.42 475,197.59 3.78 2,713.92 MWD+IFR-AK-CAZ-SC (5) 9,720.92 69.66 349.31 6,191.07 6,043.57 -495.49 -5,716.73 5,929,467.73 475,180.70 3.86 2,793.30 MWD+IFR-AK-CAZ-SC (5) 9,814.38 72.21 349.35 6,221.59 6,074.09 -408.69 -5,733.08 5,929,554.56 475,164.56 2.73 2,874.35 MWD+IFR-AK-CAZ-SC (5) 9,906.40 74.94 350.60 6,247.61 6,100.11 -321.79 -5,748.44 5,929,641.50 475,149.43 3.24 2,954.94 MWD+IFR-AK-CAZ-SC (5) 9,929.00 76.05 349.23 6,253.27 6,105.77 -300.24 -5,752.27 5,929,663.04 475,145.65 7.66 2,974.93 tanActualSurvey 7-5/8" x 9-718" 9,942.83 76.74 348.40 6,256.52 6,109.02 -287.06 -5,754.88 5,929,676.24 475,143.08 7.66 2,987.31 INC+TREND (6) 10,037.13 87.36 349.00 6,269.55 6,122.05 -195.60 -5,773.15 5,929,767.73 475,125.04 11.28 3,073.29 INC+TREND (6) 10,131.87 92.06 353.76 6,270.03 6,122.53 -101.99 -5,787.34 5,929,861.37 475,111.09 7.06 3,158.78 INC+TREND (6) 10,161.07 90.45 354.51 6,269.39 6,121.89 -72.95 -5,790.32 5,929,890.41 475,108.18 6.08 3,184.50 MWD+IFR-AK-CAZ-SC (7) 10,255.59 90.00 354.23 6,269.02 6,121.52 21.11 -5,799.59 5,929,984.49 475,099.15 0.56 3,267.60 MWD+IFR-AK-CAZ-SC (7) 10,351.16 88.84 354.20 6,269.98 6,122.48 116.19 -5,809.22 5,930,079.58 475,089.76 1.21 3,351.74 MWD+IFR-AK-CAZ-SC (7) 10,445.97 88.53 354.39 6,272.16 6,124.66 210.50 -5,818.65 5,930,173.91 475,080.57 0.38 3,435.14 MWD+IFR-AK-CAZ-SC (7) 10,540.98 89.46 354.41 6,273.82 6,126.32 305.05 -5,827.92 5,930,268.46 475,071.55 0.98 3,518.63 MWD+IFR-AK-CAZ-SC (7) 10,635.74 90.35 357.30 6,273.98 6,126.48 399.55 -5,834.76 5,930,362.97 475,064.94 3.19 3,600.74 MWD+IFR-AK-CAZ-SC (7) 10,700.70 90.69 357.59 6,273.39 6,125.89 464.44 -5,837.66 5,930,427.86 475,062.21 0.69 3,656.11 MWD+IFR-AK-CAZ-SC (7) 9/9/2016 9:34:OOAM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyon 14 1) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 25-131-1 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,731.14 90.84 0.12 6,272.99 6,125.49 494.87 -5,838.27 5,930,458.29 475,061.67 8.33 3,681.65 MWD+IFR-AK-CAZ-SC (7) 10,824.23 90.48 2.06 6,271.91 6,124.41 587.93 -5,836.50 5,930,551.34 475,063.68 2.12 3,757.73 MWD+IFR-AK-CAZ-SC (7) 10,919.63 90.62 3.55 6,271.00 6,123.50 683.21 -5,831.83 5,930,646.60 475,068.59 1.57 3,834.03 MWD+IFR-AK-CAZ-SC (7) 11,013.21 91.14 3.98 6,269.56 6,122.06 776.58 -5,825.69 5,930,739.94 475,074.97 0.72 3,907.91 MWD+IFR-AK-CAZ-SC (7) 11,109.04 91.07 4.87 6,267.71 6,120.21 872.10 -5,818.29 5,930,835.44 475,082.60 0.93 3,982.89 MWD+IFR-AK-CAZ-SC (7) 11,203.72 90.72 6.20 6,266.23 6,118.73 966.33 -5,809.16 5,930,929.63 475,091.97 1.45 4,055.81 MWD+IFR-AK-CAZ-SC (7) 11,298.73 90.14 6.77 6,265.52 6,118.02 1,060.72 -5,798.43 5,931,023.99 475,102.94 0.86 4,127.98 MWD+IFR-AK-CAZ-SC (7) 11,393.68 90.35 8.91 6,265.11 6,117.61 1,154.78 -5,785.48 5,931,118.00 475,116.13 2.26 4,198.62 MWD+IFR-AK-CAZ-SC (7) 11,487.91 90.24 9.64 6,264.63 6,117.13 1,247.78 -5,770.29 5,931,210.95 475,131.55 0.78 4,267.13 MWD+IFR-AK-CAZ-SC (7) 11,581.57 90.04 10.58 6,264.40 6,116.90 1,339.98 -5,753.85 5,931,303.10 475,148.22 1.03 4,334.28 MWD+IFR-AK-CAZ-SC (7) 11,677.85 89.83 10.96 6,264.51 6,117.01 1,434.57 -5,735.86 5,931,397.63 475,166.45 0.45 4,402.53 MWD+IFR-AK-CAZ-SC (7) 11,773.16 90.48 11.01 6,264.25 6,116.75 1,528.13 -5,717.70 5,931,491.14 475,184.84 0.68 4,469.85 MWD+IFR-AK-CAZ-SC (7) 11,866.04 90.86 12.26 6,263.17 6,115.67 1,619.09 -5,698.97 5,931,582.05 475,203.80 1.41 4,534.69 MWD+IFR-AK-CAZ-SC (7) 11.;962.22 90.86 14.79 6,261.72 6,114.22 1,712.59 -5,676.48 51931,675.48 475,226.53 2.63 4,599.52 MWD+IFR-AK-CAZ-SC (7) 12,056.22 91.10 15.80 6,260.11 6,112.61 1,803.24 -5,651.69 5,931,766.06 475,251.55 1.10 4,660.71 MWD+IFR-AK-CAZ-SC (7) 12,150.60 90.42 15.34 6,258.86 6,111.36 1,894.15 -5,626.36 5,931,856.89 475,277.10 0.87 4,721.80 MWD+IFR-AK-CAZ-SC (7) 12,244.02 89.90 14.92 6,258.60 6,111.10 1,984.33 -5,601.97 5,931,947.00 475,301.71 0.72 4,782.83 MWD+IFR-AK-CAZ-SC (7) 12,339.56 90.52 15.91 6,258.25 6,110.75 2,076.43 -5,576.58 5,932,039.03 475,327.34 1.22 4,844.88 MWD+IFR-AK-CAZ-SC (7) 12,434.41 91.07 16.78 6,256.94 6,109.44 2,167.44 -5,549.89 5,932,129.96 475,354.26 1.09 4,905.29 MWD+IFR-AK-CAZ-SC (7) 12,529.38 90.52 18.61 6,255.62 6,108.12 2,257.90 -5,521.03 5,932,220.34 475,383.34 2.01 4,964.04 MWD+IFR-AK-CAZ-SC (7) 12,624.72 91.07 18.82 6,254.29 6,106.79 2,348.19 -5,490.44 5,932,310.54 475,414.16 0.62 5,021.68 MWD+IFR-AK-CAZ-SC (7) 12,719.84 91.55 17.49 6,252.12 6,104.62 2,438.55 -5,460.81 5,932,400.82 475,444.01 1.49 5,079.91 MWD+IFR-AK-CAZ-SC (7) 12,813.56 91.34 18.34 6,249.76 6,102.26 2,527.70 -5,431.99 5,932,489.88 475,473.05 0.93 5,137.60 MWD+IFR-AK-CAZ-SC (7) 12,907.48 91.44 17.25 6,247.48 6,099.98 2,617.10 -5,403.30 5,932,579.20 475,501.97 1.17 5,195.56 MWD+IFR-AK-CAZ-SC (7) 13,003.04 91.55 15.76 6,244.98 6,097.48 2,708.68 -5,376.16 5,932,670.71 475,529.34 1.56 5,256.21 MWD+IFR-AK-CAZ-SC (7) 13,096.21 91.48 14.64 6,242.52 6,095.02 2,798.56 -5,351.74 5,932,760.52 475,553.98 1.20 5,316.96 MWD+IFR-AK-CAZ-SC (7) 13,191.72 90.89 14.47 6,240.55 6,093.05 2,890.99 -5,327.74 5,932,852.87 475,578.21 0.64 5,380.06 MWD+IFR-AK-CAZ-SC (7) 13,286.00 91.00 13.72 6,238.99 6,091.49 2,982.42 -5,304.79 5,932,944.23 475,601.40 0.80 5,442.92 MWD+IFR-AK-CAZ-SC (7) 13,379.04 90.86 11.12 6,237.48 6,089.98 3,073.26 -5,284.78 5,933,035.02 475,621.63 2.80 5,506.94 MWD+IFR-AK-CAZ-SC (7) 13,475.45 91.55 10.15 6,235.45 6,087.95 3,167.99 -5,266.99 5,933,129.69 475,639.66 1.23 5,575.43 MWD+IFR-AK-CAZ-SC (7) 13,569.02 91.72 8.48. 6,232.78 6,085.28 3,260.28 -5,251.85 5,933,221.94 475,655.03 1.79 5,643.39 MWD+IFR-AK-CAZ-SC (7) 13,662.82 91.48 8.11 6,230.16 6,082.66 3,353.07 -5,238.32 5,933,314.68 475,668.79 0.47 5,712.65 MWD+IFR-AK-CAZ-SC (7) 13,757.69 92.58 6.51 6,226.80 6,079.30 3,447.10 -5,226.26 5,933,408.67 475,681.09 2.05 5,783.77 MWD+IFR-AK-CAZ-SC (7) 13,852.49 92.52 7.30 6,222.59 6,075.09 3,541.12 -5,214.88 5,933,502.65 475,692.71 0.83 5,855.26 MWD+IFR-AK-CAZ-SC (7) 13,947.88 90.83 7.50 6,219.80 6,072.30 3,635.67 -5,202.59 5,933,597.16 475,705.23 1.78 5,926.69 MWD+IFR-AK-CAZ-SC (7) 14,042.34 90.00 7.47 6,219.11 6,071.61 3,729.32 -5,190.29 5,933,690.78 475,717.77 0.88 5,997.36 MWD+IFR-AK-CAZ-SC (7) 14,136.63 88.32 9.07 6,220.50 6,073.00 3,822.62 -5,176.73 5,933,784.02 475,731.57 2.46 6,067.03 MWD+IFR-AK-CAZ-SC (7) 14,231.28 85.61 11.73 5,225.51 6,078.01 3,915.57 -5,159.67 5,933,876.92 475,748.86 4.01 6,134.45 MWD+IFR-AK-CAZ-SC (7) 14,326.47 82.79 15.04 6,235.13 6,087.63 4,007.67 -5,137.76 5,933,968.96 475,771.00 4.55 6,198.46 MWD+IFR-AK-CAZ-SC (7) 14,421.97 84.65 17.28 6,245.58 6,098.08 4,098.84 -5,111.34 5,934,060.05 475,797.65 3.04 6,259.16 MWD+IFR-AK-CAZ-SC (7) 91PI2016 9:34:OOAM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 Database: OAKEDM P2 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 14,515.58 86.61 20.50 6,252.71 6,105.21 4,187.13 -5,081.13 5,934,148.26 475,828.08 4.02 6,315.35 MWD+IFR-AK-CAZ-SC (7) 14,610.34 87.98 20.34 6,257.18 6,109.68 4,275.84 -5,048.10 5,934,236.87 475,861.33 1.46 6,370.31 MWD+IFR-AK-CAZ-SC (7) 14,704.49 89.15 19.91 6,259.54 6,112.04 4,364.21 -5,015.72 5,934,325.15 475,893.93 1.32 6,425.35 MWD+IFR-AK-CAZ-SC (7) 14,799.41 89.41 19.22 6,260.73 6,113.23 4,453.64 -4,983.94 5,934,414.50 475,925.94 0.78 6,481.61 MWD+IFR-AK-CAZ-SC (7) 14,895.32 91.25 18.38 6,260.18 6,112.68 4,544.43 -4,953.03 5,934,505.20 475,957.07 2.11 6,539.48 MWD+IFR-AK-CAZ-SC (7) 14,989.43 91.31 18.21 6,258.08 6,110.58 4,633.76 -4,923.49 5,934,594.44 475,986.83 0.19 6,596.92 MWD+IFR-AK-CAZ-SC (7) 15,083.19 91.41 17.67 6,255.85 6,108.35 4,722.94 -4,894.62 5,934,683.54 476,015.92 0.59 6,654.59 MWD+IFR-AK-CAZ-SC (7) 15,179.49 91.48 17.08 6,253.42 6,105.92 4,814.81 -4,865.87 5,934,775.33 476,044.90 0.62 6,714.58 MWD+IFR-AK-CAZ-SC (7) 15,274.31 91.44 16.03 6,251.01 6,103.51 4,905.67 -4,838.87 5,934,866.11 476,072.14 1.11 6,774.69 MWD+IFR-AK-CAZ-SC (7) 15,367.68 91.51 15.84 6,248.61 6,101.11 4,995.42 -4,813.24 5,934,955.79 476,097.99 0.22 6,834.66 MWD+IFR-AK-CAZ-SC (7) 15,462.72 91.58 15.61 6,246.04 6,098.54 5,086.87 -4,787.49 5,935,047.16 476,123.96 0.25 6,895.98 MWD+IFR-AK-CAZ-SC (7) 15,558.50 91.96 15.61 6,243.08 6,095.58 5,179.08 -4,761.73 5,935,139.29 476,149.96 0.40 6,957.90 MWD+IFR-AK-CAZ-SC (7) 15,653.21 91.48 15.24 6,240.24 6,092.74 5,270.33 -4,736.55 5,935,230.48 476,175.36 0.64 7,019.37 MWD+IFR-AK-CAZ-SC (7) 15,749.41 91.07 15.44 6,238.10 6,090.60 5,363.08 -41711.11 5,935,323.15 476,201.04 0.47 7,081.93 MWD+IFR-AK-CAZ-SC (7) 15,844.81 91.75 15.94 6,235.75 6,088.25 5,454.90 -4,685.32 5,935,414.89 476,227.06 0.88 7,143.52 MWD+IFR-AK-CAZ-SC (7) 15,938.66 92.06 16.67 6,232.63 6,085.13 5,544.92 -4,658.98 5,935,504.84 476,253.62 0.84 7,203.33 MWD+IFR-AK-CAZ-SC (7) 16,031.05 92.51 16.66 6,228.95 6,081.45 5,633.36 -4,632.51 5,935,593.21 476,280.31 0.49 7,261.74 MWD+IFR-AK-CAZ-SC (7) 16,123.74 92.10 18.02 6,225.22 6,077.72 5,721.77 -4,604.91 5,935,681.53 476,308.14 1.53 7,319.49 MWD+IFR-AK-CAZ-SC (7) 16,220.59 91.34 19.37 6,222.31 6,074.81 5,813.46 -4,573.88 5,935,773.14 476,339.39 1.60 7,378.04 MWD+IFR-AK-CAZ-SC (7) 16,316.73 91.00 20.77 6,220.35 6,072.85 5,903.74 -4,540.89 5,935,863.33 476,372.60 1.50 7,434.33 MWD+IFR-AK-CAZ-SC (7) 16,410.44 91.17 21.14 6,218.58 6,071.08 5,991.24 -4,507.39 5,935,950.73 476,406.33 0.43 7,488.02 MWD+IFR-AK-CAZ-SC (7) 16,505.92 91.00 21.15 6,216.77 6,069.27 6,080.27 -4,472.95 5,936,039.67 476,440.99 0.18 7,542.46 MWD+IFR-AK-CAZ-SC (7) 16,599.43 91.34 21.04 6,214.86 6,067.36 6,167.50 -4,439.30 5,936,126.80 476,474.85 0.38 7,595.84 MWD+IFR-AK-CAZ-SC (7) 16,694.27 91.96 21.19 6,212.13 6,064.63 6,255.93 -4,405.15 5,936,215.14 476,509.22 0.67 7,649.95 MWD+IFR-AK-CAZ-SC (7) 16,785.89 92.34 21.77 6,208.69 6,061.19 6,341.13 -4,371.63 5,936,300.24 476,542.96 0.76 7,701.72 MWD+IFR-AK-CAZ-SC (7) 16,867.00 92.34 21.77 6,205.38 6,057.88 6,416.39 -4,341.57 5,936,375.42 476,573.21 0.00 7,747.21 PROJECTED to TD 6-3/4" open hole 9/9/2016 9:34:OOAM Page 7 COMPASS 5000.1 Build 74 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. L' Yes [ No I have checked to the best of my ability that the following data is correct.- LJ orrect. [j Surface Coordinates LJ Declination & Convergence El GRS Survey Corrections Survey Tool Codes Vincent Dgilaly s'9^d by Ymcen+osars DN, zmY�+Osm o Schl mbe+ges, Osara m SchlumbmW, eD.- SLB DE: 201F MOO 11 AS27-6LQ J tJ` .gvdM�vi tl-..�r:a Scott Brunswick Client Representative: Date: 09 -Sep -2016 21 5152 ZG S4 61 scCha 1(3- REVISED 1:28 pm, Sep 12, 2016 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S -13L1 Definitive Survey Report 08 September, 2016 NAD 83 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-13 Wellbore: 2S-131-1 Design: 2S-131-1 Schlumberger Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2S-13 25-13: 120+27.5 @ 147.50usft (Doyonl41) 2S-13: 120+27.5 @ 147.50usft (Doyonl41) True Minimum Curvature 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 25-13 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 2S-131-1 Magnetics Model Name Sample Date BGGM2015 12/15/2015 Design 2S-131-1 Audit Notes: Version: 1.0 Phase: Vertical Section: Depth From (TVD) (usft) 5,929,698.28 usft Latitude: 1,620,931.42 usft Longitude: 0.00 usft Ground Level: Declination Dip Angle 18.44 80.86 ACTUAL +N/ -S (usft) 0 00 Tie On Depth +E/ -W (usft) 0.00 70° 13' 10.067 N 150° 9'25.916 W 120.00 usft Field Strength (nT) 57,486 9,906.60 Direction (°) 325.92 Survey Program Date 9/8/2016 201.50 174.86 27.36 From To 5,929,698.22 1,620,931.35 0.11 (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 82.68 1,283.58 2S-13PB1 Srvy #1 - SLB_N SG +Battery+ GYD-GC-SS Gyrodata gyro single shots 11/30/2015 10:2: 1,304.79 2,775.54 2S-13PB1 Srvy #2 - SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/30/2015 10:21 2,868.21 9,265.50 2S-13PB1 Srvy #3 - SLB_MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/6/2015 8:33: 9,288.24 9,288.24 2S-13PB1 Srvy #4 - SLB_Inc+Filler (2S-1 INC+TREND Inclinometer + known azi trend 12/15/2015 9:3E 9,338.00 9,906.60 2S-13 Srvy #1 - SLB_MWD+GMAG (2S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/20/2015 11:31 9,942.83 10,132.07 2S-131-1 Srvy #1 - SLB_Inc-Filler (2S -13L INC+TREND Inclinometer+ known azi trend 1/16/2016 8:47: 10,161.27 16,785.89 2S-131-1 Srvy #2 - SLB_MWD+GMAG (2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/18/2016 8:57:. Survey 0.10 201.50 174.86 27.36 -0.06 -0.07 5,929,698.22 1,620,931.35 0.11 Map Map 0.54 Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -120.00 0.00 0.00 5,929,698.28 1,620,931.42 0.00 0.00 UNDEFINED 82.68 0.03 287.05 82.68 -64.82 0.00 -0.01 5,929,698.29 1,620,931.40 0.05 0.01 GYD-GC-SS (1) 107.50 0.04 238.86 107.50 -40.00 0.00 -0.03 5,929,698.29 1,620,931.39 0.11 0.02 NOT an Actual Surv1 20" X 42" 174.86 0.10 201.50 174.86 27.36 -0.06 -0.07 5,929,698.22 1,620,931.35 0.11 -0.02 GYD-GC-SS(1) 266.90 0.54 204.98 266.90 119.40 -0.53 -0.28 5,929,697.75 1,620,931.14 0.48 -0.28 GYD-GC-SS (1) 358.92 2.63 196.47 358.88 211.38 -2.95 -1.06 5,929,695.34 1,620,930.35 2.28 -1.85 GYD-GC-SS (1) 450.55 4.08 197.58 450.35 302.85 -8.07 -2.64 5,929,690.22 1,620,928.75 1.58 -5.21 GYD-GC-SS(1) 542.44 4.84 198.23 541.96 394.46 -14.87 -4.84 5,929,683.43 1,620,926.54 0.83 -9.60 GYD-GC-SS (1) 9/6/2016 1:25:40PM Page 2 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-13 Wellbore: 2S-131-1 Design: 2S-131-1 Survey Schlumberger Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2S-13 2S-13: 120+27.5 @ 147.50usft (Doyonl41) 2S-13: 120+27.5 @ 147.50usft (Doyonl41) True Minimum Curvature OAKEDMP2 9/8/2016 1:25:40PM Page 3 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 634.35 5.99 202.27 633.46 485.96 -22.99 -7.87 5,929,675.31 1,620,923.48 1.32 -14.63 GYD-GC-SS (1) 726.00 6.53 203.78 724.56 577.06 -32.19 -11.79 5,929,666.13 1,620,919.55 0.62 -20.05 GYD-GC-SS (1) 817.94 8AS 201.86 815.71 668.21 -43.26 -16.42 5,929,655.07 1,620,914.89 2.14 -26.63 GYD-GC-SS (1) 910.56 9.80 205.54 907.15 759.65 -56.71 -22.36 5,929,641.63 1,620,908.91 1.56 -34.44 GYD-GC-SS (1) 1,003.86 11.08 208.23 998.91 851.41 -71.78 -30.02 5,929,626.59 1,620,901.21 1.47 -42.62 GYD-GC-SS (1) 1,096:09 12.93 209.29 1,089.12 941.62 -88.59 -39.27 5,929,609.81 1,620,891.93 2.02 -51.37 GYD-GC-SS (1) 1,188.56 15.38 208.11 1,178.77 1,031.27 -108.43 -50.11 5,929,589.99 1,620,881.03 2.67 -61.72 GYD-GC-SS (1) 1,283.58 19.22 206.89 1,269.48 1,121.98 -133.50 -63.12 5,929,564.96 1,620,867.96 4.06 -75.20 GYD-GC-SS (1) 1,304.79 20.60 207.96 1,289.42 1,141.92 -139.91 -66.45 5,929,558.56 1,620,864.61 6.73 -78.64 MWD+IFR-AK-CAZ-SC (2) 1,396.67 21.80 208.96 1,375.08 1,227.58 -169.12 -82.29 5,929,529.40 1,620,848.70 1.36 -93.95 MWD+IFR-AK-CAZ-SC (2) 1,491.21 25.56 213.09 1,461.65 1,314.15 -201.58 -101.93 5,929,496.99 1,620,828.97 4.34 -109.83 MWD+IFR-AK-CAZ-SC (2) 1,585.16 27.45 217.68 1,545.73 1,398.23 -235.70 -126.24 5,929,462.93 1,620,804.58 2.97 -124.47 MWD+IFR-AK-CAZ-SC (2) 1,677.93 29.30 221.23 1,627.36 1,479.86 -269.70 -154.27 5,929,429.01 1,620,776.46 2.70 -136.92 MWD+IFR-AK-CAZ-SC (2) 1,771.75 30.21 225.91 1,708.82 1,561.32 -303.40 -186.36 5,929,395.40 1,620,744.29 2.66 -146.84 MWD+IFR-AK-CAZ-SC (2) 1,863.74 31.06 226.45 1,787.97 1,640.47 -335.85 -220.19 5,929,363.04 1,620,710.39 0.97 -154.76 MWD+IFR-AK-CAZ-SC (2) 1,956.72 32.83 229.72 1,866.87 1,719.37 -368.68 -256.80 5,929,330.31 1,620,673.69 2.66 -161.43 MWD+IFR-AK-CAZ-SC (2) 2,050.37 33.68 233.62 1,945.19 1,797.69 -400.50 -297.08 5,929,298.60 1,620,633.33 2.46 -165.21 MWD+IFR-AK-CAZ-SC (2) 2,143.17 34.26 235.37 2,022.15 1,874.65 -430.60 -339.29 5,929,268.60 1,620,591.05 1.23 -166.49 MWD+IFR-AK-CAZ-SC (2) 2,237.57 35.48 238.69 2,099.61 1,952.11 -459.94 -384.57 5,929,239.38 1,620,545.70 2.39 -165.42 MWD+IFR-AK-CAZ-SC (2) 2,330.47 38.90 240.04 2,173.61 2,026.11 -488.53 -432.89 5,929,210.92 1,620,497.31 3.78 -162.02 MWD+IFR-AK-CAZ-SC (2) 2,423.89 39.45 242.06 2,246.03 2,098.53 -517.09 -484.53 5,929,182.50 1,620,445.61 1.49 -156.73 MWD+IFR-AK-CAZ-SC (2) 2,515.04 40.79 245.52 2,315.74 2,168.24 -543.00 -537.21 5,929,156.73 1,620,392.85 2.85 -148.66 MWD+IFR-AK-CAZ-SC (2) 2,609.16 42.70 247.70 2,385.97 2,238.47 -567.85 -594.73 5,929,132.03 1,620,335.28 2.55 -137.01 MWD+IFR-AK-CAZ-SC (2) 2,701.86 43.56 247.40 2,453.62 2,306.12 -592.05 -653.30 5,929,107.98 1,620,276.65 0.95 -124.24 MWD+IFR-AK-CAZ-SC (2) 2,775.54 45.32 247.46 2,506.22 2,358.72 -611.85 -700.94 5,929,088.31 1,620,228.97 2.39 -113.94 MWD+IFR-AK-CAZ-SC (2) 2,835.00 46.00 247.45 2,547.78 2,400.28 -628.16 -740.21 5,929,072.10 1,620,189.66 1.14 -105.43 NOT an Actual Survey 31 13-3/8" 1 2,868.01 46.37 247.44 2,570.64 2,423.14 -637.29 -762.21 5,929,063.03 1,620,167.64 1.14 -100.67 MWD+IFR-AK-CAZ-SC (3) 2,961.88 45.93 246.36 2,635.67 2,488.17 -663.85 -824.47 5,929,036.63 1,620,105.31 0.95 -87.77 MWD+IFR-AK-CAZ-SC (3) 3,053.24 45.12 245.87 2,699.67 2,552.17 -690.24 -884.08 5,929,010.40 1,620,045.64 0.97 -76.23 MWD+IFR-AK-CAZ-SC (3) 3,145.12 45.68 246.79 2,764.19 2,616.69 -716.50 -944.00 5,928,984.29 1,619,985.67 0.94 -64.40 MWD+IFR-AK-CAZ-SC (3) 3,237.98 47.31 247.54 2,828.11 2,680.61 -742.63 -1,006.07 5,928,958.32 1,619,923.53 1.85 -51.26 MWD+IFR-AK-CAZ-SC (3) 3,332.72 50.46 248.03 2,890.40 2,742.90 -769.61 -1,072.14 5,928,931.52 1,619,857.40 3.35 -36.57 MWD+IFR-AK-CAZ-SC (3) 3,425.65 51.28 247.93 2,949.05 2,801.55 -796.64 -1,138.97 5,928,904.67 1,619,790.51 0.89 -21.51 MWD+IFR-AK-CAZ-SC (3) 3,518.99 55.39 247.67 3,004.77 2,857.27 -824.93 -1,208.28 5,928,876.56 1,619,721.13 4.41 -6.10 MWD+IFR-AK-CAZ-SC (3) 3,609.42 56.46 248.04 3,055.44 2,907.94 -853.16 -1,277.65 5,928,848.51 1,619,651.69 1.23 9.40 MWD+IFR-AK-CAZ-SC (3) 3,703.27 57.86 248.01 3,106.33 2,958.83 -882.67 -1,350.77 5,928,819.20 1,619,578.50 1.49 25.94 MWD+IFR-AK-CAZ-SC (3) 3,795.35 58.60 248.24 3,154.81 3,007.31 -911.83 -1,423.42 5,928,790.22 1,619,505.79 0.83 42.49 MWD+IFR-AK-CAZ-SC (3) 3,888.69 62.00 248.65 3,201.05 3,053.55 -941.61 -1,498.82 5,928,760.64 1,619,430.32 3.66 60.08 MWD+IFR-AK-CAZ-SC (3) 3,983.02 62.42 248.93 3,245.03 3,097.53 -971.80 -1,576.62 5,928,730.65 1,619,352.45 0.52 78.68 MWD+IFR-AK-CAZ-SC (3) 9/8/2016 1:25:40PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S -13L1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) V) (usft) (usft) (usft) (usft) (ft) (ft) (ollow) (ft) Survey Tool Name 4,075.27 61.97 248.44 3,288.06 3,140.56 -1,001.46 -1,652.63 5,928,701.19 1,619,276.37 0.68 96.71 MWD+IFR-AK-CAZ-SC (3) 4,168.33 61.01 250.91 3,332.49 3,184.99 -1,029.87 -1,729.30 5,928,672.99 1,619,199.63 2.55 116.15 MWD+IFR-AK-CAZ-SC (3) 4,262.19 60.59 251.46 3,378.28 3,230.78 -1,056.29 -1,806.86 5,928,646.76 1,619,122.02 0.68 137.73 MWD+IFR-AK-CAZ-SC (3) 4,356.57 60.80 251.48 3,424.47 3,276.97 -1,082.45 -1,884.89 5,928,620.81 1,619,043.92 0.22 159.80 MWD+IFR-AK-CAZ-SC (3) 4,449.98 61.03 251.32 3,469.88 3,322.38 -1,108.49 -1,962.26 5,928,594.98 1,618,966.50 0.29 181.59 MWD+IFR-AK-CAZ-SC (3) 4,544.76 61.00 251.15 3,515.81 3,368.31 -1,135.16 -2,040.76 5,928,568.51 1,618,887.93 0.16 203.49 MWD+IFR-AK-CAZ-SC (3) 4,638.59 61.06 250.63 3,561.26 3,413.76 -1,162.03 -2,118.33 5,928,541.84 1,618,810.31 0.49 224.70 MWD+IFR-AK-CAZ-SC (3) 4,732.01 60.86 249.57 3,606.61 3,459.11 -1,189.83 -2,195.12 5,928,514.24 1,618,733.45 1.01 244.71 MWD+IFR-AK-CAZ-SC (3) 4,826.27 60.79 250.20 3,652.56 3,505.06 -1,218.13 -2,272.40 5,928,486.14 1,618,656.10 0.59 264.58 MWD+IFR-AK-CAZ-SC (3) 4,916.93 61.06 250.33 3,696.61 3,549.11 -1,244.89 -2,346.99 5,928,459.58 1,618,581.46 0.32 284.22 MWD+IFR-AK-CAZ-SC (3) 5,010.28 61.10 250.12 3,741.76 3,594.26 -1,272.53 -2,423.88 5,928,432.14 1,618,504.50 0.20 304.41 MWD+IFR-AK-CAZ-SC (3) 5,102.78 60.72 250.05 3,786.73 3,639.23 -1,300.07 -2,499.87 5,928,404.80 1,618,428.44 0.42 324.20 MWD+IFR-AK-CAZ-SC (3) 5,195.28 60.66 249.61 3,832.01 3,684.51 -1,327.88 -2,575.59 5,928,377.19 1,618,352.67 0.42 343.59 MWD+IFR-AK-CAZ-SC (3) 5,289.37 60.74 250.17 3,878.06 3,730.56 -1,356.09 -2,652.64 5,928,349.18 1,618,275.55 0.53 363.41 MWD+IFR-AK-CAZ-SC (3) 5,381.75 60.67 250.09 3,923.26 3,775.76 -1,383.47 -2,728.41 5,928,322.00 1,618,199.72 0.11 383.19 MWD+IFR-AK-CAZ-SC (3) 5,473.45 60.63 250.62 3,968.20 3,820.70 -1,410.35 -2,803.68 5,928,295.32 1,618,124.38 0.51 403.12 MWD+IFR-AK-CAZ-SC (3) 5,567.92 60.66 250.87 4,014.51 3,867.01 -1,437.50 -2,881.42 5,928,268.37 1,618,046.59 0.23 424.19 MWD+IFR-AK-CAZ-SC (3) 5,661.68 60.74 251.47 4,060.40 3,912.90 -1,463.89 -2,958.80 5,928,242.18 1,617,969.14 0.56 445.70 MWD+IFR-AK-CAZ-SC (3) 5,757.08 60.53 251.29 4,107.18 3,959.68 -1,490.44 -3,037.60 5,928,215.84 1,617,890.29 0.27 467.87 MWD+IFR-AK-CAZ-SC (3) 5,850.57 60.90 250.91 4,152.91 4,005.41 -1,516.85 -3,114.74 5,928,189.63 1,617,813.08 0.53 489.23 MWD+IFR-AK-CAZ-SC (3) 5,943.99 60.44 248.47 4,198.68 4,051.18 -1,545.11 -3,191.11 5,928,161.57 1,617,736.64 2.33 508.62 MWD+IFR-AK-CAZ-SC (3) 6,037.22 60.79 249.67 4,244.43 4,096.93 -1,574.13 -3,266.99 5,928,132.75 1,617,660.70 1.18 527.11 MWD+IFR-AK-CAZ-SC (3) 6,129.53 60.59 248.07 4,289.62 4,142.12 -1,603.14 -3,342.06 5,928,103.93 1,617,585.56 1.53 545.15 MWD+IFR-AK-CAZ-SC (3) 6,222.41 60.88 248.38 4,335.02 4,187.52 -1,633.20 -3,417.31 5,928,074.07 1,617,510.24 0.43 562.43 MWD+IFR-AK-CAZ-SC (3) 6,316.01 60.70 248.15 4,380.70 4,233.20 -1,663.45 -3,493.20 5,928,044.02 1,617,434.28 0.29 579.90 MWD+IFR-AK-CAZ-SC (3) 6,409.32 60.61 250.20 4,426.43 4,278.93 -1,692.37 -3,569.22 5,928,015.30 1,617,358.20 1.92 598.55 MWD+IFR-AK-CAZ-SC (3) 6,502.38 58.16 250.88 4,473.82 4,326.32 -1,719.05 -3,644.72 5,927,988.82 1,617,282.63 2.71 618.76 MWD+IFR-AK-CAZ-SC (3) 6,598.21 58.41 253.51 4,524.20 4,376.70 -1,743.97 -3,722.33 5,927,964.10 1,617,204.97 2.35 641.61 MWD+IFR-AK-CAZ-SC (3) 6,689.12 58.87 256.33 4,571.52 4,424.02 -1,764.16 -3,797.27 5,927,944.11 1,617,129.98 2.70 666.89 MWD+IFR-AK-CAZ-SC (3) 6,783.66 59.28 258.89 4,620.11 4,472.61 -1,781.56 -3,876.47 5,927,926.92 1,617,050.74 2.36 696.87 MWD+IFR-AK-CAZ-SC (3) 6,878.78 58.49 262.31 4,669.28 4,521.78 -1,794.87 -3,956.79 5,927,913.82 1,616,970.39 3.19 730.86 MWD+IFR-AK-CAZ-SC (3) 6,974.96 57.42 266.31 4,720.32 4,572.82 -1,802.96 -4,037.89 5,927,905.93 1,616,889.29 3.70 769.60 MWD+IFR-AK-CAZ-SC (3) 7,068.26 56.96 269.00 4,770.88 4,623.38 -1,806.17 -4,116.23 5,927,902.92 1,616,810.95 2.47 810.84 MWD+IFR-AK-CAZ-SC (3) 7,162.25 56.44 272.56 4,822.50 4,675.00 -1,805.11 -4,194.76 5,927,904.19 1,616,732.43 3.21 855.73 MWD+IFR-AK-CAZ-SC (3) 7,254.28 55.85 275.87 4,873.78 4,726.28 -1,799.50 -4,270.96 5,927,909.99 1,616,656.25 3.05 903.08 MWD+IFR-AK-CAZ-SC (3) 7,345.72 55.88 278.70 4,925.10 4,777.60 -1,789.91 -4,346.02 5,927,919.78 1,616,581.22 2.56 953.09 MWD+IFR-AK-CAZ-SC (3) 7,441.05 55.03 280.27 4,979.15 4,831.65 -1,776.97 -4,423.47 5,927,932.91 1,616,503.82 1.62 1,007.20 MWD+IFR-AK-CAZ-SC (3) 7,533.25 52.88 282.42 5,033.41 4,885.91 -1,762.33 -4,496.55 5,927,947.74 1,616,430.78 3.00 1,060.29 MWD+IFR-AK-CAZ-SC (3) 7,625.94 51.57 285.38 5,090.19 4,942.69 -1,744.75 -4,567.66 5,927,965.50 1,616,359.72 2.89 1,114.70 MWD+IFR-AK-CAZ-SC (3) 7,719.41 52.60 289.78 5,147.65 5,000.15 -1,722.47 -4,637.92 5,927,987.96 1,616,289.53 3.87 1,172.52 MWD+IFR-AK-CAZ-SC (3) 9/8/2016 1:25:40PM Page 4 COMPASS 5000 1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2S Pad MD Reference: Well: 2S-13 North Reference: Wellbore: 2S-131-1 Survey Calculation Method: Design: 2S-131-1 Database: Survey Well 2S-13 2S-13: 120+27.5 @ 147.50usft (Doyonl41) 2S-13: 120+27.5 @ 147.50usft (Doyonl41) True Minimum Curvature OAKEDMP2 9/8/2016 1:25:40PM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MO Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,811.71 53.12 292.34 5,203.38 5,055.88 -1,696.03 -4,706.57 5,928,014.58 1,616,220.95 2.28 1,232.90 MWD+IFR-AK-CAZ-SC (3) 7,903.79 54.45 296.32 5,257.79 5,110.29 -1,665.41 -4,774.23 5,928,045.37 1,616,153.38 3.77 1,296.17 MWD+IFR-AK-CAZ-SC (3) 7,995.87 55.41 299.86 5,310.71 5,163.21 -1,629.92 -4,840.69 5,928,081.02 1,616,087.02 3.31 1,362.81 MWD+IFR-AK-CAZ-SC (3) 8,088.89 55.39 303.20 5,363.54 5,216.04 -1,589.89 -4,905.94 5,928,121.22 1,616,021.88 2.96 1,432.53 MWD+IFR-AK-CAZ-SC (3) 8,161.47 55.44 306.84 5,416.11 5,268.61 -1,546.17 -4,968.34 5,928,165.10 1,615,959.59 3.24 1,503.71 MWD+IFR-AK-CAZ-SC (3) 8,274.49 55.80 309.81 5,468.64 5,321.14 -1,498.56 -5,028.55 5,928,212.86 1,615,899.51 2.66 1,576.88 MWD+IFR-AK-CAZ-SC (3) 8,368.67 57.04 309.97 5,520.73 5,373.23 -1,448.24 -5,088.76 5,928,263.32 1,615,839.44 1.32 1,652.29 MWD+IFR-AK-CAZ-SC (3) 8,461.71 56.71 309.14 5,571.57 5,424.07 -1,398.62 -5,148.83 5,928,313.10 1,615,779.50 0.83 1,727.06 MWD+IFR-AK-CAZ-SC (3) 8,553.04 55.84 310.08 5,622.28 5,474.78 -1,350.20 -5,207.35 5,928,361.67 1,615,721.11 1.28 1,799.96 MWD+IFR-AK-CAZ-SC (3) 8,647.67 55.94 311.96 5,675.35 5,527.85 -1,298.78 -5,266.46 5,928,413.23 1,615,662.14 1.65 1,875.67 MWD+IFR-AK-CAZ-SC (3) 8,741.37 57.18 315.11 5,726.99 5,579.49 -1,244.92 -5,323.12 5,928,467.23 1,615,605.63 3.10 1,952.03 MWD+IFR-AK-CAZ-SC (3) 8,835.77 58.31 317.50 5,777.38 5,629.88 -1,187.20 -5,378.26 5,928,525.09 1,615,550.65 2.45 2,030.73 MWD+IFR-AK-CAZ-SC (3) 8,928.24 58.65 321.18 5,825.73 5,678.23 -1,127.42 -5,429.60 5,928,585.00 1,615,499.46 3.41 2,109.02 MWD+IFR-AK-CAZ-SC (3) 9,021.69 59.42 323.94 5,873.82 5,726.32 -1,063.80 -5,478.30 5,928,648.74 1,615,450.93 2.66 2,189.00 MWD+IFR-AK-CAZ-SC (3) 9,114.60 60.50 327.49 5,920.34 5,772.84 -997.35 -5,523.58 5,928,715.29 1,615,405.82 3.51 2,269.41 MWD+IFR-AK-CAZ-SC (3) 9,207.51 61.42 330.83 5,965.45 5,817.95 -927.62 -5,565.21 5,928,785.13 1,615,364.39 3.30 2,350.49 MWD+IFR-AK-CAZ-SC (3) 9,265.30 61.60 332.19 5,993.02 5,845.52 -882.98 -5,589.43 5,928,829.82 1,615,340.28 2.09 2,401.04 MWD+IFR-AK-CAZ-SC (3) 9,288.24 61.68 332.70 6,003.92 5,856.42 -865.08 -5,598.77 5,928,847.74 1,615,330.99 1.99 2,421.09 INC+TREND (4) 9,318.00 61.77 333.08 6,018.01 5,870.51 -841.75 -5,610.72 5,928,871.10 1,615,319.10 1.17 2,447.11 NOT an Actual Survey 5) 10 3/4" x 13.1/2" 9,338.00 61.83 333.34 6,027.47 5,879.97 -826.02 -5,618.66 5,928,886.85 1,615,311.20 1.17 2,464.59 MWD+IFR-AK-CAZ-SC (5) 9,399.61 61.71 338.01 6,056.62 5,909.12 -776.58 -5,641.01 5,928,936.35 1,615,288.98 6.68 2,518.07 MWD+IFR-AK-CAZ-SC (5) 9,441.73 62.23 340.89 6,076.42 5,928.92 -741.77 -5,654.06 5,928,971.19 1,615,276.02 6.16 2,554.21 MWD+IFR-AK-CAZ-SC (5) 9,536.34 64.93 344.27 6,118.52 5,971.02 -660.94 -5,679.39 5,929,052.07 1,615,250.91 4.29 2,635.35 MWD+IFR-AK-CAZ-SC (5) 9,628.18 66.40 347.72 6,156.37 6,008.87 -579.76 -5,699.62 5,929,133.29 1,615,230.89 3.78 2,713.92 MWD+IFR-AK-CAZ-SC (5) 9,720.92 69.66 349.31 6,191.07 6,043.57 -495.49 -5,716.73 5,929,217.60 1,615,214.00 3.86 2,793.30 MWD+IFR-AK-CAZ-SC (5) 9,814.38 72.21 349.35 6,221.59 6,074.09 -408.69 -5,733.08 5,929,304.43 1,615,197.87 2.73 2,874.35 MWD+IFR-AK-CAZ-SC (5) 9,906.40 74.94 350.60 6,247.61 6,100.11 -321.79 -5,748.44 5,929,391.37 1,615,182.74 3.24 2,954.94 MWD+IFR-AK-CAZ-SC (5) 9,929.00 76.05 349.23 6,253.27 6,105.77 -300.24 -5,752.27 5,929,412.92 1,615,178.96 7.66 2,974.93 NOT an Actual Survey 7-6/8" x 9-7/8" 9,942.83 76.74 348.40 6,256.52 6,109.02 -287.06 -5,754.86 5,929,426.11 1,615,176.39 7.66 2,987.31 INC+TREND (6) 10,037.13 87.36 349.00 6,269.55 6,122.05 -195.60 -5,773.15 5,929,517.60 1,615,158.36 11.28 3,073.29 INC+TREND (6) 10,131.87 92.06 353.76 6,270.03 6,122.53 -101.99 -5,787.34 5,929,611.25 1,615,144.41 7.06 3,158.78 INC+TREND (6) 10,161.07 90.45 354.51 6,269.39 6,121.89 -72.95 -5,790.32 5,929,640.29 1,615,141.50 6.08 3,184.50 MWD+IFR-AK-CAZ-SC (7) 10,255.59 90.00 354.23 6,269.02 6,121.52 21.11 -5,799.59 5,929,734.37 1,615,132.48 0.56 3,267.60 MWD+IFR-AK-CAZ-SC (7) 10,351.16 88.84 354.20 6,269.98 6,122.48 116.19 -5,809.22 5,929,829.46 1,615,123.09 1.21 3,351.74 MWD+IFR-AK-CAZ-SC (7) 10,445.97 88.53 354.39 6,272.16 6,124.66 210.50 -5,818.65 5,929,923.79 1,615,113.91 0.38 3,435.14 MWD+IFR-AK-CAZ-SC (7) 10,540.98 69.46 354.41 6,273.82 6,126.32 305.05 -5,827.92 5,930,018.34 1,615,104.89 0.98 3,518.63 MWD+IFR-AK-CAZ-SC (7) 10,635.74 90.35 357.30 6,273.98 6,126.48 399.55 -5,834.76 5,930,112.85 1,615,098.28 3.19 3,600.74 MWD+IFR-AK-CAZ-SC (7) 10,700.70 90.69 357.59 6,273.39 6,125.89 464.44 -5,837.66 5,930,177.75 1,615,095.56 0.69 3,656.11 MWD+IFR-AK-CAZ-SC (7) 9/8/2016 1:25:40PM Page 5 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-13 Wellbore: 2S -13L1 Design: 25-131-1 Survey Schlumberger Definitive Survey Report Local Co-ordinate Reference: Well 2S-13 TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Vertical Section (ft) Survey Tool Name 3,681.65 MWD+IFR-AK-CAZ-SC (7) 3,757.73 MWD+IFR-AK-CAZ-SC (7) 3,834.03 MWD+IFR-AK-CAZ-SC (7) 3,907.91 MWD+IFR-AK-CAZ-SC (7) 3,982.89 MWD+IFR-AK-CAZ-SC (7) 4,055.81 MWD+IFR-AK-CAZ-SC (7) 4,127.98 MWD+IFR-AK-CAZ-SC (7) 4,198.62 MWD+IFR-AK-CAZ-SC (7) 4,267.13 MWD+IFR-AK-CAZ-SC (7) 4,334.28 MWD+IFR-AK-CAZ-SC (7) 4,402.53 MWD+IFR-AK-CAZ-SC (7) 4,469.85 MWD+IFR-AK-CAZ-SC (7) 4,534.69 MWD+IFR-AK-CAZ-SC (7) 4,599.52 MWD+IFR-AK-CAZ-SC (7) 4,660.71 MWD+IFR-AK-CAZ-SC (7) 4,721.80 MWD+IFR-AK-CAZ-SC (7) 4,782.83 MWD+IFR-AK-CAZ-SC (7) 4,844.88 MWD+IFR-AK-CAZ-SC (7) 4,905.29 MWD+IFR-AK-CAZ-SC (7) 4,964.04 MWD+IFR-AK-CAZ-SC (7) 5,021.68 MWD+IFR-AK-CAZ-SC (7) 5,079.91 MWD+IFR-AK-CAZ-SC (7) 5,137.60 MWD+IFR-AK-CAZ-SC (7) 5,195.56 MWD+IFR-AK-CAZ-SC (7) 5,256.21 MWD+IFR-AK-CAZ-SC (7) 5,316.96 MWD+IFR-AK-CAZ-SC (7) 5,380.06 MWD+IFR-AK-CAZ-SC (7) 5,442.92 MWD+IFR-AK-CAZ-SC (7) 5,506.94 MWD+IFR-AK-CAZ-SC (7) 5,575.43 MWD+IFR-AK-CAZ-SC (7) 5,643.39 MWD+IFR-AK-CAZ-SC (7) 5,712.65 MWD+IFR-AK-CAZ-SC (7) 5,783.77 MWD+IFR-AK-CAZ-SC (7) 5,855.26 MWD+IFR-AK-CAZ-SC (7) 5,926.69 MWD+IFR-AK-CAZ-SC (7) 5,997.36 MWD+IFR-AK-CAZ-SC (7) 6,067.03 MWD+IFR-AK-CAZ-SC (7) 6,134.45 MWD+IFR-AK-CAZ-SC (7) 6,198.46 MWD+IFR-AK-CAZ-SC (7) 6,259.16 MWD+IFR-AK-CAZ-SC (7) 9/8/2016 1:25.40PM Page 6 COMPASS 5000.1 Build 74 Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS (usft) (°) (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') 10,731.14 90.84 0.12 6,272.99 6,125.49 494.87 -5,838.27 5,930,208.17 1,615,095.03 8.33 10,824.23 90.48 2.06 6,271.91 6,124.41 587.93 -5,836.50 5,930,301.22 1,615,097.04 2.12 10,919.63 90.62 3.55 6,271.00 6,123.50 683.21 -5,831.83 5,930,396.48 1,615,101.95 1.57 11,013.21 91.14 3.98 6,269.56 6,122.06 776.58 -5,825.69 5,930,489.82 1,615,108.33 0.72 11,109.04 91.07 4.87 6,267.71 6,120.21 872.10 -5,818.29 5,930,585.32 1,615,115.97 0.93 11,203.72 90.72 6.20 6,266.23 6,118.73 966.33 -5,809.16 5,930,679.51 1,615,125.35 1.45 11,298.73 90.14 6.77 6,265.52 6,118.02 1,060.72 -5,798.43 5,930,773.87 1,615,136.32 0.86 11,393.68 90.35 8.91 6,265.11 6,117.61 1,154.78 -5,785.48 5,930,867.88 1,615,149.51 2.26 11,487.91 90.24 9.64 6,264.63 6,117.13 1,247.78 -5,770.29 5,930,960.83 1,615,164.94 0.78 11,581.57 90.04 10.58 6,264.40 6,116.90 1,339.98 -5,753.85 5,931,052.98 1,615,181.61 1.03 11,677.85 89.83 10.96 6,264.51 6,117.01 1,434.57 -5,735.86 5,931,147.51 1,615,199.85 0.45 11,773.16 90.48 11.01 6,264.25 6,116.75 1,528.13 -5,717.70 5,931,241.01 1,615,218.25 0.68 11,866.04 90.86 12.26 6,263.17 6,115.67 1,619.09 -5,698.97 5,931,331.92 1,615,237.21 1.41 11,962.22 90.86 14.79 6,261.72 6,114.22 1,712.59 -5,676.48 5,931,425.35 1,615,259.94 2.63 12,056.22 91.10 15.80 6,260.11 6,112.61 1,803.24 -5,651.69 5,931,515.93 1,615,284.96 1.10 12,150.60 90.42 15.34 6,258.86 6,111.36 1,894.15 -5,626.36 5,931,606.76 1,615,310.53 0.87 12,244.02 89.90 14.92 6,258.60 6,111.10 1,984.33 -5,601.97 5,931,696.87 1,615,335.14 0.72 12,339.56 90.52 15.91 6,258.25 6,110.75 2,076.43 -5,576.58 5,931,788.90 1,615,360.77 1.22 12,434.41 91.07 16.78 6,256.94 6,109.44 2,167.44 -5,549.89 5,931,879.83 1,615,387.69 1.09 12,529.38 90.52 18.61 6,255.62 6,108.12 2,257.90 -5,521.03 5,931,970.21 1,615,416.78 2.01 12,624.72 91.07 18.82 6,254.29 6,106.79 2,348.19 -5,490.44 5,932,060.41 1,615,447.60 0.62 12,719.84 91.55 17.49 6,252.12 6,104.62 2,438.55 -5,460.81 5,932,150.68 1,615,477.46 1.49 12,813.56 91.34 18.34 6,249.76 6,102.26 2,527.70 -5,431.99 5,932,239.74 1,615,506.51 0.93 12,907.48 91.44 17.25 6,247.48 6,099.98 2,617.10 -5,403.30 5,932,329.06 1,615,535.43 1.17 13,003.04 91.55 15.76 6,244.98 6,097.48 2,708.68 -5,376.16 5,932,420.57 1,615,562.80 1.56 13,096.21 91.48 14.64 6,242.52 6,095.02 2,798.56 -5,351.74 5,932,510.37 1,615,587.45 1.20 13,191.72 90.89 14.47 6,240.55 6,093.05 2,690.99 -5,327.74 5,932,602.73 1,615,611.69 0.64 13,286.00 91.00 13.72 6,238.99 6,091.49 2,982.42 -5,304.79 5,932,694.09 1,615,634.88 0.80 13,379.04 90.86 11.12 6,237.48 6,089.98 3,073.26 -5,284.78 5,932,784.87 1,615,655.11 2.80 13,475.45 91.55 10.15 6,235.45 6,087.95 3,167.99 -5,266.99 5,932,879.54 1,615,673.15 1.23 13,569.02 91.72 8.48 6,232.78 6,085.28 3,260.28 -5,251.85 5,932,971.79 1,615,688.52 1.79 13,662.82 91.48 8.11 6,230.16 6,082.66 3,353.07 -5,238.32 5,933,064.53 1,615,702.29 0.47 13,757.69 92.58 6.51 6,226.80 6.,079.30 3,447.10 -5,226.26 5,933,158.52 1,615,714.59 2.05 13,852.49 92.52 7.30 6,222.59 6,075.09 3,541.12 -5,214.88 5,933,252.50 1,615,726.22 0.83 13,947.88 90.83 7.50 6,219.80 6,072.30 3,635.67 -5,202.59 5,933,347.01 1,615,738.74 1.78 14,042.34 90.00 7.47 6,219.11 6,071.61 3,729.32 -5,190.29 5,933,440.62 1,615,751.29 0.88 14,136.63 88.32 9.07 6,220.50 6,073.00 3,822.62 -5,176.73 5,933,533.87 1,615,765.09 2.46 14,231.28 85.61 11.73 6,225.51 6,078.01 3,915.57 -5,159.67 5,933,626.77 1,615,782.38 4.01 14,326.47 82.79 15.04 6,235.13 6,087.63 4,007.67 -5,137.76 5,933,718.81 1,615,804.53 4.55 14,421.97 84.65 17.28 6,245.58 6.,098.08 4,098.84 -5,111.34 5,933,809.90 1,615,831.18 3.04 Vertical Section (ft) Survey Tool Name 3,681.65 MWD+IFR-AK-CAZ-SC (7) 3,757.73 MWD+IFR-AK-CAZ-SC (7) 3,834.03 MWD+IFR-AK-CAZ-SC (7) 3,907.91 MWD+IFR-AK-CAZ-SC (7) 3,982.89 MWD+IFR-AK-CAZ-SC (7) 4,055.81 MWD+IFR-AK-CAZ-SC (7) 4,127.98 MWD+IFR-AK-CAZ-SC (7) 4,198.62 MWD+IFR-AK-CAZ-SC (7) 4,267.13 MWD+IFR-AK-CAZ-SC (7) 4,334.28 MWD+IFR-AK-CAZ-SC (7) 4,402.53 MWD+IFR-AK-CAZ-SC (7) 4,469.85 MWD+IFR-AK-CAZ-SC (7) 4,534.69 MWD+IFR-AK-CAZ-SC (7) 4,599.52 MWD+IFR-AK-CAZ-SC (7) 4,660.71 MWD+IFR-AK-CAZ-SC (7) 4,721.80 MWD+IFR-AK-CAZ-SC (7) 4,782.83 MWD+IFR-AK-CAZ-SC (7) 4,844.88 MWD+IFR-AK-CAZ-SC (7) 4,905.29 MWD+IFR-AK-CAZ-SC (7) 4,964.04 MWD+IFR-AK-CAZ-SC (7) 5,021.68 MWD+IFR-AK-CAZ-SC (7) 5,079.91 MWD+IFR-AK-CAZ-SC (7) 5,137.60 MWD+IFR-AK-CAZ-SC (7) 5,195.56 MWD+IFR-AK-CAZ-SC (7) 5,256.21 MWD+IFR-AK-CAZ-SC (7) 5,316.96 MWD+IFR-AK-CAZ-SC (7) 5,380.06 MWD+IFR-AK-CAZ-SC (7) 5,442.92 MWD+IFR-AK-CAZ-SC (7) 5,506.94 MWD+IFR-AK-CAZ-SC (7) 5,575.43 MWD+IFR-AK-CAZ-SC (7) 5,643.39 MWD+IFR-AK-CAZ-SC (7) 5,712.65 MWD+IFR-AK-CAZ-SC (7) 5,783.77 MWD+IFR-AK-CAZ-SC (7) 5,855.26 MWD+IFR-AK-CAZ-SC (7) 5,926.69 MWD+IFR-AK-CAZ-SC (7) 5,997.36 MWD+IFR-AK-CAZ-SC (7) 6,067.03 MWD+IFR-AK-CAZ-SC (7) 6,134.45 MWD+IFR-AK-CAZ-SC (7) 6,198.46 MWD+IFR-AK-CAZ-SC (7) 6,259.16 MWD+IFR-AK-CAZ-SC (7) 9/8/2016 1:25.40PM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: 2S-13: 120+27.5 @ 147.50usft (Doyonl41) Well: 25-13 North Reference: True Wellbore: 25-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,515.58 86.61 20.50 6,252.71 6,105.21 4,187.13 -5,081.13 5,933,898.10 1,615,861.62 4.02 6,315.35 MWD+IFR-AK-CAZ-SC (7) 14,610.34 87.98 20.34 6,257.18 6,109.68 4,275.84 -5,048.10 5,933,986.71 1,615,894.87 1.46 6,370.31 MWD+IFR-AK-CAZ-SC (7) 14,704.49 89.15 19.91 6,259.54 6,112.04 4,364.21 -5,015.72 5,934,074.99 1,615,927.48 1.32 6,425.35 MWD+IFR-AK-CAZ-SC (7) 14,799.41 89.41 19.22 6,260.73 6,113.23 4,453.64 -4,983.94 5,934,164.33 1,615,959.49 0.78 6,481.61 MWD+IFR-AK-CAZ-SC (7) 14,895.32 91.25 18.38 6,260.18 6,112.68 4,544.43 -4,953.03 5,934,255.03 1,615,990.63 2.11 6,539.48 MWD+IFR-AK-CAZ-SC (7) 14,989.43 91.31 18.21 6,258.08 6,110.58 4,633.76 -4,923.49 5,934,344.28 1,616,020.39 0.19 6,596.92 MWD+IFR-AK-CAZ-SC (7) 15,083.19 91.41 17.67 6,255.85 6,108.35 4,722.94 -4,894.62 5,934,433.37 1,616,049.49 0.59 6,654.59 MWD+IFR-AK-CAZ-SC (7) 15,179.49 91.48 17.08 6,253.42 6,105.92 4,814.81 -4,865.87 5,934,525.16 1,616,078.47 0.62 6,714.58 MWD+IFR-AK-CAZ-SC (7) 15,274.31 91.44 16.03 6,251.01 6,103.51 4,905.67 -4,838.87 5,934,615.94 1,616,105.71 1.11 6,774.69 MWD+IFR-AK-CAZ-SC (7) 15,367.68 91.51 15.84 6,248.61 6,101.11 4,995.42 -4,813.24 5,934,705.62 1,616,131.57 0.22 6,834.66 MWD+IFR-AK-CAZ-SC (7) 15,462.72 91.58 15.61 6,246.04 6,098.54 5,086.87 -4,787.49 5,934,796.99 1,616,157.55 0.25 6,895.98 MWD+IFR-AK-CAZ-SC (7) 15,558.50 91.96 15.61 6,243.08 6,095.58 5,179.08 -4,761.73 5,934,869.12 1,616,183.54 0.40 6,957.90 MWD+IFR-AK-CAZ-SC (7) 15,653.21 91.48 15.24 6,240.24 6,092.74 5,270.33 -4,736.55 5,934,980.30 1,616,208.96 0.64 7,019.37 MWD+IFR-AK-CAZ-SC (7) 15,749.41 91.07 15.44 6,238.10 6,090.60 5,363.08 -4,711.11 5,935,072.98 1,616,234.64 0.47 7,081.93 MWD+IFR-AK-CAZ-SC (7) 15,844.81 91.75 15.94 6,235.75 6,088.25 5,454.90 -4,685.32 5,935,164.72 1,616,260.66 0.88 7,143.52 MWD+IFR-AK-CAZ-SC (7) 15,938.66 92.06 16.67 6,232.63 6,085.13 5,544.92 -4,658.98 5,935,254.66 1,616,287.23 0.84 7,203.33 MWD+IFR-AK-CAZ-SC (7) 16,031.05 92.51 16.66 6,228.95 6,081.45 5,633.36 -4,632.51 5,935,343.03 1,616,313.92 0.49 7,261.74 MWD+IFR-AK-CAZ-SC (7) 16,123.74 92.10 18.02 6,225.22 6,077.72 5,721.77 -4,604.91 5,935,431.35 1,616,341.75 1.53 7,319.49 MWD+IFR-AK-CAZ-SC (7) 16,220.59 91.34 19.37 6,222.31 6,074.81 5,813.46 -4,573.88 5,935,522.95 1,616,373.02 1.60 7,378.04 MWD+IFR-AK-CAZ-SC (7) 16,316.73 91.00 20.77 6,220.35 6,072.85 5,903.74 -4,540.89 5,935,613.14 1,616,406.23 1.50 7,434.33 MWD+IFR-AK-CAZ-SC (7) 16,410.44 91.17 21.14 6,218.58 6,071.08 5,991.24 -4,507.39 5,935,700.54 1,616,439.96 0.43 7,488.02 MWD+IFR-AK-CAZ-SC (7) 16,505.92 91.00 21.15 6,216.77 6,069.27 6,080.27 -4,472.95 5,935,789.48 1,616,474.62 0.18 7,542.46 MWD+IFR-AK-CAZ-SC (7) 16,599.43 91.34 21.04 6,214.86 6,067.36 6,167.50 -4,439.30 5,935,876.61 1,616,508.49 0.38 7,595.84 MWD+IFR-AK-CAZ-SC (7) 16,694.27 91.96 21.19 6,212.13 6,064.63 6,255.93 -4,405.15 5,935,964.95 1,616,542.87 0.67 7,649.95 MWD+IFR-AK-CAZ-SC (7) 16,785.89 92.34 21.77 6,208.69 6,061.19 6,341.13 -4,371.63 5,936,050.05 1,616,576.61 0.76 7,701.72 MWD+IFR-AK-CAZ-SC (7) 16,867.00 92.34 21.77 6,205.38 6,057.88 6,416.39 -4,341.57 5,936,125.22 1,616,606.86 0.00 7,747.21 PROJECTED to TD 6-3/4" open hole 9/8/2016 1:25:40PM Page 7 COMPASS 5000.1 Build 74 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. L, Yes L No I have checked to the best of my ability that the following data is correct: J Surface Coordinates 1J Declination & Convergence (L GRS Survey Corrections LJ Survey Tool Codes Vincent ,.db D a <_� yv—,o.. DN: cry-Yincmt Ehara, o-SchWnhe9e', Asara°^mit au=Scml berger. vosratTsAmm. r -US SLB DE_ D w.'2016MM 113517406W Scott Brunswick 4 ��,Hw Client Representative: : t15 Date: 09 -Seg -2016 THE STATE Alaska Oil and Gas of A LASKA Conservation Commission GOVERNOR BILL WALKER Graham Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S -13L1 Permit to Drill Number: 215-152 Sundry Number: 316-431 Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov 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 P oerster Chair DATED this lS day of September, 2016. RBDMS �v SEE 19 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED AUG 23 2016 ATS 91isI/( AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑✓ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ Strati ra hic g p ❑ Service PTD 215-152 / semdr9-9,E�73 3. Address: 6. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 50-103-20720-60-00 a 7. If perforating: 8. Well Name and Number: KRU 2S-131_1 What Regulation or Conservation Order governs well spacing in this pool? NnC Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool - ADL 25603, 25590 ' 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): 16878.5 6216.9 9926.5 6261.5 3129 RHC 9758' 9926.5 Casing Length Size MD TVD Burst Collapse Structural 78' 20" 117.5 117.5 Conductor 78' 20" 117.5 117.5 Surface 2807.7' 13.375" 2847.1 2559.3 5020 2260 Intermediate 6631.84' 10.75" 9329.5 6029.5 5210 2470 Production 10407.83 7.625" 10445.72 6331.5 6890 4790 Liner 6860.34 4.5" 16841.11 6245.5 8000 6350 Perforation Depth MD (ft): Perforation Depth TVD (74-1'/2" ing Size: Tubing Grade: Tubing MD (ft): N/A N/A x 3-1/2" L-80 9811.5 Packers and SSSV Type: FHL Retreivable Packers and SSSV MD (ft) and TVD (ft): 9710.3 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 10/1/2016 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17. 1 hereby certify that the foregoing is true and the procedure approved Scott B unser k 2633--4249 / herein will not be deviated from without prior written approval. Contact p - �7 ` f� Email scott.a.brunswick(cr�cop.com // Printed Name & "7`�r,� Title 24-5-41-20 Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: :?D`�e-�� Plug Integrity El BOP Test 1� Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No [ Spacing Exception Required? Yes ❑ No Subsequent Form Required: J d - 4 RBDMS 1,L- SEP 19 2016 APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: / �/ f1_ � �� � Submit Form and Form 10-403�F2esed 11/2615 0 r a I a n s valid for 12 months from the date of appy Attachments in Duplicate q 11(0 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 23, 2016 ConocoPhillips p RECEIVED Alaska Oil and Gas Conservation Commission AUG 2 3 2016 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 A OGCC Re: Sundry Permit -- Request to plug for re -drill KRU 2S-13 & KRU 2S-131_1 laterals (PTD215-152) Dear Sir or Madam: Well 2S-13 was spudded in November 2015, however, ConocoPhillips encountered problems pulling the whipstock assembly out of the 7-5/8" production casing after drilling to TD of the 2S -13L1 lateral. Numerous fishing attempts were performed trying to fish the whipstock out of the hole in order to complete the well as designed with no success. ConocoPhillips requested & gained approval to shutdown operations (Sundry 316-073), run a kill string, and suspend the wellbore for a future return to fish the whipstock, regaining access to the 2S-13 lower lateral, and attempt to run the liner in the 2S -13L1 upper lateral & complete the well as permitted under 215-152. While the rig was away, ConocoPhillips was able to run a downhole camera to evaluate the condition of the whipstock & window. The camera images showed shale collapsed onto the whipstock to the point the whipstock could not be seen. Due to the condition of the window & risk of fishing, ConocoPhillips current plan is to abandon the 2S-13 & 2S -13L1 laterals. Once cement has been pumped to abandon the laterals with Doyon142, the operation will be to cut & pull 7-5/8" casing in order to use a whipstock in the 10-3/4" liner & re -drill the intermediate #2 hole section. A 7-5/8" liner will be run & set into the Kuparuk formation with a tieback string back to surface. Once this operation is complete, the well will be set up to drill the multi -lateral as originally planned. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10-403 2. 2S-13 & 2S -13L1 Abandonment Procedure 3. 2S-13 & 2S-131-1 Suspension Schematic Application information already on file with 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 Scott Brunswick at 263-4249 (Scott.A.Brunswick(cDconocophillips.com) or Chip Alvord at 265-6120. Sincerely, Scott Brunswick Drilling Engineer Doyon 142 KRU 2S-13 & KRU 2S-131-1 Abandonment Procedure The proposed scope of work for this sundry application includes: 1. Move Doyon rig 142 & rig up over well KRU 25-13. 2. Displace wellbore through the tubing kill string over the kill weight fluid. 3. Perform 30 -minute flow check ensuring wellbore is killed. 4. Rig down tree & rig up BOPE. 5. Perform full BOPE test. 6. Pull tubing kill string & lay down. 7. Pick up 4" drillpipe. 8. RIH with 3-1/2" tubing cement stinger & cement retainer. 9. Set cement retainer at +/- 9811.5' MD (+/- 9800' D141 RKB MD). (top of window at 9926.5' MD (9915' D141 RKB MD)) a. Note: For reference all depths are Doyon 142 RKB reference unless specified & have included Doyon 141 original depths for reference if cross correlated with previously submitted reports. Difference in RKB between Doyon 142 & Doyon 141 is 11.5', Doyon 142 rig floor is higher than Doyon 141. 10. Sting out, pressure test to 3500 psi for 10 minutes. a. 20 AAC 25.112 (3) by the downsqueeze method using a production packer set no less than 50 feet but no more than 500 feet above the casing shoe, a volume of cement sufficient to fill the wellbore from 100 feet below the casing shoe to the packer must be pumped through the packer, and cement must be pumped above the packer to cap it with a 50 foot cement plug. 11. Establish circulation. 12. Sting in, initiate injection. 13. Sting out & begin pumping cement. Cement down squeeze & cement cap volumes Cement from 10,111.5' MD (placing 185' MD cement below top of window) to retainer at 9,811.5' MD (115' above top of window), & 100' MD cap on top of retiner with 15.8 ppg Class G. Assume 40% excess open hole volume. Tail slurry: (10,111.5' - 9,926.5') X 0.24826 ft3/ft X 1.4 (40% excess) = 65 ft' below window annular volume (9,926.5'- 9,811.5') X 0.24826 ft3/ft = 29 ft' above window to retainer volume Total volume squeezed = 65 + 29 = 94 ft' => 81 Sx @ 1.17 ft3/sk (9,811.5' - 9,711.5') X 0.24826 ft3/ft = 25 ft' cap on top of retainer Total cap volume = 25 ft' => 22 Sx @ 1.17 ft3/sk System: 103 Sx 15.8 ppg Class G 14. Sting back in prior to cement reaching end of tubing. 15. By the down squeeze method, pump cement injecting 81 sx 15.8 ppg class G cement below the retainer injecting into formation. a. If injection locks up, sting out & lay remaining cement in the string on top of cement retainer as cap. 16. Sting out & lay in a minimum of 50' cement cap on top of cement retainer. Target a 100' cement cap. 17. Pick up above cement & circulate casing clean. v a. WOC to tag (notify AOGCC for opportunity to witness tag of cement) V �.}-y`C A 18. Pressure test to 3500 psi for 10 minutes. 19. POOH & lay down cement stinger. 20. RIH with casing cutter & cut 7-5/8" casing at +/- 9186.5' ( D141 RKB MD 9175' MD) (logged TOC is 9201.5' (D141 RKB MD 9190' MD in the 7-5/8" x 10-3/4" annulus)). 21. Pull casing cutter out of hole & lay down. 22. Establish circulation through the casing cut swapping out fluid in the 7-5/8" x 10-3/4" annulus over to the kill weight fluid (current fluid is freeze protection). 23. Monitor IA & OA fluid for flow ensuring static. 24. Pull 7-5/8" casing & lay down. 25. Lay down 4" drillpipe & pick up 5" drillpipe. 26. Pick up casing scraper clean out BHA & TIH cleaning out 10-3/4" liner for proper 10-3/4" whipstock placement & setting. 27. POOH & lay down clean out BHA. a. Possible E -Line logging run to determine location of casing centralizers on the 10-3/4" liner. This will assist drive proper location of window within the casing joint. 28. Pick up & RIH with 10-3/4" whipstock BHA. 29. Set whipstock with bottom of window being placed at +/- 9141.5' MD / 5945' TVD (D141 RKB MD 9130' MD / 5933.5' TVD). a. Note the depths in this procedure may change slightly based on actual location of casing collars & centralizers on the 10-3/4" liner. A logging run be performed to determine exactly where the centralizers may be on the outside of the 10-3/4" liner. 30. Set whipstock with a high left orientation & mill window (20-30° left of high side). 31. Once window has been milled creating +/- 20' of rat hole, dress off window with mills. 32. Perform FIT with milling BHA in the hole ensuring a minimum of 13.0 ppg LOT and maximum of 16.0 ppg FIT. 33. POOH & lay down milling BHA. 34. Pick up 9-7/8" directional BHA for drill a 9-7/8" intermediate #2 hole section to TD landing in the Kuparuk A4 sand. (LWD: GR/RES) 35. RIH & slide steerable tool to bottom. 36. Orient & begin drilling intermediate #2 hole section a. Once drilling with BHA begin new permit to drill. Figure 1: Existing Wellbore Schematic 2S-13 Grassroots Horizontal A -Sand Injector Conoc®Phillips Existing Wellbore Schematic D142 RKB tTop Kuparuk C 9,933.5' MD /6,263.5' TVD I Whipstock Top of Window 9,926.5' MD / 6,261.5' TVD 9-7/8" Intermediate #2 Hole I,' L I:• 7-5(8" Flex Lock Liner Hanq2r 1 ZXP Last Edited: SAB -8/22/16 Kuparirk'A3i 7Q 2615'MD./_6,323STVD '_ 20" Conductor to -117.5' a_____ _ _______ _ -- I: 16" Surface Hole a E a 2SF13•A3:TD:16, 649.MD:/6233 TV,D::;: N —.1 Packer @ 106)55 Swell Packer a t 6603, S 1 Intermediate Casina 4-11Y" IBTM kill string ' 7-518" 29.7# J L-80 Hyd563 Casing 10,445.7' MD /6,331.5' TVD (89°) 2S-13PB1 (9-718" Intermediate #2 Pilot Hole plugged w/cement) Surface Casina 13-3/8 68# L-80 HYD 563 LA 2,847.1' MD / 2,559.3' TVD 12-1/4" X 13-1/2" Intermediate #1 Hole I. 10-3/4" TOC Planned: 5,491.5' (at minimum 500' M D above C37) 'ty::.C-3768515,• s. . MD/4,659:5'TVD 4-,'/V (BTM XO:td V/:"EUE tubing tall.::::: 7.5 TVD: :: -. wProtect;: ';:; ;�; :_Top air 8; 217;5MD-Y5,;443.5'TVD.,:- TciBdrrh=ia 837:1:5` M01:5,529.5' TVD : - 7-5/8 Logged TOC: 9,201.6 MD / 5,962.5'TVD 10-3/4" INT #1 Liner 9,329.5' MID 16.029.6 ND - HRZ9,2'17:5MD/5,974.5'TVO 3-% x 7-5/8 FHL Retrievable Packer Lower Kakrbik (K-.1 Marker);9,650.5' MD 16,173.5' TVD ` -9,710.3' MD a t 3-W, EUE tubing, tall Q -9611:5' tTop Kuparuk C 9,933.5' MD /6,263.5' TVD I Whipstock Top of Window 9,926.5' MD / 6,261.5' TVD 9-7/8" Intermediate #2 Hole I,' L I:• 7-5(8" Flex Lock Liner Hanq2r 1 ZXP - Kuparirk'A3i 7Q 2615'MD./_6,323STVD '_ a_____ _ _______ _ -- I: 2SF13•A3:TD:16, 649.MD:/6233 TV,D::;: —.1 Packer @ 106)55 Swell Packer a t 6603, S 1 Intermediate Casina 6-3/4" Production Hole ' 7-518" 29.7# J L-80 Hyd563 Casing 10,445.7' MD /6,331.5' TVD (89°) 2S-13PB1 (9-718" Intermediate #2 Pilot Hole plugged w/cement) 10.314.5' MD / 6.597.5' TVD l--iaure 2'. cost rrmosea vvorK VVeIIDore JCnemaUC 2S-13 & 2S -13L1 Abandonment Grassroots Horizontal A -Sand Injector Proposed Wellbore Schematic D142 RKB ConocoPhillips 20" Conductor to — 117.5' Last Edited: SAB -8/22/16 16" Surface Hole Surface Casing 13-3/8" 68# L-80 HYD 563 2,847.1' MD / 2,559.3' TVD s c� 12-1/4" X 13-1/2" Intermediate #1 Hole ' t Intermediate Casing 6-314" Production Hole ' J 7-5/8" 29.7# L-80 Hyd563 Casing 10,445.7' MD / 6,331.5' TVD (89°) 2S-13 P131 (9-7/8" Intermediate #2 Pilot Hole plugged w/cement) 10,314.5' MD / 6,597.5' ND 10-3/4" Planned TOC: 5,480' (at minimum 500' MD above C37) . . . . . . . . . . . . . . . . . . . - - C:376,851.5'MD./4;6$9;5'TVD. ::: Grbv✓ler-Aiti. Icebe i 7 233:5' MD /:4 667.5 TVD: = fvIDJ�5,443.5 7-5ie" casing cut g9186.5'MD : T4 Berinida:: 8; 371.5':MD'J�5,S29.5' IVD, :::: y J 7-5/8 Logged TOC: 9,201.6 MD/ 5,962.5'TVD _____ CementF,judr.91 -.7W Cap Topg Cap Top MD 10-3/4" INT #1 Liner 9,329.5- MD 16,029-5- TVD HRL9,211.6 MD 15.974.5 -TVD Laver Kalubk (K-1 Marker). 9,650.5'MD 16,173.5' TVC a Cement Retainer @ 9811.5' MD - Top Kuparuk C 9,933.5' MD /6,263.5' TVD i Whipstock Top of Window 9,926.5' MD /6,261.5' TVD \ 9-7/8" Intermediate #2 Hole Cement Abandon Kuparuk A4::9963-'S'M¢/6271,5'TVD:-'•:-: Squeeze Bottom __.__.�__.________________ Plug 10111.5'MD 6 2S-131-1 PB2 A4 Lateral TD:16,878.5' MD /6,216.9 TVD 6 ; ' t Intermediate Casing 6-314" Production Hole ' J 7-5/8" 29.7# L-80 Hyd563 Casing 10,445.7' MD / 6,331.5' TVD (89°) 2S-13 P131 (9-7/8" Intermediate #2 Pilot Hole plugged w/cement) 10,314.5' MD / 6,597.5' ND Figure 3: 2S-13 Post New PTD Wellbore Schematic ®13 Dual Lat Recovery_ Grassroots Horizontal A -Sand Injector W®noConrhi"ips Proposed Wellbore Schematic D142 RKB Last Edited: SAB -8/22/16 20" Conductor to - 117.5' 16" Surface Hole 4-1W' 1 BTM Tbing Surtace Casina 13-3/8 68# L-80 HYD 563 2,847.1' MD / 2,559.3' TVD 10-3/4" Planned TOC: 5,491.5'(at minimum 12-1/4" X 13-1/2" Intermediate #1 Hole 500' MD above C37) eL C-376,851>5' MD /4:659,5'.NP' �.7-5/8"x:10-'/."�Lrnei•T•Recker9939.5`MDLS"t7375'TVD ,�:GrowlerAA� Iceber :'7,233:5':MD'%4,8675'l'VD:- ' .TopCam 9217;$MD754435 TVD a. I I _ Too Bermuda.:8;371 5 Mb/.5,5295 TVD: Swell Packer@1MX SwNl Packer�l6X%x Intermediate Casina 7-5/8" 29.7# L-80 Hyd663 Casing 10,832.5' MD / 6-3/4" Production Hole 6,368.5' TVD (91°) Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, September 14, 2016 2:42 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2S-13(PTD 215-151) Plug for Redrill Updated a 10-403 to reflect the 2S-13 name & API, etc as the one I sent over had 2S-131_1 and gave a copy of the letter & form to Ann just now to be sent over. She'll probably wait until normal delivery tomorrow morning. From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, September 14, 2016 2:15 PM To: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]KRU 2S-13(PTD 215-151) Plug for Redrill Scott, Since the mother bore will also be abandoned in this plug for redrill(PFR), we will need a 10-403 for a plug for redrill of KRU 2S-13 in addition to the plug for redrill you have already submitted on KRU 2S-131-1. The submission for PFR for 2S- 13 would be the same as what you have already submitted for 2S -13L1 with the exception of the 10-403 form which will have KRU 2S-13 information. Hope this makes sense. Call me with questions. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppp_alaska.gov 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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.aov 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 Geologist 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. STATE OF ALASKA AL .(A OIL AND GAS CONSERVATION COMM. 3ION REPORT OF SUNDRY WELL OPERATIONS 1. operations Abandon �� Plug Perforations �Fracture Stimulate', Pull Tubing 'F" Operations Shutdown Fv— Performed: Suspend F Perforate ; Other Stimulate I,..... Alter Casing _... Change Approved Program Plug for Redrill F_ Perforate New Pool F_ Repair Well F_ Re-enter Susp Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory Stratigraphic Service W,50-103-20720-60 215-152/316-073 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25603. AD: 25590 KRU 2S-131_1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Casing Caliper, GR/Res/Den/Neu/LWD Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 16867 feet Plugs (measured) None true vertical 6205 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 9968, 9699 true vertical 0 feet (true vertical) 6263, 9699 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108 108 SURFACE 2808 133/8 2835 2548 SURFACE 6624 103/4 9318 6018 INTERMEDIATE 9921 75/8 9947 6320 SLOTTED LINE[ 6860 41/2 16829 6234 RECEIVED Perforation depth: Measured depth: 0 True Vertical Depth: 0 LIAR 0 3 2015 AOGCR= Tubing (size, grade, MD, and TVD) Suspension String: 4 1/2, L-80, 9802 MD, 6218 TVD Packers & SSSV (type, MD, and TVD) PACKER -HRD-E ZXP Liner Top Packer @ 9969 MD, 6263 TVD PACKER - BAKER 47D2 FHL Retrievable packer, 60K shear release @ 9699 MD and 6183 TVD, SSV: NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): Cement Plug @ 9710-10303, Cement Plug @ 9117-9710 (KRU 2S-13 PB1) Treatment descriptions including volumes used and final pressure: 31 bbls 13.0 ppg MPII @ 4.4 PBM, 575 PSI 66 BBLS OF 17.0 PPG Cement w/1.5 ppb CemNet @ 4bpm, 475-40 psi SEE ATTACHED SCHEMATIC FOR COMPLETE PLUG DETAILS 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation SHUT-IN Subsequent to operation SHUT-IN 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations W Exploratory F Development F Service fv— Stratigraphic F 16. Well Status after work: ""' Oil � Gas � WDSPL Copies of Logs and Surveys Run Printed and Electronic Fracture Stimulation Data F GSTOR F WINJ �WAG GINJ l' SUSP SPLUG F- 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 316-073 Contact Scott Brunswick () 263-4249 Email scott.a.brunswick(cDcop.com Printed Name Scott Brunswick Title Sr. Drilling Engineer Signature Phone: 263-4249 Date Form 10-404 Revised 5/2015 �` /l 6BDy S Lt, MAR 0 4 2016 Submit Original Only z e - Cement Detail Report 2S-13 String: Cement Plug Job: DRILLING ORIGINAL, 11/28/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug 12/17/2015' 12/17/2015 19:30 2S-13 Comment Batch up & pump 5 bbls of 13.0 ppg MPII to flood lines. PT lines 400 / 4000 psi. Pump 25 bbls of 13.0 ppg MPII @ 3.4 bpm, 460 psi. Load wiper ball in pipe & batch up cement. Pump 70 bbls of 15.8 ppg cement w/ 1.5 ppb CemNet @ 4.4 bpm, 430-100 psi. Pump 5.3 bbls of 13.7 MPII @ 3.5 bpm, 30 psi. Swap to rig & displace with 156 bbls of 11.9 ppg mud @ 4.5 bpm, 125-780 psi. CIP 19:28 hrs. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Plug 9,710.0 10,303.0 No No 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) 5 5 5 780.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Plug back Intermediate #2 pilot hole. Cement Fluids &Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Plug Back Cement 9,710.0 10,303.0 338 G 70.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.08 15.80 94.3 6.20 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder ID177 1 0.015 gal/sx Page 1/1 Report Printed: 3/1/2016 Cement Detail Report 2S-13 String: Cement Plug Job: DRILLING ORIGINAL, 11/28/2015 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug 12/17/2015, 12/18/2015 00:40 2S-13 Comment Pump 31 bbls 13.0 ppg MPII @ 4.4 bpm, 575 psi. Shut down to batch up cement, load wiper ball in pipe. Pump 66 bbls of 17.0 ppg cement w/ 1.5 ppb CemNet @ 4 bpm, 475-40 psi. Pump 7 bbls of 13.0 ppg MPII @ 3 bpm, 10 psi. Swap to rig to displace 143 bbls with 11.9 ppg mud @ 4.5 bpm, 120-800 psi. CIP @ 00:40 hrs. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Plug 1 9,117.0 9,710.0 No No 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) 4 5 5 800.0 1 No I No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment KOP for intermediate # 2. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Plug Back Cement 9,117.0 9,710.0 371 G 66.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.00 3.86 17.00 175.0 7.40 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.9 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder ID177 1 0.015 gal/sx Page 1/1 Report Printed: 3/1/2016 ConocoPhillips Alaska. Ira;, KUP SVC Well Attribut Max Wellbore APIIUWI Fill Name Wellbore Status ncl (°) 501032072060 KUPARUK RIVER UNIT SVC 92 Comment HIS (ppm) Date Annotation End Date SSSV: NONE I I Last W0: 2S -13L1 Ji TD 2/6/2016 Verb.] malty e Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: NEW WELL; GLV C/0 lehallf 2/24/2016 ............................_................................................... Notes:Gen—e—r—aTTS—aTeWy End Date Annotation HANGER; 23.8 .................................................................. ................... NOTE: Do not use for production or injection in current state. CONDUCTOR; 27.6107.5 SURFACE, 27.3-2.835.0 GAS LIFT, 3,479.2 SURFACE; 2,693.9-9,318.0 XO Enie,,rg; 9,685.6 PACKER; 9,698.8 NIPPLE; 9,758.4 SHOE; 9,8015 INTERMEDIATE; 26.2-10,434.0 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time. Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 11/28/2015 11/28/2015 1.25 MIRU MOVE MOB P Move boiler, motor, pump, & pits 0.0 0.0 12:00 13:15 modules out of way to move sub base. Remove matting boards 11/28/2015 11/28/2015 0.50 MIRU MOVE MOB P Move sub base off of 2S-08 0.0 0.0 13:15 13:45 11/28/2015 11/28/2015 1.25 MIRU MOVE MOB P Move and spot sub over 2S-13 0.0 0.0 13:45 15:00 11/28/2015 11/28/2015 0.50 MIRU MOVE MOB P Set matting boards for modules. 0.0 0.0 15:00 15:30 11/28/2015 11/28/2015 2.50 MIRU MOVE MOB P Move and spot pits, pump, motor and 0.0 0.0 15:30 18:00 boiler modules. Sim-ops/Change out two sub tires. 11/28/2015 11/28/2015 1.00 MIRU MOVE MOB P Set herculite. Move and spot 0.0 0.0 18:00 19:00 rockwasher 11/28/2015 11/28/2015 1.50 MIRU MOVE MOB P Set matting boards. Move and spot 0.0 0.0 19:00 20:30 pipe sheds. 11/28/2015 11/29/2015 3.50 MIRU MOVE RURD P Berm boiler complex. Set enviro-vac, 0.0 0.0 20:30 00:00 assemble mud pumps, set pipe skate. Hook up elecric, water, steam, air and mud lines.lnstall drain plugs in centrifugal pumps. Berm rock washer and install cuttings tank. Install landing and staire on pump room. 11/29/2015 11/29/2015 3.00 MIRU MOVE RURD P Work on rig acceptance check list. 0.0 0.0 00:00 03:00 Assemble mud pumps. Install landings under stairways. Hook up pipe shed tioga heater. Line up steam, air and water throughout rig. Trim herculite. Rig accepted @ 03:00 hrs 11/29/15 11/29/2015 11/29/2015 4.50 MIRU MOVE RURD P Lay down 4" handling and vendor 0.0 0.0 03:00 07:30 tools. Onboard mud into pits. Load BHA into pipe shed. Install surface riser. Test gas alarms. Hook up hydraulic hoses to diverter. Change out heads on iron roughneck. Install mousehole. Sim-ops/Energize seals and set slips on diverter adapter. Test same to 500 psi/15 mins. Witnessed by Co Man. 11/29/2015 11/29/2015 3.00 MIRU MOVE PULD P PU and stand back 72 jts of 5" DP. 0.0 0.0- 07:30 10:30 11/29/2015 11/29/2015 1.00 MIRU MOVE SFTY P Conduct pre spud meeting. 0.0 0.0 10:30 11:30 11/29/2015 11/29/2015 0.50 MIRU MOVE SFTY P Hold diverting shallow gas and rig 0.0 0.0 11:30 12:00 evacuation drill. 11/29/2015 11/29/2015 1.00 MIRU MOVE PULD P PU and stand back 18 jts of 5" DP. 0.0 0.0 12:00 13:00 Sim-ops/Function test diverter 11/29/2015 11/29/2015 1.00 MIRU MOVE BOPE P Perform diverter test, knife valve open 0.0 0.0 13:00 14:00 in 9 sec, annular closed in 18 sec. Accumulator test; system pressure 2900 psi, pressure after closure 1900, 200 psi recharge time 25 sec, full recharge time 123 sec. 5 nitrogen bottles averaged 1925 psi. Tested gas & pit level (gain/loss) alarms, good. Witnessed by AOGCC Rep Matt Herrera Page 1/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (MB) End Depth (MB) 11/29/2015 11/29/2015 1.00 MIRU MOVE PULD P PU and stand back 24 its of 5" DP. 0.0 0.0 14:00 15:00 11/29/2015 11/29/2015 0.50 MIRU MOVE RURD P Load into pipe shed and strap 5" 0.0 0.0 15:00 15:30 HWDP. 11/29/2015 11/29/2015 1.25 MIRU MOVE PULD P PU and stand back 24 its of 5" HWDP. 0.0 0.0 15:30 16:45 11/29/2015 11/29/2015 1.00 MIRU MOVE SLPC P Slip and cut 71' drilling line. 0.0 0.0 16:45 17:45 11/29/2015 11/29/2015 0.75 MIRU MOVE SVRG P Service rig. Lube top drive, blocks and 0.0 0.0 17:45 18:30 crown. Adjust link tilt rams 11/29/2015 11/29/2015 2.50 MIRU MOVE RURD P Change out top drive saver sub from 0.0 0.0 18:30 21:00 XT -39 to 4 1/2" IF. Change bell guide and grabbers. Safety wire all bolts. 11/29/2015 11/29/2015 0.75 MIRU MOVE BHAH P Mobilize BHA and handling tools to rig 0.0 0.0 21:00 21:45 floor 11/29/2015 11/29/2015 1.00 MIRU MOVE SFTY P Conduct pre spud meeting discussing 0.0 0.0 21:45 22:45 Well 2S-13, diverting shallow gas and rig evacuation. 11/29/2015 11/30/2015 1.25 MIRU MOVE SEQP P Fill conductor. Test mud lines to 3500 0.0 0.0 22:45 00:00 psi. 11/30/2015 11/30/2015 2.50 MIRU MOVE BHAH P MU BHA as per DD. Wash down and 0.0 107.0 00:00 02:30 tag @ 97' MD. Clean out to 107' MD. 11/30/2015 11/30/2015 1.75 SURFAC DRILL DDRL P Spud well, Drilled ahead f/ 107' MD to 107.0 221.0 02:30 04:15 221' MD. TVD=221', ADT= 1.27 hrs, Total bit hrs=1.27 Total Jar hrs= 0, Pump @ 500 gpm= 470 psi, 85% FO. Rotate @ 40 rpm's w/ 2K Tq on/ OK off. P/U= 45K, S/0= 45K, ROT= 45K. WOB= 8-10K. 11/30/2015 11/30/2015 2.25 SURFAC DRILL BHAH P Stand back 2 stands of 5" HWDP and 221.0 221.0 04:15 06:30 L/D XO. M/U X -O, arcVision, Telescope, UBHO, 2x 8" NMDC, and Jars. Wash to 221' MD. No fill 11/30/2015 11/30/2015 5.50 SURFAC DRILL DDRL P Drilled ahead f/ 221' MD to 459' MD. 221.0 459.0 06:30 12:00 TVD=456', ADT= 2.36 hrs, AST=1.23 hrs. Total bit hrs=3.63 Total Jar hrs= 19.84, Pump @ 500 gpm= 790 psi, 84% FO. Rotate @ 40 rpm's w/ 3K Tq on/ OK off. P/U= 65K, S/0= 65K, ROT= 65K. WOB= 25K. 11/30/2015 11/30/2015 6.00 SURFAC DRILL DDRL P Drilled ahead f/ 459' MD to 1008' MD. 459.0 1,008.0 12:00 18:00 TVD=1003', ADT= 4.29 hrs, AST=1.50 hrs. Total bit hrs=7.92 Total Jar hrs= 24.13, Pump @ 600 gpm= 1280 psi, 87% FO. Rotate @ 60 rpm's w/ 2-6K Tq on/ 2K off. P/U= 81 K, S/0= 81 K, ROT= 81 K. WOB= 20-25K. 11/30/2015 12/1/2015 6.00 SURFAC DRILL DDRL P Drilled ahead f/1008' MD to 1455' 1,008.0 1,455.0 18:00 00:00 MD. TVD=1431', ADT= 4.23 hrs, AST=2.91 hrs. Total bit hrs=12.15 Total Jar hrs= 28.36, Pump @ 600 gpm= 1400 psi, 84% FO. Rotate @ 60 rpm's w/ 4-1 OK Tq on/ 2K off. P/U= 90K, S/0= 88K, ROT= 88K. WOB= 20 30K. Page 2/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur hr j Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth-(ftKB) 12/1/2015 12/1/2015 6.00 SURFAC DRILL DDRL P Drilled ahead (/1455' MD to 2031' 1,455.0 2,031.0 00:00 06:00 MD. TVD=1929', ADT= 3.86 hrs, AST=1.09 hrs. Total bit hrs=16.01 Total Jar hrs= 32.22, Pump @ 725 gpm= 2050 psi, 80% FO. Rotate @ 60 rpm's w/ 5-8K Tq on/ 2-4K off. P/U= 102K, S/O= 90K, ROT= 93K. WOB= 30-35K. 12/1/2015 12/1/2015 6.00 SURFAC DRILL DDRL P Drilled ahead (/2031' MD to 2499' 2,031.0 2,499.0 06:00 12:00 MD. TVD=2301', ADT= 3.78 hrs, AST=.74 hrs. Total bit hrs=19.79 Total Jar hrs= 36, Pump @ 725 gpm= 2190 psi, 72% FO. Rotate @ 60 rpm's w/ 5- 7K Tq on/ 2-61K off. P/U= 107K, S/O= 91 K, ROT= 96K. WOB= 30-35K. 12/1/2015 12/1/2015 5.00 SURFAC DRILL DDRL P Drilled ahead f/2499' MD to 2850' 2,499.0 2,850.0 12:00 17:00 MD. TVD=2558', ADT= 3.33 hrs, AST=1.42 hrs. Total bit hrs=23.12 Total Jar hrs= 39.33, Pump @ 750 gpm= 2400 psi, 66% FO. Rotate @ 60 rpm's w/ 7-9K Tq on/ 5-6K off. P/U= 112K, S/O= 94K, ROT= 99K. WOB= 25-30K. 12/1/2015 12/1/2015 3.25 SURFAC CASING CIRC P CBU x3. Pump nut plug sweep. 750 2,850.0 2,685.0 17:00 20:15 gpm, 2200 psi, 60 rpm, 5K tq, Rack back one stand DP each BU to 2685' MD. 12/1/2015 12/1/2015 0.25 SURFAC CASING OWFF P Monitor well. Static 2,685.0 2,685.0 20:15 20:30 12/1/2015 12/2/2015 3.50 SURFAC CASING BKRM P BROOH f/ 2685' MD t/2160" MD. 750 2,685.0 1,755.0 20:30 00:00 gpm, 2150 psi, 60 rpm, 5-10K tq, PU=100K. Minor packoffs encountered and unloading excessive cuttings causing shakers to overload. Reduce pump rates f1750 to 600 to 550 gpm. Continue to BROOH to 1755' MD. 60 rpm, 5-10K tq, 550 to 675 gpm, 1200 to 1650 psi. 12/2/2015 12/2/2015 1.75 SURFAC CASING BKRM P BROOH f/1755' MD t/1430' MD. 700 1,755.0 1,381.0 00:00 01:45 gpm, 1710 psi, 60 rpm, 5-10 tq, Rot=100K, FO 65%. Slow BROOH to 250 fph for the last two stands to get BU per stand. Pull with no pump or rotation f/1430' MD t/1381' MD. 12/2/2015 12/2/2015 0.50 SURFAC CASING SRVY P Blow down TD. PU and drop multi 1,381.0 1,381.0 01:45 02:15 shot gyro @ 1381' MD. Allow to seat on UBHO as per Gyro Data rep. 12/2/2015 12/2/2015 0.75 SURFAC CASING TRIP P POOH on elevators (/1381' MD t/735' 1,381.0 735.0 02:15 03:00 MD taking gyro shot each stand. 12/2/2015 12/2/2015 0.25 SURFAC CASING OWFF P Monitor well. Static 735.0 735.0 03:00 03:15 12/2/2015 12/2/2015 0.75 SURFAC CASING TRIP P POOH and stand back 6 std's HWDP. 735.0 367.0 03:15 04:00 Take gyro shot each stand. Page 3/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Lag Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKS) 12/2/2015 12/2/2015 4.00 SURFAC CASING BHAH P Lay down 6 jts HWDP, jars, NMDC. 367.0 0.0 04:00 08:00 Retrieve gyro. Lay down 2 NMDC and UBHO. Drain mud motor. Break off bit. RIH and flush MWD, LWD and motor with fresh water. Lay down MWD, LWD, stab and motor as per DD. Calc disp=32.3 bbls Act disp=59.9 bbls. 12/2/2015 12/2/2015 1.50 SURFAC CASING BHAH P Clean and clear rig floor 0.0 0.0 08:00 09:30 12/2/2015 12/2/2015 0.75 SURFAC CASING WWWH P Pick up single DP and stack washer. 0.0 0.0 09:30 10:15 Flush diverter system and landing ring. Blow down TD. Lay down stack washer. 12/2/2015 12/2/2015 1.75 SURFAC CASING RURD P Rig up to run casing. 0.0 0.0 10:15 12:00 12/2/2015 12/2/2015 0.25 SURFAC CASING SFTY P PJSM on running casing. 0.0 0.0 12:00 12:15 12/2/2015 12/2/2015 0.75 SURFAC CASING RURD P Rig up to run casing. 0.0 0.0 12:15 13:00 12/2/2015 12/3/2015 11.00 SURFAC CASING PUTB P Run 13 3/8", 68#, Hyd 563 Dopeless L 0.0 1,485.0 13:00 00:00 -80 casing per running order. Install bowspring centralizers on each joint. Lost slack off weight @ 980' MD. Work and push pipe f/980' MD U1485' MD. PU 135K. Calc disp=37 bbls Act disp=15.8 bbls 12/3/2015 12/3/2015 0.25 SURFAC CASING PUTB P Run 13 3/8", 68#, Hyd 563 Dopeless L 1,485.0 1,525.0 00:00 00:15 -80 casing per running detail to 1525' MD. 12/3/2015 12/3/2015 0.75 SURFAC CASING CIRC P Circulate casing volume staging pump 1,525.0 1,525.0 00:15 01:00 up to 6 bpm, 220 psi, FO 84%. PU 110K SO 97K. 12/3/2015 12/3/2015 5.00 SURFAC CASING PUTB P Run 13 3/8", 68#, Hyd 563 Dopeless L 1,525.0 2,804.0 01:00 06:00 -80 casing per running detail from 1525' MD to 2804' MD. Ran a total of 71 bowspring centralizers. Light coat of Seal Guard pipe dope applied to seal area of collar and to thread and seal area of pin end. Torqued to 27,000 ft/lbs. Calc disp=69.55 bbls Act disp=46 bbls. 13 3/8" Hyd 563 Dopeless-0 reject/4 remakes 12/3/2015 12/3/2015 1.00 SURFAC CASING HOSO P Make up hanger and landing joint. 2,804.0 2,835.0 06:00 07:00 Land casing at 2835' MD. 12/3/2015 12/3/2015 2.50 SURFAC CEMENT CIRC P Break circ. Stage pumps up to 7 bpm, 2,835.0 2,835.0 07:00 09:30 300 psi. Pump 50 bbl nut plug marker pill. FO 84%. PU 172K SO 140K. Page 4169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 .... Rig: DOYON 141 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) 12/3/2015 12/3/2015 0.75 SURFAC CEMENT RURD P Rig up cement lines. Blow down top 2,835.0 2,835.0 09:30 10:15 drive 12/3/2015 12/3/2015 6.00 SURFAC CEMENT CMNT P Pump 5 bbls of fresh water & PT lines 2,835.0 2,835.0 10:15 16:15 to 3500 psi. Pump 20 bbls 8.3 ppg CW -100 , 4 bpm, 150 psi. Pump 100 bbls of 10.5 ppg MPH w/ red dye at 3.5 bpm, 150 psi. Drop bottom plug & pump 496.5 bbls of 11.0 ppg Lead Cement at 6.5 bpm, 350 psi. Pump 79 bbls of 12.0 ppg Tail Cement at 6 bpm, 450 psi. Drop top plug & kick out with 10 bbls of fresh H2O at 5 bpm, 160 psi. Swap to rig & displace cement with 10.1 ppg mud at 5.5 bpm, 700 psi. Bump plug w/ 3998 stks, pressure up to 1200 psi & hold for 5 min. Check floats, Floats not holding. Shut in and hold 100 psi. CIP at 15:45 hrs. Total of 282 bbls of cement returns to surface. Flow line packed off at 156 bbls of displacement. Take returns to cellar 12/3/2015 12/3/2015 1.75 SURFAC CEMENT WOC T Flush flow line and diverter 2,835.0 2,835.0 16:15 18:00 w/blackwater pill. Function annular multiple times. Sim-ops/Clean pits and cellar box. 12/3/2015 12/3/2015 3.00 SURFAC CEMENT RURD P Clear rig floor, lay down bail 2,835.0 2,835.0 18:00 21:00 extensions, elevators, spiders, thread protectors. Sim-ops/Break bolts on BOPE for BWM, clean pits and rock washer. Load pipeshed w/5" DP. 12/3/2015 12/3/2015 1.75 SURFAC CEMENT RURD P Check for flow out of casing. Static. 2,835.0 0.0 21:00 22:45 Rig down circ lines. Lay down Volant CRT. Lay down landing joint. Clear rig floor. 12/3/2015 12/4/2015 1.25 SURFAC CEMENT NUND P Nipple down diverter system. Sim- 0.0 0.0 22:45 00:00 ops/Clean pits. Clean out and inspect mud pumps. Clean suction screen on mud pumps. Change out #2 centrifugal pump in rock washer. Clean out cement from flow line. 12/4/2015 12/4/2015 6.00 SURFAC CEMENT NUND P Remove riser from rig floor. ND knife 0.0 0.0 00:00 06:00 valve. De-energize slips and seals on conductor adapter. ND , clean and remove adapter, riser spool and annular from cellar. Remove 4" conductor valves and cap off. Cement 30" below hanger. 12/4/2015 12/4/2015 2.00 SURFAC WHDBOP NUND P Orient and install Cameron 13 5/8" 0.0 0.0 06:00 08:00 MBS.Test wellhead seals to 5000 psi./15 min. Good. 12/4/2015 12/4/2015 2.75 SURFAC WHDBOP NUND P Remove 13 5/8" x 11" adapter flange. 0.0 0.0 08:00 10:45 Set BOPE on wellhead. Page 5/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Lag Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 12/4/2015 12/4/2015 3.75 SURFAC WHDBOP SVRG P Perform BWM. Open all ram doors 0.0 0.0 10:45 14:30 and pressure wash out. Take pictures of wear plates and rams, Inspect all BOP equipment as per CPAI BWM policy. Sim-ops/Load and strap DP in pipe shed, Change out link tilt ram on TD. Rig on shore power @ 13:30 hrs 12/4/2015 12/4/2015 6.50 SURFAC WHDBOP NUND P NU BOPE. Install 13 5/8" x 13 5/8" 0.0 0.0 14:30 21:00 drilling spool. Install choke and kill lines. Cut trip nipple to length. Attempt to set trip nipple. Taper on nipple pushing nipple up when upper air boot is inflated. Send to shop for modification 12/4/2015 12/4/2015 1.00 SURFAC WHDBOP RURD P Set test plug. Rig up to test BOPE. 0.0 0.0 21:00 22:00 12/4/2015 12/5/2015 2.00 SURFAC WHDBOP BOPE T Perform body test on BOPE. Two 0.0 0.0 22:00 00:00 plastic injection port check valves leaking on wellhead.Trouble shoot check valves. Tape and tighten up bull plugs in ports. Upper flange on spacer spool leaking on high test. Retorque bolts. 12/5/2015 12/5/2015 2.75 SURFAC WHDBOP BOPE T PJSM, Tighten bolts on 13-5/8" spacer 0.0 0.0 00:00 02:45 spool and pressure up, still leaking. Loosen all bolts on spacer spool and pick up BOP stack. Loosen and retighten all bolts on spacer spool. Retest to 3500 psi, good. 12/5/2015 12/5/2015 4.25 SURFAC WHDBOP BOPE P Test BOPE w/ 5" test joint to 250/3500 0.0 0.0 02:45 07:00 psi for 5 min each. Test #1; Top pipe rams, CV 1,12,13,and 14. Test #2: Upper IBOP, HCR kill, CV 9 and 11. Test #3: Lower IBOP, CV 5,8 and 10. Test #4: Dart valve, CV 4, 6 and 7. Test #5: Floor valve and CV 2. Test #6" HCR choke and 4" kill line Demco. Test # 7: Manual choke and HCR kill. Test #8: Annular to 250/2500 psi. Test #9: Lower pipe rams Test# 10: Blind rams and CV 3. Accumulator test: System pressure= 3000 psi, pressure after closing= 1900 psi, 200 psi attained after 43 sec, full pressure attained after 178 sec. Five bottle nitrogen avg= 1900 psi. 3 failures= Lower IBOP, work valve and retest, good. Wellhead port leaking, install bull plugs. 13-5/8" spacer spool on bottom on BOP stack, loosen all bolts, retighten and retest, Test all gas alarms. AOGCC rep Chuck Scheve waived witness of the test. 12/5/2015 12/5/2015 1.00 SURFAC WHDBOP RURD P R/D testing equipment, blow down 0.0 0.0 07:00 08:00 choke manifold , kill line and choke line. Install wear bushing as per Cameron. Page 6/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/5/2015 12/5/2015 1.00 SURFAC CEMENT RURD P PJSM, Rig up to pick up 5" DP, 0.0 0.0 08:00 09:00 SIMOPS, install riser. 12/5/2015 12/5/2015 4.50 SURFAC CEMENT PULD P PU and stand back 159 jts 5" DP. 0.0 0.0 09:00 13:30 Flush flow line 12/5/2015 12/5/2015 1.00 SURFAC CEMENT RURD P Clear rig floor. Mobilize tools to rig 0.0 0.0 13:30 14:30 floor. 12/5/2015 12/5/2015 0.25 SURFAC CEMENT SFTY P PJSM on picking up BHA 0.0 0.0 14:30 14:45 12/5/2015 12/5/2015 1.50 SURFAC CEMENT BHAH P PU BHA #2 to aDNvision. 0.0 138.0 14:45 16:15 12/5/2015 12/5/2015 0.75 SURFAC CEMENT BHAH P Load nuclear sources. 138.0 138.0 16:15 17:00 12/5/2015 12/5/2015 2.50 SURFAC CEMENT BHAH P Continue to PU BHA #2 138.0 786.0 17:00 19:30 12/5/2015 12/5/2015 1.50 SURFAC CEMENT PULD P PU 28 jts 5" DP. Single in hole w/BHA 786.0 1,643.0 19:30 21:00 #2 12/5/2015 12/5/2015 1.00 SURFAC CEMENT CIRC T Observed debris (scale, mud and 1,643.0 1,643.0 21:00 22:00 cement) coming out of DP while being picked up. Break circ and stage pumps up to 700 gpm/1600 psi. Circulate out clabbered up mud. 12/5/2015 12/5/2015 1.00 SURFAC CEMENT PULD P PU 32 jts 5" DP. Single in hole w/BHA 1,643.0 2,650.0 22:00 23:00 #2. PU 125K, SO 80K. Calc disp=37.27 bbls Act disp=32.1 bbls 12/5/2015 12/6/2015 1.00 SURFAC CEMENT CIRC P Rig up to test casing. Break 2,650.0 2,650.0 23:00 00:00 circulation. Stage pumps up to 700 gpm/2425 psi. 12/6/2015 12/6/2015 1.00 SURFAC CEMENT PRTS P Pressure test 13 3/8" casing to 3500 2,650.0 2,650.0 00:00 01:00 psi/30 min. chart. Good. Rig down test equip. 12/6/2015 12/6/2015 3.50 SURFAC CEMENT DRLG P Wash down and tag top plug @2720' 2,650.0 2,850.0 01:00 04:30 MD. Drlg cement plugs, float collar, shoe track, float shoe and rat hole to 2850' MD. 500 gpm, 920 psi, 57% fo, 60 rpm, 3-11 K tq, PU 125K SO 90K Rot 11 OK. Tag bottom plug @2753' MD. Tag float shoe @ 2836' MD. 12/6/2015 12/6/2015 0.50 SURFAC CEMENT DDRL P Drilled ahead f/ 2850' MD to 2870' 2,850.0 2,870.0 04:30 05:00 MD. TVD=2572', ADT= .16 hrs, Total bit hrs=.16 Total Jar hrs= .16, Pump @ 700 gpm= 1630 psi, 62% FO. Rotate @ 60 rpm's w/ 5-12K Tq on/ 5- 10K off. P/U= 125K, S/O= 90K, ROT= 11 OK. WOB= 5-1 OK. ECD=10.2 12/6/2015 12/6/2015 0.25 SURFAC CEMENT CIRC P CBU @ 920 gpm, 2625 psi, 68% FO 2,870.0 2,870.0 05:00 05:15 12/6/2015 12/6/2015 0.50 SURFAC CEMENT TRIP P POOH (/2870' MD t/2743' MD. Lay 2,870.0 2,743.0 05:15 05:45 down single jt DP and stand back one stand DP. 12/6/2015 12/6/2015 1.25 SURFAC CEMENT FIT P Blow down TD. Rig up and perform 2,743.0 2,743.0 05:45 07:00 FIT to an EMW of 15 ppg. 700 psi applied. Rig down test equip and blow down kill line. 12/6/2015 12/6/2015 0.25 INTRM1 DRILL TRIP P f/2743' MD U2870' MD. 2,743.0 2,870.0 07:00 07:15 �RIH Page 7/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/6/2015 12/6/2015 0.25 INTRMI DRILL DISP P Pump hi-vis spacer. Displace mud 2,870.0 2,870.0 07:15 07:30 system over to 9.6 ppg LSND. 550 gpm, 1000 psi, 52% FO. Slow pump rate to 250 gpm, 220 psi, 43% FO, 60 rpm, 5-12K tq 12/6/2015 12/6/2015 0.75 INTRM1 DRILL WAIT T Rockwasher filling up due to 2,870.0 2,870.0 07:30 08:15 insufficient availability of vac trucks. Shut down displacement and redistribute mud in pits. Offload new mud into pits and move truck to offload rockwasher 12/6/2015 12/6/2015 0.25 INTRM1 DRILL DISP P Continue to displace mud system 2,870.0 2,870.0 08:15 08:30 over to 9.6 ppg LSND. 300 gpm, 300 psi, 48% FO, 40 rpm, 8K tq 12/6/2015 12/6/2015 2.25 INTRM1 DRILL DDRL P Drilled ahead f/ 2870' MD to 3025' 2,870.0 3,025.0 08:30 10:45 MD. TVD=2680', ADT= 1.74 hrs, Total bit hrs=1.90 Total Jar hrs= 1.90, Pump @ 803 gpm= 1465 psi, 65% FO. Rotate @ 70 rpm's w/ 7-1 OK Tq on/ 7K off. P/U= 125K, S/O= 91 K, ROT= 101 K. WOB= 4-7K. ECD=10.28 Max gas=258 units SPR's @ 2930' MD, 2610' TVD, MW 9.6 ppg, 09:30 hrs #1 @30=110;@40=140 psi #2@30=105;@40=140 psi 12/6/2015 12/6/2015 0.50 INTRMI DRILL CIRC P Break connection and drop RFID tag 3,025.0 3,025.0 10:45 11:15 @ 3020' MD to open reamer Circulate down as per WFT rep. Lost 75 psi indicating cutters open. Pull reamer against upper formation ledge @ 2855' MD and observed 1 OK overpull. 12/6/2015 12/6/2015 0.75 INTRM1 DRILL DDRL P Drilled ahead f/ 3025' MD to 3055' 3,025.0 3,055.0 11:15 12:00 MD. TVD=2702', ADT= .35 hrs, Total bit hrs=2.25 Total Jar hrs= 2.25, Pump @ 900 gpm= 1465 psi, 65% FO. Rotate @ 70 rpm's w/ 7-1 OK Tq on/ 7K off. P/U= 125K, S/O= 91 K, ROT= 101 K. WOB= 4-7K. ECD=10.28 Max gas=65 units 12/6/2015 12/6/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/ 3055' MD to 3520' 3,055.0 3,520.0 12:00 18:00 MD. TVD=3008', ADT= 5.32 hrs, Total bit hrs=7.57 Total Jar hrs= 7.57, Pump @ 850 gpm= 1700 psi, 65% FO. Rotate @ 100 rpm's w/ 6-1 OK Tq on/ 2 -12K off. P/U= 127K, S/O= 99K, ROT= 108K. WOB= 12-17K. ECD=10.44 Max gas= 139 units Pump 30 bbls hi-vis sweeps every 300' drilled. 100% to 200% cuttings increase. Page 8/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/6/2015 12/7/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/ 3520' MD to 3953' 3,520.0 3,953.0 18:00 00:00 MD. TVD=3232', ADT= 4.45 hrs, Total bit hrs= 12.02 Total Jar hrs= 12.02 Pump @ 910 gpm= 2100 psi, 66% FO. Rotate @ 140 rpm's w/ 8-12K Tq on/ 3-1 OK off. P/U= 130K, S/O= 96K, ROT= 106K. WOB= 10-20K. ECD=10.45 Max gas= 125 units .Pump 30 bbls hi-vis sweeps every 300' drilled. 100% to 200% cuttings increase. SPR's @ 3582' MD, 3039' TVD, MW 9.6 ppg, 19:00 hrs #1 @ 30 = 140; @ 40 = 170 psi #2 @ 30 = 130; @ 40 = 170 psi SPR's @ 3953' MD, 3232' TVD, MW 9.6 ppg, 23:45 hrs #1 @ 30 = 160; @ 40 = 190 psi #2 @ 30 = 150; @ 40 = 190 psi 12/7/2015 12/7/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/ 3953' MD to 4513' 3,953.0 4,513.0 00:00 06:00 MD. TVD=3501', ADT= 5.09 hrs, Total bit hrs=17.11 Total Jar hrs= 17.11 Pump @ 899 gpm= 2290 psi, 66% FO. Rotate @ 140 rpm's w/ 10-11 K Tq on/ 7-8K off. P/U= 145K, S/O= 96K, ROT= 113K. WOB= 15-20K. ECD=10.65 Max gas=87 units .Pump 30 bbls hi-vis sweeps every 300' drilled. 100% to 200% cuttings increase. 12/7/2015 12/7/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/4513' MD to 4889' 4,513.0 4,889.0 06:00 12:00 MD. TVD=3683', ADT= 4.58 hrs, Total bit hrs=21.69 Total Jar hrs= 21.69 Pump @ 925 gpm= 2550 psi, 66% FO. Rotate @ 140 rpm's w/ 10-15K Tq on/ 8-9K off. P/U= 149K, S/O= 98K, ROT= 115K. WOB= 20-25K. ECD=10.66 Max gas=92 units Pump 30 bbls hi-vis sweeps every 300' drilled. 100% to 200% cuttings increase. SPR's @ 4889' MD, 3683' TVD, MW 9.8 ppg, 11:30 hrs #1 @ 30 = 200; @ 40 = 230 psi #2 @ 30 = 200; @ 40 = 230 psi Page 9/69 Report Printed: 2/29/2016 - , Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/7/2015 12/7/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/4889' MD to 5353' 4,889.0 5,353.0 12:00 18:00 MD. TVD=3908', ADT= 4.86 hrs, Total bit hrs=26.55 Total Jar hrs= 26.55 Pump @ 925 gpm= 2650 psi, 67% FO. Rotate @ 140 rpm's w/ 9-13K Tq on/ 3-1 OK off. P/U= 142K, S/O= 11 OK, ROT= 115K. WOB= 15-25K. ECD=10.51 Max gas=122 units Pump 30 bbls hi -vis sweeps every 300' drilled. 100% to 200% cuttings increase. SPR's @ 5353' MD, 3908' TVD, MW 9.8 ppg, 18:00 hrs #1 @ 30 = 200; @ 40 = 240 psi #2@30=210;@40=240 psi 12/7/2015 12/8/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/5353' MD to 5820' 5,353.0 5,820.0 18:00 00:00 MD. TVD=4138', ADT= 4.54 hrs, Total bit hrs=31.09 Total Jar hrs= 31.09 Pump @ 925 gpm= 2900 psi, 67% FO. Rotate @ 140 rpm's w/ 12-15K Tq on/ 6-1 OK off. P/U= 143K, S/O= 105K, ROT= 120K. WOB= 15-22K. ECD=10.51 Max gas=122 units Pump 30 bbls hi -vis sweeps every 300' drilled. 100% to 200% cuttings increase. SPR's @ 5820' MD, 3908' TVD, MW 9.7+ ppg, 23:45 hrs #1 @ 30 = 200; @ 40 = 240 psi #2 @ 30 = 210; @ 40 = 240 psi 12/8/2015 12/8/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/5820' MD to 6309' 5,820.0 6,309.0 00:00 06:00 MD. TVD=4378', ADT= 4.72 hrs, Total bit hrs=35.81 Total Jar hrs= 35.81 P/U= 160K, S/O= 112K, ROT= 130K.Tq on13-14K / off 8-9K. ECD=10.78, FO 73%, WOB 15-20K, RPM 140, GPM 924, PSI 3020, Max gas= 112 units Total footage 489' MD 12/8/2015 12/8/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/6309' MD to 6715' 6,309.0 6,715.0 06:00 12:00 MD. TVD=4586', ADT= 4.62 hrs, Total bit hrs=40.30 Total Jar hrs= 40.30 P/U= 158K, S/O= 120K, ROT= 134K.Tq on11-12K / off 7-81K. ECD=10.82, FO 73%, WOB 10-15K, RPM 140, GPM 921, PSI 3250, Max gas=247 units Total footage 406' MD Fire Drill CRT 78 Sec @ 09:00 hrs. SPR's @ 6657' MD, 4474' TVD, MW 9.9 ppg, 11:15 hrs #1 @ 30 = 280; @ 40 = 320 psi #2 @ 30 = 280; @ 40 = 330 psi Page 10169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/8/2015 12/8/2015 1.75 INTRM1 DRILL DDRL P Drilled ahead (/6715' MD to 6848' 6,715.0 6,848.0 12:00 13:45 MD. TVD=4654', ADT= 1.60 hrs, Total bit hrs=42.03 Total Jar hrs= 42.03 P/U= 158K, S/O= 120K, ROT= 134K.Tq on11-12K / off 7-81K. ECD=10.82, FO 74%, WOB 10-16K, RPM 140, GPM 920, PSI 3300, Max gas=227 units Total footage 133' MD 12/8/2015 12/8/2015 1.75 INTRM1 DRILL RGRP T PJSM, perform MPI inspection on 6,848.0 6,848.0 13:45 15:30 grabber cylinder block pin holes on the top drive. Circulate @ 500 gpm, 1100 psi, 15 rpm, Tq 6K. 12/8/2015 12/8/2015 2.50 INTRM1 DRILL DDRL P Drilled ahead f/6848' MD to 7038' 6,848.0 7,038.0 15:30 18:00 MD. TVD=4752', ADT= 2.00 hrs, Total bit hrs=44.03 Total Jar hrs= 44.03 P/U= 155K, S/O= 120K, ROT= 131 K.Tq on11-13K / off 5-9K. ECD=10.47, FO 67%, WOB 13-15K, RPM 140, GPM 925, PSI 3180, Max gas= 144 units Total footage 190' MD Spill Drill CRT 105 Sec @ 18:00 Hrs 12/8/2015 12/9/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/7038' MD to 7445' 7,038.0 7,445.0 18:00 00:00 MD. TVD=4981', ADT= 4.70 hrs, Total bit hrs=48.73 Total Jar hrs= 48.73 P/U= 164K, S/O= 121K, ROT= 138K.Tq on10-20K / off 8-12K. ECD=10.49, FO 67%, WOB 10-25K, RPM 140, GPM 925, PSI 3300, Max gas=191 units Total footage 407' MD. SPR's @ 7132' MD, 4804' TVD, MW 9.7+ ppg, 19:00 hrs #1 @ 30 = 210; @ 40 = 260 psi #2 @ 30 = 220; @ 40 = 260 psi 12/9/2015 12/9/2015 1.00 INTRM1 DRILL RGRP T PJSM; bell nipple riser leaking. 7,445.0 7,745.0 00:00 01:00 Change out air boot & reset bell nipple / MPD clamp. 12/9/2015 12/9/2015 5.00 INTRM1 DRILL DDRL P Drilled ahead f/7445'-7797' MD. 7,745.0 7,797.0 01:00 06:00 TVD=5196', ADT= 4.07 hrs, Total bit hrs=52.80 Total Jar hrs= 52.80 P/U= 171K, S/O= 128K, ROT= 145K.Tq on15K / off 9-10K. ECD=10.58, FO 67%, WOB 15-20K, RPM 140, GPM 925, PSI 3230, Max gas=609 units Total footage 352' MD. Page 11/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cade 'Time P-T-X Operation (ftKB) End Depth (ftKB) 12/9/2015 12/9/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/7797'-8200' MD. 7,797.0 8,200.0 06:00 12:00 TVD=5427', ADT= 4.48 hrs, Total bit hrs=57.28 Total Jar hrs= 57.28 P/U= 175K, S/O= 130K, ROT= 145K.Tq on15-16K / off 9-1 OK. ECD=10.70, FO 67%, WOB 20-25K, RPM 140, GPM 925, PSI 3420, Max gas=334 units Total footage 352' MD. SPR's @ 8059' MD, 5346' TVD, MW 9.9 ppg, 09:54 hrs #1 @ 30 = 250; @ 40 = 330 psi #2 @ 30 = 250; @ 40 = 320 psi 12/9/2015 12/9/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/8200'-8513' MD. 8,200.0 8,513.0 12:00 18:00 TVD=5600', ADT= 4.12 hrs, Total bit hrs=61.40 Total Jar hrs= 6140 P/U= 180K, S/O= 132K, ROT= 147K.Tq on17-18K / off 10-12K. ECD=10.43, FO 67%, WOB 15-20K, RPM 140, GPM 925, PSI 3275, Max gas=1691 units Total footage 313' MD. 12/9/2015 12/10/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead f/8513'-8898' MD. 8,513.0 8,898.0 18:00 00:00 TVD=5811', ADT= 4.73 hrs, Total bit hrs=66.13 Total Jar hrs= 66.13 P/U= 195K, S/O= 135K, ROT= 151 K.Tq on10-18K / off 11 K. ECD=10.51, FO 67%, WOB 15-20K, RPM 140, GPM 925, PSI 3500, Max gas=597 units Total footage 385' MD. SPR's @ 8525' MD, 5604' TVD, MW 9.8 ppg, 18:00 hrs #1 @ 30 = 230; @ 40 = 290 psi #2 @ 30 = 230; @ 40 = 280 psi 12/10/2015 12/10/2015 6.00 INTRM1 DRILL DDRL P Drilled ahead (/8898'-9329' MD. 8,898.0 9,329.0 00:00 06:00 TVD=6024', ADT= 4.51 hrs, Total bit hrs=70.64 Total Jar hrs= 70.64 P/U= 205K, S/O= 130K, ROT= 155K.Tq on15-17K / off 10-15K. ECD=10.77, FO 67%, WOB 20-25K, RPM 140, GPM 913, PSI 3450, Max gas=1566 units Total footage 431' MD. TD 9329' MD, 6024' TVD Page 12/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 r- • a ' r Rig: DOYON 141 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) 12/10/2015 12/10/2015 1.75 INTRM1 CASING DHEQ T Drop RFID chip to close under reamer 9,329.0 9,329.0 06:00 07:45 @ 920 gpm, 3660 psi, FO 68%, 80 rpm, Tq 10K. Reduce rate to 305 gpm / 3660 psi, 61 gpm / 305 psi, FO 30%, 40 rpm, Tq 8-1 OK. Shut down 10 min to let tool relax. Pump at 920 gpm, observed 100 psi over previous pressure, then drop down 3660 psi. No change in MWD turbine rpm. Drop another chip & repeat process with no change. 12/10/2015 12/10/2015 2.75 INTRM1 CASING CIRC P CBU 3 times @ 925 gpm, 3660 psi, 9,329.0 9,180.0 07:45 10:30 140 rpm, Tq 12K, PU 205K, SO 130K, ROT 155K. Rack back a stand every BU 9329'-9180' MD. Blow down TD. SPR's @ 9180' MD, 5944' TVD, MW 10.1 ppg, 10:00 hrs #1 @ 30 = 280; @ 40 = 350 psi #2 @ 30 = 280; @ 40 = 350 psi 12/10/2015 12/10/2015 0.50 INTRM1 CASING OWFF P Monitor well, static(drop 3" in the 9,180.0 9,180.0 10:30 11:00 stack). 12/10/2015 12/10/2015 5.00 INTRM1 CASING TRIP P PJSM; TOH f/ 9180'-2745' MD, PU 9,180.0 2,745.0 11:00 16:00 120K, SO 80K. 12/10/2015 12/10/2015 1.00 INTRM1 CASING CIRC T Break circulation staging up to 900 2,745.0 2,745.0 16:00 17:00 gpm. Attempt to rotate and stall out with torque, attempt to PU & SO. Shut down pumps & let reamer relax. PU 120K, SO 80K. Drop 10 RFID chips & repeat closing procedure with no success. 12/10/2015 12/10/2015 0.50 INTRM1 CASING CIRC P Continue CBU for total of 3 times @ 2,745.0 2,745.0 17:00 17:30 920 gpm, 2300 psi. 12/10/2015 12/10/2015 0.50 INTRM1 CASING OWFF P Monitor well, static. Blow down TD. 2,745.0 2,745.0 17:30 18:00 12/10/2015 12/10/2015 1.00 INTRM1 CASING TRIP P PJSM; TOH f/ 2745'-786' MD, PU 2,745.0 786.0 18:00 19:00 110K, SO 101K. 12/10/2015 12/10/2015 0.25 INTRM1 CASING OWFF P Monitor well at the HWDP, static. 786.0 786.0 19:00 19:15 12/10/2015 12/10/2015 0.50 INTRM1 CASING TRIP P PJSM; stand back HWDP, 786'-233' 786.0 233.0 19:15 19:45 MD. 12/10/2015 12/10/2015 1.50 INTRM1 CASING BHAH P PJSM; lay down BHA 233'-138' MD. 233.0 138.0 19:45 21:15 Reamer had 1 broken cutter & 3 w/ minimal chips. 12/10/2015 12/10/2015 1.00 INTRM1 CASING BHAH P PJSM; remove & secure sources. 138.0 138.0 21:15 22:15 12/10/2015 12/10/2015 1.25 INTRM1 CASING BHAH P Continue laying down BHA, 138'-0. 138.0 0.0 22:15 23:30 Calculated fill for trip out 91.78, actual 105.57 bbls. 12/10/2015 12/11/2015 0.50 INTRM1 CASING BHAH P PJSM; clear & clean rig floor. 0.0 0.0 23:30 00:00 12/11/2015 12/11/2015 2.00 INTRM1 CASING BOPE P PJSM; C/O upper rams to 10.75" solid 0.0 0.0 00:00 02:00 body rams. (C/O 1 top ram seal) SIMOPS C/O clamp cylinder body on TD. 12/11/2015 12/11/2015 1.25 INTRM1 CASING SLPC P PJSM; slip & cut 60' of drill line. 0.0 0.0 02:00 03:15 SIMOPS rig up MPD lines in the cellar & continue on cylinder body for TD. Page 13/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/11/2015 12/11/2015 2.50 INTRM1 CASING BOPE P PJSM; pull wear bushing & install test 0.0 0.0 03:15 05:45 plug. Rig up to test. SIMOPS finish rigging up MPD lines in cellar. 12/11/2015 12/11/2015 0.75 INTRM1 CASING BOPE P PJSM; test 10.75" test joint as follows, 0.0 0.0 05:45 06:30 annular 250/2500 psi for 5 min each, upper 10.75" rams 250/3500 psi for 5 min each charted. 12/11/2015 12/11/2015 1.00 INTRMI CASING BOPE P PJSM; rig down test equipment & 0.0 0.0 06:30 07:30 install wear bushing. 12/11/2015 12/11/2015 0.50 INTRM1 CASING SVRG P PJSM; service rig & TD. 0.0 0.0 07:30 08:00 12/11/2015 12/11/2015 0.50 INTRM1 CASING RGRP T PJSM; finish installing new clamp 0.0 0.0 08:00 08:30 cylinder body on TD. 12/11/2015 12/11/2015 2.25 INTRM1 CASING RURD P PJSM; rig up to run casing. 0.0 0.0 08:30 10:45 12/11/2015 12/11/2015 1.25 INTRM1 CASING PUTB P PJSM; pick up & TIH w/ 10.75", 45.5 0.0 187.0 10:45 12:00 #, L-80, Hydril 521 casing. Pick up shoe track & test float equipment, running in the hole to 187' MD. 12/11/2015 12/11/2015 0.75 INTRM1 CASING RURD T Casing stop ring & centralizer hanging 187.0 187.0 12:00 12:45 up on riser ledge. Adjust stack & reposition slips. 12/11/2015 12/11/2015 5.75 INTRM1 CASING PUTB P Run 10.75", 45.5 #, L-80, Hydril 521 187.0 2,690.0 12:45 18:30 casing TIH 187'-2690' MD, PU 135K, SO 94K. 12/11/2015 12/11/2015 1.00 INTRM1 CASING CIRC P CBU staging up the pump from 1.5 - 3 2,690.0 2,690.0 18:30 19:30 bpm, 200 psi. 12/11/2015 12/11/2015 1.75 INTRMI CASING PUTB P Run 10.75", 45.5 #, L-80, Hydril 521 2,690.0 3,460.0 19:30 21:15 casing f/ 2690'-3460' MD. 12/11/2015 12/11/2015 1.00 INTRM1 CASING CIRC P CBU staging up the pump from 1.5 - 3 3,460.0 3,460.0 21:15 22:15 bpm, 450 psi. 12/11/2015 12/12/2015 1.75 INTRM1 CASING PUTB P Run 10.75", 45.5 #, L-80, Hydril 521 3,460.0 4,115.0 22:15 00:00 casing f/ 3460'-4115' MD, PU 165K, SO 50-35K. Calculated displacement 69, actual 64 bbls. Run 108 joints. Install a total of 57 bowspring centralizers. Install 1 bowspring on each joints 2-33, 1 on every other joint 33-37, & 1 on every 3 joint 40-94. No rejects or remakes for this run. 12/12/2015 12/12/2015 1.00 INTRM1 CASING PUTB P PJSM, Cont to RIH w/ 10-3/4" 45.5#, L 4,115.0 4,545.0 00:00 01:00 -80 H521 casing f/ 4115' to 4545', Began push mud away, lost 4 bbls of the 6 bbl casing displacement. 12/12/2015 12/12/2015 2.25 INTRM1 CASING CIRC T Circulate and condition mud, stage 4,545.0 4,545.0 01:00 03:15 pumps up f/ 1.5 bpm= 800 psi to 2 bpm-250 psi 30% FO. Circulated out 10.4 ppg w/ 300+ FV. P/U= 174K, S/O= 121 K. 12/12/2015 12/12/2015 4.25 INTRMI CASING PUTB P Cont RIH w/ 10-3/4" 45.5#, L-80 H521 4,545.0 5,335.0 03:15 07:30 casing f/ 4545' to 5335. Wash casing down @ 2 bpm=500-600 psi w/ 30% FO. Washing casing down to keep gels broke / mud moving in the annulus. Page 14/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/12/2015 12/12/2015 2.00 INTRM1 CASING CIRC T Started pushing away mud again. 5,335.0 5,335.0 07:30 09:30 Circulate and condition mud, stage pumps up f/ 1 bpm= 600 psi, 27% FO to 5.5 bpm= 375 psi, 45% FO. circulated out 10.9 ppg mud w/ 300+ FV. P/U=185K, S/0=105K. 12/12/2015 12/12/2015 4.25 INTRM1 CASING PUTB P Cont RIH w/ 10-3/4" 45.5#, L-80 H521 5,335.0 6,603.0 09:30 13:45 casing f/ 5335' to 6603', washing casing down @ 2 bpm=400-600 psi. P/U=185K, S/0= 105K. Displacement f/ 0 to 12 hours, actual 12.25 bbls, Calculated 25.32 bbls. 12/12/2015 12/12/2015 2.00 INTRM1 CASING CIRC P Circulate and condition mud, stage 6,603.0 6,603.0 13:45 15:45 pumps up f/ 1.5 bpm= 725 psi, 27% FO to 5 bpm= 300 psi, 40% FO. circulated out 10.8 ppg mud w/ 300+ FV. P/U=225K, S/0=160K. 12/12/2015 12/12/2015 1.25 INTRM1 CASING OTHR P PJSM; make up liner hanger & fill tie 6,603.0 6,631.0 15:45 17:00 back w/ Pal mix as per Baker Rep. 12/12/2015 12/12/2015 0.50 INTRM1 CASING CIRC P Circulate thru liner hanger picking up a 6,631.0 6,691.0 17:00 17:30 single of HWDP F/ 6631'-6691'@ 4 bpm, 300 psi, FO 40%. 12/12/2015 12/12/2015 2.00 INTRM1 CASING RUNL P Run liner in the hole w/5" HWDP f/ 6,691.0 7,505.0 17:30 19:30 6691' to 7505', PU 205K, SO 65K. 12/12/2015 12/12/2015 3.25 INTRM1 CASING CIRC P Circulate and condition mud, stage 7,505.0 7,505.0 19:30 22:45 pumps up f/ 1 bpm= 350 psi, 18% FO to 5 bpm= 450 psi, 44% FO. circulated out 11.0 ppg mud w/ 200 FV. P/U=260K, S/0=165K. 12/12/2015 12/12/2015 1.00 INTRM1 CASING RUNL P Run liner in the hole w/5" HWDP f/ 7,505.0 7,894.0 22:45 23:45 7505' to 7894', PU 275K, SO 157K. Calculated displacement 28.62, actual 21.68 bbls. Losses for tour 7 bbls. 12/12/2015 12/13/2015 0.25 INTRM1 CASING RURD P Rig up to rabbit HWDP f/ derrick. 7,894.0 7,894.0 23:45 00:00 12/13/2015 12/13/2015 2.25 INTRM1 CASING CIRC P Circulate and condition mud, stage 7,894.0 7,894.0 00:00 02:15 pumps up f/ 1 bpm=330 psi, 18% FO to 4.5 bpm=475 psi, 36% FO. P/U=270K, S/0= 170K. SIMOPS, drift stuck in HWDP. Attempt to free drift. 12/13/2015 12/13/2015 0.75 INTRMI CASING RUNL P RIH w/ 10-3/4" liner on 5" HWDP f/ 7,894.0 8,170.0 02:15 03:00 2894' MD to 8170' MD 12/13/2015 12/13/2015 3.25 INTRM1 CASING RUNL P RIH w/ 10-3/4" liner on 5" HWDP and 8,170.0 9,318.0 03:00 06:15 5" DP f/ 8170' to 9218'. Wash liner in the hole pumping @ 2 bpm=580 psi, 30% FO. RIH and tag bottom @ 9329' MD, set down 1 OK w/ 100 psi pump pressure increase. P/U= 310K, S/0= 145K. Actual displacement= 10.55 bbls, Calculated displacement= 17.9 bbls. Page 15/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) .t 2S-13 IN Rig: DOYON 141 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 (ftK8) 12/13/2015 12/13/2015 1.75 INTRM1 CEMENT RGRP T After tagging bottom, P/U 15' and the 9,318.0 9,318.0 06:15 08:00 draw works clutch began to slip @ 330K hook load. Unable to pick drill string up any further. Trouble shoot clutch and add DE in clutch plates. Break off stand and burn clutch, no success, still slipping @ 350K. Decision made to cement liner without pipe movement. Cont to circulate @ 3 bpm=550 psi w/ 36 % FO. 12/13/2015 12/13/2015 2.00 INTRM1 CEMENT CIRC P Circulate and condition mud, stage 9,318.0 9,318.0 08:00 10:00 pumps up f/ 3 bpm=400 psi, 31 %FO to 6 bpm=580 psi, 47% FO. Circulate out 10.80 pp, 300+ FV. 12/13/2015 12/13/2015 1.25 INTRM1 CEMENT RURD P Blow down top drive, and L/D 2 joints 9,318.0 9,318.0 10:00 11:15 of 5" DP. Make up Baker swivel, cement head and space out pups. 12/13/2015 12/13/2015 0.25 INTRM1 CEMENT HOSO P Stage pumps up 2-5 bpm, 300-500 9,318.0 9,318.0 11:15 11:30 psi, FO 30-41 %, PU 345K, SO 170K. Set liner on depth at 9318' as follows, slack off to 9318' MD, pick up to 315K & park. ( String weight broke over at 315K). 12/13/2015 12/13/2015 0.50 INTRM1 CEMENT CIRC P Continue circulating & conditioning 9,318.0 9,318.0 11:30 12:00 mud for cement job at 6 bpm, 600 psi, FO 43%. 12/13/2015 12/13/2015 4.50 INTRM1 CEMENT CMNT P PJSM for cementing 10.75" liner. 9,318.0 9,318.0 12:00 16:30 Pump 5 bbls of CW -100 & PT lines to 400/4000 psi for 5 min. Pump 35 bbls of CW -100 @ 4 bpm, 500 psi. Batch up mud push. Pump 40 bbls of 11.5 ppg MPII @ 5 bpm, 450 psi. Batch up cement. Pump 320 bbls of 15.8 ppg cement @ 5.5 bpm, 300 psi. Kick out top plug with 10 bbls of H2O. Swap to rig pumping 10.0 ppg mud to displace. Pump 21 bbls to @ 6 bpm = 140 psi, slow to 3 bpm = 75 psi, observe latch up with pressure increase to 650 psi. Continue pumping 6.5 bpm = 400 psi. Observe cement lift with pressure increasing to 1640 psi. Started seeing losses @ 555 bbls into displacement observed losses. Slowed pump to 3 bpm = 1100 psi. Bump the plug with 641 bbls, pressure up to 1700 psi. Hold pressure for 5 min & bleed off. Floats good. CIP @ 16:20 hrs. 75 bbls lost during displacement. 12/13/2015 12/13/2015 0.75 INTRM1 CEMENT PACK P Set liner hanger per Baker Rep. 9,318.0 2,692.0 16:30 17:15 Pressure up to 2500 psi & slack off to 80K. Bleed off pressure. Rotate to the right to release running tool. Pressure up to 550 psi picking up pull running tool form liner top. Stage pumps up to wash cement from liner top 3-8 bpm = 250-500 psi. Liner set at 2694' MD. 12/13/2015 12/13/2015 2.25 INTRM1 CEMENT CIRC P Circulate & condition mud @ 695 gpm, 2,692.0 2,692.0 17:15 19:30 1340 psi, FO 60%. Estimate 25 bbls of cement flushed to surface. Page 16/69 Report Printed: 2/29/2016 AME "p,Operations Summary (with Timelog Depths) .�...� Wit, 2S-13 Rig: DOYON 141 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) 12/13/2015 12/13/2015 0.25 INTRM1 CEMENT TRIP P PJSM; TOH f/ 2692'-2374' MD. 2,692.0 2,374.0 19:30 19:45 12/13/2015 12/13/2015 0.75 INTRM1 CEMENT PRTS P PJSM; rig up test equipment, test liner 2,374.0 2,374.0 19:45 20:30 top packer to 1000 psi for 10 min on chart, rig down test equipment. 12/13/2015 12/13/2015 0.50 INTRM1 CEMENT TRIP P PJSM; TOH f/ 2374'-1262' MD. 2,374.0 1,262.0 20:30 21:00 12/13/2015 12/14/2015 3.00 INTRM1 CEMENT PULD P PJSM; pull out of the hole laying down 1,262.0 0.0 21:00 00:00 42 joints of HWDP f/ 1262'-0. HWDP sheathed with cement inside & out. 12/14/2015 12/14/2015 1.00 INTRM1 CEMENT BHAH P PJSM; break apart & lay down liner 0.0 0.0 00:00 01:00 running tool as per Baker Rep. 12/14/2015 12/14/2015 0.50 INTRM1 CEMENT RURD P PJSM; break 2 pup joints from cement 0.0 0.0 01:00 01:30 head. 12/14/2015 12/14/2015 1.00 INTRM1 CEMENT PULD P PJSM; pick up 1 stand of 5" DP, lay 0.0 0.0 01:30 02:30 down 1 stand of 5" DP & 1 stand of 5" HWDP from derrick. 12/14/2015 12/14/2015 0.50 INTRM1 CEMENT WWWH P PJSM; flush stack & blow down TD. 0.0 0.0 02:30 03:00 12/14/2015 12/14/2015 0.50 INTRM1 CEMENT RURD P Clear & clean rig floor. 0.0 0.0 03:00 03:30 12/14/2015 12/14/2015 1.25 INTRM1 CEMENT BOPE P PJSM; drain stack, change out top 0.0 0.0 03:30 04:45 rams to 3.5" X 6" VBR's, & pull wear bushing. 12/14/2015 12/14/2015 3.00 INTRM1 CEMENT MPDA P PJSM; pull trip nipple & install MPD 0.0 0.0 04:45 07:45 test cap. Rig up & test MPD system to 1200 psi. Blow down MPD lines. Remove test cap. Spill drill CRT 79 secs @ 05:30 hrs. 12/14/2015 12/14/2015 1.00 INTRM1 CEMENT BOPE P PJSM; rig up to test BOPE. 0.0 0.0 07:45 08:45 Switch from shore power to rig generators @ 08:00 hrs. 12/14/2015 12/14/2015 1.50 INTRM1 CEMENT BOPE P PJSM; test 3-1/2" joint, annular to 0.0 0.0 08:45 10:15 250/2500 psi, test upper & lower VBR's to 250/3500 psi, each test 5 min. Test upper VBR's w/ 5" joint to 25/3500 psi for 5 min each test. All tests charted. 12/14/2015 12/14/2015 0.50 INTRM1 CEMENT BOPE P PJSM; rig down test equipment & blow 0.0 0.0 10:15 10:45 down lines. 12/14/2015 12/14/2015 1.25 INTRMI CEMENT BHAH P PJSM; mobilize BHA tools up beaver 0.0 0.0 10:45 12:00 slide. 12/14/2015 12/14/2015 1.75 INTRM1 CEMENT BHAH P PJSM; pick up BHA 3 as per SLB f/ 0- 0.0 773.0 12:00 13:45 773' MD. 12/14/2015 12/14/2015 0.75 INTRM1 CEMENT TRIP P PJSM; TIH f/ 773'-1500' MD. 773.0 1,500.0 13:45 14:30 12/14/2015 12/14/2015 0.25 INTRM1 CEMENT DHEQ P Shallow hole test MWD 500 gpm, 900 1,500.0 1,500.0 14:30 14:45 psi, 35 rpm, Tq 4K. 12/14/2015 12/14/2015 0.50 INTRM1 CEMENT CIRC T Circulate & condition mud due to 1,500.0 1,500.0 14:45 15:15 cement contamination @ 3 bpm, 150 psi. 12/14/2015 12/14/2015 2.25 INTRM1 CEMENT TRIP P PJSM; TIH f/ 1500'-6340' MD, filling 1,500.0 6,340.0 15:15 17:30 I I pipe every 20 stands. Page 17/69 Report Printed: 2/29/2016 - Operations Summary (with Timelog Depths) ) 6 K 2S-13 Rig: DOYON 141 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) 12/14/2015 12/14/2015 2.50 INTRMI CEMENT CIRC T Attempt to turn on logging tool @ 500 6,340.0 6,340.0 17:30 20:00 gpm, 1800 psi. Slow down due to thick mud running over the shakers. Circulate & condition mud due to cement contamination @ 3 bpm, 500 psi. Stage up parameters to 500 gpm; 1375 psi, 75 rpm, Tq 10-13K, PU 175K, SO 105K, ROT 132K. 12/14/2015 12/14/2015 3.25 INTRM1 CEMENT DLOG P PJSM; TIH logging f/ 6340'-9167' MD 6,340.0 9,167.0 20:00 23:15 @ 1500 fph, fill every 20 stands. Calculated displacement 86, actual 86 bbls. 12/14/2015 12/15/2015 0.75 INTRMI CEMENT CIRC P CBU @ 500 gpm, 1550 psi, 40 rpm, 9,167.0 9,167.0 23:15 00:00 Tq 15-20K, PU 205K, SO 115K, ROT 152K. Spill Drill CRT 77 sec @ 23:35 hrs. 12/15/2015 12/15/2015 1.00 INTRM1 CEMENT CIRC P CBU @ 500 gpm, 1550 psi, 40 rpm, 9,167.0 9,176.0 00:00 01:00 Tq 15-20K, PU 205K, SO 115K, ROT 152K. 12/15/2015 12/15/2015 1.25 INTRM1 CEMENT RURD P PJSM; rig up to test casing & blow 9,176.0 9,176.0 01:00 02:15 down TD. 12/15/2015 12/15/2015 0.75 INTRM1 CEMENT PRTS P PJSM; test 10-3/4" liner to 3500 psi for 9,176.0 9,176.0 02:15 03:00 30 min. Pumped 12.2 bbls pressuring up to 3550. After 30 minutes pressure at 3475 psi. Bled back 12.0 bbls. Test charted. 12/15/2015 12/15/2015 0.25 INTRMI CEMENT RURD P PJSM; rig down test equipment & blow 9,176.0 9,176.0 03:00 03:15 down kill line. 12/15/2015 12/15/2015 0.50 INTRM1 CEMENT COCF P Clean out to top of plugs at landing 9,176.0 9,205.0 03:15 03:45 collar 9176'-9205' MD @ 500 gpm, 1675 psi, FO 58%, 60 rpm, Tq 23- 25K. 12/15/2015 12/15/2015 4.75 INTRM1 CEMENT DRLG P Drill out shoe track & rat hole f/ 9205'- 9,205.0 9,329.0 03:45 08:30 9329' MD, 500 grpm, 1675-1725' psi, 60 rpm, Tq 23-25K, WOB 2-15K. Fire Drill CRT 160 sec @ 04:45 hrs. 12/15/2015 12/15/2015 0.50 INTRM1 CEMENT DDRL P DDrilling intermediate #2 pilot hole f/ 9,329.0 9,349.0 08:30 09:00 9329'-9349' MD, 6033' TVD, ADT .3, Bit hrs .3, Jars 70.94, PU 245K, SO 115K, ROT 156K, Tq on 20-25K, off 23K, ECD 10.52, FO 59%, WOB 10- 15K, 80 rpm, 600 gpm, 2180 psi, Max Gas 0 Total footage 20' MD. 12/15/2015 12/15/2015 1.50 INTRM1 CEMENT CIRC P Circulate & condition for even mud @ 9,349.0 9,349.0 09:00 10:30 680 gpm, 2645 psi, FO 62%. 80 rpm, Tq 21-22K- 12/15/2015 12/15/2015 0.25 INTRM1 CEMENT TRIP P TOH f/ 9349'-9257' MD & blow down 9,349.0 9,257.0 10:30 10:45 TD. 12/15/2015 12/15/2015 1.00 INTRM1 CEMENT LOT P PJSM; rig up for LOT. Perform LOT to 9,257.0 9,257.0 10:45 11:45 EMW 15.0 ppg. Pressure up to 1550 psi after pumping 5.4 bbls & start to break over with 6.7 bbls pumped away using 10.0 ppg mud. Shut in & record pressures, with 1375 psi at 10 minutes. Bled back 5.6 bbls. Rig down test equipment & blow down Kill line. 12/15/2015 0.25 INTRM2 DRILL TRIP P TIH f/ 9257'-9291' MD 9,257.0 9,291.0 112/15/2015 11:45 12:00 I Page 18/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/15/2015 12/15/2015 1.00 INTRM2 DRILL MPDA P PJSM; remove trip nipple & install 9,291.0 9,291.0 12:00 13:00 RCD. 12/15/2015 12/15/2015 0.75 INTRM2 DRILL CIRC P Circulate & condition mud to increase 9,291.0 9,291.0 13:00 13:45 f/ 9.9 ppg to 10.5 ppg at 700 gpm, 2100 psi, 50 rpm, Tq 20K. 12/15/2015 12/15/2015 4.25 INTRM2 DRILL DDRL P DDrilling intermediate #2 pilot hole f/ 9,291.0 9,576.0 13:45 18:00 9349'-9576' MD, 6136' TVD, ADT 3.36, Bit hrs 3.66, Jars 74.3, PU 210K, SO 106K, ROT 142K, Tq on 20-24K, off 16-17K, ECD 11.70, FO 66%, WOB 7-1 OK, 140 rpm, 695 gpm, 2750 psi, Max Gas 818. Total footage 227' MD SPR's @ 9348' MD, 6032' TVD, MW 10.5 ppg, 13:45 hrs #1 @ 30 = 170; @ 40 = 245 psi #2 @ 30 = 170; @ 40 = 250 psi 12/15/2015 12/16/2015 6.00 INTRM2 DRILL DDRL P DDrilling intermediate #2 pilot hole f/ 9,576.0 9,909.0 18:00 00:00 9576'-9909' MD, 6301' TVD, ADT 4.47, Bit hrs 8.13, Jars 78.77, PU 216K, SO 108K, ROT 142K, Tq on 22- 25K, off 17-18K, ECD 11.98, FO 71 %, WOB 12-18K, 100 rpm, 750 gpm, 3375 psi, Max Gas 5110. Total footage 333' MD SPR's @ 9909' MD, 6299' TVD, MW 10.5+ ppg, 23:45 hrs #1 @ 30 = 330; @ 40 = 380 psi #2 @ 30 = 310; @ 40 = 370 psi 12/16/2015 12/16/2015 6.25 INTRM2 DRILL DDRL P DDrilling intermediate #2 pilot hole f/ 9,909.0 10,303.0 00:00 06:15 9909'-10303' MD, 6585' TVD, ADT 4.16, Bit hrs 12.29, Jars 82.93, PU 235K, SO 116K, ROT 152K, Tq on 25- 28K, off 22-23K, ECD 12.08, FO 87%, WOB 10-15K, 120 rpm, 750 gpm, 3360 psi, Max Gas 9895. Total footage 394' MD TD 10303' MD. SPR's @ 9909' MD, 6299' TVD, MW 10.6 ppg, 00:00 hrs #1 @ 30 = 330; @ 40 = 380 psi #2@30=310;@40=370 psi 12/16/2015 12/16/2015 2.00 INTRM2 PLUG CIRC P Circulate & condition to 10.7 ppg mud 10,303.0 10,303.0 06:15 08:15 weight in & out @ 750 gpm, 3350 psi, 120 rpm, Tq 22K. 12/16/2015 12/16/2015 0.50 INTRM2 PLUG OWFF P Perform finger print (pore pressure 10,303.0 10,303.0 08:15 08:45 test) to a EMW of 11.63 ppg. 12/16/2015 12/16/2015 3.25 INTRM2 PLUG CIRC P Weight up mud system f/ 10.7 ppg to 10,303.0 10,303.0 08:45 12:00 11.5 ppg. 750gpm, 3420 psi, FO 88%, 120 rpm, Tq 20-25K. Reduce rate to 535 gpm, 2050 psi, FO 65%, as ECD climbs due to weight up. PU 205K, SO 126K, ROT 154K. 12/16/2015 12/16/2015 6.00 INTRM2 PLUG CIRC P Continue weight up f/ 11.5 - 11.9 ppg 10,303.0 10,303.0 12:00 18:00 & vis 45 to 57 FV. Pump at 500 gpm, 2000 psi, 35 rpm, Tq 13K. SPR's @ 10280' MD, 6567' TVD, MW 11.9+ ppg, 18:00 hrs #1 @ 30 = 540; @ 40 = 660 psi #2 @ 30 = 550; @ 40 = 620 psi Page 19169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (f.KB) End Depth (ftKB) 12/16/2015 12/16/2015 0.75 INTRM2 PLUG OWFF P Monitor well pumping across the top of 10,303.0 10,303.0 18:00 18:45 the hole, no gain or loss. Blow down TD. 12/16/2015 12/16/2015 1.75 INTRM2 PLUG SMPD P PJSM; TOH f/ 10303'-9260' MD. 10,303.0 9,260.0 18:45 20:30 12/16/2015 12/16/2015 0.50 INTRM2 PLUG OWFF P Monitor well pumping across the top of 9,260.0 9,260.0 20:30 21:00 the hole, no gain or losses. 12/16/2015 12/17/2015 3.00 INTRM2 PLUG SMPD P PJSM; Strip OOH f/ 9260'-5143' MD. 9,260.0 5,143.0 21:00 00:00 Calculated fill 43, actual 58 bbls. 12/17/2015 12/17/2015 1.50 INTRM2 PLUG SMPD P PJSM; StripOOH f/ 5143'-2641' MD, 5,143.0 2,641.0 00:00 01:30 holding 110 psi while tripping & 30 psi in the slips. 12/17/2015 12/17/2015 2.00 INTRM2 PLUG MPDA P PJSM; drain stack, blow down MPD 2,641.0 2,641.0 01:30 03:30 choke / lines, pull RCD bearing & install trip nipple. 12/17/2015 12/17/2015 1.00 INTRM2 PLUG TRIP P TOH f/ 2641'-773' MD. 2,641.0 773.0 03:30 04:30 12/17/2015 12/17/2015 0.25 INTRM2 PLUG OWFF P Monitor well, static. 773.0 773.0 04:30 04:45 12/17/2015 12/17/2015 0.75 INTRM2 PLUG TRIP P TOH f/ 773'-108' MD, rack back 6 773.0 108.0 04:45 05:30 stands of HWDP & 1 stand of NMFC. 12/17/2015 12/17/2015 1.75 INTRM2 PLUG BHAH P PJSM; lay down BHA 3 as per SLB. 108.0 0.0 05:30 07:15 Calculated fill 59.2, actual 67.22 bbls. 12/17/2015 12/17/2015 0.75 INTRM2 PLUG BHAH P Clear & clean rig floor. 0.0 0.0 07:15 08:00 12/17/2015 12/17/2015 0.75 INTRM2 PLUG RURD P PJSM; mobilize casing tools to the rig 0.0 0.0 08:00 08:45 floor & rig up to run tubing. 12/17/2015 12/17/2015 1.25 INTRM2 PLUG PULD P PJSM; PU mule shoe, 36 joints of 3- 0.0 1,134.0 08:45 10:00 1/2" ELIE, 9.3 #, L-80 work string & 2 XO's f/ 0-1134' MD. 3 joints rejected; 2 w/ bad pin ends & 1 w/ bad box. 12/17/2015 12/17/2015 4.00 INTRM2 PLUG TRIP P PJSM; TIH w/ 5" DP & cement stinger 1,134.0 10,117.0 10:00 14:00 f/ 1134'-10117' MD. 12/17/2015 12/17/2015 0.75 INTRM2 PLUG WASH P Wash down f/ 10117'-10303' MD, 200 10,117.0 10,303.0 14:00 14:45 gpm, 700 psi. 12/17/2015 12/17/2015 3.50 INTRM2 PLUG CIRC P Circulate & condition for cement plugs 10,303.0 10,303.0 14:45 18:15 @ 300-350 gpm, 1075-1250 psi. PU 185K, SO 106K. 12/17/2015 12/17/2015 1.25 INTRM2 PLUG CMNT P PJSM; batch up & pump 5 bbls of 13.0 10,303.0 10,303.0 18:15 19:30 ppg MPII to flood lines. PT lines 400 / 4000 psi. Pump 25 bbls of 13.0 ppg MPII @ 3.4 bpm, 460 psi. Load wiper ball in pipe & batch up cement. Pump 70 bbls of 15.8 ppg cement w/ 1.5 ppb CemNet @ 4.4 bpm, 430-100 psi. Pump 5.3 bbls of 13.7 MPII @ 3.5 bpm, 30 psi. Swap to rig & displace with 156 bbls of 11.9 ppg mud @ 4.5 bpm, 125-780 psi. CIP 19:28 hrs. 12/17/2015 12/17/2015 0.75 INTRM2 PLUG TRIP P TOH f/ 10303'-9710' MD @ 1500 fph. 10,303.0 9,710.0 19:30 20:15 12/17/2015 12/17/2015 3.25 INTRM2 PLUG CIRC P Circulate & condition mud @ 4-8 bpm, 9,710.0 9,710.0 20:15 23:30 725-1300 psi. Page 20169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/17/2015 12/18/2015 0.50 INTRM2 PLUG CMNT P PJSM; pump 31 bbls 13.0 ppg MPII @ 9,710.0 9,710.0 23:30 00:00 4.4 bpm, 575 psi. Shut down to batch up cement, load wiper ball in pipe. Pump 66 bbls of 17.0 ppg cement w/ 1.5 ppb CemNet @ 4 bpm, 475-40 psi. Pump 7 bbls of 13.0 ppg MPII @ 3 bpm, 10 psi. Swap to rig to displace with 11.9 ppg mud. 12/18/2015 12/18/2015 0.75 INTRM2 PLUG CMNT P Swap to rig to displace 143 bbls with 9,710.0 9,710.0 00:00 00:45 11.9 ppg mud @ 4.5 bpm, 120-800 psi. CIP @ 00:40 hrs. 12/18/2015 12/18/2015 0.75 INTRM2 PLUG TRIP P PJSM; TOH f/ 9710'-9117' MD, 1000- 9,710.0 9,117.0 00:45 01:30 1500 fph. 12/18/2015 12/18/2015 2.00 INTRM2 PLUG CIRC P Circulate excess cement to surface. 9,117.0 9,066.0 01:30 03:30 Load foam wiper ball & pump pipe volume @ 200 gpm, 675 psi, FO 44%. Increase pump rate to 350-600 gpm, 980-1855 psi, FO 52-61 %. Rack back stand 9117'-9066' MD, blow down TD. 12/18/2015 12/18/2015 0.50 INTRM2 PLUG OWFF P Monitor well, static, 9,066.0 9,066.0 03:30 04:00 12/18/2015 12/18/2015 3.75 INTRM2 PLUG TRIP P PJSM; TOH f/ 9066-1228' MD. 9,066.0 1,228.0 04:00 07:45 Calculated fill 66.3, actual 72.76 bbls. 12/18/2015 12/18/2015 0.50 INTRM2 PLUG OWFF P Monitor well, static, 1,228.0 1,228.0 07:45 08:15 12/18/2015 12/18/2015 0.25 INTRM2 PLUG TRIP P Rack back 1 stand & break out XO's. 1,228.0 1,134.0 08:15 08:30 12/18/2015 12/18/2015 2.50 INTRM2 PLUG PULD P PJSM; TOH laying down 3-1/2" tubing 1,134.0 0.0 08:30 11:00 f/ 1134'-0. 12/18/2015 12/18/2015 1.00 INTRM2 PLUG RURD P PJSM; rig down casing equipment & 0.0 0.0 11:00 12:00 clear rig floor. 12/18/2015 12/18/2015 1.00 INTRM2 PLUG WWWH P PJSM; flush stack & pull wear 0.0 0.0 12:00 13:00 bushing. 12/18/2015 12/18/2015 0.50 INTRM2 WHDBOP RURD P Set test plug & rig up to test. 0.0 0.0 13:00 13:30 Page 21169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation ^B) End Depth (ftKB) 12/18/2015 12/18/2015 6.50 INTRM2 WHDBOP BOPE P Test BOPE w/ 5" test joint to 250/3500 0.0 0.0 13:30 20:00 psi for 5 min each. Test #1; Top pipe rams, CV 1,12,13,and 14 & manual kill. Test #2: Upper IBOP, HCR kill, CV 9 and 11. Test #3: Lower IBOP, CV 5,8 and 10. Test #4: Dart valve, CV 4, 6 and 7. Test #5: Floor valve and CV 2. Test #6" HCR choke and 4" kill line Demco. Test # 7: Manual choke and HCR kill. Test #8: Annular to 250/2500 psi. Test #9: Lower pipe rams(fail) Test# 10: Blind rams and CV 3. Test #10; 4" TJ in the annular 250/2500 psi. Test #11; 4" TJ in the lower VBR's, (fail). Test #12; 4"TJ in upper VBR's (fail). Tested hydraulic & manual chokes to 1100 psi. Accumulator test: System pressure= 3000 psi, pressure after closing= 1900 psi, 200 psi attained after 42 sec, full pressure attained after 171 sec. Five bottle nitrogen avg= 1975 psi. 3 Fail / Pass= #1 Lower VBR's failed, changed out testing good w/ 4" test joint. While testing w/ 5" found deformities on test joint. Repositioned joint & good test w/ 5". #2 Visual alarm in pits failed. Found loose ground wire, tightened. Retest visual alarm good. #3 4"TJ in upper VBR's. Fail initial, function & retest good.Test all gas alarms. AOGCC rep Matt Herrera witnessed the test. 12/18/2015 12/18/2015 2.50 INTRM2 WHDBOP BOPE T PJSM; change out lower 2-7/8" X 5" 0.0 0.0 20:00 22:30 VBR's. Retest w/ 4" TJ to 250 / 3500 psi good. Retest w/ 5" TJ 250 / 3500 psi, good. Tests charted for 5 minutes each. While attempting to test 5" TJ found deformities on TJ. repositioned joint higher & VBR's tested good. 12/18/2015 12/18/2015 0.75 INTRM2 WHDBOP RURD P PJSM; rig down test equipment & blow 0.0 0.0 22:30 23:15 down lines. Set wear bushing w/ 13.25" ID. 12/18/2015 12/18/2015 0.50 INTRM2 PLUG BHAH P PJSM; moblize BHA 4 to rig floor. 0.0 0.0 23:15 23:45 12/18/2015 12/19/2015 0.25 INTRM2 PLUG BHAH P PJSM; make up bit & 6-3/4" Xceed. 0- 0.0 26.0 23:45 00:00 26' 12/19/2015 12/19/2015 2.50 INTRM2 PLUG BHAH P PJSM; Pick up BHA 4 as per SLB 26'- 26.0 746.0 00:00 02:30 746' MD. 12/19/2015 12/19/2015 0.50 INTRM2 PLUG TRIP P TIH f/ 746'-1492' MD. 746.0 1,492.0 02:30 03:00 12/19/2015 12/19/2015 1.00 INTRM2 PLUG DHEQ P Shallow hole test MWD, stage up 1,492.0 1,492.0 03:00 04:00 pumps to 500 gpm, 90 psi, FO 56W 12/19/2015 12/19/2015 4.25 INTRM2 PLUG TRIP P TIH f/ 1492'-8675' MD, fill every 20 1,492.0 8,675.0 04:00 08:15 stands, calculated displacement 83.3, actual 83.3 bbls. 12/19/2015 12/19/2015 2.00 INTRM2 PLUG SLPC P PJSM; cut & slip 66' of drill line, 8,675.0 8,675.0 08:15 10:15 inspect brakes, & service TD. Page 22/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/19/2015 12/19/2015 1.75 INTRM2 PLUG REAM P PJSM; wash & ream to TOC @ 9131' 8,675.0 9,131.0 10:15 12:00 MD, 450 gpm, 1540 psi, 30 rpm, Tq 18K, PU 215k, SO 100K, ROT 140K, FO 56%. 12/19/2015 12/19/2015 3.25 INTRM3 DRILL DRLG P Drill out cement f/ 9131'-9323' MD, PU 9,131.0 9,323.0 12:00 15:15 230K, SO 100K, ROT 139K, Tq on 20- 25K, off 20K, ECD 12.69, FO 61%, WOB 12-19K, rpm 80, gpm 650, 2550 psi, Max Gas 0. 12/19/2015 12/19/2015 1.00 INTRM3 DRILL CIRC T CBU to troubleshoot lost real time 9,323.0 9,323.0 15:15 16:15 communication with the Xceed rotary steerable. Pump at 650 gpm, 2850 psi. Decision made to trip & change out. 12/19/2015 12/19/2015 0.75 INTRM3 DRILL OWFF T Monitor well, static. 9,323.0 9,323.0 16:15 17:00 12/19/2015 12/19/2015 1.25 INTRM3 DRILL MPDA T PJSM; install MPD bearing. 9,323.0 9,323.0 17:00 18:15 12/19/2015 12/19/2015 2.75 INTRM3 DRILL SMPD T PJSM; stripOOH f/ 9323'-5510' MD; 9,323.0 5,510.0 18:15 21:00 holding 30 psi in the slips & 130 psi while tripping. 12/19/2015 12/19/2015 0.25 INTRM3 DRILL CIRC T PJSM; pump 28 bbl dry job @ 320 5,510.0 5,510.0 21:00 21:15 gpm, 700 psi. 12/19/2015 12/19/2015 0.75 INTRM3 DRILL SMPD T PJSM; stripOOH f/ 5510'-3965' MD, 5,510.0 3,965.0 21:15 22:00 holding 30 psi in the slips & 130 psi while tripping. 12/19/2015 12/19/2015 0.50 INTRM3 DRILL SVRG T PJSM; service rig & clear drains under 3,965.0 3,965.0 22:00 22:30 rig floor. 12/19/2015 12/19/2015 0.75 INTRM3 DRILL SMPD T PJSM; stripOOH f/ 3965'-2636' MD, 3,965.0 2,636.0 22:30 23:15 holding 30 psi in the slips & 130 psi while tripping. 12/19/2015 12/20/2015 0.75 INTRM3 DRILL MPDA T PJSM; remove MPD bearing & install 2,636.0 2,636.0 23:15 00:00 trip nipple. 12/20/2015 12/20/2015 1.50 INTRM3 DRILL MPDA T PJSM; continue installing trip nipple & 2,636.0 2,636.0 00:00 01:30 change out air boots. 12/20/2015 12/20/2015 1.25 INTRM3 DRILL TRIP T PJSM; TOH f/ 2636'-746' MD. 2,636.0 746.0 01:30 02:45 Calculated fill 16.4, actual 16.1 bbls. 12/20/2015 12/20/2015 0.25 INTRM3 DRILL OWFF T Monitor well at the HWDP, static. 746.0 746.0 02:45 03:00 12/20/2015 12/20/2015 2.25 INTRM3 DRILL BHAH T PJSM; stand back 6 HWDP w/ Jars, 746.0 0.0 03:00 05:15 NMFC, lay down MWD, EcoScope, Xceed. 12/20/2015 12/20/2015 0.50 INTRM3 DRILL BHAH T Clear & clean rig floor, prep Xceed. 0.0 0.0 05:15 05:45 12/20/2015 12/20/2015 2.25 INTRM3 DRILL BHAH T PJSM; make up bit, Xceed, 0.0 746.0 05:45 08:00 EcoScope, & MWD. Load source. Make up XO, NMFC, Well Commander, 6 stands of HWDP w/ jars to 746' MD. Calculated displacement 15.2, actual 15,2 bbls. 12/20/2015 12/20/2015 0.50 INTRM3 DRILL TRIP T PJSM; TIH f/ 746'-1678' MD. 746.0 1,648.0 08:00 08:30 12/20/2015 12/20/2015 0.50 INTRM3 DRILL DHEQ T Shallow test MWD @ 500 gpm, 1025 1,648.0 1,648.0 08:30 09:00 psi, FO 56%. 12/20/2015 12/20/2015 4.00 INTRM3 DRILL TRIP T PJSM; TIH f/ 1678'-9230' MD, fill 1,648.0 9,230.0 09:00 13:00 every 20 stands, calculated displacement 111.3, actual 117.4 bbls. Page 23/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 1 • •.• r, Rig: DOYON 141 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) 12/20/2015 12/20/2015 0.75 INTRM3 DRILL WASH T Wash down f/ 9230'-9323', testing 9,230.0 9,323.0 13:00 13:45 tools, pumping @ 525 gpm, 2200 psi. 12/20/2015 12/20/2015 0.75 INTRM3 DRILL CIRC T CBU @ 525 gpm, 2200 psi. SIMOPS 9,323.0 9,323.0 13:45 14:30 change out micro switch on drawworks. 12/20/2015 12/20/2015 0.50 INTRM3 DRILL OWFF P Monitor well, static. 9,323.0 9,323.0 14:30 15:00 12/20/2015 12/20/2015 0.75 INTRM3 DRILL MPDA P PJSM; install MPD bearing. 9,323.0 9,323.0 15:00 15:45 12/20/2015 12/20/2015 1.25 INTRM3 DRILL CIRC P Circulate & condition to bring MW 9,323.0 9,323.0 15:45 17:00 down from 11.7+ ppg to 11.2 ppg @ 700 gpm, 3000 psi, FO 90%. 12/20/2015 12/21/2015 7.00 INTRM3 DRILL DDRL P DDrilling intermediate #3 pilot hole f/ 9,323.0 9,633.0 17:00 00:00 9323'-9633' MD, 6159' TVD, ADT 5.08, Bit hrs 5.08, Jars 88.01, PU 240K, SO 102K, ROT 140K, Tq on 20- 25K, off 18-22K, ECD 12.05, FO 87%, WOB 15-20K, 80 rpm, 650 gpm, 2650 psi, Max Gas 253. Total footage 310' MD SPR's @ 9416' MD, 6064' TVD, MW 11.1+ ppg, 18:00 hrs #1 @ 30 = 300; @ 40 = 375 psi #2 @ 30 = 290; @ 40 = 395 psi 12/21/2015 12/21/2015 7.00 INTRM3 DRILL DDRL P DDrilling intermediate #3 pilot hole f/ 9,633.0 9,831.0 00:00 07:00 9633'-9831' MD, 6229' TVD, ADT 5.05, Bit hrs 10. 13, Jars 93.06, PU 251 K, SO 96K, ROT 147K, Tq on 20- 22K, off 20-24K, ECD 11.94, FO 88%, WOB 13-20K, 60-100 rpm, 650 gpm, 2740 psi, Max Gas 834. Total footage 198' MD 12/21/2015 12/21/2015 1.00 INTRM3 DRILL CIRC T Pump 12.1 ppg weighted sweep @ 9,831.0 9,831.0 07:00 08:00 750 gpm, 3440 psi, 140 rpm, Tq 15- 20K, FO 86%. 12/21/2015 12/21/2015 4.00 INTRM3 DRILL DDRL P DDrilling intermediate #3 pilot hole f/ 9,831.0 9,928.0 08:00 12:00 9831'-9928' MD, 6256' TVD, ADT 2.65, Bit hrs 12.69, Jars 95.62, PU 275K, SO 90K, ROT 145K, Tq on 15- 25K, off 15-25K, ECD 12.2, FO 88%, WOB 15-20K,140 rpm, 750 gpm, 3460 psi, Max Gas 1164. Total footage 97' MD SPR's @ 9881' MD, 6242' TVD, MW 11.1 ppg, 10:15 hrs #1 @ 30 = 400; @ 40 = 500 psi #2 @ 30 = 410; @ 40 = 472 psi 12/21/2015 12/21/2015 6.00 INTRM3 DRILL DDRL P DDrilling intermediate #3 pilot hole f/ 9,928.0 10,235.0 12:00 18:00 9928'-10235' MD, 6310' TVD, ADT 5.07, Bit hrs 17.76, Jars 100.69, PU 270K, SO 87K, ROT 140K, Tq on 20- 29K, off 18-28K, ECD 12.21, FO 88%, WOB 20-25K,110 rpm, 750 gpm, 3450 psi, Max Gas 1285. Total footage 307' MD Page 24169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/21/2015 12/21/2015 4.75 INTRM3 DRILL DDRL P DDrilling intermediate #3 pilot hole f/ 10,235.0 10,444.0 18:00 22:45 9928'-10444' MD, 6320' TVD, ADT 3.31, Bit hrs 21.07, Jars 104.0, PU 272K, SO 88K, ROT 140K, Tq on 20- 28K, off 19-25K, ECD 12.20, FO 88%, WOB 20-25K,110 rpm, 750 gpm, 3500 psi, Max Gas 1233. Total footage 516' MD. TD Intermediate #3 hole section at 10444' MD, 6320' TVD. 12/21/2015 12/22/2015 1.25 INTRM3 CASING CIRC P Pump weighted sweep & CBU at 750 10,444.0 10,444.0 22:45 00:00 gpm, 3450 psi, 115 rpm, Tq 20-22K, FO 88%, PU 270K, SO 87K, ROT 140K. SPR's @ 10444' MD, 6320' TVD, MW 11.1+ ppg, 23:00 hrs #1 @ 30 = 380; @ 40 = 490 psi #2 @ 30 = 395; @ 40 = 500 psi 12/22/2015 12/22/2015 1.75 INTRM3 CASING CIRC P Pump weighted sweep & CBU at 750 10,444.0 10,444.0 00:00 01:45 gpm, 3450 psi, 115 rpm, Tq 20-22K, FO 88%, PU 270K, SO 87K, ROT 140K. 12/22/2015 12/22/2015 0.50 INTRM3 CASING OWFF P Lay down pup jt. Blow down TD. 10,444.0 10,444.0 01:45 02:15 Perform wellbore finger print. Pressure built to 146 psi/11.6 ppg EMW. 12/22/2015 12/22/2015 1.00 INTRM3 CASING CIRC P CBU. 750 gpm, 3430 psi, 110 rpm, 20- 10,444.0 10,444.0 02:15 03:15 25K tq, FO=70% 12/22/2015 12/22/2015 6.00 INTRM3 CASING CIRC P Circ and weight up mud system to 10,444.0 10,444.0 03:15 09:15 11.9 ppg using 16.0 ppg spike fluid. 380 gpm, 1220 psi, 110 rpm, 20-25K tq, FO=70% 12/22/2015 12/22/2015 0.75 INTRM3 CASING OWFF P Blow down TD, Pump across top of 10,444.0 10,444.0 09:15 10:00 hole, Monitor well. 12/22/2015 12/22/2015 2.00 INTRM3 CASING SMPD P Strip out of hole using RCD f/10444' 10,444.0 9,865.0 10:00 12:00 MD U9884' MD. Hold 130 psi back pressure. Wipe through tight hole (/9885' MD t/9865' MD Calc disp.=3.9 bbls Act disp=4.2 bbls 12/22/2015 12/22/2015 1.50 INTRM3 CASING SMPD T Wipe through tight hole N9865' MD 9,865.0 9,557.0 12:00 13:30 t/9557' MD 12/22/2015 12/22/2015 3.50 INTRM3 CASING SMPD P Strip out of hole using RCD (/9557' 9,557.0 9,318.0 13:30 17:00 MD t/9318' MD. Hold 130 psi back pressure. Calc disp.=3.9 bbls Act disp=4.2 bbls 12/22/2015 12/23/2015 7.00 INTRM3 CASING WAIT T Circ @ 9318' MD. 315 gpm, 840 psi, 9,318.0 9,318.0 17:00 00:00 40 rpm, 20K tq. PU 265K SO 109K FO 52%. Wait on new 11.2 ppg LSND mud from mud plant. 12/23/2015 12/23/2015 6.00 INTRM3 CASING WAIT T Circ @ 9318' MD. 275 gpm, 810 psi, 9,318.0 9,318.0 00:00 06:00 40 rpm, 20K tq. PU 215K SO 108K Rot 147K FO 50%. Sim-ops/Work on kMP2's, Clean pits. Bring on new 11.2 ppg LSND mud.. Wait on additional new 11.2 ppg LSND mud from mud plant. Page 25/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/23/2015 12/23/2015 7.75 INTRM3 CASING WAIT T Circ @ 9318' MD. 275 gpm, 810 psi, 9,318.0 9,318.0 06:00 13:45 40 rpm, 20K tq. PU 215K SO 108K Rot 147K FO 50%. Sim -ops/ Check and service mud pumps, Change out hydraulic ram on torque tube beaver tail. Bring on new 11.2 ppg LSND mud..Wait on trucks. 12/23/2015 12/23/2015 2.25 INTRM3 CASING DISP T Displace well to new 11.2 ppg LSND 9,318.0 9,318.0 13:45 16:00 mud.350 gpm, 1050 psi, 90 rpm, 21 K tq, PU 185K, SO 117K, Rot 145K SPR's @ 9414' MD, 6063' TVD, MW 11.2+ ppg, 16:00 hrs #1 @ 30 = 350; @ 40 = 420 psi #2 @ 30 = 335; @ 40 = 455 psi 12/23/2015 12/23/2015 6.50 INTRM3 CASING REAM T Ream in hole f/9318' MD t/10444' 9,318.0 10,444.0 16:00 22:30 MD. 600 gpm, 2300 psi, 90 rpm, 10- 14K tq, FO=80%, PU 180K SO 118K, Rot 147K 12/23/2015 12/24/2015 1.50 INTRM3 CASING CIRC T CBU x2. 680 gpm, 90 rpm, 10-12K tq, 10,444.0 10,444.0 22:30 00:00 PU 200K, SO 118K, Rot 147K. 12/24/2015 12/24/2015 1.00 INTRM3 CASING CIRC T CBU x2. 680 gpm, 2760 psi, 90 rpm, 10,444.0 10,444.0 00:00 01:00 10-15K tq, PU 200K, SO 105K, Rot 137K. FO=87% 12/24/2015 12/24/2015 3.75 INTRM3 CASING CIRC T Weight up mud from 11.2 ppg to 11.9 10,444.0 10,440.0 01:00 04:45 ppg using 16 ppg spike fluid and dry product. Final circulation rates/320 gpm, 1056 psi, 70 rpm, 11 K tq, FO=70%, ECD= 12.54, PU 200K SO 100K, Rot 148K SPR's @ 10438' MD, 6320' TVD, MW 11.9+ ppg, 04:35 hrs #1 @ 30 = 420; @ 40 = 500 psi #2@30=425;@40=510 psi 12/24/2015 12/24/2015 0.75 INTRM3 CASING OWFF T Close MPD choke and check for 10,440.0 10,440.0 04:45 05:30 pressure f/5 min.. No pressure build up. Blow down TD. Monitor well. Static. 12/24/2015 12/24/2015 2.50 INTRM3 CASING SMPD T Strip OOH f/10444' MD t/9233' MD 10,440.0 9,233.0 05:30 08:00 holding 130 psi back pressure. PU 215K. Pull 40K over @ 9840' MD, Wipe through tight spot. Calc disp=10.1 bbls Act disp=11.9 bbls 12/24/2015 12/24/2015 0.75 INTRM3 CASING OWFF P Monitor well. Static. 9,233.0 9,233.0 08:00 08:45 12/24/2015 12/24/2015 5.75 INTRM3 CASING SMPD P Strip OOH (/9233' MD t/2556' MD 9,233.0 2,556.0 08:45 14:30 holding 130 psi back pressure. Calc disp=51.9 bbls Act disp=62.3 bbls 12/24/2015 12/24/2015 1.00 INTRM3 CASING MPDA P Remove RCD bearing assy. Install trip 2,556.0 2,556.0 14:30 15:30 nipple. 12/24/2015 12/24/2015 0.50 INTRM3 CASING TRIP P POOH on elevators. (/2556' MD 2,556.0 1,600.0 15:30 16:00 t/1600' MD. 12/24/2015 12/24/2015 0.25 INTRM3 CASING SFTY P Safety Standdown. Discuss incident 1,600.0 1,600.0 16:00 16:15 that occurred on Rig 7ES and staying focused during the holiday season. 12/24/2015 12/24/2015 0.75 INTRM3 CASING TRIP P POOH on elevators. f/1600' MD t/840' 1,600.0 840.0 16:15 17:00 MD. Page 26/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/24/2015 12/24/2015 0.25 INTRM3 CASING OWFF P Monitor well. Static. 840.0 840.0 17:00 17:15 12/24/2015 12/24/2015 0.75 INTRM3 CASING TRIP P POOH on elevators. f/840' MD t/193' 840.0 193.0 17:15 18:00 MD. 12/24/2015 12/24/2015 2.00 INTRM3 CASING BHAH P Lay down BHA as per SLB.. Clean 193.0 0.0 18:00 20:00 and clear rig floor Cal disp=30 bbls Act disp=31 bbls. 12/24/2015 12/24/2015 0.25 INTRM3 CASING RURD P Pull wear bushing 0.0 0.0 20:00 20:15 12/24/2015 12/24/2015 0.50 INTRM3 CASING MPDA P Flush MPD choke skid and lines 0.0 0.0 20:15 20:45 w/fresh water 12/24/2015 12/24/2015 0.50 INTRM3 CASING WWWH P Rig up stack flushing tool and flush 0.0 0.0 20:45 21:15 BOPE. 12/24/2015 12/24/2015 1.00 INTRM3 CASING BOPE P Change upper pipe rams to 7 5/8" 0.0 0.0 21:15 22:15 solid body rams. Sim-ops/Rig up Volant CRT to TD. 12/24/2015 12/24/2015 0.50 INTRM3 CASING BOPE P Rig up to test 7 5/8" rams 0.0 0.0 22:15 22:45 12/24/2015 12/24/2015 1.00 INTRM3 CASING BOPE P Test 7 5/8: rams to 250/3500 psi and 0.0 0.0 22:45 23:45 annular to 250/2500 psi 5 min each test. Rig down test equip. 12/24/2015 12/25/2015 0.25 INTRM3 CASING RURD P Rig up bail extensions and side door 0.0 0.0 23:45 00:00 elevators 12/25/2015 12/25/2015 0.25 INTRM3 CASING SFTY P Safety Standdown. Discuss incident 0.0 0.0 00:00 00:15 that occurred on Rig 7ES and staying focused during the holiday season. 12/25/2015 12/25/2015 0.25 INTRM3 CASING RURD P Change out rotary master bushings 0.0 0.0 00:15 00:30 12/25/2015 12/25/2015 1.00 INTRM3 CASING RURD P Perform dummy run of 7 5/8" hanger. 0.0 0.0 00:30 01:30 12/25/2015 12/25/2015 1.00 INTRM3 CASING RURD P Rig up to run 7 5/8" casing 0.0 0.0 01:30 02:30 12/25/2015 12/25/2015 9.50 INTRM3 CASING PUTB P Make up shoe track. Check floats. 0.0 3,683.0 02:30 12:00 Run 7 5/8" 29.7# L-80 Dopeless Hyd 563 casing to 3683' MD. Calc disp=39.96 bbls Act disp=38 bbls. 12/25/2015 12/25/2015 2.25 INTRM3 CASING PUTB P Run 7 5/8" 29.7# L-80 Dopeless Hyd 3,683.0 4,916.0 12:00 14:15 563 casing f/3683' MD t/4916' MD. Calc disp=13.3 bbls Act disp=11.2 bbls. 12/25/2015 12/25/2015 1.75 INTRM3 CASING CIRC P Circulate casing volume. Stage rate 4,916.0 4,916.0 14:15 16:00 up to 5.5 bpm, 300 psi. PU 125K SO 107K 12/25/2015 12/26/2015 8.00 INTRM3 CASING PUTB P Run 7 5/8" 29.7# L-80 Dopeless Hyd 4,916.0 8,720.0 16:00 00:00 563 casing f/4916' MD t/8720' MD. Slow running speed to 500 fph @ 8000' MD. PU 195K SO 133K Calc disp=39.98 bbls Act disp=38.15 bbls. 12/26/2015 12/26/2015 2.00 INTRM3 CASING PUTB P Run 7 5/8" 29.7# L-80 Dopeless Hyd 8,720.0 9,297.0 00:00 02:00 563 casing f/8720' MD t/9297' MD. Calc disp=7.38 bbls Act disp=3.15 bbls. 12/26/2015 12/26/2015 6.00 INTRM3 CASING CIRC P Circulate surface to surface volume. 9,297.0 9,297.0 02:00 08:00 Stage pumps up to 3 bpm, 420 psi, PU 195K SO 137K 43% FO Page 27/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation (ftKB) End Depth. (ftKB) 12/26/2015 12/26/2015 5.50 INTRM3 CASING PUTB P Run 7 5/8" 29.7# L-80 Dopeless Hyd 9,297.0 10,405.0 08:00 13:30 563 casing f/9297' MD t/10405 MD. Calc disp=11.96 bbls Act disp=6 bbis. Total of 254 jts run/ 7 5/8" 29.7# L-80 Dopeless Hyd 563 0 rejects -0 remakes 12/26/2015 12/26/2015 0.50 INTRM3 CASING HOSO P Make up hanger and landing jt. Land 10,405.0 10,434.0 13:30 14:00 casing @ 10434' MD. PU 220K SO 123K 12/26/2015 12/26/2015 7.25 INTRM3 CEMENT CIRC T Break circulation@ 1 bpm, 500 psi. 10,434.0 10,434.0 14.00 21:15 Stage rate up to 3 BPM, 600 psi, 42% FO. After 170 bbis pumped began losing returns. Reduce pump rate to 2 bpm, 500 psi, 13% FO. Land casing and reduce pump rate to 1 bpm, 400 psi, 2% FO. 20 bph loss rate. Max gas=1096 units 12/26/2015 12/26/2015 0.75 INTRM3 CEMENT RURD P Monitor well. Rig up cement line. Blow 10,434.0 10,434.0 21:15 22:00 down TD. 12/26/2015 12/27/2015 2.00 INTRM3 CEMENT WAIT T Circulate while waiting on additional 10,434.0 10,434.0 22:00 00:00 mud from mud plant. .5 bpm, 400 psi7% FO to 1 bpm, 425 psi, 11% FO. Variable loss rates from 14 bph to 30 bph. Max gas=1169 units. PU 225K SO 140K. 12/27/2015 12/27/2015 3.00 INTRM3 CEMENT WAIT T Circulate while waiting on additional 10,434.0 10,434.0 00:00 03:00 mud from mud plant. .5 bpm, 400 psi10% FO to 1 bpm, 425 psi, 11% FO. 25.9 bbis lost to formation. 12/27/2015 12/27/2015 4.50 INTRM3 CEMENT CMNT P PJSM; line up to cementers & pump 5 10,434.0 10,434.0 03:00 07:30 bbis of CW -100. Pressure test lines 500 / 3500 psi for 5 min. Pump 5 bbls of CW -100, 3 bpm, 540 psi. Pump 40 bbls of 12.5 ppg MPII at 3 bpm, 540 psi. Load wiper plug in pipe. Pump 72 bbis of 15.8 ppg cement slurry w/ 2 Ib/bbl CemNet at3 bpm, 275 psi. Load shut off plug in pipe. Pump 10 bbis of H2O. Swap to rig & displace with 460 bbis of 11.8+ ppg mud at 3 bpm, 250- 600 psi. Bump plug & pressure up to 1200 psi & hold for 5 min. CIP 07:30 hrs. While chasing the plug with the rig pump the pits received an average of 50% returns from 0 to 420 bbis away. Returns steadily increased the last 40 bbis and full returns were achieved the last 20 bbis as the cement came up the annulus. 400 psi lift pressure was observed. 12/27/2015 12/27/2015 0.25 INTRM3 CEMENT OWFF T Bleed off pressure. Check floats. Not 10,434.0 10,434.0 07:30 07:45 holding. Pressure up to 1400 psi/5 min. Quickly bleed off pressure. Floats not holding. Pressure up to 1400 psi and hold. Page 28/69 Report Printed: 2/29/2016 - Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/27/2015 12/27/2015 4.25 INTRM3 CEMENT WOC T Wait on cement. Monitor annulus via 10,434.0 10,434.0 07:45 12:00 pit #5. Sim-ops/Lay down elevators and bale extensions. Work on MP2's. Change oil in iron roughneck spinners. Clean and clear floor. Losses for previous 12 hrs=361.7 bbls 12/27/2015 12/27/2015 8.00 INTRM3 CEMENT WOC T Wait on cement. Monitor annulus via 10,434.0 10,434.0 12:00 20:00 pit #5. Sim -ops/ Work on MP2's. Perform derrick inspection. Unload and clean rock washer. Inspect rock washer drag chain. Change out brushes on mud pump #1 B montor and mud pump A and B motors. Work on ejecters on pipe skate. Change oil on degasser. Check torque on shaker mount bolts. Change fluorescent lights on rig floor to LED's. Filter gear oil on both mud pumps. Strap drill pipe in pipe shed. 12/27/2015 12/27/2015 0.50 INTRM3 CEMENT OWFF T Bleed pressure off of 7 5/8" casing. 10,434.0 10,434.0 20:00 20:30 Check for flow. Static. 12/27/2015 12/27/2015 3.00 INTRM3 CEMENT CIRC P Pressure up 7 5/8" casing to 3000 psi 10,434.0 10,434.0 20:30 23:30 and open stage collar. Break circ @ 2 bpm, 700 psi. Stage pump up to 6 bpm, 800 psi, 45% FO. CBU x2. 12/27/2015 12/28/2015 0.50 INTRM3 CEMENT CIRC T Monitor well. Mud out of balance, U- 10,434.0 10,434.0 23:30 00:00 tubing from annulus to 7 5/8" casing. Continue to circulate 12/28/2015 12/28/2015 1.50 INTRM3 CEMENT CIRC T CBU. 6 bpm. 700 psi, FO=44% 10,434.0 10,434.0 00:00 01:30 12/28/2015 12/28/2015 1.25 INTRM3 CEMENT OWFF T Monitor well. Mud out of balance. U- 10,434.0 10,434.0 01:30 02:45 tubing from annulus up 7 5/8" casing. 140 psi on shut in casing guage. Mix 25 bbl 12.5 ppg pill. 12/28/2015 12/28/2015 0.25 INTRM3 CEMENT CIRC T Pump 25 bbl pill down 7 5/8" casing. 10,434.0 10,434.0 02:45 03:00 12/28/2015 12/28/2015 0.75 INTRM3 CEMENT OWFF T Monitor well. Out of balance, 10,434.0 10,434.0 03:00 03:45 continues to u -tube at a decreased rate. 115 psi on shut in casing guage. 12/28/2015 12/28/2015 0.25 INTRM3 CEMENT CIRC T Pump 25 bbl 12.7 ppg pill. 10,434.0 10,434.0 03:45 04:00 12/28/2015 12/28/2015 0.75 INTRM3 CEMENT OWFF T Monitor well. Out of balance, 10,434.0 10,434.0 04:00 04:45 continues to u -tube at a decreased rate. 80 psi on shut in casing guage. 12/28/2015 12/28/2015 0.25 INTRM3 CEMENT CIRC T Pump 32 bbl 12.7 ppg pill. 10,434.0 10,434.0 04:45 05:00 12/28/2015 12/28/2015 2.75 INTRM3 CEMENT COND T Monitor well. Out of balance, 10,434.0 10,434.0 05:00 07:45 continues to u -tube at a decreased rate of 2.2 bph. 50 psi on shut in casing guage. Condition mud in pits. Increase YP to 45. 12/28/2015 12/28/2015 2.00 INTRM3 CEMENT CIRC T Circulate surface to surface volume. 10,434.0 10,434.0 07:45 09:45 11.9 ppg mud, 8 bpm, 890 psi, FO=50%. 12/28/2015 12/28/2015 2.00 INTRM3 CEMENT COND T Monitor well. Out of balance. 100 psi 10,434.0 10,434.0 09:45 11:45 on shut in casing guage. Mix 100 bbl 13.8 ppg pill. Page 29/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/28/2015 12/28/2015 2.25 INTRM3 CEMENT CIRC T Pump 100 bbl 13.8 ppg pill. Shut down 10,434.0 10,434.0 11:45 14:00 pump and monitor well. Mud level dropping in casing and flowing out annulus @ 5 bph. 12/28/2015 12/28/2015 0.75 INTRM3 CEMENT RURD P Rig down circ lines. Lay down Volant 10,434.0 0.0 14:00 14:45 CRT. Lay down landing joint. 12/28/2015 12/28/2015 3.75 INTRM3 CEMENT WWSP P Drain and flush BOPE. Set packoff 0.0 0.0 14:45 18:30 and energize seals.Test seals to 5000 psi/ 10 min. witnessed by Co Man. 12/28/2015 12/28/2015 0.50 INTRM3 CEMENT RURD P Rig up to lay down 5" drill pipe. 0.0 0.0 18:30 19:00 12/28/2015 12/29/2015 5.00 INTRM3 CEMENT PULD P Lay down 312 jts of 5" DP from derrick 0.0 0.0 19:00 00:00 using mousehole. Sim-ops/Freeze protect OA. Pump 274 bbls 9.8 ppg inhibited brine followed by 223 bbls diesel @ 4 bpm. FCP= 1250 psi. Shut in pressure=960 psi 12/29/2015 12/29/2015 1.50 INTRM3 CEMENT PULD P Lay down 33 jts of 5" DP from derrick 0.0 0.0 00:00 01:30 using mousehole. 12/29/2015 12/29/2015 2.50 INTRM3 CEMENT RURD P Change out TD saver sub, bell guide 0.0 0.0 01:30 04:00 and grabbers. Sim -ops/ Unload 5" DP from pipe shed. 12/29/2015 12/29/2015 2.00 INTRM3 CEMENT BOPE P Change upper pipe rams to 3 1/2" x 6: 0.0 0.0 04:00 06:00 VBR's. Sim-ops/Unload 5" DP from pipe shed. Load and strap 12 jts HWDP in pipe shed. Change out to 4" handling equipment on rig floor. 12/29/2015 12/29/2015 2.00 INTRM3 CEMENT BOPE P Intall test plug. Rig up to test upper 0.0 0.0 06:00 08:00 rams. Test upper VBR's to 250/5000 psi for 5 min each. Rig down test equip. Set 12.5" ID wear bushing. 12/29/2015 12/29/2015 0.50 INTRM3 CEMENT OTHR T Attempt to drop cancellation plug 0.0 0.0 08:00 08:30 using sash cord. Unable to drop plug due to cord winding up on itself as plug was lowered down BOPE. 12/29/2015 12/29/2015 1.50 INTRM3 CEMENT PULD P Pick up and stand back 45 jts 4" DP. 0.0 0.0 08:30 10:00 12/29/2015 12/29/2015 1.50 INTRM3 CEMENT RURD P Pull wear bushing. Pick up 7 5/8" 0.0 0.0 10:00 11:30 landing jt and run in to top of packoff. Drop cancellation plug. Lay down landing jt. Install wear bushing. 12/29/2015 12/29/2015 0.50 INTRM3 CEMENT BHAH P Mobilize BHA tools to rig floor. 0.0 0.0 11:30 12:00 12/29/2015 12/29/2015 1.75 INTRM3 CEMENT BHAH P Make up BHA to 113' MD. Make up 0.0 113.0 12:00 13:45 bit, boot basket, stab, NMDC, stab, 2x NMDC, saver sub and x -o 12/29/2015 12/29/2015 7.00 INTRM3 CEMENT PULD P RIH picking up HWDP (17 jts) and 4" 0.0 5,930.0 13:45 20:45 DP (167 jts) from pipe shed 12/29/2015 12/29/2015 0.75 INTRM3 CEMENT CIRC P Circ and cond mud. Return mud @ 5,930.0 5,930.0 20:45 21:30 11.4 ppg and aired up. 8 bpm, 1600 psi. 12/29/2015 12/29/2015 0.25 INTRM3 CEMENT OWFF P Monitor well, Static. Blow down TD 5,930.0 5,930.0 21:30 21:45 Page 30/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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). 12/29/2015 12/30/2015 2.25 INTRM3 CEMENT PULD P RI picking up 4" DP (79 jts) from pipe 5,930.0 8,426.0 21:45 00:00 shed. PU 125K SO 90K. Calc disp=53.78 bbls Act disp=53.5 bbls. Filled pipe every 60 jts. 12/30/2015 12/30/2015 0.75 INTRM3 CEMENT PULD P PJSM, Cont to RIH picking up 4" DP 8,426.0 8,917.0 00:00 00:45 to 8917' MD.Tag up on stage collar @ 8917' MD. P/U= 125K, S/O= 92K. Calculated displacement= 2.8 bbls, Actual displacement= 2.8 bbls. 12/30/2015 12/30/2015 0.25 INTRM3 CEMENT OTHR P Set down 45K on cancellation plug to 8,917.0 8,917.0 00:45 01:00 close the stage collar as per PEST rep. 12/30/2015 12/30/2015 0.50 INTRM3 CEMENT PRTS P Stand back 1 stand of drill pipe and 8,917.0 8,900.0 01:00 01:30 R/U to test stage collar. Attempt to test stage collar to 3500 psi, did not test. 12/30/2015 12/30/2015 0.25 INTRM3 CEMENT OTHR T Run back in the hole to 8917' MD and 8,900.0 8,917.0 01:30 01:45 set down 55K on stage collar and close as per PESI rep. 12/30/2015 12/30/2015 0.75 INTRM3 CEMENT PRTS T Stand back 1 stand of drill pipe and 8,917.0 8,900.0 01:45 02:30 R/U to test stage collar. Test stage collar to 3500 psi, for 15 min on chart. 12/30/2015 12/30/2015 1.00 INTRM3 CEMENT SVRG P Service rig and C/O Totco display on 8,900.0 8,900.0 02:30 03:30 the drillers console. 12/30/2015 12/30/2015 1.00 INTRM3 CEMENT DRLG P Drill out cancellation plug @ 8917' MD 8,900.0 8,993.0 03:30 04:30 as per DD. Pump @ 250 gpm= 1650 psi, 50 RPMs w/ Tq 8K on, 5K off, WOB= 12-16K. FO= 44%, P/U 125K, S/O= 90K, ROT= 105K. After drilling out plug worked up/down though the stage collar 3 times, good. Obtain SPR's @ 8899' MD, TVD 5810', MW= 11.9 ppg, 03:30 hours MP #1= 30 spm=875 psi, 40 spm=1060 psi. MP#2= 30 spm=840 psi, 40 spm= 1025 psi. 12/30/2015 12/30/2015 0.75 INTRM3 CEMENT CIRC P CBU @ 335 gpm=2210 psi, 53% FO 8,993.0 8,993.0 04:30 05:15 12/30/2015 12/30/2015 0.75 INTRM3 CEMENT PRTS P R/U to test stage collar. Test stage 8,993.0 8,993.0 05:15 06:00 collar to 3500 psi, for 15 min on chart. 12/30/2015 12/30/2015 0.25 INTRM3 CEMENT OWFF P OWFF, static. Hold PJSM on POOH 8,993.0 8,993.0 06:00 06:15 12/30/2015 12/30/2015 0.25 INTRM3 CEMENT CIRC P Pump dry job. Blow down lines 8,993.0 8,993.0 06:15 06:30 12/30/2015 12/30/2015 3.25 INTRM3 CEMENT TRIP P POOH f/8993' MD t/653' MD. 8,993.0 653.0 06:30 09:45 12/30/2015 12/30/2015 0.25 INTRM3 CEMENT OWFF P Monitor well. Static 653.0 653.0 09:45 10:00 12/30/2015 12/30/2015 1.50 INTRM3 CEMENT BHAH P Stand back 2 std's HWDP and jars. 653.0 0.0 10:00 11:30 Lay down BHA. 12/30/2015 12/30/2015 0.50 INTRM3 CEMENT BHAH P Clean and clear rig floor. 0.0 0.0 11:30 12:00 12/30/2015 12/30/2015 1.50 INTRM3 WHDBOP RURD P Pull wear bushing. Rig up to test 0.0 0.0 12:00 13:30 I BOPE. Page 31169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/30/2015 12/30/2015 7.00 INTRM3 WHDBOP BOPE P Test BOPE w/ 4" test joint to 250/3500 0.0 0.0 13:30 20:30 psi for 5 min each. #1: Top pipe rams, CV 1,12,13, 14 & manual kill valve. #2: Upper IBOP, HCR kill, CV 9, & 11. #3: Lower IBOP, CV 5,8 & 10. #4: Dart, CV 4,6 & 7. #5: FOSV and CV 2. #6: Manual choke valve & 4" kill line Demco valve, # 7: Manual choke valve & HCR kill. #8: Annular preventer tested to 250/2500 psi. #9: Lower pipe rams. # 10: Blind rams and CV 3. Perform manual and hydraulic draw down test. #11; Test upper VBR w/ 4.5" joint 250/3500 psi for 5 min ea. #12 Test lower VBR w/ 4.5" joint 250/3500 psi, #13 Annular w/ 4.5" joint 250/2500 psi 5 min. #14 HCR choke valve 250/3500 psi/5 min Test gas, flow & pit level alarms. Accumulator test: system pressure= 3000 psi, After closing= 1900 psi, 200 psi attained after 43 sec, full pressure attained after 158 sec, Five bottle nitrogen avg= 1950 psi. The BOP test witness was waived by AOGCC Rep. Chuck Scheve. 12/30/2015 12/30/2015 1.00 INTRM3 WHDBOP RURD P Rig down test equipment. Blow down 0.0 0.0 20:30 21:30 choke and kill lines. Set 12.5" ID wear bushing 12/30/2015 12/30/2015 2.00 INTRM3 CEMENT SLPC P PJSM-Slip and cut 85' drilling line. 0.0 0.0 21:30 23:30 Adjust brakes. Service TD. MP2 on drawworks. Set 12.5" ID wear bushing. Install split master bushing. 12/30/2015 12/31/2015 0.50 INTRM3 CEMENT BHAH P Mobilize BHA tools to rig floor. 0.0 0.0 23:30 00:00 12/31/2015 12/31/2015 3.00 INTRM3 CEMENT BHAH P PJSM, P/U BHA as per DD. Make up 0.0 445.0 00:00 03:00 PowerDrive, receiver sub, MicroScope, Impulse, SonicScope and ADN. Load Nuclear sources, make up 2 floats, NMDC and Stab. RIH w/jars and 2 stand of HWDP. 12/31/2015 12/31/2015 1.00 INTRM3 CEMENT PULD P RIH picking up 4" DO to 1389' MD 445.0 1,389.0 03:00 04:00 12/31/2015 12/31/2015 0.50 INTRM3 CEMENT DHEQ P Shallow hole test MWD tools as per 1,389.0 1,389.0 04:00 04:30 SLB rep, 200 gpm=1020 psi. 12/31/2015 12/31/2015 5.50 INTRM3 CEMENT PULD P Cont to RIH picking up 4" DP to 8291' 1,389.0 8,291.0 04:30 10:00 MD. Picked up a total of 249 joints of 4" DP. 12/31/2015 12/31/2015 0.75 INTRM3 CEMENT TRIP P RIH out of derrick f/ 8291' MD to 9100' 8,291.0 9,100.0 10:00 10:45 MD 12/31/2015 12/31/2015 1.25 INTRM3 CEMENT DLOG P Turn on SoinicScope and RIH logging 9,100.0 9,613.0 10:45 12:00 cement job @ 900 fph f/ 9100' MD to 9613' MD, Actual displacement= 56.1 bbls, Calculated displacement= 56.1 bbs. 12/31/2015 12/31/2015 1.00 INTRM3 CEMENT DLOG P Continue to RIH f/9613' MD t/10181' 9,613.0 10,181.0 12:00 13:00 MD logging cement job. 12/31/2015 12/31/2015 1.25 INTRM3 CEMENT PRTS P Rig up and test casing to 3500 psi/30 10,181.0 10,181.0 13:00 14:15 min. Charted. Page 32/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 12/31/2015 12/31/2015 1.50 INTRM3 CEMENT COCF P Wash and ream (/10181 MD t/10275' 10,181.0 10,303.0 14:15 15:45 MD.Drill cement stringers to 10303' MD. 200 gpm, 1975 psi, 40-60 rpm, 8- 11 K tq, 10-15K WOB 12/31/2015 12/31/2015 5.25 INTRM3 CEMENT DRLG P Drill out shoe track f/10303' t/10437' 10,303.0 10,437.0 15:45 21:00 MD. 200 gpm, 1900 psi, 12-15K WOB, 80 rpm, 8-11 K tq, SPR's @ 10326' MD, TVD 6318', MW=11.7+ ppg, 18:00 hours MP #1= 20 spm=680 psi, 30 spm=880 psi. MP #2= 20 spm=840 psi, 30 spm=890 psi. 12/31/2015 12/31/2015 1.25 INTRM3 CEMENT CIRC P CBU @ 10437' MD. 200 gpm, 2100 10,437.0 10,437.0 21:00 22:15 psi, 80 rpm, 8-9K tq. 12/31/2015 12/31/2015 0.25 INTRM3 CEMENT OWFF P Monitor well. Static. 10,437.0 10,437.0 22:15 22:30 12/31/2015 1/1/2016 1.50 INTRM3 CEMENT MPDA P Pull trip nipple. Install RCD bearing 10,437.0 10,400.0 22:30 00:00 assy. 1/1/2016 1/1/2016 3.00 INTRM3 CEMENT DISP P PJSM, Displace well to 10.5 ppg 10,400.0 10,400.0 00:00 03:00 FloThru mud system. Pump @ 220 gpm= 2730 psi, FCP= 2150 psi, 80 rpm's, 1 OK Tq, 44% FO. 1/1/2016 1/1/2016 0.25 INTRM3 CEMENT DRLG P Drilling rat hole f/ 10437' MD to 10444' 10,400.0 10,444.0 03:00 03:15 MD @ 200 gpm= 2070 psi, 80 rpm, 10K Tq, WOB= 5-15K. Obtain SPR's 10437' MD 6320 TVD, MW=10.5 ppg, 3:00 hours MP#1: 20 spm=640 psi, 30 spm=890 psi. MP #2: 20 spm=625 psi, 30 spm=940 psi. 1/1/2016 1/1/2016 0.50 INTRM3 CEMENT DDRL P Drill 20' of new hole f/ 10440' MD to 10,444.0 10,464.0 03:15 03:45 10464' MD, 6320 TVD. ADT= .56 hrs, Bit hrs= .56, Total Jar hrs= 131.84. P/U= 152K, S/O= 73K, ROT= 105K. Pump @ 200 gpm= 2060 psi, 44% FO. Rot @ 80 rpm's w/ 11 K Tq on, 1 OK Tq off. ECD= 11.88 ppg, WOB= 15K. 1/1/2016 1/1/2016 0.75 INTRM3 CEMENT CIRC P Circulate and condtion mud for FIT, 10,464.0 10,464.0 03:45 04:30 pump @ 200 gpm=2060 psi, 48% FO. 10.5 ppg MW- In/Out. 1/1/2016 1/1/2016 0.25 INTRM3 CEMENT SMPD P Strip OOH f/ 10464' MD to 10370' MD, 10,464.0 10,370.0 04:30 04:45 blow down top drive. 1/1/2016 1/1/2016 1.50 INTRM3 CEMENT FIT P Rig up and perform FIT to 14.5 ppg 10,370.0 10,370.0 04:45 06:15 EMW. 1/1/2016 1/1/2016 0.25 PROD1 DRILL SMPD P Trip back in 1 stand t/ 10464' MD. 10,370.0 10,464.0 06:15 06:30 1/1/2016 1/1/2016 5.50 PROD1 DRILL DDRL P Drill ahead f/ 10464 MD to 10652 MD, 10,464.0 10,652.0 06:30 12:00 6315 TVD. ADT= .3.7 hrs, Bit hrs= .4.26, Total Jar hrs= 135.54. P/U= 159K, S/O= 76K, ROT= 108K. Pump @ 250 gpm= 2820 psi, 46% FO. Rot @ 120 rpm's w/ 12K Tq on, 11 K Tq off. ECD= 11.91 ppg, WOB= 13-15K. Max Gas= 815 units. Page 33/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/1/2016 1/1/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 10652' MD to 11073' 10,652.0 11,073.0 12:00 18:00 MD, 6320' TVD. ADT= .4.53 hrs, Bit hrs= .8.79, Total Jar hrs= 140.07. P/U= 155K, S/O= 67K, ROT= 106K. Pump @ 250 gpm= 2850 psi, 48% FO. Rot @ 140-150 rpm's w/ 13-14K Tq on, 11-12K Tq off. ECD= 12.09 ppg, WOB= 15-17K. Max Gas= 2047 units. SPR's 10936' MD 6312' TVD, MW=10.5+ ppg, 16:00 hours MP#1: 20 spm=750 psi, 30 spm=1025 psi. MP #2: 20 spm=720 psi, 30 spm=1050 psi. 1/1/2016 1/2/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 11073' MD to 11504' 11,073.0 11,504.0 18:00 00:00 MD, 6310' TVD. ADT= .4.27 hrs, Bit hrs= .13.06, Total Jar hrs= 144.34. P/U= 155K, S/O= 62K, ROT= 102K. Pump @ 250 gpm= 2900 psi, 48% FO. Rot @ 150 rpm's w/ 13K Tq on, 11-12K Tq off. ECD= 12.09 ppg, WOB= 15-18K. Max Gas= 1997 units. SPR's 11409' MD 6303' TVD, MW=10.5+ ppg, 22:00 hours MP#1: 20 spm=700 psi, 30 spm=980 psi. MP #2: 20 spm=700 psi, 30 spm=1060 psi. 1/2/2016 1/2/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 11504' MD to 12039' 11,504.0 12,039.0 00:00 06:00 MD, 6304' TVD. ADT= 4.78 hrs, Bit hrs= 17.84, Total Jar hrs= 149.12. P/U= 152K, S/O= 65K, ROT= 105K. Pump @ 250 gpm= 2810 psi, 48% FO. Rot @ 150 rpm's w/ 14-15K Tq on, 10-11 K Tq off. ECD= 12.03 ppg, WOB= 15-18K. Max Gas= 3280 units. 1/2/2016 1/2/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 12039' MD to 12501' 12,039.0 12,501.0 06:00 12:00 MD, 6320' TVD. ADT= 3.92 hrs, Bit hrs= 21.06, Total Jar hrs= 153.04. P/U= 162K, S/O= 70K, ROT= 106K. Pump @ 250 gpm= 2850 psi, 49% FO. Rot @ 150 rpm's w/1 5K Tq on, 12 -13K Tq off. ECD= 12.05 ppg, WOB= 15-18K. Max Gas= 3329 units. SPR's 12451' MD 6321' TVD, MW=10.5 ppg, 11:00 hours MP#1: 20 spm=750 psi, 30 spm=1060 psi. MP #2: 20 spm=740 psi, 30 spm=1070 psi. Page 34/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dar (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 1/2/2016 1/2/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 12501' MD to 12925' 12,501.0 12,925.0 12:00 18:00 MD, 6311' TVD. ADT= 4.37 hrs, Bit hrs= 26.13, Total Jar hrs= 157.41. P/U= 165K, S/O= 61K, ROT= 106K. Pump @ 250 gpm= 3110 psi, 48% FO. Rot @ 150 rpm's w/14K Tq on, 12K Tq off. ECD= 12.05 ppg, WOB= 15-18K. Max Gas= 1871 units. SPR's 12921' MD 6311' TVD, MW= 10.5+ ppg, 18:00 hours MP#1: 20 spm=770 psi, 30 spm=1120 psi. MP #2: 20 spm=760 psi, 30 spm=1110 psi. 1/2/2016 1/3/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 12925' MD to 13285' 12,925.0 13,285.0 18:00 00:00 MD, 6293' TVD. ADT= 4.22 hrs, Bit hrs= 30.35, Total Jar hrs= 161.63. P/U= 170K, S/O= 66K, ROT= 105K. Pump @ 250 gpm= 3020 psi, 59% FO. Rot @ 150 rpm's w/14K Tq on, 11 K Tq off. ECD= 12.06 ppg, WOB= 15-18K. Max Gas= 2200 units. Pumped 26 bbis 10 Ib/bbl nut plug sweep. 1/3/2016 1/3/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 13285' MD to 13774' 13,285.0 13,774.0 00:00 06:00 MD, 6262' TVD. ADT= 4.56 hrs, Bit hrs= 34.91, Total Jar hrs= 166.19. P/U= 170K, S/O= 60K, ROT= 102K. Pump @ 250 gpm= 3200 psi, 49% FO. Rot @ 150 rpm's w/1 8K Tq on, 13K Tq off. ECD= 12.22 ppg, WOB= 15-18K. Max Gas= 3254 units. 1/3/2016 1/3/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 13774' MD to 14288' 13,774.0 14,288.0 06:00 12:00 MD, 6243' TVD. ADT= 3.89 hrs, Bit hrs= 38.80, Total Jar hrs= 170.08. P/U= 170K, S/O= 58K, ROT= 102K. Pump @ 250 gpm= 3200 psi, 49% FO. Rot @ 150 rpm's w/1 9K Tq on, 13 -14K Tq off. ECD= 12.18 ppg, WOB= 15-18K. Max Gas= 4484 units. OA= 150 psi SPR's 14060' MD 6285' TVD, MW= 10.7 ppg, 08:45 hours MP#1: 20 spm=800 psi, 30 spm=1100 psi. MP #2: 20 spm=800 psi, 30 spm=1150 psi. Page 35/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/3/2016 1/3/2016 5.50 PROD1 DRILL DDRL P Drill ahead f/ 14288' MD to 14665' 14,288.0 14,665.0 12:00 17:30 MD, 6232' TVD. ADT= 4.37 hrs, Bit hrs= 43.17, Total Jar hrs= 174.45. P/U= 165K, S/O= 60K, ROT= 104K. Pump @ 250 gpm= 3200 psi, 48% FO. Rot @ 150 rpm's w/1 5K Tq on, 13 -14K Tq off. ECD= 12.26 ppg, WOB= 18-20K. Max Gas= 4000 units. SPR's 14624' MD 6234' TVD, MW=10.6 ppg, 17:00 hours MP#1: 20 spm=750 psi, 30 spm=1130 psi. MP #2: 20 spm=736 psi, 30 spm=1130 psi. 1/3/2016 1/3/2016 2.50 PROD1 DRILL WAIT T LWD logs indicate faulting out of zone. 14,665.0 14,665.0 17:30 20:00 Fault @ 14521' MD 6237' TVD. CBU x2 for geologic interpretation of cuttings. 250 gpm, 3300 psi, 150 rpm. 13K tq. Decision made to drill ahead @ down angle to enter target zone. 1/3/2016 1/4/2016 4.00 PROD1 DRILL DDRL P Drill ahead f/ 14665' MD to 14817' 14,665.0 14,817.0 20:00 00:00 MD, 6241' TVD. ADT= 3.05 hrs, Bit hrs= 46.22, Total Jar hrs= 177.50. P/U= 175K, S/O= 51 K, ROT= 104K. Pump @ 250 gpm= 3275 psi, 44% FO. Rot @ 150 rpm's w/1 SK Tq on, 14K Tq off. ECD= 12.18 ppg, WOB= 16-19K. Max Gas= 493 units. 1/4/2016 1/4/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 14817' MD to 15291' 14,817.0 15,291.0 00:00 06:00 MD, 6275' TVD. ADT= 4.74 hrs, Bit hrs= 50.96, Total Jar hrs= 182.24. P/U= 185K, S/O= 52K, ROT= 102K. Pump @ 250 gpm= 3220 psi, 48% FO. Rot @ 150 rpm's w/1 7K Tq on, 14 -15K Tq off. ECD= 12.26 ppg, WOB= 18K. Max Gas= 4033 units. 1/4/2016 1/4/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 15291' MD to 15731' 15,291.0 15,731.0 06:00 12:00 MD, 6266' TVD. ADT= 3.81 hrs, Bit hrs= 54.77, Total Jar hrs= 186.05. P/U= 180K, S/O= 50K, ROT= 103K. Pump @ 250 gpm= 3290 psi, 49% FO. Rot @ 150 rpm's w/1 8.5K Tq on, 15-16K Tq off. ECD= 12.45 ppg, WOB= 15-18K. Max Gas= 4989 units. SPR's 15,671' MD 6266' TVD, MW=10.6 ppg, 11:00 hours MP#1: 20 spm=970 psi, 30 spm=1270 psi. MP #2: 20 spm=900 psi, 30 spm=1240 psi. OA Pressure= 50 psi Page 36/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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 (ftKE) 1/4/2016 1/4/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 15731' MD to 16160' 15,731.0 16,160.0 12:00 18:00 MD, 6252' TVD. ADT= 4.68 hrs, Bit hrs= 59.45, Total Jar hrs= 190.73. P/U= 180K, S/O= 40K, ROT= 103K. Pump @ 250 gpm= 3300 psi, 49% FO. Rot @ 150 rpm's w11 7K Tq on, 13K Tq off. ECD= 12.36 ppg, WOB= 15K. Max Gas= 4976 units. 1/4/2016 1/5/2016 6.00 PROD1 DRILL DDRL P Drill ahead f/ 16160' MD to 16560' 16,160.0 16,560.0 18:00 00:00 MD, 6244' TVD. ADT= 4.37 hrs, Bit hrs= 63.82, Total Jar hrs= 195.10. P/U= 175K, S/O= 44K, ROT= 104K. Pump @ 250 gpm= 3325 psi, 50% FO. Rot @ 150 rpm's w/1 8K Tq on, 15K Tq off. ECD= 12.41 ppg, WOB= 17K. Max Gas= 3683 units. SPR's 16239' MD 6250' TVD, MW=10.6+ ppg, 19:15 hours MP#1: 20 spm=840 psi, 30 spm=1230 psi. MP #2: 20 spm=840 psi, 30 spm=1230 psi. OA Pressure= 50 psi 1/5/2016 1/5/2016 3.50 PROD1 DRILL DDRL P Drill ahead f/ 16560' MD to 16849' 16,560.0 16,849.0 00:00 03:30 MD, 6233' TVD. ADT= 2.62 hrs, Bit hrs= 66.44, Total Jar hrs= 197.72. P/U= 184K, S/O= OK, ROT= 105K. Pump @ 250 gpm= 3350 psi, 50% FO. Rot @ 150 rpm's w/1 9.5K Tq on, 15K Tq off. ECD= 12.52 ppg, WOB= 10K. Max Gas= 5496 units. SPR's 16849' MD 6233' TVD, MW=10.7 ppg, 03:15 hours MP#1: 20 spm=900 psi, 30 spm=1310 psi. MP #2: 20 spm=900 psi, 30 spm=1300 psi. 1/5/2016 1/5/2016 1.25 PROD1 CASING CIRC P CBU @ 250 gpm, ICP 3350 psi, FCP 16,849.0 16,849.0 03:30 04:45 3220 psi, 120 rpm, Tq 14-15K, FO 50%. 1/5/2016 1/5/2016 0.25 PROD1 CASING SMPD P PJSM; TOH f/ 16849'-16809' MD. 16,849.0 16,809.0 04:45 05:00 1/5/2016 1/5/2016 1.00 PROD1 CASING OWFF P Perform fingerprint of well bore. 16,809.0 16,809.0 05:00 06:00 Reduce back pressure to 300 & 275 psi. Observe pressure build to 343 psi. Test indicated a EMW 11.73 ppg pore pressure. MW 10.7 ppg & 6321' TVD were used for calculations. 1/5/2016 1/5/2016 0.25 PROD1 CASING SMPD P PJSM; TIH f/ 16809'-16849' MD. 16,809.0 16,849.0 06:00 06:15 1/5/2016 1/5/2016 1.50 PROD1 CASING CIRC P CBU @ 250 gpm, 3220 psi, 100 rpm, 16,849.0 16,849.0 06:15 07:45 Tq 14K, FO 50%. 1/5/2016 1/5/2016 3.50 PROD1 CASING BKRM P PJSM; BROOH f/ 16849'-15170' @ 16,849.0 15,170.0 07:45 11:15 250 gpm, 3220 psi, 100 rpm, Tq 14K, FO 50%, 1000-1200 fph. Page 37/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Lag. Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/5/2016 1/5/2016 1.75 PROD1 CASING BKRM P PJSM; BROOH f/ 15170'-15009' @ 15,170.0 15,009.0 11:15 13:00 250 gpm, 3100 psi, 130 rpm, Tq 11 K, FO 48%, 100 fph. Slowed BROOH speed to get 2 BU before the Kalubik. 1/5/2016 1/5/2016 3.00 PROD1 CASING BKRM P PJSM; Slowly BROOH thought the 15,009.0 14,599.0 13:00 16:00 Kalubik f/ 15009'-14600'@ 3-2 bpm, 1400-1100 psi, 20 rpm, Tq 8-91K, FO 10%, 225 fph. No problems going thought the shale. 1/5/2016 1/6/2016 8.00 PROD1 CASING BKRM P PJSM; BROOH f/ 14599'-11792'@ 14,599.0 11,792.0 16:00 00:00 250 gpm, ICP 3150 psi, FCP 2800 psi, 100 rpm, Tq 10-7K, FO 52%, 1000 fph. 1/6/2016 1/6/2016 2.75 PROD1 CASING BKRM P PJSM, BROOH f/ 11,792' MD to 11,792.0 10,432.0 00:00 02:45 inside casing shoe @ 10432' MD @ 250 gpm= 2680 psi, 100 rpm, Tq 8K, FO 52%, 1000 fph. Actual displacement= 17.06 bbls, Calculated displacement= 8.4 bbls. 1/6/2016 1/6/2016 2.00 PROD1 CASING CIRC P CBU X 2, pump @ 250 gpm=2680 psi, 10,432.0 10,432.0 02:45 04:45 47% FO, 100 rpm's, 6K Tq. 1/6/2016 1/6/2016 3.50 PROD1 CASING DISP P Displace well as follows, Pump 30 10,432.0 9,897.0 04:45 08:15 bbls of High Vis 12.0 ppg brine spacer down pipe and chase with 79 bbls of 12.0 ppg NaBr brine. POOH w/ pump laying high vis spacer @ 2400 fph f/ 10434' to 9897', pump @ 2 bpm=200 psi. At 9897' MD cont to pump 12.0 ppg NaBr brine displacing well. Pump @ 3 bpm=550 psi, 38% FO and increased pump to 5 bpm= 1625 psi, 43% FO. 1/6/2016 1/6/2016 0.25 PROD1 CASING OWFF P Close MPD choke and monitor well 9,897.0 9,897.0 08:15 08:30 against closed chokes. 1/6/2016 1/6/2016 0.50 PROD1 CASING MPDA P Flush MPD system with fresh water 9,897.0 9,897.0 08:30 09:00 and blow down MPD/Top drive. 1/6/2016 1/6/2016 0.50 PROD1 CASING OWFF P OWFF, drain stack and monitor well 9,897.0 9,897.0 09:00 09:30 though IA, static. 1/6/2016 1/6/2016 0.75 PROD1 CASING MPDA P Remove MPD bearing and install trip 9,897.0 9,897.0 09:30 10:15 nipple. 1/6/2016 1/6/2016 0.25 PROD1 CASING RURD P PJSM; install stripping rubber catcher, 9,897.0 9,897.0 10:15 10:30 fill stack, drop 2" OD rabbit on stand # 100. 1/6/2016 1/6/2016 5.25 PROD1 CASING TRIP P PJSM; TOH f/ 9897'- 445' MD, 9,897.0 445.0 10:30 15:45 calculated fill for trip 62.52, actual 68.9 bbls. 1/6/2016 1/6/2016 0.25 PROD1 CASING OWFF P Monitor well at HWDP, static. 445.0 445.0 15:45 16:00 1/6/2016 1/6/2016 3.00 PROD1 CASING BHAH P PJSM; lay down BHA as per SLB. 445.0 0.0 16:00 19:00 1/6/2016 1/6/2016 0.50 PROD1 CASING BHAH P PJSM; clear BHA from floor & clean. 0.0 0.0 19:00 19:30 1/6/2016 1/6/2016 0.75 COMPZI CASING RURD P PJSM; rig up casing running 0.0 0.0 19:30 20:15 equipment. 1/6/2016 1/6/2016 0.25 COMPZ1 CASING BOPE P Function test of BOPE. Function 0.0 0.0 20:15 20:30 annular & all rams. Page 38/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB). 1/6/2016 1/7/2016 3.50 COMPZ1 CASING PUTB P PJSM; run 4-1/2", 11.6#, L-80, IBTM 0.0 3,746.0 20:30 00:00 liner in the hole from surface to 3746' MD, 88 joints. Installed 6-1/8" Hydroform centralizer on every third joint. PU 64K, SO 64K, calculated displacement 13.5, actual 10.15 bbls. 1/7/2016 1/7/2016 2.50 COMPZ1 CASING PUTB P PJSM; run 4-1/2", 11.6#, L-80, IBTM 3,746.0 6,814.0 00:00 02:30 liner in the hole from 3746'-6885' MD. Installed 6-1/8" Hydroform centralizer on every third joint, total of 58 centralizers ran. PU 85K, SO 70K, calculated displacement 15.87, actual 12.6 bbls. 4-1/2" liner 0 rejects, 0 remakes. 4-1/2" slotted liner 6 rejects (not able to drift in shed), 0 remakes. 1/7/2016 1/7/2016 1.25 COMPZ1 CASING OTHR P PJSM; make up SBE & ZXP liner top 6,814.0 6,885.0 02:30 03:45 packer / hanger as per Baker Rep. Mix & add Xanplex in packer. SIMOPS rig down casing handling equipment. 1/7/2016 1/7/2016 0.25 COMPZ1 CASING CIRC P Circulate to ensure assembly is clear 6,885.0 6,980.0 03:45 04:00 f/ 6885'-6980' MD, 5 bpm, 285 psi, FO 37%, blow down TD. 1/7/2016 1/7/2016 6.75 COMPZ1 CASING RUNL P PJSM; TIH w/ 4-1/2" liner on 4" DP f/ 6,980.0 16,849.0 04:00 10:45 6980'-16849' MD, tagging bottom. PU 160K, SO 60K, filled every 20 stands, calculated displacement 56.7, actual 58.8 bbls. 1/7/2016 1/7/2016 0.25 COMPZ1 CASING CIRC P Break circulation to ensure assembly 16,849.0 16,849.0 10:45 11:00 is clear @ 4 bpm, 500 psi, FO 34%. 1/7/2016 1/7/2016 2.00 COMPZ1 CASING PACK P PJSM; Set liner hanger/ packer as 16,849.0 9,958.0 11:00 13:00 follows; pick up to set depth of 16829' MD, liner top at 9958' MD. Drop 1.5" ball, pump down @ 3 bpm, 400 psi. Pressure up to 2000 psi to set hanger. Hold for 10 minutes & set down to 45K to confirm hanger set. Pressure up to 3500 psi to set packer. Continue pressuring up to 4500 psi to release from liner hanger/ packer. Bleed off pressure. PU to break overweight of 130K. Lay down 10' pup joint. Test liner top packer to 3500 for 5 minutes good. 1/7/2016 1/7/2016 0.75 COMPZ1 WELLPR CRIH P PJSM; rig up & spot 22 bbls of 9,958.0 9,950.0 13:00 13:45 corrosion inhibited brine ( Congor 303A & Busan) f/ 9958'-9950'. Pump to the bit at 6 bpm, 850 psi. Lay in hole @ 3 bpm, 200 psi, 1400 fph, PU 125K. 1/7/2016 1/7/2016 1.25 COMPZ1 WELLPR CIRC P CBU 2X f/ 9950'-9888' MD @ 345 9,950.0 9,888.0 13:45 15:00 gpm, 1450 psi. 1/7/2016 1/7/2016 0.50 COMPZ1 WELLPR OWFF P Monitor well, static. 9,888.0 9,888.0 15:00 15:30 1/7/2016 1/7/2016 1.50 COMPZ1 WELLPR SLPC P PJSM; slip & cut 65' of drill line. 9,888.0 9,888.0 15:30 17:00 Service drawworks, perform MP2 on blocks & top drive. 1/7/2016 1/7/2016 3.50 COMPZ1 WELLPR TRIP P PJSM; TOH f/ 9888'-46' MD, 9,888.0 46.0 17:00 20:30 calculated fill 57.68, actual 61.25 bbls. Page 39/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/7/2016 1/7/2016 1.25 COMPZ1 WELLPR BHAH P PJSM; lay down liner running tools as 46.0 0.0 20:30 21:45 per Baker Rep. Clear & clean rig floor. 1/7/2016 1/7/2016 1.00 PROD2 WHPST BHAH P PJSM; mobilize whipstock & mill 0.0 0.0 21:45 22:45 1 assembly BHA to rig floor. 1/7/2016 1/8/2016 1.25 PROD2 WHPST BHAH P PJSM; make up mill assembly, 0.0 0.0 22:45 00:00 window mill, lower watermelon mill, flex joint, & upper watermelon mill. Lay mill assembly down in shed. Pick up & make up Gen 2 whipstock, debris cup, drain sub, safety disconnect, bottom trip anchor, blank sub, & string magnet. 1/8/2016 1/8/2016 2.75 PROD2 WHPST BHAH P PJSM; continue making up whipstock 0.0 428.0 00:00 02:45 assembly as per MWD & Baker Rep f/ 0'- 428' MD. 1/8/2016 1/8/2016 1.25 PROD2 WHPST TRIP P PJSM; TIH f/ 428'- 1560' MD at 2700 428.0 1,560.0 02:45 04:00 fph. 1/8/2016 1/8/2016 0.25 PROD2 WHPST DHEQ P Shallow hole test MWD @ 200 gpm, 1,560.0 1,560.0 04:00 04:15 550 psi, FO 34%. 1/8/2016 1/8/2016 5.75 PROD2 WHPST TRIP P TIH f/ 1560'- 9912' MD, fill every 20 1,560.0 9,912.0 04:15 10:00 stands, PU 135K, SO 100K, calculated displacement 60.14, actual 48.3 bbls. 1/8/2016 1/8/2016 0.50 PROD2 WHPST SRVY P Orient assembly to 54° left @ 250 9,912.0 9,912.0 10:00 10:30 gpm, 1450 psi, FO 43%. 1/8/2016 1/8/2016 0.25 PROD2 WHPST HOSO T TIH to tag nogo @ 9969' MD, liner top 9,912.0 9,969.0 10:30 10:45 11' MD deep. 1/8/2016 1/8/2016 1.75 PROD2 WHPST WAIT T Double check all tallies & numbers. 9,969.0 9,969.0 10:45 12:30 Confer with town. Decision made to TOH & lengthen assembly below the whipstock. SIMOPS monitor well, obtain slow pump rates, & blow down TD. SPR's @ 9958' MD, 6234' TVD, MW 12.0 ppg, 12:00 hrs. #1 @ 20 = 80; @ 30 = 300 psi #2 @ 20 = 80; @ 30 = 250 psi 1/8/2016 1/8/2016 6.50 PROD2 WHPST TRIP T PJSM; TOH f/ 6966'- 480' MD, 9,969.0 480.0 12:30 19:00 calculated fill 61, actual 63 bbls. 1/8/2016 1/8/2016 0.25 PROD2 WHPST OWFF T Monitor well, static. 480.0 480.0 19:00 19:15 1/8/2016 1/8/2016 2.25 PROD2 WHPST BHAH T PJSM; rack back HWDP, change out 480.0 480.0 19:15 21:30 shear screws on anchor, add magnet below whipstock, replace debris cup, orient whipstock w/ MWD, and install new 45K shear out lug. 1/8/2016 1/8/2016 1.00 PROD2 WHPST TRIP T PJSM; TIH f/ 480'- 1550' MD. 480.0 1,550.0 21:30 22:30 1/8/2016 1/8/2016 0.25 PROD2 WHPST DHEQ T Shallow hole test MWD @ 200 gpm, 1,550.0 1,550.0 22:30 22:45 625 psi, FO 33%, PU 55K, SO 53K, blow down TD. 1/8/2016 1/9/2016 1.25 PROD2 WHPST TRIP T TIH f/ 1550'- 3271' MD, fill every 20 1,550.0 3,271.0 22:45 00:00 stands, calculated displacement 22, actual 21 bbls. 1/9/2016 1/9/2016 5.75 PROD2 WHPST TRIP T TIH f/ 3271'- 9924' MD, fill every 20 3,271.0 9,924.0 00:00 05:45 stands, PU 135K, SO 100K, calculated displacement 37.8, actual 43.8 bbls. Page 40169 Report Printed: 2/29/2016 q Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/9/2016 1/9/2016 2.25 PROD2 WHPST RGRP T PJSM; change out upper IBOP due to 9,924.0 9,924.0 05:45 08:00 it leaking. 1/9/2016 1/9/2016 1.75 PROD2 WHPST SRVY T Obtain parameters, attempt to orient, 9,924.0 9,924.0 08:00 09:45 MWD would not turn on. Try multiple flow rates 250-300 gpm, 1250-1850 psi. Troubleshoot MWD. Decision made to trip out for MWD. Spill Drill CRT = 120 sec @ 09:00 hrs. 1/9/2016 1/9/2016 0.50 PROD2 WHPST PULD T Lay down single of drill pipe f/ 9924'- 9,924.0 9,892.0 09:45 10:15 9892' MD. Obtain SPR's & blow down TD. SPR's @ 9924' MD, 6234' TVD, MW 11.9+ ppg, 09:30 hrs. #1 @20=120;@30=310 psi #2 @ 20 = 150; @ 30 = 320 psi 1/9/2016 1/9/2016 0.50 PROD2 WHPST OWFF T Monitor well, static. 9,892.0 9,892.0 10:15 10:45 1/9/2016 1/9/2016 5.75 PROD2 WHPST TRIP T PJSM; TOH f/ 9892'- 470' MD, 9,892.0 470.0 10:45 16:30 calculated fill 60.1, actual 65.15 bbls. 1/9/2016 1/9/2016 0.25 PROD2 WHPST OWFF T Monitor well, static. 470.0 470.0 16:30 16:45 1/9/2016 1/9/2016 2.50 PROD2 WHPST BHAH T PJSM; rack back HWDP, change out 470.0 470.0 16:45 19:15 MWD, anchor shear screws, debris cup, & whipstock lug, TIH w/ HWDP. 1/9/2016 1/9/2016 1.00 PROD2 WHPST TRIP T PJSM; TIH w/ whipstock assembly f/ 470.0 1,560.0 19:15 20:15 470'- 1560' MD. 1/9/2016 1/9/2016 0.25 PROD2 WHPST DHEQ T Shallow hole test MWD, 200 gpm, 575 1,560.0 1,560.0 20:15 20:30 psi. 1/9/2016 1/10/2016 3.50 PROD2 WHPST TRIP T PJSM; TIH f/ 1560'- 6579' MD, 1,560.0 6,579.0 20:30 00:00 calculated displacement 42, actual 44 bbls. 1/10/2016 1/10/2016 2.50 PROD2 WHPST TRIP T PJSM; TIH f/ 6579'- 9924' MD, 6,579.0 9,924.0 00:00 02:30 calculated displacement18.9, actual 21.7 bbls. 1/10/2016 1/10/2016 1.50 PROD2 WHPST RGRP T PJSM; change out swivel packing & 9,924.0 9,924.0 02:30 04:00 test to 3500 psi. 1/10/2016 1/10/2016 0.50 PROD2 WHPST SRVY T Obtain parameters & orient assembly 9,924.0 9,924.0 04:00 04:30 to 52° left, 204 gpm, 980 psi, FO 34%, PU 131K, SO 105K. 1/10/2016 1/10/2016 0.50 PROD2 WHPST HOSO P PJSM; set whipstock at 52° left as 9,924.0 9,915.0 04:30 05:00 follows. Set down on No Go @ 9969' MD with 80K to observe screws shear on anchor. PU to 140K to confirm anchor set. Work string 2X setting down to 40K each time. Observe lug shear on 2nd time. PU to observe milling assembly free w/ PU130K, SO 104K. Top of window @ 9915' MD, bottom of window @ 9929' MD. SPR's @ 9914' MD, 6250' TVD, MW 11.9+ ppg, 04:45 hrs. #1 @ 20 = 110; @ 30 = 280 psi #2 @ 20 = 100; @ 30 = 280 psi Page 41/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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 (WB) 1/10/2016 1/10/2016 7.00 PROD2 WHPST MILL P PJSM; mill window per Baker Rep. f/ 9,915.0 9,923.0 05:00 12:00 9915'- 9923' MD, PU 130K, SO 104K, ROT 120K, Tq on 7-8K, off 5-6K, FO 46%, WOB 1-5K, 100 rpm, 300 gpm, 2000 psi, Max Gas 0. Fire Drill CRT 98 sec @ 07:00 hrs. 1/10/2016 1/10/2016 6.00 PROD2 WHPST MILL P PJSM; mill window per Baker Rep. f/ 9,923.0 9,931.0 12:00 18:00 9923'- 9931' MD, PU 135K, SO 93K, ROT 115K, Tq on 7-9K, off 5-6K, FO 45%, WOB 10-15K, 70-100 rpm, 300 gpm, 1950 psi, Max Gas 0. 1/10/2016 1/10/2016 1.25 PROD2 WHPST CIRC T Milling continued to slow down to less 9,931.0 9,869.0 18:00 19:15 than 1 fph. Geology confirmed a Siderite stringer outside of window. Confer with Baker Rep & town to decide to pull out of hole for bit. CBU f/ 9931'- 9869' MD, 300 gpm, 1850 psi, 30 rpm, Tq 5-6K, FO 45%. Obtain SPR's. SPR's @ 9914' MD, 6250' TVD, MW 12.0 ppg, 19:00 hrs. #1 @ 20 = 165; @ 30 = 320 psi #2@20=160;@30=315 psi 1/10/2016 1/10/2016 0.50 PROD2 WHPST OWFF T Monitor well, static. 9,869.0 9,869.0 19:15 19:45 1/10/2016 1/10/2016 3.25 PROD2 WHPST TRIP T PJSM; lay down single & TOH f/ 9869' 9,869.0 415.0 19:45 23:00 - 415' MD. Kick w/ Tripping Drill CRT 81 sec @ 22:00 hrs. 1/10/2016 1/10/2016 0.25 PROD2 WHPST OWFF T Monitor well, static. 415.0 415.0 23:00 23:15 1/10/2016 1/11/2016 0.75 PROD2 WHPST BHAH T PJSM; lay down magnet & rack back 3 415.0 92.0 23:15 00:00 stands of HWDP. Calculated fill 54, actual 58 bbls. 1/11/2016 1/11/2016 0.50 PROD2 WHPST BHAH T PJSM; lay down milling assembly as 92.0 0.0 00:00 00:30 per Baker Rep. 1/11/2016 1/11/2016 0.75 PROD2 WHPST BHAH T PJSM; clear & clean floor. Mobilize 0.0 0.0 00:30 01:15 new milling assembly to the rig floor. 1/11/2016 1/11/2016 0.50 PROD2 WHPST BHAH T PJSM; make up milling BHA as per 0.0 347.0 01:15 01:45 Baker Rep. f/ 0 - 347' MD. 1/11/2016 1/11/2016 3.75 PROD2 WHPST TRIP T PJSM; TIH f/ 347'- 9895' MD, fill 347.0 9,895.0 01:45 05:30 every 20 stands, calculated displacement 60.1, actual 55.3 bbls. 1/11/2016 1/11/2016 0.25 PROD2 WHPST CIRC T Obtain milling parameters @ 300 gpm, 9,895.0 9,895.0 05:30 05:45 1400 psi, 100 rpm, Tq 7K, PU 131 K, SO 100K, ROT 113K, 1/11/2016 1/11/2016 0.25 PROD2 WHPST REAM T Wash & ream f/ 9895'- 9922' MD, 300 9,895.0 9,922.0 05:45 06:00 gpm, 1400 psi, 100 rpm, Tq 7K. 1/11/2016 1/11/2016 0.75 PROD2 WHPST MILL T Dress window f/ 9922'- 9931' MD, 300 9,922.0 9,931.0 06:00 06:45 gpm, 1400 psi, FO 45%, 100 rpm, Tq 6-9K. 1/11/2016 1/11/2016 2.00 PROD2 WHPST MILL P Mill window f/ 9931'- 9947' MD, PU 9,931.0 9,947.0 06:45 08:45 145K, SO 75K, ROT 120K, Tq on 8k, off 6-7K, FO 52%, WOB 5-1 OK, 100 rpm, 425 gpm, 2500 psi, Max gas 290 1/11/2016 1/11/2016 1.00 PROD2 WHPST CIRC P Circulate & condition brine, pump 9,947.0 9,947.0 08:45 09:45 super sweep then circulate @ 426 gpm, 2450 psi, FO 52%, 70 rpm, Tq 7K. Page 42/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/11/2016 1/11/2016 0.50 PROD2 WHPST TRIP P PJSM, TOH f/ 9947'- 9892' MD, 9,947.0 9,892.0 09:45 10:15 obtain SPR's, blow down TD. SPR's @ 9947' MD, 6249' TVD, MW 12.0 ppg, 10:00 hrs. #1 @ 20 = 170; @ 30 = 310 psi #2 @ 20 = 170; @ 30 = 290 psi 1/11/2016 1/11/2016 0.50 PROD2 WHPST OWFF P Monitor well, static. 9,892.0 9,892.0 10:15 10:45 1/11/2016 1/11/2016 4.00 PROD2 WHPST TRIP P PJSM; TOH f/ 9892'- 370' MD, 9,892.0 370.0 10:45 14:45 calculated fill 54.1, actual 57.48 bbls. 1/11/2016 1/11/2016 0.25 PROD2 WHPST OWFF P Monitor well, static. 370.0 370.0 14:45 15:00 1/11/2016 1/11/2016 1.00 PROD2 WHPST BHAH P PJSM; stand back HWDP, lay down 370.0 0.0 15:00 16:00 milling BHA per Baker Rep. 1/11/2016 1/11/2016 0.25 PROD2 WHPST BHAH P Clear & clean rig floor. 0.0 0.0 16:00 16:15 1/11/2016 1/11/2016 0.50 PROD2 WHPST RURD P PJSM; pull wear bushing, blow down 0.0 0.0 16:15 16:45 kill & choke lines. 1/11/2016 1/11/2016 0.50 PROD2 WHPST WWWH P PJSM; make up stack washer, flush 0.0 0.0 16:45 17:15 stack, lay down stack washer. 1/11/2016 1/11/2016 0.75 PROD2 WHDBOP RURD P PJSM; rig up test equipment. 0.0 0.0 17:15 18:00 1/11/2016 1/11/2016 5.00 PROD2 WHDBOP BOPE P PJSM; test BOPE w/ 4" test joint to 0.0 0.0 18:00 23:00 250/3500 psi for 5 min each. #1: Top pipe rams, CV 1, 12,13, 14 & manual kill valve. #2: Upper IBOP, HCR kill, CV 9, & 11. #3: Lower IBOP, CV 5,8 & 10. #4: Dart, CV 4,6 & 7. #5: FOSV and CV 2. #6: Manual choke valve & 4" kill line Demco valve,(Demco valve failed, seat replaced) # 7: Manual choke valve & HCR kill. #8: Annular preventer tested to 250/2500 psi. 1/11/2016 1/12/2016 1.00 PROD2 WHDBOP BOPE T Attempt to test / trouble shoot lower 0.0 0.0 23:00 00:00 pipe rams w/ 4" & 4.5" test joint. 1/12/2016 1/12/2016 1.50 PROD2 WHDBOP BOPE T Attempt to test / trouble shoot lower 0.0 0.0 00:00 01:30 pipe rams w/ 4" & 4.5" test joint. 1/12/2016 1/12/2016 2.50 PROD2 WHDBOP BOPE P PJSM; test annular w/ 4/5" joint to 0.0 0.0 01:30 04:00 250 / 2500 psi for 5 minutes each. Test 3.5"X6" VBR's w/ 4/5" test joint & blind rams to 250 / 3500 psi for 5 minutes each. Accumulator Draw Down - Initial system pressure 3000 psi, pressure after closure 1900 psi, 200 psi attained in 43 sec, full pressure attained in 171 sec, 5 nitrogen bottles averaged 1950 psi. Tested pit level sensors & gas alarms. 1/12/2016 1/12/2016 0.50 PROD2 WHDBOP BOPE T PJSM; remove test plug & install 10.5" 0.0 0.0 04:00 04:30 wear bushing. 1/12/2016 1/12/2016 0.25 PROD2 WHDBOP MPSP T PJSM; mobilize storm packer & tools 0.0 0.0 04:30 04:45 to rig floor. 1/12/2016 1/12/2016 1.00 PROD2 WHDBOP TRIP T PJSM; TIH w/ mule shoe, 3 stands of 0.0 1,036.0 04:45 05:45 HWDP & 8 stands of 4" DP f/ 0 - 1036' MD. Page 43/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) A 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase pp Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 1/12/2016 1/12/2016 0.75 PROD2 WHDBOP MPSP T PJSM; make up storm packer as per 1,036.0 0.0 05:45 06:30 Baker Rep. TIH & set storm packer @ 89' MD below RKB per Baker Rep. Test to 450 psi for 5 min. Rack back stand. 1/12/2016 1/12/2016 0.25 PROD2 WHDBOP BOPE T PJSM; drain stack, remove wear 0.0 0.0 06:30 06:45 bushing & install test plug. 1/12/2016 1/12/2016 0.75 PROD2 WHDBOP BOPE T PJSM; remove 2-7/8" X 5" VBR's & 0.0 0.0 06:45 07:30 install new 2-7/8" X 5" VBR's. 1/12/2016 1/12/2016 1.75 PROD2 WHDBOP BOPE T PJSM; RU & pretest lower VBR's. Find 0.0 0.0 07:30 09:15 & repair additional surface equipment leak. 1/12/2016 1/12/2016 1.75 PROD2 WHDBOP BOPE T Test lower VBR's w/ 4" & 4.5" test 0.0 0.0 09:15 11:00 joints to 250 / 3500 psi for 5 min each. Retest inline 4" kill line Demco valve. Perform draw down on chokes. 1/12/2016 1/12/2016 0.50 PROD2 WHDBOP RURD T PJSM; rig down test equipment & blow 0.0 0.0 11:00 11:30 down all lines. SIMOPS remove test plug and install 10.5" wear bushing. 1/12/2016 1/12/2016 0.75 PROD2 WHDBOP MPSP T PJSM; TIH to 89'& check for pressure 0.0 1,036.0 11:30 12:15 under storm packer. Release storm packer, pull to surface & lay down per Baker Rep. 1/12/2016 1/12/2016 0.75 PROD2 WHDBOP TRIP T PJSM; TOH w/ 8 stands of 4" DP, 3 1,036.0 0.0 12:15 13:00 stands of HWDP & mule shoe f/1036' - 0' MD. 1/12/2016 1/12/2016 0.50 PROD2 WHPST BHAH P PJSM; mobilize tools for motor kick off 0.0 0.0 13:00 13:30 BHA. Clear & clean rig floor. 1/12/2016 1/12/2016 3.00 PROD2 WHPST BHAH P PJSM; pick up BHA 13 as per SLB, 0.0 468.0 13:30 16:30 load sources & change bend in motor f/ 1.5 to 1.15°. 1/12/2016 1/12/2016 0.25 PROD2 WHPST TRIP P PJSM; TIH f/ 468'- 1500' MD. 468.0 1,500.0 16:30 16:45 1/12/2016 1/12/2016 0.50 PROD2 WHPST DHEQ P Shallow test MWD @ 210 gpm, 900 1,500.0 1,500.0 16:45 17:15 psi, good. 1/12/2016 1/12/2016 3.50 PROD2 WHPST TRIP P TIH f/ 1500'- 9921' MD, calculated 1,500.0 9,921.0 17:15 20:45 displacement 60 bbls, actual 59 bbls. 1/12/2016 1/12/2016 1.25 PROD2 WHPST SLPC P PJSM; slip & cut 65' of drill line. 9,921.0 9,921.0 20:45 22:00 1/12/2016 1/12/2016 0.50 PROD2 WHPST SVRG P Service rig. 9,921.0 9,921.0 22:00 22:30 1/12/2016 1/13/2016 1.50 PROD2 WHPST CIRC P CBU @ 210 gpm, 1250 psi, PU 148K, 9,921.0 9,897.0 22:30 00:00 SO 95K, f/ 9921'- 9897' MD, tag bottom @ 9943' MD. Verify pipe tally. 1/13/2016 1/13/2016 0.75 PROD2 WHPST CIRC P Circulate at 200 gpm, 1200 psi with no 9,897.0 9,886.0 00:00 00:45 rotation. 36% flow. P/U = 145 kips, S/0 = 95 kips 1/13/2016 1/13/2016 0.50 PROD2 WHPST RURD P Lay down on joint. Blow down top 9,886.0 9,886.0 00:45 01:15 drive and rig up for FIT test 1/13/2016 1/13/2016 0.25 PROD2 WHPST LOT P Perform LOT. Pumped 2 bbl. Bled 9,886.0 9,886.0 01:15 01:30 back .35 bbl. Fluid leaked of at 450 psi with 12.0 ppg brine @ 6258' TVD. LOT = 13.4 ppg EMW 1/13/2016 1/13/2016 0.25 PROD2 WHPST RURD P Rig down test equipment. Blow down 9,886.0 9,886.0 01:30 01:45 j kill line. Pick up single j Page 44169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) R 2S-13 Rig: DOYON 141 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) 1/13/2016 1/13/2016 0.50 PROD2 DRILL SRVY P Orient tool face to high -side. Wash 9,886.0 9,900.0 01:45 02:15 down from 9886' to 9900' with no rotation @ 198 gpm, 1210 psi, 35% flow. 1/13/2016 1/13/2016 0.50 PROD2 DRILL TRIP P Slide with no pumps from 9900' to 9,900.0 9,947.0 02:15 02:45 9947' MD. 1/13/2016 1/13/2016 1.00 PROD2 DRILL DDRL P Drill from 9947' to 9968'. TVD = 9,934.0 9,968.0 02:45 03:45 6263;. AST = .87, ART = 0, Bit hours = .87 hrs, Total jars hours = .87 hrs. P/U = 145 kips, S/O = 95 kips, Flow = 26%, WOB = 3-7 kips, RPM = o, 198 gpm @ 1250 psi, 47 spm, 1/13/2016 1/13/2016 0.50 PROD2 DRILL TRIP P POOH from 9968' to 9850'. Blow 9,968.0 9,850.0 03:45 04:15 down Top Drive 1/13/2016 1/13/2016 0.25 PROD2 DRILL OWFF P Monitorwell- static 9,850.0 9,850.0 04:15 04:30 1/13/2016 1/13/2016 0.75 PROD2 DRILL MPDA P Pull trip nipple and install RCD bearing 9,850.0 9,850.0 04:30 05:15 1/13/2016 1/13/2016 1.75 PROD2 DRILL DISP P Displace well to 10.5 ppg flo-thru mud 9,850.0 9,900.0 05:15 07:00 at 200 gpm, 1525 psi, 41 % flow w/o rotation. Work pipe from 9826' to 9900'. FCP = 1900 psi 1/13/2016 1/13/2016 0.75 PROD2 DRILL SRVY P Obtain parameters and SPR's. 9,900.0 9,900.0 07:00 07:45 Oriental tool face to high side and shut down pumps. SPR's @ 9915' MD, 6237' TVD, MW 10.7 ppg, 07:00 hrs. #1 @ 20 = 610; @ 30 = 860 psi #2 @ 20 = 600; @ 30 = 880 psi 1/13/2016 1/13/2016 4.25 PROD2 DRILL DDRL T Attempt to slide through window w/o 9,900.0 9,918.0 07:45 12:00 success. Couldn't get past 9918'. Orient 30 deg, 40 deg and 60 deg. deg left of high -side and attempt to slide through setting 10-15 k down without success. Pick up and check torque. Slack off 10-15 k while rotating 3 rpm with no increase in torque. Set down while pumping 1 bpm without success. 1/13/2016 1/13/2016 1.75 PROD2 DRILL DDRL T PJSM; attempt to work through 9,918.0 9,918.0 12:00 13:45 window as follows, orient 20° left & tag up at 9918' MD w/ 20K WOB. Continue to work pipe 360° & tagging up at 9918' MD, no success. Decision made to TOH for milling assembly. 1/13/2016 1/13/2016 4.25 PROD2 DRILL CIRC T CBU working pipe f/ 9910'- 9890' MD, 9,918.0 9,910.0 13:45 18:00 200 gpm, 1950 psi, PU 145K, SO 81 K. Waiting on truck to bring KW brine. 1/13/2016 1/13/2016 2.50 PROD2 DRILL DISP T PJSM; displace well to 12.0 ppg KW 9,910.0 9,910.0 18:00 20:30 brine @ 200 gpm, 1900 psi. 1/13/2016 1/13/2016 0.50 PROD2 DRILL OWFF T Monitor well, static. 9,910.0 9,910.0 20:30 21:00 1/13/2016 1/13/2016 1.50 PROD2 DRILL MPDA T PJSM; blow down MPD choke skid & 9,910.0 9,910.0 21:00 22:30 lines. Remove RCD & install trip nipple. Replace leaking air boot. Page 45/69 Report Printed: 2/29/2016 - Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/13/2016 1/14/2016 1.50 PROD2 DRILL TRIP T PJSM; TOH f/ 9910'- 7183' MD, PU 9,910.0 7,183.0 22:30 00:00 125K, SO 88K, calculated fill 14.7, actual 15 bbls. 1/14/2016 1/14/2016 2.50 PROD2 DRILL TRIP T POOH from 7183'to 468' 7,183.0 468.0 00:00 02:30 1/14/2016 1/14/2016 0.25 PROD2 DRILL OWFF T Monitor well at top of BHA 468.0 468.0 02:30 02:45 1/14/2016 1/14/2016 1.50 PROD2 DRILL BHAH T Rack back 3 stand of HWDP and one 468.0 60.0 02:45 04:15 stand of flex collars 1/14/2016 1/14/2016 1.00 PROD2 DRILL BHAH T Download sources and lay down 60.0 0.0 04:15 05:15 motor and MWD tools 1/14/2016 1/14/2016 0.25 PROD2 DRILL BHAH T Clear rig floor 0.0 0.0 05:15 05:30 1/14/2016 1/14/2016 0.25 PROD2 DRILL SFTY T Pre -job safety meeting on picking up 0.0 0.0 05:30 05:45 milling BHA 1/14/2016 1/14/2016 0.50 PROD2 DRILL BHAH T Bring milling tools to the rig floor. 0.0 0.0 05:45 06:15 1/14/2016 1/14/2016 1.00 PROD2 DRILL BHAH T Make up milling BHA 0.0 325.0 06:15 07:15 1/14/2016 1/14/2016 4.00 PROD2 DRILL TRIP T RIH from 325'to 9875' filling every 20 325.0 9,875.0 07:15 11:15 stands. 1/14/2016 1/14/2016 0.25 PROD2 DRILL CIRC T Break circulation and fill pipe. Collect 9,875.0 9,875.0 11:15 11:30 parameters PU 138K, SO 91 K, ROT 115K, 90 rpm, Tq 7K. SPR's @ 9872' MD, 6243' TVD, MW 12.0 ppg,11:00 hrs. #1 @ 20 = 180; @ 30 = 330 psi #2@20=180;@30=340 psi 1/14/2016 1/14/2016 0.50 PROD2 DRILL MILL T Wash from 9875 and set down at 9,875.0 9,915.0 11:30 12:00 9915'. Mill with 90 rpm, and 1-3k WOB. Pump at 350 gpm, 1875 psi and 50% flow. 1/14/2016 1/14/2016 9.00 PROD2 DRILL MILL T PJSM; mill whipstock & window f/ 9,915.0 9,928.0 12:00 21:00 9915' -9928' MD, 6244' TVD, PU 138K, SO 92K, ROT 115K, 100 rpm, Tq on 7-9K, off 5-6K, FO 48%, WOB 1 -7K, 300-350 gpm, 1750 psi. 1/14/2016 1/14/2016 1.25 PROD2 DRILL CIRC T CBU w/ super sweep @ 310 gpm, 9,928.0 9,878.0 21:00 22:15 1750 psi. Decide to TOH to recover possible junk in milling assembly. Blow down TD. SPR's @ 9878' MD, 6240' TVD, MW 12.0 ppg, 22:00 hrs. #1 @ 20 = 130; @ 30 = 300 psi #2 @ 20 = 130; @ 30 = 280 psi 1/14/2016 1/14/2016 0.50 PROD2 DRILL OWFF T Monitor well, static. 9,878.0 9,878.0 22:15 22:45 1/14/2016 1/15/2016 1.25 PROD2 DRILL TRIP T PJSM; TOH f/ 9878'-8900' MD, 3000 9,878.0 8,900.0 22:45 00:00 fph, calculated fill 5.4, actual 5.6 bbls. 1/15/2016 1/15/2016 5.00 PROD2 DRILL TRIP T PJSM; continue to TOH f/ 8900'- 325' 8,900.0 325.0 00:00 05:00 MD, 3000 fph, calculated fill 54.54, actual 55.42 bbls. 1/15/2016 1/15/2016 0.25 PROD2 DRILL OWFF T Monitor well, static. 325.0 325.0 05:00 05:15 1/15/2016 1/15/2016 0.50 PROD2 DRILL BHAH T Rack back 3 stands of HWDP. 325.0 48.0 05:15 05:45 Page 46169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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), 1/15/2016 1/15/2016 0.25 PROD2 DRILL BHAH T Drain stack & pull milling BHA to 48.0 0.0 05:45 06:00 surface looking for any junk or debris. 1/15/2016 1/15/2016 0.25 PROD2 DRILL BHAH T PJSM; lay down milling BHA per 0.0 0.0 06:00 06:15 Baker Rep. 1/15/2016 1/15/2016 0.75 PROD2 DRILL BHAH T PJSM; pick up new 6-1/8" mill bit, new 0.0 336.0 06:15 07:00 lower water melon mill, magent, w/ 3 stands of HWDP. 1/15/2016 1/15/2016 5.00 PROD2 DRILL TRIP T PJSM; TIH f/ 336'- 9900' MD, filling 336.0 9,900.0 07:00 12:00 every 20 stands, calculated displacement 59, actual 61 bbls. 1/15/2016 1/15/2016 1.00 PROD2 DRILL REAM T Wash & ream f/ 9900'- 9928' MD, tag 9,900.0 9,928.0 12:00 13:00 up & clean out fill 9923'-9928', PU 128K, SO 98K, ROT 11 OK, 300 gpm, 1400 psi, FO 52%, 90 rpm, Tq 8K. 1/15/2016 1/15/2016 2.00 PROD2 DRILL MILL T Mill & dress window f/ 9928'- 9948' 9,928.0 9,938.0 13:00 15:00 MD, 300 gpm, 1500 psi, 90-100 rpm, Tq 6K, FO 47%, PU 128K, SO 98K, ROT 11 OK. 1/15/2016 1/15/2016 0.25 PROD2 DRILL REAM T Wash & ream f/ 9938'- 9968' MD, to 9,938.0 9,968.0 15:00 15:15 bottom exposing lower mills out of window, PU 138K, SO 98K, ROT 115K, 350 gpm, 1750 psi, FO 47%, 100 rpm, Tq 6-8K. 1/15/2016 1/15/2016 0.50 PROD2 DRILL CIRC T Pump super sweep, pulling up into 9,968.0 9,900.0 15:15 15:45 casing f/ 9968'-9900' MD. Pump at 350 gpm, 2000 psi, 100 rpm, Tq 8k. 1/15/2016 1/15/2016 0.75 PROD2 DRILL MILL T Work mills through window (TOW 9,900.0 9,900.0 15:45 16:30 9915'& BOW 9929') several times until clean. PU 138, SO 92, ROT 115K, 350 gpm, 1750 psi, 100 rpm, Tq 7-9K. Obtain SPR's & blow down TD. SPR's @ 9909' MD, 6242' TVD, MW 12.0 ppg, 16:00 hrs. #1 @ 20 = 190; @ 30 = 300 psi #2 @ 20 = 200; @ 30 = 290 psi 1/15/2016 1/15/2016 0.25 PROD2 DRILL OWFF T Monitor well, static. 9,900.0 9,900.0 16:30 16:45 1/15/2016 1/15/2016 5.00 PROD2 DRILL TRIP T PJSM; TOH f/ 9909'- 336' MD, 9,900.0 336.0 16:45 21:45 calculated fill 54.5, actual 55.4 bbls. Kick w/ Tripping Drill CRT 77 sec @ 20:00 hrs. 1/15/2016 1/15/2016 0.25 PROD2 DRILL OWFF T Monitor well, static. 336.0 336.0 21:45 22:00 1/15/2016 1/15/2016 1.00 PROD2 DRILL BHAH T PJSM; rack back 3 stands of HWDP & 336.0 0.0 22:00 23:00 lay down milling assembly per Baker Rep. Mill bit 1/4" out of gauge. Lower mill showed wear on carbides. Upper mill small amount of wear. Extreme magnet had slots filled with metal shaving & larger debris. 1/15/2016 1/15/2016 0.25 PROD2 DRILL BHAH T PJSM; clear & clean rig floor. 0.0 0.0 23:00 23:15 1/15/2016 1/16/2016 0.75 PROD2 DRILL BHAH T PJSM; pick up kick off BHA # 16 per 0.0 0.0 23:15 00:00 SLB DD. 1/16/2016 1/16/2016 2.00 PROD2 DRILL BHAH T PJSM; continue making up kick off 0.0 352.0 00:00 02:00 BHA #16 f/ 0 - 352' MD, Page 47169 Report Printed: 2/29/2016 R Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/16/2016 1/16/2016 0.50 PROD2 DRILL TRIP T PJSM; TIH f/ 352'- 1286' MD, 352.0 1,286.0 02:00 02:30 1/16/2016 1/16/2016 0.25 PROD2 DRILL DHEQ T Shallow test MWD, 200 gpm, 750 psi, 1,286.0 1,286.0 02:30 02:45 FO 39%. Tested good. Blow down TD. 1/16/2016 1/16/2016 4.50 PROD2 DRILL TRIP T PJSM; TIH f/ 1286'- 9864' MD, fill 1,286.0 9,864.0 02:45 07:15 every 20 stands, calculated displacement 60.2, actual 60.2 bbls. 1/16/2016 1/16/2016 1.25 PROD2 DRILL MPDA T PJSM; remove trip nipple & install 9,864.0 9,864.0 07:15 08:30 RCD bearing. 1/16/2016 1/16/2016 2.50 PROD2 DRILL DISP T PJSM; displace KW brine to 10.7 ppg 9,864.0 9,864.0 08:30 11:00 FloThru mud system @ 5 bpm, 2050 psi, PU 135K, SO 85K, orient motor to 52° L. SPR's @ 9864' MD, 6236' TVD, MW 10.7 ppg, 11:00 hrs. #1 @ 20 = 710; @ 30 = 1000 psi #2 @ 20 = 720; @ 30 = 1000 psi 1/16/2016 1/16/2016 1.00 PROD2 DRILL WASH T Begin to trip in hole & tag up at 9908' 9,864.0 9,908.0 11:00 12:00 MD, wash down @ 30 gpm, 850 psi, 30-50 fph, PU 145K, SO 87K. 1/16/2016 1/16/2016 3.50 PROD2 DRILL WASH T PJSM; wash down f/ 9908'- 9930' MD 9,908.0 9,930.0 12:00 15:30 as follows. Work through window @ 30 gpm, 850 psi, 52° L, push through w/ 7K WOB to 9922' MD. Stall motor at 9922', pick up & orient to 52° L, washing back to 9922'. Increase pumps to 215 gpm, 1975 psi & slowly wash down to 9930' MD. 1/16/2016 1/16/2016 0.50 PROD2 DRILL WASH T Wash to bottom f/ 9930'- 9964' MD, 9,930.0 9,964.0 15:30 16:00 215 gpm, 1975 psi. 1/16/2016 1/16/2016 0.50 PROD2 DRILL WASH T Attempt to work through window w/ no 9,964.0 9,968.0 16:00 16:30 pumps. Tag up at 9919' MD on the way back in. Wash back down to 9968' MD @ 60 gpm, 900 psi. 1/16/2016 1/16/2016 3.50 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 9,968.0 10,085.0 16:30 20:00 f/ 9968'- 10085' MD, 6272' TVD, AST 1.58, ART 1.10, ADT 2.68, BIT 2.68, JARS 3.55, PU 135K, SO 87K, ROT 11 OK, Tq on 7-8K, off 6-7K, FO 41 %, WOB 10-30K, 250 gpm, 2550 psi, Max gas 432. 1/16/2016 1/16/2016 3.25 PROD2 DRILL REAM T Ream last stand to lessen dog leg per 10,085.0 10,085.0 20:00 23:15 DD, 250 gpm, 2300 psi, 60 rpm, Tq 8- 9K. 1/16/2016 1/17/2016 0.75 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 10,085.0 10,123.0 23:15 00:00 f/ 10085'- 10123' MD, 6274' TVD, AST 0, ART .59, ADT .59, BIT 3.0, JARS 3.87, PU 135K, SO 87K, ROT 11 OK, Tq on 7-8K, off 6-7K, FO 41 %, WOB 10-15K, 250 gpm, 2550 psi, Max gas 432. Fire Drill CRT115 sec @ 23:45 hrs. 1/17/2016 1/17/2016 1.50 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 10,123.0 10,180.0 00:00 01:30 f/ 10123'- 10180' MD, 6269' TVD, AST .68, ART .59, ADT 1.27, BIT 427, JARS 5.14, PU 135K, SO 85K, ROT 11 OK, Tq on 8K, off 7-8K, FO 47%, WOB 15-20K, 60 rpm, 250 gpm, 2520 psi, Max gas 336. Page 48/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/17/2016 1/17/2016 1.75 PROD2 DRILL CIRC P Pump high -vis sweep to surface with 10,180.0 10,180.0 01:30 03:15 100% increase in cutting @ 250 gpm, 2425 psi, 60 rpm, Tq 7-8K, FO 44%. SPR's @ 10178' MD, 6268' TVD, MW 10.7 ppg, 03:15 hrs. #1 @ 20 = 680; @ 30 = 940 psi #2 @ 20 = 680; @ 30 = 900 psi 1/17/2016 1/17/2016 1.00 PROD2 DRILL BKRM P PJSM; BROOH f/ 10180'- 9945' MD, 10,180.0 9,945.0 03:15 04:15 250 gpm, 2350 psi, 60 rpm, Tq 7-81K. Orient motor 60° L. 1/17/2016 1/17/2016 0.25 PROD2 DRILL SMPD P Pull BHA through window 9945'- 9,945.0 9,900.0 04:15 04:30 9900' MD, motor @ 60° L, PU 140K (Co. Man, DD & Baker Rep witness). 1/17/2016 1/17/2016 0.50 PROD2 DRILL OWFF P Monitor well & verify 11.7 ppg pore 9,900.0 9,900.0 04:30 05:00 pressure. 1/17/2016 1/17/2016 3.50 PROD2 DRILL DISP P PJSM; displace to 12.0 ppg KW brine 9,900.0 9,900.0 05:00 08:30 @ 5 bpm, 1290 psi, FO 32%. SPR's @ 9893' MD, 6244' TVD, BW 12.0 ppg, 08:15 hrs. #1 @ 20 = 225; @ 30 = 420 psi #2 @ 20 = 225; @ 30 = 420 psi 1/17/2016 1/17/2016 1.50 PROD2 DRILL OWFF P Monitor well, slight flow to static. 9,900.0 9,900.0 08:30 10:00 1/17/2016 1/17/2016 1.25 PROD2 DRILL MPDA P Remove RCD bearing & install trip 9,900.0 9,900.0 10:00 11:15 nipple. Blow down MPD choke skid & lines. 1/17/2016 1/17/2016 5.00 PROD2 DRILL TRIP P PJSM; TOH f/ 9900'- 380' MD, SLM 9,900.0 380.0 11:15 16:15 out, calculated fill 60.1, actual 63.1 bbls. 1/17/2016 1/17/2016 0.25 PROD2 DRILL OWFF P Monitor well, static. 380.0 380.0 16:15 16:30 1/17/2016 1/17/2016 1.25 PROD2 DRILL BHAH P PJSM; lay down BHA as per SLB. 380.0 0.0 16:30 17:45 1/17/2016 1/17/2016 0.50 PROD2 DRILL BHAH P PJSM; clear & clean rig floor. 0.0 0.0 17:45 18:15 1/17/2016 1/17/2016 1.25 PROD2 DRILL BHAH P PJSM; make up 6-3/4" rotary 0.0 125.0 18:15 19:30 steerable BHA # 17 per SLB DD to 125' MD. 1/17/2016 1/17/2016 1.25 PROD2 DRILL BHAH T PJSM; trouble shoot source 125.0 125.0 19:30 20:45 installation problem, in adnVISION tool. Install source. 1/17/2016 1/17/2016 1.25 PROD2 DRILL BHAH P Continue picking up BHA per SLB DD 125.0 414.0 20:45 22:00 f/ 125'-414' MD. 1/17/2016 1/17/2016 0.25 PROD2 DRILL TRIP P PJSM; TIH f/ 414'-1540' MD. 414.0 1,540.0 22:00 22:15 1/17/2016 1/17/2016 0.25 PROD2 DRILL DHEQ P Shallow hole test MWD @ 200 gpm, 1,540.0 1,540.0 22:15 22:30 950 psi, FO 41 %. 1/17/2016 1/18/2016 1.50 PROD2 DRILL TRIP P TIH f/ 1540'-4959' MD, fill every 20 1,540.0 4,959.0 22:30 00:00 stands, calculated displacement 28, actual 31 bbls. 1/18/2016 1/18/2016 4.25 PROD2 DRILL TRIP P TIH f/ 4959'-9866' MD, fill every 20 4,959.0 9,866.0 00:00 04:15 stands, 5000 fph, calculated displacement 58.1, actual 56.7 bbls. 1/18/2016 1/18/2016 1.50 PROD2 DRILL SLPC P PJSM; cut & slip 65' of drill line, 9,866.0 9,866.0 04:15 05:45 service TD. 1/18/2016 1/18/2016 1.50 PROD2 DRILL MPDA P PJSM; remove trip nipple, install RCD 9,866.0 9,866.0 05:45 07:15 bearing & hook up lines. Page 49169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/18/2016 1/18/2016 3.00 PROD2 DRILL DISP P PJSM; displace well f/ 12.0 ppg KW 9,866.0 9,866.0 07:15 10:15 brine to 10.7 ppg Flo-Thru mud system. Obtain SPR's. SPR's @ 9863' MD, 6245' TVD, MW 10.7 ppg, 10:00 hrs. #1 @ 20 = 760; @ 30 = 990 psi #2 @ 20 = 770; @ 30 = 1044 psi 1/18/2016 1/18/2016 3.00 PROD2 DRILL WASH P PJSM; wash & work through window 9,866.0 10,180.0 10:15 13:15 to bottom f/ 9866'- 10180' MD, PU 145K, SO 90K, ROT 11 OK, 210-250 gpm, 2110-2475 psi. 1/18/2016 1/18/2016 4.75 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 10,180.0 10,526.0 13:15 18:00 f/ 10180'- 10526' MD, 6273' TVD, ADT 3.6, BIT 3.6, JARS 8.74, PU 140K, SO 80K, ROT 105K, Tq on 11 K, off 11 K, ECD 12.17, FO 44%, WOB 9- 12K, 150 rpm, 250 gpm, 2600 psi, Max gas 210. Total Footage 346' Table Top Man Down Drill 18:00 hrs. 1/18/2016 1/19/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 10,526.0 11,028.0 18:00 00:00 f/ 10526'- 11028' MD, 6270' TVD, ADT 3.87, BIT 7.47, JARS 12.61, PU 143K, SO 77K, ROT 108K, Tq on 12- 13K, off 11 K, ECD 12.27, FO 50%, WOB 10-13K, 150 rpm, 250 gpm, 2725 psi, Max gas 1476. Total Footage 502' SPR's @ 10996' MD, 6270' TVD, MW 10.6+ ppg, 23:15 hrs. #1 @ 20 = 840; @ 30 = 1080 psi #2 @ 20 = 770; @ 30 = 1080 psi 1/19/2016 1/19/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 11,028.0 11,571.0 00:00 06:00 f/ 11028'- 11571' MD, 6264' TVD, ADT 4.71, BIT 12.18, JARS 17.32, PU 143K, SO 77K, ROT 105K, Tq on 12K, off 11 K, ECD 12.31, FO 50%, WOB 4- 1 OK, 140 rpm, 250 gpm, 2810 psi, Max gas 1468. Total Footage 543' SPR's @ 11561' MD, 6264' TVD, MW 10.6+ ppg, 05:51 hrs. #1 @ 20 = 790; @ 30 = 1115 psi #2 @ 20 = 785; @ 30 = 1080 psi 1/19/2016 1/19/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 11,571.0 12,136.0 06:00 12:00 f/ 11571'- 12136' MD, 6259' TVD, ADT 3.67, BIT 15.85, JARS 20.99, PU 145K, SO 75K, ROT 105K, Tq on 13K, off 11-12K, ECD 12.37, FO 52%, WOB 9-13K, 140 rpm, 260 gpm, 3040 psi, Max gas 1665. Total Footage 565' SPR's @ 12042' MD, 6260' TVD, MW 10.5+ ppg, 10:45 hrs. #1 @ 20 = 830; @ 30 = 1130 psi #2 @ 20 = 810; @ 30 = 1020 psi Page 50/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Lag Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 1/19/2016 1/19/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 12,136.0 12,800.0 12:00 18:00 f/ 12136'- 12800' MD, 6251' TVD, ADT 4.91, BIT 20.76, JARS 25.90, PU 160K, SO 67K, ROT 105K, Tq on 13- 14K, off 11 K, ECD 12.35, FO 52%, WOB 10-13K, 140 rpm, 250 gpm, 2900 psi, Max gas 1007. Total Footage 664' SPR's @ 12800' MD, 6251' TVD, MW 10.5+ ppg, 17:45 hrs. #1 @ 20 = 800; @ 30 = 1115 psi #2 @ 20 = 800; @ 30 = 1145 psi 1/19/2016 1/20/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 12,800.0 13,271.0 18:00 00:00 f/ 12800'- 13271' MD, 6238' TVD, ADT 3.59, BIT 24.35, JARS 29.49, PU 160K, SO 65K, ROT 105K, Tq on 14K, off 13K, ECD 12.30, FO 51%, WOB 7- 12K, 140 rpm, 251 gpm, 2950 psi, Max gas 2487. Total Footage 471' SPR's @ 13268' MD, 6238' TVD, MW 10.6 ppg, 23:45 hrs. #1 @ 20 = 900, @ 30 = 1150 psi #2 @ 20 = 990; @ 30 = 1220 psi 1/20/2016 1/20/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 13,271.0 13,760.0 00:00 06:00 f/ 13271'- 13760' MD, 6228' TVD, ADT 4.33, BIT 28.68, JARS 33.82, PU 160K, SO 62K, ROT 103K, Tq on 14- 15K, off 13K, ECD 12.35, FO 51 %, WOB 5-13K, 140 rpm, 250 gpm, 2910 psi, Max gas 581. Total Footage 489' 1/20/2016 1/20/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 13,760.0 14,122.0 06:00 12:00 f/ 13760'- 14122' MD, 6220' TVD, ADT 4.24, BIT 32.92, JARS 38.06, PU 160K, SO 62K, ROT 101 K, Tq on 14- 15K, off 13K, ECD 12.39, FO 52%, WOB 6-11 K, 140 rpm, 250 gpm, 3000 psi, Max gas 2523. Total Footage 362' SPR's @ 13837' MD, 6226' TVD, MW 10.5+ ppg, 08:15 hrs. #1 @ 20 = 850; @ 30 = 1185 psi #2 @ 20 = 850; @ 30 = 1175 psi 1/20/2016 1/20/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 14,122.0 14,665.0 12:00 18:00 f/ 14122'- 14665' MD, 6264' TVD, ADT 4.42, BIT 37.34, JARS 42.48, PU 171 K, SO 66K, ROT 104K, Tq on 15K, off 13K, ECD 12.42, FO 50%, WOB 8- 11 K, 140 rpm, 250 gpm, 3050 psi, Max gas 3213. Total Footage 543' SPR's @ 14592' MD, 6264' TVD, MW 10.5+ ppg, 17:30 hrs. #1 @ 20 = 860; @ 30 = 1280 psi #2 @ 20 = 850; @ 30 = 1290 psi Page 51/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 4 16i Rig: DOYON 141 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) 1/20/2016 1/21/2016 6.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 14,665.0 15,152.0 18:00 00:00 f/ 14665'- 15152' MD, 6257' TVD, ADT 3.97, BIT 41.31, JARS 46.45, PU 171 K, SO 64K, ROT 104K, Tq on 15.5K, off 13.5K, ECD 12.45, FO 50%, WOB 8-15K, 140 rpm, 250 gpm, 3150 psi, Max gas 6050. Total Footage 487' SPR's @ 15068' MD, 6259' TVD, MW 10.5 ppg, 23:00 hrs. #1 @ 20 = 900; @ 30 = 1220 psi #2 @ 20 = 880; @ 30 = 1240 psi 1/21/2016 1/21/2016 5.75 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 15,152.0 15,613.0 00:00 05:45 f/ 15152'- 15613' MD, 6244' TVD, ADT 4.16, BIT 45.47, JARS 50.61, PU 165K, SO 52K, ROT 102K, Tq on 15K, off 13K, ECD 12.41, FO 50%, WOB 4- 9K, 140 rpm, 250 gpm, 3110 psi, Max gas 6024. Total Footage 461' SPR's @ 15542' MD, 6245' TVD, MW 10.5+ ppg, 04:30 hrs. #1 @ 20 = 965; @ 30 = 1255 psi #2 @ 20 = 940; @ 30 = 1275 psi 1/21/2016 1/21/2016 3.25 PROD2 DRILL CIRC T Circulate out gas cut mud. 140 rpm, 15,613.0 15,613.0 05:45 09:00 13K tq, 250 gpm, 3120 psi. Non pressurized mud weights of 10 ppg in/9.9 ppg out observed. 1/21/2016 1/21/2016 0.25 PROD2 DRILL OWFF T Perform draw down test. Shut in with 15,613.0 15,613.0 09:00 09:15 380 psi. Pressure built to 440 psi/15 mins. Bleed to 380 psi. Pressure built to 444 psi/10 mins. Suspect gas migration and expansion. 1/21/2016 1/21/2016 2.00 PROD2 DRILL CIRC T CBU. 140 rpm, 13K tq, 250 gpm, 3120 15,613.0 15,613.0 09:15 11:15 psi. 1/21/2016 1/21/2016 0.75 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 15,613.0 15,637.0 11:15 12:00 f/ 15613'- 15637' MD, 6241' TVD, ADT .34, BIT 45.81, JARS 50.95, PU 165K, SO 52K, ROT 102K, Tq on 15K, off 13K, ECD 12.54, FO 50%, WOB 5- 10K, 140 rpm, 250 gpm, 3190 psi, Max gas 2882. Total Footage 24' 1/21/2016 1/21/2016 2.50 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 15,637.0 15,829.0 12:00 14:30 f/ 15637'- 15829' MD, 6235' TVD, ADT 2.24, BIT 48.05, JARS 52.19, PU 165K, SO 48K, ROT 103K, Tq on 15K, off 13K, ECD 12.45, FO 50%, WOB 6- 9K, 140 rpm, 250 gpm, 3150 psi, Max gas 1992. Total Footage 192' 1/21/2016 1/21/2016 1.25 PROD2 DRILL MPDA T PJSM. RCD element leaking. Blow 15,829.0 15,829.0 14:30 15:45 down TD. Change out RCD bearing assy. Page 52/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/21/2016 1/21/2016 3.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 15,829.0 16,018.0 15:45 18:45 f/ 15829'- 16018' MD, 6232' TVD, ADT 2.03, BIT 50.08, JARS 55.22, PU 165K, SO 50K, ROT 103K, Tq on 15- 16K, off 13K, ECD 12.53, FO 50%, WOB 6-10K, 140 rpm, 250 gpm, 3200 psi, Max gas 2159. Total Footage 189' 1/21/2016 1/21/2016 1.25 PROD2 DRILL MPDA T PJSM. RCD element leaking. Blow 16,018.0 16,018.0 18:45 20:00 down TD. Change out RCD bearing assy. Upon inspecting failed element it was determined to be a 5" element rather than 4". 1/21/2016 1/22/2016 4.00 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 16,018.0 16,280.0 20:00 00:00 f/ 16018'- 16280' MD, 6280' TVD, ADT 2.82, BIT 52.90, JARS 58.04, PU 169K, SO 38K, ROT 102K, Tq on 15- 16K, off 13K, ECD 12.67, FO 51 %, WOB 7-10K, 140 rpm, 250 gpm, 3225 psi, Max gas 3557. Total Footage 262' SPR's @ 16019' MD, 6230' TVD, MW 10.5+ ppg, 20:00 hrs. #1 @ 20 = 970; @ 30 = 1290 psi #2 @ 20 = 980; @ 30 = 1335 psi 1/22/2016 1/22/2016 8.50 PROD2 DRILL DDRL P Directional drill 6-3/4" L1 hole section 16,280.0 16,867.0 00:00 08:30 f/ 16280'- 16867' MD, 6207' TVD, ADT 5.98, BIT 58.88, JARS 64.02, PU 170K, SO 35K, ROT 102K, Tq on 16K, off 15K, ECD 12.74, FO 52%, WOB 6- 9K, 140 rpm, 250 gpm, 3250 psi, Max gas 2815. Total Footage 587' SPR's @ 16586' MD, 6215' TVD, MW 10.5+ ppg, 04:15 hrs. #1 @ 20 = 990; @ 30 = 1314 psi #2 @ 20 = 970; @ 30 = 1335 psi 1/22/2016 1/22/2016 4.00 PROD2 CASING CIRC P Circulate and condition mud. 140 rpm, 16,867.0 16,867.0 08:30 12:30 250 gpm, 3240 psi, 51 % FO Max gas=3340 1/22/2016 1/22/2016 0.50 PROD2 CASING OWFF P Perform draw down test. Shut in 289 16,867.0 16,867.0 12:30 13:00 psi. Built to 419 psi/5 min. Bleed to 310 psi. Built to 416 psi/5 min. Bleed to 300 psi. Built to 415 psi/5 min. Bleed to 300 psi. Built to 414 psi/5 min. 11.85 ppg EMW observed. 1/22/2016 1/22/2016 3.50 PROD2 CASING CIRC P Circulate and condition mud. 140 rpm, 16,867.0 16,867.0 13:00 16:30 250 gpm, 3250 psi. 52% FO. 1/22/2016 1/22/2016 0.25 PROD2 CASING CIRC P Obtain SPR's and survey as per 16,867.0 16,867.0 16:30 16:45 MWD. SPR's @ 16867' MD, 6207' TVD, MW 10.5+ ppg, 16:30 hrs. #1 @ 20 = 1050; @ 30 = 1375 psi #2 @ 20 = 1050; @ 30 = 1385 psi 1/22/2016 1/23/2016 7.25 PROD2 CASING BKRM P BROOH from 16867' MD to 14788' 16,867.0 14,788.0 16:45 00:00 MD. 250 gpm, 3250 psi, 140 rpm 13K tq, 12.51 ECD. Calc disp=10.8 bbls Act disp=31.3 bbls Page 53169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) TT 2S-13 Rig: DOYON 141 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) 1/23/2016 1/23/2016 6.00 PROD2 CASING BKRM P BROOH from 14788' MD to 12708' 14,788.0 12,708.0 00:00 06:00 MD. 250 gpm, 2750 psi, 140 rpm 9K tq, Rot wt 105K, FO 50%, 12.23 ECD. Calc disp=13.5 bbls Act disp=31.5 bbls 1/23/2016 1/23/2016 6.50 PROD2 CASING BKRM P BROOH from 12708' MD to 10440' 12,708.0 10,440.0 06:00 12:30 MD. 250 gpm, 2750 psi, 140 rpm 7K tq, Rot wt 105K, FO 49%, 12.17 ECD. Calc disp=11.88 bbls Act disp=19.8 bbls 1/23/2016 1/23/2016 2.50 PROD2 CASING PMPO P Pump OOH from 10440' MD to 9866' 10,440.0 9,866.0 12:30 15:00 MD. 250 gpm, 2600 psi, PU 130K. Hold 150 psi back pressure. Calc disp=4.32 Act disp=9.22 Pinhole washout observed on stand #103 1/23/2016 1/23/2016 2.00 PROD2 CASING CIRC P Pick up working single. CBU @ 9895' 9,866.0 9,866.0 15:00 17:00 MD. 250 gpm, 2600 psi, 100 rpm, 6K tq, 12.11 ECD. Lay down working single. 1/23/2016 1/23/2016 1.25 PROD2 CASING DISP P Pump and spot at bit 32 bbl 12.2 ppg 9,866.0 9,393.0 17:00 18:15 viscous brine spacer. Lay in spacer from 9866' MD to 9393' MD. 63 gpm, 175 psi. Hold 280 psi back pressure. 1/23/2016 1/23/2016 1.25 PROD2 CASING DISP P Displace 10.5 ppg FLOTHRU mud to 9,393.0 9,393.0 18:15 19:30 12.2 ppg KCI/Naar brine. 205 gpm, 1450 psi, 80 rpm, 6K tq. 1/23/2016 1/23/2016 1.00 PROD2 CASING OWFF P Blow down TD. Monitor well by 9,393.0 9,393.0 19:30 20:30 pumping across top of hole. Lost .7 bbl/30 min. 1/23/2016 1/23/2016 1.25 PROD2 CASING MPDA P Blow down MPD choke skid and lines. 9,393.0 9,393.0 20:30 21:45 Pull RCD bearing assy. Install trip nipple. 1/23/2016 1/23/2016 0.50 PROD2 CASING SVRG P Service rig 9,393.0 9,393.0 21:45 22:15 1/23/2016 1/24/2016 1.75 PROD2 CASING TRIP P POOH on elevators from 9393' MD to 9,393.0 7,030.0 22:15 00:00 7030' MD PU 125K. Drop 2" rabbit on stand #94. Calc disp=13.5 Act disp=17.34 SPR's @ 8927' MD, 5825' TVD, MW 12.1+ ppg, 22:30 hrs. #1 @ 20 = 220; @ 30 = 480 psi #2 @ 20 = 230; @ 30 = 520 psi 1/24/2016 1/24/2016 4.00 PROD2 CASING TRIP P POOH on elevators from 7030' MD to 7,030.0 414.0 00:00 04:00 414' MD. Calc disp=51.3 bbls Act disp=62.7 bbls 1/24/2016 1/24/2016 0.25 PROD2 CASING OWFF P Monitor well. Static. 414.0 414.0 04:00 04:15 1/24/2016 1/24/2016 3.00 PROD2 CASING BHAH P Lay down jars. Pick up 1 jt HWDP and 414.0 0.0 04:15 07:15 stand back 2 stds HWDP. Lay down BHA # 17. Calc disp=56.6 bbls Act disp=70.5 bbls for trip. 1/24/2016 1/24/2016 1.00 PROD2 CASING BHAH P Clean and clear rig floor. 0.0 0.0 07:15 08:15 Page 54/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/24/2016 1/24/2016 1.50 COMPZ2 FISH BHAH P Pick up whip stock retrieval BHA. 0.0 366.0 08:15 09:45 Orient MWD 1/24/2016 1/24/2016 0.25 COMPZ2 FISH TRIP P RIH to 1379' MD. 366.0 1,379.0 09:45 10:00 1/24/2016 1/24/2016 0.25 COMPZ2 FISH DHEQ P Shallow test MWD. 200 gpm, 1100 1,379.0 1,379.0 10:00 10:15 psi, 33% FO 1/24/2016 1/24/2016 5.50 COMPZ2 FISH TRIP P RIH from 1379' MD to 9818' MD. Fill 1,379.0 9,818.0 10:15 15:45 pipe every 20 stds. 1/24/2016 1/24/2016 1.25 COMPZ2 FISH CIRC P Break circ. Orient whip stock retrieval 9,818.0 9,917.0 15:45 17:00 hook to 131'R. Wash down to 9927' MD. Wash retrieval slot from 9917' MD to 9927' MD. PU 130K, SO 100K, 250 gpm, 2200 psi. 1/24/2016 1/24/2016 0.75 COMPZ2 FISH FISH T Orient retrieval hook to 50°L. Slack off 9,917.0 9,917.0 17:00 17:45 to 9919' MD. PU and attempt to hook whip stock. No overpull observed. After two attempts turn string to right and set 1 OK down on bottom of retrieval slot at 9919' MD. PU and attempt to engage whip stock multiple times. No overpull observed. 1/24/2016 1/24/2016 1.00 COMPZ2 FISH CIRC T Orient to 130°R. Wash retrieval slot 9,917.0 9,917.0 17:45 18:45 from 9917' MD to 9927' MD .250 gpm, 2200 psi. 1/24/2016 1/24/2016 1.50 COMPZ2 FISH FISH T Orient to 40°L and attempt to hook 9,917.0 9,917.0 18:45 20:15 whip stock. Set down 5-15K on bottom of retrieval slot @ 9919' MD.Vary flow rates from 180 gpm to 250 gpm/1700 psi to 2200 psi. Able to set down on slot from 40°L to 19°L orientation. 1/24/2016 1/24/2016 0.25 COMPZ2 FISH CIRC T Orient to 130°R. Wash retrieval slot 9,917.0 9,915.0 20:15 20:30 from 9915' MD to 9927' MD. 290 gpm,3100 psi. Partial packoffs observed when passing top of whip stock. 1/24/2016 1/24/2016 1.50 COMPZ2 FISH FISH T Orient to 40°L and attempt to hook 9,915.0 9,915.0 20:30 22:00 whip stock. Set down 5-15K on bottom of retrieval slot @ 9919' MD.Vary flow rates from 180 gpm to 250 gpm/1700 psi to 2200 psi. Able to set down on slot from 58°L to 7°L orientation. 1/24/2016 1/24/2016 1.50 COMPZ2 FISH FISH T Consult with Rig Engineer and Drilling 9,915.0 9,913.0 22:00 23:30 Superintedent. Work hook 360° while attempting to engage whip stock.. No overpull observed. Observe set down weight on bottom of slot from 54°L to 13°L orientation. 180 gpm, 1300 psi with intermittent pack offs. 1/24/2016 1/25/2016 0.50 COMPZ2 FISH CIRC T Lay down single jt DP. Pump and spot 9,913.0 9,913.0 23:30 00:00 32 bbl 12.2 ppg viscous pill. 1/25/2016 1/25/2016 0.50 COMPZ2 FISH CIRC T Spot 32 bbls 12.2 ppg viscous brine 9,913.0 9,913.0 00:00 00:30 pill 1/25/2016 1/25/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static. 9,913.0 9,913.0 00:30 01:00 1/25/2016 1/25/2016 4.75 COMPZ2 FISH TRIP T POOH from 9913' MD to 3009' MD. 9,913.0 3,009.0 01:00 05:45 I Page 55/69 Repori Printed: 2/29/2016 - Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/25/2016 1/25/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static. 3,009.0 3,009.0 05:45 06:15 1/25/2016 1/25/2016 2.00 COMPZ2 FISH TRIP T POOH from 3009' MD to 366' MD. 3,009.0 366.0 06:15 08:15 Calc disp=54.5 bbls Act disp=62.1 bbls 1/25/2016 1/25/2016 0.25 COMPZ2 FISH OWFF T Monitor well. 366.0 366.0 08:15 08:30 1/25/2016 1/25/2016 1.25 COMPZ2 FISH BHAH T Stand back 3 stands HWDP. Lay 366.0 0.0 08:30 09:45 down BHA as per Baker rep. Calc disp=57 bbls Act disp=66.2 bbls for trip. 1/25/2016 1/25/2016 0.25 COMPZ2 WHDBOP RURD T Pull wear bushing 0.0 0.0 09:45 10:00 1/25/2016 1/25/2016 0.75 COMPZ2 WHDBOP WWWH T Make up stack washer. Flush BOPE. 0.0 0.0 10:00 10:45 Lay down stack washer 1/25/2016 1/25/2016 2.25 COMPZ2 WHDBOP RURD T Rig up to test BOPE. 0.0 0.0 10:45 13:00 1/25/2016 1/25/2016 7.00 COMPZ2 WHDBOP BOPE T PJSM; test BOPE w/ 4" test joint to 0.0 0.0 13:00 20:00 250/3500 psi for 5 min each. #1: Top pipe rams, CV 1,12,13, 14 & manual kill valve. #2: Upper IBOP, HCR kill, CV 9, & 11. #3: Lower IBOP (Lower IBOP failed initial test was cycled and passed retest), CV 5,8 & 10. #4: Dart, CV 4,6 & 7. #5: FOSV and CV 2. #6: HCR choke, 4" kill line Demco valve. # 7: Manual choke valve & HCR kill. #8: Annular preventer tested to 250/2500 psi. #9 Lower VBR's. #10 Blind rams, CV 3 #11 Upper VBR's w/ 4 1/2" test jt. #12 Annular preventer tested to 250/2500 psi. w/ 4 1/2" test jt. Perform draw down on chokes.Accumulator Draw Down - Initial system pressure 3000 psi, pressure after closure 1800 psi, 200 psi attained in 39 sec, full pressure attained in 177 sec, 5 nitrogen bottles averaged 1910 psi. Tested pit level sensors & gas alarms. Test witness waived by AOGCC rep Brian Bixby. 1/25/2016 1/25/2016 1.50 COMPZ2 WHDBOP RURD T Rig down test equipment. Set 12.32" 0.0 0.0 20:00 21:30 ID wear bushing. Blow down choke and kill lines. Reposition trip nipple. 1/25/2016 1/25/2016 1.25 COMPZ2 FISH BHAH T Pick up whip stock retrieval BHA. 0.0 366.0 21:30 22:45 Orient MWD 1/25/2016 1/25/2016 0.25 COMPZ2 FISH TRIP T RIH to 1498' MD. 366.0 1,498.0 22:45 23:00 1/25/2016 1/25/2016 0.25 COMPZ2 FISH DHEQ T Shallow test MWD. 200 gpm, 2000 1,498.0 1,498.0 23:00 23:15 psi. Blow down TD. 1/25/2016 1/26/2016 0.75 COMPZ2 FISH TRIP T RIH from 1498' MD to 3197' MD. Fill 1,498.0 3,197.0 23:15 00:00 pipe. 1/26/2016 1/26/2016 3.50 COMPZ2 FISH TRIP T PJSM. RIH from 3197' MD to 8872' 3,197.0 8,872.0 00:00 03:30 MD. Fill every 20 stands. Calc disp=52.8 bbls Act disp=50.1 bbls 1/26/2016 1/26/2016 1.50 COMPZ2 FISH SLPC T PJSM. Slip and cut 78' drilling line. 8,872.0 8,872.0 03:30 05:00 I Service top drive. Page 56169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) r°- 2S-13 41 Rig: DOYON 141 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) 1/26/2016 1/26/2016 1.00 COMPZ2 FISH TRIP T RIH from 8872' MD to 9913' MD. 8,872.0 9,913.0 05:00 06:00 Calc disp=58.2 bbls Act disp=55.1 bbls 1/26/2016 1/26/2016 0.50 COMPZ2 FISH CIRC T Break circ. Orient whip stock retrieval 8,913.0 8,919.0 06:00 06:30 hook to 130°R. Wash down to 9927' MD. Wash retrieval slot from 9917' MD to 9926' MD. PU 160K, SO 90K, 200 gpm, 1000 psi. 1/26/2016 1/26/2016 2.00 COMPZ2 FISH FISH T Orient retrieval hook to 51°L. Attempt 8,919.0 8,919.0 06:30 08:30 to hook whip stock. No overpull observed. Orient to 44°L,31 °L, 38°L, 48°L attempting to hook whipstock. No overpull observed. At 60°L set down 1 OK wt. on bottom of retrieval slot. PU and observe 75K overpull and fire jar. PU 90K overpull. Work pipe between 250K hoist wt and 120K slack wt. 1/26/2016 1/26/2016 0.75 COMPZ2 FISH FISH T Pick up 290K hoist wt. Observe hoist 8,919.0 8,919.0 08:30 09:15 wt drop to 265K. Continue to pull to 300K hoist wt. Work drill string between 300K and 120K. 1/26/2016 1/26/2016 1.75 COMPZ2 FISH JAR T Cock and fire jar w/100K overpull. Pull 8,919.0 8,919.0 09:15 11:00 to 300K. Observe 8' travel up and down. Anchor is 8" below whipstock. Suspect anchor hanging up on bottom of window. Anchor OD is 6 1/8". Fire jar 13 X. 1/26/2016 1/26/2016 0.50 COMPZ2 FISH SFTY T Perform derrick inspection 8,919.0 8,919.0 11:00 11:30 1/26/2016 1/26/2016 1.50 COMPZ2 FISH JAR T Jar on whip stock w/100K overpull. 8,919.0 8,919.0 11:30 13:00 Pull up to 320K. Fire jar 7 X. 1/26/2016 1/26/2016 0.25 COMPZ2 FISH SFTY T Perform derrick inspection 8,919.0 8,919.0 13:00 13:15 1/26/2016 1/26/2016 1.25 COMPZ2 FISH JAR T Jar on whip stock w/100K overpull. 8,919.0 8,919.0 13:15 14:30 Pull up to 350K. Fire jar 20 X. 1/26/2016 1/26/2016 1.00 COMPZ2 FISH JAR T Cock jar. Pick up to neutral weight. 8,919.0 8,908.0 14:30 15:30 Turn on MWD. MWD showing whip stock oriented to 44°L. Turn drill string and orient whip stock to 14°L. Jar on whip stock w/100K overpull. Pull up to 350K. Move whip stock up 3'. Cock jar. Lost free travel of fish. Fire jar 32 X. 1/26/2016 1/26/2016 0.25 COMPZ2 FISH SFTY T Inspect top drive. 8,908.0 8,908.0 15:30 15:45 1/26/2016 1/26/2016 2.00 COMPZ2 FISH JAR T Jar on whip stock w/100K overpull. 8,908.0 8,919.0 15:45 17:45 Pull up to 350K. Recover free travel of 8'. Fire jar 27 X. Hook slipping out of slot while cocking jar. 1/26/2016 1/26/2016 1.00 COMPZ2 FISH OWFF T Monitor well. Static. Inspect top drive 8,919.0 9,908.0 17:45 18:45 and derrick. Lay down single jt DP. 1/26/2016 1/26/2016 5.00 COMPZ2 FISH TRIP T POOH from 9908' MD to 366' MD. PU 9,908.0 366.0 18:45 23:45 160K. Calc disp=54.54 bbls Act disp=57.22 bbls 1/26/2016 1/27/2016 0.25 COMPZ2 FISH OWFF T Monitorwell. Static. 366.0 366.0 23:45 00:00 1/27/2016 1/27/2016 0.25 COMPZ2 FISH OWFF T OWFF, static. 366.0 366.0 00:00 00:15 Page 57/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/27/2016 1/27/2016 1.00 COMPZ2 FISH BHAH T PJSM, L/D whipstock fishing BHA. L/D 366.0 0.0 00:15 01:15 9 joints of HWDP, XO, Pump out sub, Float sub, Oil Jars and Bent hook. Observed hook missing the jet. Actual displacement= 3.4 bbls, Calculated displacement= 3.4 bbls 1/27/2016 1/27/2016 0.25 COMPZ2 FISH BHAH T Mobilize fishing tools to rig floor. 0.0 0.0 01:15 01:30 1/27/2016 1/27/2016 1.50 COMPZ2 FISH BHAH T PJSM, M/U BHA as per Baker rep. 0.0 322.0 01:30 03:00 Bull noise, 6.75' OD string mill, Oil jars and 4-3/4" DC. Actual displacement= 4.2 bbls. Calculated displacement= 5.5 bbls. 1/27/2016 1/27/2016 4.00 COMPZ2 FISH TRIP T RIH w/ string mill on 4" DP f/ 322' MD 322.0 9,869.0 03:00 07:00 to 9869' MD, filling every 20 stands. Actual displacement= 58.1 bbls, Calculated displacement = 60 bbls. 1/27/2016 1/27/2016 0.50 COMPZ2 FISH WASH T Wash down to 9914.79' MD, no 9,869.0 9,914.8 07:00 07:30 obstruction in casing observed. P/U= 153K, S/0= 90K, ROT= 115K w/ 7K tq, Pump @ 6 bpm=910 psi w/ 40% FO. Obtain SPR's @ 9882' MD TVD= 6237', MW=12.1+ 7:00 hours MP#1: 20 spm=110 psi, 30 spm=230 psi MP #2: 20 spm= 90 psi, 30 spm= 220 psi. 1/27/2016 1/27/2016 1.00 COMPZ2 FISH CIRC T Circaulte and condtion fluid, add 1% 9,914.8 9,914.8 07:30 08:30 v/v of SafeLube to system. Pump @ 6 bpm=910 psi, 40% FO. 1/27/2016 1/27/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static. 9,914.8 9,914.0 08:30 09:00 1/27/2016 1/27/2016 5.25 COMPZ2 FISH TRIP T POOH from 9914' MD to 385' MD. 9,914.0 385.0 09:00 14:15 1/27/2016 1/27/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 385.0 385.0 14:15 14:30 1/27/2016 1/27/2016 0.50 COMPZ2 FISH BHAH T Stand back 4 3/4" DC's. Lay down mill 385.0 0.0 14:30 15:00 and bullnose. Calc disp=60 bbls Act disp=65.76 bbls for trip. 1/27/2016 1/27/2016 0.25 COMPZ2 FISH BHAH T Clear rig floor. Mobilize fishing tools to 0.0 0.0 15:00 15:15 floor. 1/27/2016 1/27/2016 1.25 COMPZ2 FISH BHAH T Make up bent retrieval tool BHA. Bent 0.0 373.0 15:15 16:30 hook, oil jar, float sub, MWD, 4 3/4" DC's, intensifier, pump out sub. 1/27/2016 1/27/2016 0.50 COMPZ2 FISH TRIP T RIH with fishing BHA to 1316' MD. 373.0 1,316.0 16:30 17:00 1/27/2016 1/27/2016 0.25 COMPZ2 FISH DHEQ T Shallow test MWD. 200 gpm, 775 psi. 1,316.0 1,316.0 17:00 17:15 1/27/2016 1/27/2016 3.50 COMPZ2 FISH TRIP T RIH with fishing BHA from 1316' MD 1,316.0 8,219.0 17:15 20:45 to 8219' MD Fill pipe every 20 stds. Calc disp=51.08 bbls Act disp=50 bbls Page 58/69 Report Printed: 2/29/2016 � Operations Summary (with Timelog Depths) z 2S-13 Rig: DOYON 141 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) 1/27/2016 1/27/2016 0.75 COMPZ2 FISH CIRC T Observed no returns to surface. 8,219.0 8,219.0 20:45 21:30 Monitor well. Fluid level dropping in annulus. Fluid u -tubing up drillstring. Circulate drill pipe volume. 250 gpm, 1700 psi. No losses, no gains. Monitor well. Static 1/27/2016 1/27/2016 0.75 COMPZ2 FISH TRIP T RIH from 8219' MD to 9815'MD. 8,219.0 9,815.0 21:30 22:15 Calc disp=59.72 Act disp=59.45 bbls 1/27/2016 1/27/2016 1.25 COMPZ2 FISH CIRC T Break circ. Wash down from 9815' MD 9,815.0 9,926.0 22:15 23:30 to 9926' MD. Orient to 155°R. Wash retrieval slot. PU 140K SO 95K 1/27/2016 1/28/2016 0.50 COMPZ2 FISH FISH T Orient to 20°L. Attempt to hook whip 9,926.0 9,905.0 23:30 00:00 stock. Orient to 60°L. Hook whip stock at 9915' MD. Pick up to 175K. Fire jar. 1/28/2016 1/28/2016 3.50 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K. 9,905.0 9,915.0 00:00 03:30 24 gpm, 80 psi. Warm up jar w/50K over pull/ pull to 100K over. Work up to jar at 100K over pull/pulling to 200K over. Fire jar 70X. 1/28/2016 1/28/2016 0.50 COMPZ2 FISH SFTY T Inspect derrick and top drive. 9,915.0 9,915.0 03:30 04:00 1/28/2016 1/28/2016 4.00 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K. 9,915.0 9,905.0 04:00 08:00 24 gpm, 80 ps. Jar at 100K over pull/pulling to 200K over. Move whip stock up hole to 9905' MD. MWD indicates fish rotating as it is worked through free travel. Fire jar 64X. 1/28/2016 1/28/2016 1.25 COMPZ2 FISH SFTY T Inspect derrick and top drive. Consult 9,905.0 9,905.0 08:00 09:15 with Drilling Engineer. 1/28/2016 1/28/2016 2.75 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K. 9,905.0 9,895.0 09:15 12:00 24 gpm, 80 ps. Jar at 100K over pull/pulling to 200K over. Move whip stock up hole to 9895' MD. Fire jar 32X. 1/28/2016 1/28/2016 5.75 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K. 9,895.0 9,883.0 12:00 17:45 48 gpm, 200 psi. Jar at 100K over pull/pulling to 200K over. Move whip stock up hole to 9883' MD. Free travel down to 9923' MD. Fire jar 79 X. 1/28/2016 1/28/2016 0.75 COMPZ2 FISH SFTY T Inspect derrick and top drive. 9,883.0 9,883.0 17:45 18:30 1/28/2016 1/29/2016 5.50 COMPZ2 FISH JAR T Jar on whip stock. PU 150K SO 95K. 9,883.0 9,881.0 18:30 00:00 48 gpm, 200 psi. Jar at 100K over pull/pulling to 215K over. Move whip stock up hole to 9881' MD. Free travel down to 9923' MD. Fire jar 90 X. 1/29/2016 1/29/2016 0.50 COMPZ2 FISH JAR T Jar on whip stock @ 9881' MD. PU 9,881.0 9,115.0 00:00 00:30 150K SO 95K. 180 gpm, 1100 psi. Jar at 100K over pull/pulling to 215K over. Free travel down to 9923' MD. Fire jar 4 X. Set whip stock back down to 9115' MD. Page 59/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 1/29/2016 1/29/2016 3.00 COMPZ2 FISH FISH T Attempt to release hook. Orient whip 9,115.0 9,115.0 00:30 03:30 stock to 32°L. Slack off to 55K 3X. On third attempt observed hook jump out of retrieval slot. Slack off to 9928' MD. Wash fill 200 gpm, 1150 psi. Orient hook to 45° R. PU and observe overpull at 9907' MD. Slack off and orient hook to 60°R. Shut down pump. PU and observe overpull @ 9907' MD. Slack off and orient hook 130°R. PU and observe overpull @ 9907' MD. 1/29/2016 1/29/2016 1.25 COMPZ2 FISH SFTY T Inspect derrick and TD. 9,115.0 9,115.0 03:30 04:45 1/29/2016 1/29/2016 2.50 COMPZ2 FISH FISH T Orient hook 56°L. Wash down to 9934' 9,115.0 9,857.0 04:45 07:15 MD. Orient hook to 150°R. PU and observe overpull @ 9907' MD. Slack off and orient hook to 45°L working drill string from 9907' MD to 9916' MD. PU and encounter overpull @ 9881' MD. Pull 100K over. Orient hook to 120°L. PU to 9857' MD. No overpull observed. SPR's @ 9857' MD TVD= 6231', MW=12.23 07:00 hours MP #1: 20 spm=180 psi, 30 spm=400 psi MP #2: 20 spm=170 psi, 30 spm=390 psi. 1/29/2016 1/29/2016 0.75 COMPZ2 FISH OWFF T Monitor well. Gas breaking out at 9,857.0 9,857.0 07:15 08:00 surface. 1/29/2016 1/29/2016 1.00 COMPZ2 FISH CIRC T CBU. 290 gpm, 2340 psi. 9,857.0 9,857.0 08:00 09:00 1/29/2016 1/29/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static. 9,857.0 9,857.0 09:00 09:30 1/29/2016 1/29/2016 6.50 COMPZ2 FISH TRIP T Blow down TD. POOH from 9857' MD 9,857.0 373.0 09:30 16:00 to 373' MD. Observed 22K overpull @ 8250' MD. 1/29/2016 1/29/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 373.0 373.0 16:00 16:15 1/29/2016 1/29/2016 1.00 COMPZ2 FISH BHAH T Lay down pump out sub and 373.0 0.0 16:15 17:15 intensifier. Stand back 3 stands 4 3/4" drill collars. Lay down MWD, jar, one joint 3 1/2" HWDP and bent retrieval tool. No fish. Calc disp=58.55 bbls Act disp=66.34 bbls for trip 1/29/2016 1/29/2016 0.75 COMPZ2 FISH BHAH T Clean and clear rig floor. 0.0 0.0 17:15 18:00 1/29/2016 1/29/2016 1.75 COMPZ2 FISH ELOG T PJSM- Rig up wireline. Make up 0.0 0.0 18:00 19:45 wireline tools. 1/29/2016 1/29/2016 3.00 COMPZ2 FISH ELOG T RIH with wireline tools to 9915' MD. 40 0.0 0.0 19:45 22:45 arm caliper/GR/CCI/tractor. Run caliper log from 9915' MD to 9600' MD. 1/29/2016 1/30/2016 1.25 COMPZ2 FISH ELOG T POOH with wire line. 0.0 0.0 22:45 00:00 Total losses for tour=3.24 bbls 1/30/2016 1/30/2016 0.50 COMPZ2 FISH ELOG T POOH w/wireline 0.0 0.0 00:00 00:30 1/30/2016 1/30/2016 0.50 COMPZ2 FISH ELOG T Change out 40 arm caliper tool 0.0 0.0 00:30 01:00 Page 60/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 ;-0 4 i Rig: DOYON 141 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 (WB) 1/30/2016 1/30/2016 2.50 COMPZ2 FISH ELOG T RIH with wireline tools to 9915' MD. 40 0.0 0.0 01:00 03:30 arm caliper/GR/CCI/tractor. Run caliper log from 9915' MD to 9600' MD. 1/30/2016 1/30/2016 2.00 COMPZ2 FISH ELOG T POOH w/wireline 0.0 0.0 03:30 05:30 1/30/2016 1/30/2016 1.00 COMPZ2 FISH ELOG T Lay down wireline tools. Rig down 0.0 05:30 06:30 wireline equipment. 1/30/2016 1/30/2016 1.25 COMPZ2 FISH BHAH T Mobilize Baker fishing tools to rig floor. 0.0 0.0 06:30 07:45 1/30/2016 1/30/2016 1.75 COMPZ2 FISH BHAH T Make up clean out BHA. PU bullnose, 0.0 369.0 07:45 09:30 flex jt, string mill, 3 1/2" HWDP jt, string magnet, x -o, boot basket x2, bit sub, float sub, jar, x -o. 4 3/4" DC's x9, x -o, intensifier, pump out sub, x -o. 1/30/2016 1/30/2016 4.25 COMPZ2 FISH TRIP T RIH to 9822' MD. Fill every 20 stds. 369.0 9,822.0 09:30 13:45 PU 140K SO 95K Calc disp=60.27 bbls Act disp=56.85 bbls 1/30/2016 1/30/2016 1.75 COMPZ2 FISH MILL T Break circ. Wash down and tag up at 9,822.0 9,912.0 13:45 15:30 9888' MD (mill depth). Ream f/9888' MD t/9900' MD (mill depth) 80 rpm, 350 gpm, 1800 psi, 5-8K WOB.. Work pipe f/9900' MD t/9888' MD (mill depth) x2. No excessive drag up or down. Ream f/9900' MD t/9910' MD (mill depth) x5. Torque @ 6.5-7K. After 5th ream observed erratic torque @ 6.5-10K. Ream f/9910' MD t/9921' MD (mill depth). Bull nose @ 9931' MD. WOB 1-2K. Experiencing 500- 800 psi pump pressure spikes and steady torque @ 8.5-9K. Appear to be cutting new window. Pump viscous SuperSweep. Ream up to 9912' MD (bull nose depth). Shut down rotary and stage pump up to 400 gpm, 2290 psi. 1/30/2016 1/30/2016 0.75 COMPZ2 FISH CIRC T Circulate sweep out of hole. 400 gpm, 9,912.0 9,912.0 15:30 16:15 2290 psi. Did not observe any debris at shakers with sweep. 1/30/2016 1/30/2016 0.50 COMPZ2 FISH OWFF T Lay down working single DP. Blow 9,902.0 9,916.0 16:15 16:45 down TD. Monitor well. Static. 1/30/2016 1/30/2016 2.25 COMPZ2 FISH TRIP T POOH from 9916' MD to 6986' MD. 9,916.0 6,986.0 16:45 19:00 PU 150K. Observed 20K drag pulling mill through stage collar @ 8920' MD. 1/30/2016 1/30/2016 1.00 COMPZ2 FISH SVRG T Service rig. 6,986.0 6,986.0 19:00 20:00 1/30/2016 1/30/2016 2.75 COMPZ2 FISH TRIP T POOH from 6986' MD to 369' MD. 6,986.0 369.0 20:00 22:45 1/30/2016 1/30/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 369.0 369.0 22:45 23:00 1/30/2016 1/31/2016 1.00 COMPZ2 FISH BHAH T Lay down string mill BHA as per Baker 369.0 56.0 23:00 00:00 fishing hand. Stand back 3 stds 4 3/4" DC's. Calc disp=60.82 bbls Act disp=64 bbls for trip. 1/31/2016 0.50 COMPZ2 FISH BHAH T PJSM-Lay down string mill BHA as 56.0 0.0 11/31/2016 00:00 00:30 1 per Baker fishing hand. Page 61/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth;(ftK6) 1/31/2016 1/31/2016 0.75 COMPZ2 FISH BHAH T Clean and clear rig floor. 0.0 0.0 00:30 01:15 1/31/2016 1/31/2016 1.75 COMPZ2 FISH SLPC T PJSM-Slip and cut 65' drilling line. 0.0 0.0 01:15 03:00 1/31/2016 1/31/2016 1.75 COMPZ2 FISH BHAH T PJSM-Make up bent retrieval tool BHA 0.0 290.0 03:00 04:45 as per Baker fishing hand. PU bent retrieval tool, 3 1/2" HWDP jt, bumper sub, jar, float sub, MWD, x -o, 4 3/4" DC's x6, x -o, intensifier, pump out sub, x -o. 1/31/2016 1/31/2016 0.25 COMPZ2 FISH TRIP T RIH from 290' MD to 1706' MD. 290.0 1,706.0 04:45 05:00 1/31/2016 1/31/2016 0.25 COMPZ2 FISH DHEQ T Shallow test MWD. 1,706.0 1,706.0 05:00 05:15 1/31/2016 1/31/2016 2.75 COMPZ2 FISH TRIP T RIH from 1706' MD to 9838' MD. Fill 1,706.0 9,838.0 05:15 08:00 every 20 stds. Calc disp=59.62 bbls Act disp=56.29 bbls 1/31/2016 1/31/2016 0.50 COMPZ2 FISH FISH T Break circ. Obtain SPR's and 9,838.0 9,838.0 08:00 08:30 parameters. PU 140K SO 95K, 204 gpm, 1440 psi. Orient jet tol38°R. SPR's @ 9838' MD TVD= 6231', MW=12.23 08:15 hours MP #1: 20 spm=240 psi, 30 spm=520 psi MP #2: 20 spm=240 psi, 30 spm=520 psi. 1/31/2016 1/31/2016 1.00 COMPZ2 FISH FISH T Wash down to 9919' MD. Observed 9,838.0 9,840.0 08:30 09:30 slight tag up @ 9917' MD. Set 5K down wt @ 9919' MD. Down wt. fell off set 5K down @ 9921' MD. Wash fill down to 9931' MD. Wash retrieval slot 3x working drillstring from 9930' MD to 9920' MD. Observed 3K drag while pulling up. No drag while slacking off. Pull up to orient hook. Observed 15K overpull @ 9905' MD.Slack off and turn drill string 90° to the right. Pull up to 9840' MD. No overpull observed. 1/31/2016 1/31/2016 1.00 COMPZ2 FISH FISH T Orient to 41°L. RIH Wash down to 9,840.0 9,920.0 09:30 10:30 9914' MD. PU to 9877' MD to confirm hook not in retrieval slot. Did not see any overpull or tool face changes. RIH to 9929' MD. Work drill string attempting to locate retrieval slot. Pull up to 9900' MD. Slack off and tag @ 9917' MD. Pull up to 9875' MD. Slack off and tag @ 9917' MD. Maintain 1 OK down wt and wash down to 9920' MD. Page 62/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) M 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log StartDepth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB). 1/31/2016 1/31/2016 3.50 COMPZ2 FISH FISH T Pick up to 9840' MD and orient to 140° 9,920.0 9,830.0 10:30 14:00 R. RIH to 9930' MD and wash retrieval slot. No set down wt or overpull observed. Reorient and attempt to locate retrieval slot. Working pipe from 15°L to 65°L. Did not observe indications of locating slot. PU to 9875' MD. Slack off and tag up @ 9917' MD. Orient to 140°R. Slack off and wash retrieval slot. Reorient and attempt to locate retrieval slot, working pipe from 30°R to 125°L.No indications of retrieval slot observed. PU to 9830' MD. 1/31/2016 1/31/2016 1.25 COMPZ2 FISH FISH T Orient to 41'L. Slack off and attempt 9,830.0 9,838.0 14:00 15:15 to locate retrieval slot without circulating. No indications of slot. Start pumping and jet plugged. 170 gpm,3500 psi.Work pump on and off to unplug jet. Contnue to work pipe to locate retrieval slot. Tag up @ 9919' MD 3x. Pick up to 9910' MD and observed tool face shift to right, from 40°L to 20°L, 30°L to 15°L and 20°L to 9°L. Pull up and observe 20K overpull @ 9906' MD. Continue to pull up and observe 20K overpull @ 9900' MD. While pulling up tool face shifted to 30°R. PU to 9838' MD with no overpull. Stand back one stand DP. Blow down TD. 1/31/2016 1/31/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 9,838.0 9,838.0 15:15 15:30 1/31/2016 1/31/2016 0.50 COMPZ2 FISH TRIP T POOH from 9838' MD to 9648' MD 9,838.0 9,648.0 15:30 16:00 monitoring for swab and overpull. No swab or overpull observed. Fluid level dropping in BOPE as drill string is hoisted. 1/31/2016 1/31/2016 5.75 COMPZ2 FISH TRIP T POOH from 9648' MD to 290' MD. 9,648.0 290.0 16:00 21:45 1/31/2016 1/31/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 290.0 290.0 21:45 22:00 1/31/2016 1/31/2016 1.00 COMPZ2 FISH BHAH T Lay down BHA as per Baker fishing 290.0 0.0 22:00 23:00 hand. Lay down intensifier. Stand back 2 stds 4 3/4" DC's, Lay down MWD and bumper sub. Lay down retrieval tool. No fish. Calc disp=56.34 bbls Act disp=63 bbls 1/31/2016 1/31/2016 0.50 COMPZ2 FISH BHAH T Clean and clear rig floor. 0.0 0.0 23:00 23:30 1/31/2016 2/1/2016 0.50 COMPZ2 FISH SVRG T Service rig. Lube drawworks, TD and 0.0 0.0 23:30 00:00 traveling blocks. 2/1/2016 2/1/2016 0.75 COMPZ2 FISH BHAH T PJSM, M/U Baker box tap as per 0.0 237.0 00:00 00:45 Baker rep. 2/1/2016 2/1/2016 4.00 COMPZ2 FISH TRIP T RIH f/ 237' MD t/ 9784' MD filling pipe 237.0 9,784.0 00:45 04:45 every 20 stands. Actual displacement= 55.3 bbls, Calculated displacement=58.5 bbls. Page 63169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) y 2S-13 Rig: DOYON 141 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) 2/1/2016 2/1/2016 0.25 COMPZ2 FISH FISH T Break circ. Obtain SPR's and 9,784.0 9,784.0 04:45 05:00 parameters. PU 143K SO 90K Rot 115K 168 gpm, 450 psi. 20 rpm, 5K tq, SPR's @ 9784' MD TVD= 6215', MW=12.22 05:00 hours MP #1: 20 spm=200 psi, 30 spm=420 psi MP #2: 20 spm=220 psi, 30 spm=400 psi. 2/1/2016 2/1/2016 3.25 COMPZ2 FISH FISH T Wash down from 9784' MD to 9811' 9,784.0 9,920.0 05:00 08:15 MD. 168 gpm, 520 psi. Shut down pump, attempt to engage whip stock to 9919' MD (20 rpm, 5K tq). Slight down drag @ 9914' MD. PU to 9910' MD and slack off to 9921' MD. Did not observe any torque increase. PU to 9910' MD. Pump @ 84 gpm, 500 psi. Slack off without rotary to 9920' MD. Work box tap between 9910' MD and 9922' MD with rotary on/rotary off, pump on/pump off. Work two turns lefthand torque to box tap . Unable to engage fish. 2/1/2016 2/1/2016 0.25 COMPZ2 FISH TRIP T Consult with Drilling Engineer. 9,920.0 9,879.0 08:15 08:30 Decision made to POOH. POOH from 9920' MD to 9879' MD. Blow down TD 2/1/2016 2/1/2016 0.50 COMPZ2 FISH OWFF T Monitor well. Static 9,879.0 9,879.0 08:30 09:00 2/1/2016 2/1/2016 3.50 COMPZ2 FISH TRIP T POOH from 9879' MD to 237' MD. 9,879.0 237.0 09:00 12:30 Calc disp=59.04 bbls Act disp=64.79 bbls 2/1/2016 2/1/2016 0.25 COMPZ2 FISH OWFF T Monitor well. Static. 237.0 237.0 12:30 12:45 2/1/2016 2/1/2016 0.25 COMPZ2 FISH BHAH T Lay down box tap BHA as per Baker 237.0 0.0 12:45 13:00 fishing hand. Stand back 2 std's 4 3/4" DC's. Lay down pumo out sub and box tap. 2/1/2016 2/1/2016 0.50 COMPZ2 FISH BHAH T Clean and clear rig floor. 0.0 0.0 13:00 13:30 2/1/2016 2/1/2016 1.50 COMPZ2 FISH BHAH T PJSM-Make up bent retrieval tool BHA 0.0 290.0 13:30 15:00 as per Baker fishing hand. PU bent retrieval tool, 3 1/2" HWDP jt, bumper sub, jar, float sub, MWD, x-o, 4 3/4" DC's x6, x-o, intensifier, pump out sub, x-o. 2/1/2016 2/1/2016 0.25 COMPZ2 FISH TRIP T RIH to 1234' MD 290.0 1,234.0 15:00 15:15 2/1/2016 2/1/2016 0.25 COMPZ2 FISH DHEQ T Shallow test MWD. 200 gpm, 700 psi. 1,234.0 1,234.0 15:15 15:30 Blow down TD 2/1/2016 2/1/2016 3.50 COMPZ2 FISH TRIP T RIH from 1234' MD to 9838' MD. PU 1,234.0 9,838.0 15:30 19:00 140K SO 93K. PU 140K SO 94K w/pumps on. Calc disp=59.21 bbls Act disp=56.35 bbls Page 64/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 2/1/2016 2/1/2016 2.50 COMPZ2 FISH FISH T Wash down from 9838' MD to 9924' 9,838.0 9,831.0 19:00 21:30 MD oriented 60°R. Work pipe between 9924' MD and 9917' MD orienting to 43°L. Slack off 10K at 9920' MD. Pick up to 9981' MD. Observed 15K overpull. Slack off drillstring and orient to 150°R to wash retrieval slot. Wash slot from 9925' MD to 9928' MD.275 gpm, 2200 psi. Orient hook to 43°L. Set down 15K at 9920' MD. Weight abruptly fell off. Pick up drillstring to 9870' MD. Did not see any overpull at 9881' MD. Turn off pump and pull up to 9931' MD monitoring for swab. No swab and fluid level dropping in BOPE. 2/1/2016 2/2/2016 2.50 COMPZ2 FISH FISH T Slack off drill string to 9922' MD. Pick 9,831.0 9,915.0 21:30 00:00 up and orient to 150°R to wash slot. Wash down to 9925' MD with 25K. Orient to 43°L. Set down 20K at 9920' MD. Pick up drill string, did not see overpull. Work drill string between 9922' MD and 9906' MD. Set down 15K twice more at 9920' MD. No overpull observed while picking up drill string after setting down at 9920' MD. 2/2/2016 2/2/2016 2.75 COMPZ2 FISH FISH T PJSM; continue to fish whipstock. Try 9,915.0 9,838.0 00:00 02:45 numerous time to find bottom of slot, 275 gpm, 1800 psi. Pick up to 9983'& observe tool face shift to left with over pull, indicating hook dragging up split casing. Slack of to 9915' them pick up to 9890' & orient to 150° right. Slack off to 9921' setting 1 OK down. Reorient hook to 43° left. Work string f/ 9921'-9912'. Slack off to 9921' set 1 OK down. Pick up & observe 1 OK overpull @ 9916', continuing to pick up to 9838' without tool face changing & no overpull. (Decision made to TOH) 2/2/2016 2/2/2016 0.75 COMPZ2 FISH OWFF T Monitor well, observe gas bubbles 9,838.0 9,838.0 02:45 03:30 breaking out at surface. 2/2/2016 2/2/2016 0.75 COMPZ2 FISH CIRC T CBU at 300 gpm, 2000 psi, FO 46%. 9,838.0 9,838.0 03:30 04:15 2/2/2016 2/2/2016 0.50 COMPZ2 FISH OWFF T Monitor well, static. 9,838.0 9,838.0 04:15 04:45 2/2/2016 2/2/2016 6.50 COMPZ2 FISH TRIP T PJSM; TOH f/ 9838'-290' MD, 9,838.0 290.0 04:45 11:15 observed overpull at 8917' (stage collar), calculated fill 57.4, actual 62.6 bbls. 2/2/2016 2/2/2016 0.50 COMPZ2 FISH BHAH T PJSM; rack back 2 stands of collars & 290.0 0.0 11:15 11:45 pull BHA to floor w/ no fish. 2/2/2016 2/2/2016 2.00 COMPZ2 FISH WAIT T Clear & clean rig floor, perform derrick 0.0 0.0 11:45 13:45 inspection, & unload 4-1/2" liner from shed while waiting for a decision from town. 2/2/2016 2/2/2016 0.25 COMPZ2 FISH BHAH T Lay down Baker hook assembly. 0.0 0.0 13:45 14:00 2/2/2016 2/2/2016 0.50 COMPZ2 FISH BHAH T PJSM; mobilize BHA to rig floor. 0.0 0.0 14:00 14:30 Page 65/69 Report Printed: 2/29/2016 Ago "Ik Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 2/2/2016 2/2/2016 1.25 COMPZ2 FISH BHAH T PJSM; pick up clean out BHA per 0.0 286.0 14:30 15:45 Baker Rep. to 286' MD. 2/2/2016 2/2/2016 3.75 COMPZ2 FISH TRIP T PJSM; TIH f/ 286'-9834' MD, PU 286.0 9,834.0 15:45 19:30 142K, SO 90K, calculated displacement 59.5, actual 59.2 bbls. 2/2/2016 2/2/2016 1.25 COMPZ2 FISH WASH T Break circulation & wash down f/ 9,834.0 9,915.0 19:30 20:45 9834'-9918' two times at 200 gpm, 700 psi. Could not wash past 9918'. Rotate 40 rpm w/ same parameters to 9926' MD & stall out w/ 9K Tq. Shut off rotary & attempt to wash down working the pipe several times from 9915'-9926'@ 300 gpm, 1500 psi, FO 44%. SPR's @ 9905' MD TVD= 6228', MW=12.3+ 19:30 hours MP #1: 20 spm=120 psi, 30 spm=280 psi MP #2: 20 spm=130 psi, 30 spm=260 psi. 2/2/2016 2/2/2016 1.00 COMPZ2 FISH CIRC T Pump high-vis super sweep around @ 9,915.0 9,915.0 20:45 21:45 300 gpm, 1500 psi, FO 44%. Observe minimal increase in returns. 2/2/2016 2/2/2016 0.25 COMPZ2 FISH PMPO T PJSM; pump out of hole from 9915'- 9,915.0 9,834.0 21:45 22:00 9834' MD, 210 gpm, 800 psi, PU 150K. 2/2/2016 2/2/2016 0.75 COMPZ2 FISH CIRC T CBU @ 400 gpm, 2000 psi, FO 52 %. 9,834.0 9,834.0 22:00 22:45 2/2/2016 2/2/2016 0.50 COMPZ2 FISH OWFF T Monitor well, static. 9,834.0 9,834.0 22:45 23:15 2/2/2016 2/3/2016 0.75 COMPZ2 FISH PULD X PJSM; pull out of the hole laying down 9,834.0 9,361.0 23:15 00:00 4" DP f/ 9834'-9361- MD, PU 150K, calculated fill 2.7, actual 3.4 bbls. 2/3/2016 2/3/2016 5.75 COMPZ2 FISH PULD X PJSM; continue laying down 4" DP 9,361.0 286.0 00:00 05:45 while pulling out of the hole f/ 9361'- 286' MD. Calculated fill 60, actual 64.9 bbls. 2/3/2016 2/3/2016 0.25 COMPZ2 FISH OWFF X Monitor well, static. 286.0 286.0 05:45 06:00 2/3/2016 2/3/2016 1.75 COMPZ2 FISH BHAH X PJSM; lay down 6 drill collars & BHA 286.0 0.0 06:00 07:45 as per Baker Rep. 2/3/2016 2/3/2016 1.00 COMPZ2 FISH BHAH X PJSM; clear & clean rig floor. 0.0 0.0 07:45 08:45 2/3/2016 2/3/2016 0.75 COMPZ2 RPCOMP WWWH X PJSM; remove wear bushing & flush 0.0 0.0 08:45 09:30 stack. SIMOPS unload 4" DP from pipe shed. 2/3/2016 2/3/2016 1.00 COMPZ2 RPCOMP RURD X PJSM; mobilize casing tools & rig up 0.0 0.0 09:30 10:30 to run tubing. 2/3/2016 2/3/2016 0.50 COMPZ2 RPCOMP SVRG X PJSM; service rig. 0.0 0.0 10:30 11:00 Page 66169 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftK6) End Depth.(WEI) 2/3/2016 2/3/2016 11.25 COMPZ2 RPCOMP PUTB X PJSM; Make up suspension string 3.5" 0.0 9,773.0 11:00 22:15 WLEG, 3.5" tubing jt, 2.75" D nipple w/ RHC installed, 3.5" tubing jt, Baker 47D2 FHL retrievable packer (60K shear release), 4-1/2" 12.6 # L-80 IBTM tubing from 0-9773' MD. Calculated displacement 44.8, actual 40 bbls. Ran 334 joints of 4-1/2" tubing with no remakes or rejects. 2/3/2016 2/3/2016 0.50 COMPZ2 RPCOMP THGR X Make up tubing hanger & landing joint. 9,773.0 9,773.0 22:15 22:45 2/3/2016 2/3/2016 0.50 COMPZ2 RPCOMP RURD X PJSM; flush mud pumps & kill line w/ 9,773.0 9,773.0 22:45 23:15 fresh H2O. Blow down kill & choke lines. 2/3/2016 2/4/2016 0.75 COMPZ2 RPCOMP THGR X PJSM; land hanger, WLEG set at 9,773.0 9,801.0 23:15 00:00 9802' MD. PU 115K, SO 75K. RILDS. 2/4/2016 2/4/2016 0.75 COMPZ2 RPCOMP THGR X PJSM; continue RILDS. Test hanger 9,801.0 0.0 00:00 00:45 seals to 5000 psi for 10 minutes, witnessed good. 2/4/2016 2/4/2016 0.50 COMPZ2 RPCOMP RURD X PJSM; drop ball & rod, rig up to test 0.0 0.0 00:45 01:15 tubing & IA. 2/4/2016 2/4/2016 0.75 COMPZ2 RPCOMP PACK X PJSM; pressure up & test tubing to 0.0 0.0 01:15 02:00 3500 psi for 30 minutes, charted (packer pinned at 1680 psi & sets at 2500 psi). Bleed down tubing to 2000 psi & shut in. Attempt to pressure test IA to 3500 psi with no success. 2/4/2016 2/4/2016 2.00 COMPZ2 RPCOMP RGRP XT Trouble shoot surface test equipment. 0.0 0.0 02:00 04:00 Change out multiple pressure sensators & pressure sensor lines. 2/4/2016 2/4/2016 0.50 COMPZ2 RPCOMP SEQP XT Pressure test surface equipment & 0.0 0.0 04:00 04:30 test equipment, good. 2/4/2016 2/4/2016 1.50 COMPZ2 RPCOMP PRTS XT Attempt to test IA several more times 0.0 0.0 04:30 06:00 with no success. 2/4/2016 2/4/2016 2.00 COMPZ2 RPCOMP PRTS XT Pressure up tubing to 4200 psi 0.0 0.0 06:00 08:00 ( applying more pressure to the packer) holding for -10 minutes. Bleed pressure to 2000 psi on tubing. Retest surface equipment, good. Attempt to pressure test IA to 3500 psi, no success. Bleed pressure from IA & tubing. Pressure up IA to 1000 psi for 10 minutes, observing 100 psi loss. 2/4/2016 2/4/2016 8.50 COMPZ2 RPCOMP WAIT XT Wait on orders. SIMOPS rig down 0.0 0.0 08:00 16:30 MPD unit, clean brine residue from rig, remove Katch Kan, remove MPD lines, clean drip pans, & change out liners / swabs on #1 mud pump. Fire Drill CRT 75 sec @ 09:00 hrs. 2/4/2016 2/4/2016 0.50 COMPZ2 RPCOMP CIRC X PJSM; pump down IA & shear SOV 0.0 0.0 16:30 17:00 AT 3000 PSI. Pump 2 bbls through SOV at 2 bpm, 500 psi. 2/4/2016 2/4/2016 0.50 COMPZ2 RPCOMP RURD X Rig down circulating lines & lay down 0.0 0.0 17:00 17:30 landing joint. 2/4/2016 2/4/2016 0.50 COMPZ2 WHDBOP MPSP X PJSM; set BPV & test to 1000 psi for 0.0 0.0 17:30 18:00 1 10 minutes, charted. Rig down lines. Page 67/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation (ftKB) End Depth (ftKB) 2/4/2016 2/4/2016 2.50 COMPZ2 WHDBOP MPDA X PJSM, rig down MPD equipment from 0.0 0.0 18:00 20:30 BOPE. 2/4/2016 2/4/2016 0.50 COMPZ2 WHDBOP OTHR X PJSM; rig down scaffolding around 0.0 0.0 20:30 21:00 BOPE. 2/4/2016 2/4/2016 2.00 COMPZ2 WHDBOP NUND X PJSM; nipple down BOPE, remove 0.0 0.0 21:00 23:00 adapter spools. 2/4/2016 2/5/2016 1.00 COMPZ2 WHDBOP NUND X PJSM; nipple up tree adapter flange 0.0 0.0 23:00 00:00 per CIW Rep. 2/5/2016 2/5/2016 0.50 COMPZ2 WHDBOP NUND X PJSM; continue nipple up of adapter 0.0 0.0 00:00 00:30 flange. 2/5/2016 2/5/2016 0.50 COMPZ2 WHDBOP PRTS X Test SRL seals to 5000 psi for 10 0.0 0.0 00:30 01:00 minutes, witnessed good. 2/5/2016 2/5/2016 0.75 COMPZ2 WHDBOP PRTS X Test hanger seals to 250 psi for 5 min 0.0 0.0 01:00 01:45 & 5000 psi for 10 minutes, witnessed good. 2/5/2016 2/5/2016 0.75 COMPZ2 WHDBOP NUND X PJSM; nipple up CIW tree as per 0.0 0.0 01:45 02:30 Cameron Rep. 2/5/2016 2/5/2016 1.25 COMPZ2 WHDBOP OTHR X PJSM; scaffold crew set up scaffolding 0.0 0.0 02:30 03:45 around tree. 2/5/2016 2/5/2016 0.50 COMPZ2 WHDBOP NUND X Install pump in flange on tree & rig up 0.0 0.0 03:45 04:15 to test. 2/5/2016 2/5/2016 0.75 COMPZ2 WHDBOP PRTS X Pressure test tree to 250 / 5000 psi for 0.0 0.0 04:15 05:00 15 minutes, witnessed good. Remove test dart. 2/5/2016 2/5/2016 1.25 COMPZ2 WHDBOP FRZP X Rig up to freeze protect. SIMOPS 0.0 0.0 05:00 06:15 mobilize lubricator to rig floor. 2/5/2016 2/5/2016 2.00 COMPZ2 WHDBOP FRZP X PJSM; freeze protect well, pump 85 0.0 0.0 06:15 08:15 bbls of diesel down the IA taking returns from the tubing, 1.5 bpm, ICP 680 psi, FCP 1300 psi. 2/5/2016 2/5/2016 1.25 COMPZ2 WHDBOP FRZP X U-tube freeze protect, starting tubing 0.0 0.0 08:15 09:30 pressure 500 psi, ending tubing pressure 450 psi. SIMOPS Lay down 1 stand of drill collars & 30 joints of 4" DP. 2/5/2016 2/5/2016 1.00 COMPZ2 WHDBOP MPSP X PJSM; rig up & set Type H BPV as per 0.0 0.0 09:30 10:30 Cameron Rep. 2/5/2016 2/5/2016 1.00 COMPZ2 WHDBOP MPSP X PJSM; rig up & test BPV pumping 0.0 0.0 10:30 11:30 down the IA, test to 1000 psi for 10 minutes. Tubing pressure 0 psi, IA pressure 400 psi. 2/5/2016 2/5/2016 0.50 DEMOB MOVE RURD X PJSM; blow down & rig down freeze 0.0 0.0 11:30 12:00 protect lines. Spill Drill CRT 87 sec @ 11:45 hrs. 2/5/2016 2/5/2016 1.75 DEMOB MOVE RURD X PJSM; secure well, install gauges on 0.0 0.0 12:00 13:45 IA & tubing. SIMOPS rig down scaffolding. 2/5/2016 2/5/2016 4.50 DEMOB MOVE PULD X PJSM; lay down 204 joints of 4" DP 0.0 0.0 13:45 18:15 from derrick. 2/5/2016 2/5/2016 0.50 DEMOB MOVE RURD X Clean & clear rig floor. Lay down 0.0 0.0 18:15 18:45 mouse hole. 2/5/2016 2/5/2016 1.25 DEMOB MOVE SLPC X PJSM; slip & cut 130' of drill line. 0.0 0.0 18:45 20:00 2/5/2016 2/5/2016 0.50 DEMOB MOVE SVRG X PJSM; service rig. 0.0 0.0 20:00 20:30 2/5/2016 2/5/2016 2.00 DEMOB MOVE RURD X PJSM; change out saver sub f/ XT39 0.0 0.0 20:30 22:30 to 4-1/2 IF. Page 68/69 Report Printed: 2/29/2016 Operations Summary (with Timelog Depths) 2S-13 Rig: DOYON 141 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) 2/5/2016 2/6/2016 1.50 DEMOB MOVE RURD X PJSM; clean cellar & prep for rig 0.0 0.0 22:30 00:00 move. 2/6/2016 2/6/2016 6.00 DEMOB MOVE RURD X PJSM; continue cleaning around the 0.0 0.0 00:00 06:00 rig. Prep for rig move. 2/6/2016 2/6/2016 6.00 DEMOB MOVE RURD X PJSM; blow down steam & water 0.0 0.0 06:00 12:00 lines. Unhook interconnects between modules. Slide skate ramp to pipe shed. Prep for trucks to hook up to modules. Rig Release at 12:00 hrs. Page 69/69 Report Printed: 2/29/2016 P70 2/5-157- Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Thursday, March 17, 2016 9:00 AM To: Loepp, Victoria T (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: KRU 2S-13 PTD 215-152 Sundry 316-073: Operations Shutdown Follow Up Flag: Follow up Flag Status: Flagged OK, thanks, looks like Ann sent over the 1-404 on 3/3/16. From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, March 17, 2016 8:47 AM To: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: [EXTERNAL]KRU 2S-13 PTD 215-152 Sundry 316-073: Operations Shutdown Scott, A 10-404 including a summary of daily well operations and a copy of all logs run in the well is required at this time. Well operations must resume within 12 months or the operator must proceed to suspend or abandon the well. When you decide on a plan forward either a 10-403 to resume operations under the original PTD must be filed or a new PTD if the course of work varies from the original PTD.(20 AAC 25.072). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a)alaska.gov 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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Thursday, March 17, 2016 8:35 AM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) Subject: 2S-13 PTD 215-152 Sundry 316-073 Victoria The asset has decided not to return to complete 2S-13 until October/November of 2016 (last well of current 2S program). We ran numerous downhole video logs since the rig left and found that the well is not salvageable in its current state (the whipstock cannot be fished due to hole collapse, the formation has collapsed large rocks on top of the whipstock inside the casing). The plan when we return is to pump cement to abandon the laterals, then either: Cut & pull the 7-5/8" casing, whipstock out of the 10-3/4" liner, run a 7-5/8" liner & tieback, drill the laterals as the original plan Or Whipstock out of the 7-5/8" casing & redrill the upper lateral, completing as a single lateral. I am looking into an option to attempt to intersect the lower lateral that is currently lined in hope that injection could be achieved into it, this of course would be discussed with you if it looks possible. The current sundry 316-073 is an operational shut down, is there any other paperwork we need to turn in, other than an updated or new PTD once the plan forward is decided? Thanks Scott Schlumberger Customer: ConocoPhillios Alaska Well No: 2S-131_1 Job#: 14AKA0060 Drilling & Measurements MWD/LWD Log Product Delivery Dispatched To: Date Dispatched: oil 5 -)52---, ,,,76 6 q q 4C Transmittal #: 28MAR16-SP02 AOGCC: Makana Bender 28 -Mar -15 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E -Delivery Date Color Log Prints: 1 Contents on CD N/A VISION*Service MicroScope Resistivity x x LAS Digital Data N/A Contents on CD N/A Directional Data N/A Contents on CD N/A As -Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS Graphics: pdf x x Please sign and email a copy to: Please sign and email a copy to: Tom. Osterkamp(a)conocophill ips.com AlaskaPTSPrintCenter(o)slb.com Tom Osterkamp Attn: Stephanie Pacillo 907- 3-4795 Ll Received By: F.I( w FEB 24 2016) Schlumhepgep°Gcc Customer: ConocoPhillips Alaska Well No: 2S -13L1 Job#: 14A KA0060 Drilling & Measurements MWD/LWD Log Product Delivery Dispatched To: Date Dispatched: Dispatched By: 215152 26 849 Transmittal #: 24FEB16-SP02 DATA LOGGED 3i%/201f, f1 K.BENDER AOGCC: Makana Bender 24 -Feb -16 Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E -Delivery Date Color Log Prints: 6 Contents on CD N/A VISION*Service 2" MD 2' TVD x x x x x _ VISION*Service x x VISION*Service 2" TVDSS 5" MD VISION*Service x VISION*Service 5' TVD 5' TVDSS x x x _ VISION*Service 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 x x Graphics: pdf/tiff Surveys: pdf / txt Please sign and email a copy to: Please sign and email a copy to: Richard. E.Elgarico(a)conocophillips.com Alas kaPTSPrintCenter(a)sIb.com Ricky Elgarico Attn: Stephanie Pacillo 907-265-6580 ✓�..k�� Received By: v 215152 C OV F. D 26849 FEB 2 4 2010 FINAL NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S -13L1 2S -13L1 Definitive Survey Report 04 February, 2016 NAD 27 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: We112S-13 Project: Kuparuk River Unit TVD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyon 141) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: Rig: 2S-131-1 Database: OAKEDMP2 'roject Kuparuk River Unit, North Slope Alaska, United States flap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point flap Zone: Alaska Zone 04 Using geodetic scale factor Well 2S-13 Well Position +N/ -S 0.00 usft Northing: 5,929,948.80 usfl Latitude: 70° 13' 11.188 N Vertical +E/ -W 0.00 usft Easting: 480,898.10 usfl Longitude: 150° 9' 14.766 W Position Uncertainty 0.00 usft Wellhead Elevation: 119.40 usfl Ground Level: 119.80usft Wellbore 2S-131-1 DLS Section (usft) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (usft) (usft) (ft) (ft) (nT) (ft) Survey Tool Name BGGM2015 12/15/2015 18.44 80.86 57,486 Design Rig: 2S-1311 0.00 5,929,948.80 480,898.10 Audit Notes: 0.00 UNDEFINED 82.68 0.03 287.05 Version: 1.0 Phase: ACTUAL Tie On Depth: 9,906.40 5,929,948.80 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 0.10 201.50 (usft) (usft) (usft) (°) -0.07 5,929,948.74 27.50 0.00 0.00 15.00 266.90 Survey Program Date 204.98 266.90 119.60 From To 5,929,948.27 480,897.82 0.48 (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 82.68 1,283.58 2S-13PB1 Srvy #1 - Gyro on Battery (2S GYD-GC-SS Gyrodata gyro single shots 12/1/2015 10:2 1,304.79 2,775.54 2S-13PB1 Srvy #2 - GMAG (2S-13PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/1/2015 10:2 2,868.01 9,265.30 2S-13PB1 Srvy #3 - GMAG (2S-13PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/7/2015 8:3 9,288.24 9,288.24 2S-13PB1 Srvy#4 - Inc+trend (2S-13PB1 INC+TREND Inclinometer + known azi trend 12/16/2015 9: 9,338.00 9,906.40 2S-13 Srvy #1 - GMAG (2S-13) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/20/2015 11 9,942.83 10,131.87 2S-131-1 Srvy #1 - Inc+Trend (2S-131-1) INC+TREND Inclinometer + known azi trend 1/16/2016 8:4 10,161.07 16,785.89 2S-131-1 Srvy #2 - GMAG (2S-131-1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/18/2016 8:5 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 27.50 0.00 0.00 27.50 -119.80 0.00 0.00 5,929,948.80 480,898.10 0.00 0.00 UNDEFINED 82.68 0.03 287.05 82.68 -64.62 0.00 -0.01 5,929,948.80 480,898.09 0.05 0.00 GYD-GC-SS (1) 174.86 0.10 201.50 174.86 27.56 -0.06 -0.07 5,929,948.74 480,898.03 0.11 -0.08 GYD-GC-SS (1) 266.90 0.54 204.98 266.90 119.60 -0.53 -0.28 5,929,948.27 480,897.82 0.48 -0.59 GYD-GC-SS (1) 358.92 2.63 196.47 358.88 211.58 -2.95 -1.06 5,929,945.85 480,897.03 2.28 -3.12 GYD-GC-SS (1) 450.55 4.08 197.58 450.35 303.05 -8.07 -2.64 5,929,940.73 480,895.44 1.58 -8.48 GYD-GC-SS (1) 542.44 4.84 198.23 541.96 394.66 -14.87 -4.84 5,929,933.94 480,893.22 0.83 -15.62 GYD-GC-SS (1) 634.35 5.99 202.27 633.46 486.16 -22.99 -7.87 5,929,925.83 480,890.17 1.32 -24.25 GYD-GC-SS (1) 726.00 6.53 203.78 724.56 577.26 -32.19 -11.79 5,929,916.65 480,886.23 0.62 -34.14 GYD-GC-SS (1) 214/2016 8:38: LOAM Page 2 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyon 141) Site: Kuparuk 2S Pad MD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyonl41) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: Rig: 2S -13L1 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 817.94 8.48 201.86 815.71 668.41 -43.26 -16.42 5,929,905.58 480,881.57 2.14 -46.04 GYD-GC-SS (1) 910.56 9.80 205.54 907.15 759.85 -56.71 -22.36 5,929,892.15 480,875.60 1.56 -60.57 GYD-GC-SS (1) 1,003.86 11.08 208.23 998.91 851.61 -71.78 -30.02 5,929,877.11 480,867.90 1.47 -77.10 GYD-GC-SS (1) 1,096.09 12.93 209.29 1,089.12 941.82 -88.59 -39.27 5,929,860.32 480,858.61 2.02 -95.73 GYD-GC-SS(1) 1,188.56 15.38 208.11 1,178.77 1,031.47 -108.43 -50.11 5,929,840.51 480,847.73 2.67 -117.70 GYD-GC-SS(1) 1,283.58 19.22 206.89 1,269.48 1,122.18 -133.50 -63.12 5,929,815.47 480,834.65 4.06 -145.29 GYD-GC-SS (1) 1,304.79 20.60 207.96 1,289.42 1,142.12 -139.91 -66.45 5,929,809.07 480,831.30 6.73 -152.34 MWD+IFR-AK-CAZ-SC (2) 1,396.67 21.80 208.96 1,375.08 1,227.78 -169.12 -82.29 5,929,779.91 480,815.39 1.36 -184.65 MWD+IFR-AK-CAZ-SC (2) 1,491.21 25.56 213.09 1,461.65 1,314.35 -201.58 -101.93 5,929,747.50 480,795.67 4.34 -221.09 MWD+IFR-AK-CAZ-SC (2) 1,585.16 27.45 217.68 1,545.73 1,398.43 -235.70 -126.24 5,929,713.44 480,771.28 2.97 -260.34 MWD+IFR-AK-CAZ-SC (2) 1,677.93 29.30 221.23 1,627.36 1,480.06 -269.70 -154.27 5,929,679.51 480,743.16 2.70 -300.44 MWD+IFR-AK-CAZ-SC (2) 1,771.75 30.21 225.91 1,708.82 1,561.52 -303.40 -186.36 5,929,645.91 480,710.99 2.66 -341.29 MWD+IFR-AK-CAZ-SC (2) 1,863.74 31.06 226.45 1,787.97 1,640.67 -335.85 -220.19 5,929,613.54 480,677.09 0.97 -381.40 MWD+IFR-AK-CAZ-SC (2) 1,956.72 32.83 229.72 1,866.87 1,719.57 -368.68 -256.80 5,929,580.81 480,640.39 2.66 -422.58 MWD+IFR-AK-CAZ-SC (2) 2,050.37 33.68 233.62 1,945.19 1,797.89 -400.50 -297.08 5,929,549.10 480,600.03 2.46 -463.74 MWD+IFR-AK-CAZ-SC (2) 2,143.17 34.26 235.37 2,022.15 1,874.85 -430.60 -339.29 5,929,519.10 480,557.75 1.23 -503.75 MWD+IFR-AK-CAZ-SC (2) 2,237.57 35.48 238.69 2,099.61 1,952.31 -459.94 -384.57 5,929,489.88 480,512.41 2.39 -543.80 MWD+IFR-AK-CAZ-SC (2) 2,330.47 38.90 240.04 2,173.61 2,026.31 -488.53 -432.89 5,929,461.42 480,464.02 3.78 -583.92 MWD+IFR-AK-CAZ-SC (2) 2,423.89 39.45 242.06 2,246.03 2,098.73 -517.09 -484.53 5,929,432.99 480,412.32 1.49 -624.87 MWD+IFR-AK-CAZ-SC (2) 2,515.04 40.79 245.52 2,315.74 2,168.44 -543.00 -537.21 5,929,407.22 480,359.57 2.85 -663.54 MWD+IFR-AK-CAZ-SC (2) 2,609.16 42.70 247.70 2,385.97 2,238.67 -567.85 -594.73 5,929,382.51 480,301.99 2.55 -702.43 MWD+IFR-AK-CAZ-SC (2) 2,701.86 43.56 247.40 2,453.62 2,306.32 -592.05 -653.30 5,929,358.46 480,243.37 0.95 -740.96 MWD+IFR-AK-CAZ-SC (2) 2,775.54 45.32 247.46 2,506.22 2,358.92 -611.85 -700.94 5,929,338.79 480,195.69 2.39 -772.42 MWD+IFR-AK-CAZ-SC (2) 2,835.00 46.00 247.45 2,547.78 2,400.48 -628.16 -740.21 5,929,322.58 480,156.38 1.14 -798.33 NOT an Actual Survey ) 13-3/8" x 16" 2,868.01 46.37 247.44 2,570.64 2,423.34 -637.29 -762.21 5,929,313.50 480,134.36 1.14 -812.85 MWD+IFR-AK-CAZ-SC (3) 2,961.88 45.93 246.36 2,635.67 2,488.37 -663.85 -824.47 5,929,287.11 480,072.03 0.95 -854.62 MWD+IFR-AK-CAZ-SC (3) 3,053.24 45.12 245.87 2,699.67 2,552.37 -690.24 -884.08 5,929,260.87 480,012.36 0.97 -895.54 MWD+IFR-AK-CAZ-SC (3) 3,145.12 45.68 246.79 2,764.19 2,616.89 -716.50 -944.00 5,929,234.76 479,952.39 0.94 -936.41 MWD+IFR-AK-CAZ-SC (3) 3,237.98 47.31 247.54 2,828.11 2,680.81 -742.63 -1,006.07 5,929,208.79 479,890.25 1.85 -977.72 MWD+IFR-AK-CAZ-SC (3) 3,332.72 50.46 248.03 2,890.40 2,743.10 -769.61 -1,072.14 5,929,181.98 479,824.12 3.35 -1,020.88 MWD+IFR-AK-CAZ-SC (3) 3,425.65 51.28 247.93 2,949.05 2,801.75 -796.64 -1,138.97 5,929,155.13 479,757.23 0.89 -1,064.28 MWD+IFR-AK-CAZ-SC (3) 3,518.99 55.39 247.67 3,004.77 2,857.47 -824.93 -1,208.28 5,929,127.02 479,687.86 4.41 -1,109.54 MWD+IFR-AK-CAZ-SC (3) 3,609.42 56.46 248.04 3,055.44 2,908.14 -853.16 -1,277.65 5,929,098.96 479,618.42 1.23 -1,154.77 MWD+IFR-AK-CAZ-SC (3) 3,703.27 57.86 248.01 3,106.33 2,959.03 -882.67 -1,350.77 5,929,069.64 479,545.23 1.49 -1,202.19 MWD+IFR-AK-CAZ-SC (3) 3,795.35 58.60 248.24 3,154.81 3,007.51 -911.83 -1,423.42 5,929,040.66 479,472.52 0.83 -1,249.17 MWD+IFR-AK-CAZ-SC (3) 3,888.69 62.00 248.65 3,201.05 3,053.75 -941.61 -1,498.82 5,929,011.08 479,397.05 3.66 -1,297.45 MWD+IFR-AK-CAZ-SC (3) 3,983.02 62.42 248.93 3,245.03 3,097.73 -971.80 -1,576.62 5,928,981.09 479,319.19 0.52 -1,346.75 MWD+IFR-AK-CAZ-SC (3) 4,075.27 61.97 248.44 3,288.06 3,140.76 -1,001.46 -1,652.63 5,928,951.62 479,243.10 0.68 -1,395.07 MWD+IFR-AK-CAZ-SC (3) 4,168.33 61.01 250.91 3,332.49 3,185.19 -1,029.87 -1,729.30 5,928,923.41 479,166.37 2.55 -1,442.35 MWD+IFR-AK-CAZ-SC (3) 2/4/2016 8:38:10AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well2S-13 Project: Kuparuk River Unit TVD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyon 14 1) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: Rig: 2S -13L1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NAS +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,262.19 60.59 251.46 3,378.28 3,230.98 -1,056.29 -1,806.86 5,928,897.19 479,088.75 0.68 -1,487.95 MWD+IFR-AK-CAZ-SC (3) 4,356.57 60.80 251.48 3,424.47 3,277.17 -1,082.45 -1,884.89 5,928,871.23 479,010.66 0.22 -1,533.41 MWD+IFR-AK-CAZ-SC (3) 4,449.98 61.03 251.32 3,469.88 3,322.58 -1,108.49 -1,962.26 5,928,845.39 478,933.24 0.29 -1,578.59 MWD+IFR-AK-CAZ-SC (3) 4,544.76 61.00 251.15 3,515.81 3,368.51 -1,135.16 -2,040.76 5,928,818.92 478,854.68 0.16 -1,624.67 MWD+IFR-AK-CAZ-SC (3) 4,638.59 61.06 250.63 3,561.26 3,413.96 -1,162.03 -2,118.33 5,928,792.25 478,777.05 0.49 -1,670.70 MWD+IFR-AK-CAZ-SC (3) 4,732.01 60.86 249.57 3,606.61 3,459.31 -1,189.83 -2,195.12 5,928,764.65 478,700.19 1.01 -1,717.43 MWD+IFR-AK-CAZ-SC (3) 4,826.27 60.79 250.20 3,652.56 3,505.26 -1,218.13 -2,272.40 5,928,736.54 478,622.85 0.59 -1,764.77 MWD+IFR-AK-CAZ-SC (3) 4,916.93 61.06 250.33 3,696.61 3,549.31 -1,244.89 -2,346.99 5,928,709.98 478,548.20 0.32 -1,809.92 MWD+IFR-AK-CAZ-SC (3) 5,010.28 61.10 250.12 3,741.76 3,594.46 -1,272.53 -2,423.88 5,928,682.53 478,471.25 0.20 -1,856.52 MWD+IFR-AK-CAZ-SC (3) 5,102.78 60.72 250.05 3,786.73 3,639.43 -1,300.07 -2,499.87 5,928,655.19 478,395.19 0.42 -1,902.78 MWD+IFR-AK-CAZ-SC (3) 5,195.28 60.66 249.61 3,832.01 3,684.71 -1,327.88 -2,575.59 5,928,627.58 478,319.42 0.42 -1,949.24 MWD+IFR-AK-CAZ-SC (3) 5,289.37 60.74 250.17 3,878.06 3,730.76 -1,356.09 -2,652.64 5,928,599.56 478,242.30 0.53 -1,996.44 MWD+IFR-AK-CAZ-SC (3) 5,381.75 60.67 250.09 3,923.26 3,775.96 -1,383.47 -2,728.41 5,928,572.37 478,166.47 0.11 -2,042.50 MWD+IFR-AK-CAZ-SC (3) 5,473.45 60.63 250.62 3,968.20 3,820.90 -1,410.35 -2,803.68 5,928,545.70 478,091.14 0.51 -2,087.94 MWD+IFR-AK-CAZ-SC (3) 5,567.92 60.66 250.87 4,014.51 3,867.21 -1,437.50 -2,881.42 5,928,518.74 478,013.34 0.23 -2,134.28 MWD+IFR-AK-CAZ-SC (3) 5,661.68 60.74 251.47 4,060.40 3,913.10 -1,463.89 -2,958.80 5,928,492.55 477,935.89 0.56 -2,179.80 MWD+IFR-AK-CAZ-SC (3) 5,757.08 60.53 251.29 4,107.18 3,959.88 -1,490.44 -3,037.60 5,928,466.21 477,857.05 0.27 -2,225.84 MWD+IFR-AK-CAZ-SC (3) 5,850.57 60.90 250.91 4,152.91 4,005.61 -1,516.85 -3,114.74 5,928,439.99 477,779.84 0.53 -2,271.32 MWD+IFR-AK-CAZ-SC (3) 5,943.99 60.44 248.47 4,198.68 4,051.38 -1,545.11 -3,191.11 5,928,411.92 477,703.40 2.33 -2,318.38 MWD+IFR-AK-CAZ-SC (3) 6,037.22 60.79 249.67 4,244.43 4,097.13 -1,574.13 -3,266.99 5,928,383.10 477,627.46 1.18 -2,366.05 MWD+IFR-AK-CAZ-SC (3) 6,129.53 60.59 248.07 4,289.62 4,142.32 -1,603.14 -3,342.06 5,928,354.28 477,552.32 1.53 -2,413.51 MWD+IFR-AK-CAZ-SC (3) 6,222.41 60.88 248.38 4,335.02 4,187.72 -1,633.20 -3,417.31 5,928,324.42 477,477.01 0.43 -2,462.01 MWD+IFR-AK-CAZ-SC (3) 6,316.01 60.70 248.15 4,380.70 4,233.40 -1,663.45 -3,493.20 5,928,294.36 477,401.05 0.29 -2,510.88 MWD+IFR-AK-CAZ-SC (3) 6,409.32 60.61 250.20 4,426.43 4,279.13 -1,692.37 -3,569.22 5,928,265.64 477,324.97 1.92 -2,558.48 MWD+IFR-AK-CAZ-SC (3) 6,502.38 58.16 250.88 4,473.82 4,326.52 -1,719.05 -3,644.72 5,928,239.15 477,249.40 2.71 -2,603.80 MWD+IFR-AK-CAZ-SC (3) 6,598.21 58.41 253.51 4,524.20 4,376.90 -1,743.97 -3,722.33 5,928,214.43 477,171.74 2.35 -2,647.96 MWD+IFR-AK-CAZ-SC (3) 6,689.12 58.87 256.33 4,571.52 4,424.22 -1,764.16 -3,797.27 5,928,194.43 477,096.75 2.70 -2,686.86 MWD+IFR-AK-CAZ-SC (3) 6,783.66 59.28 258.89 4,620.11 4,472.81 -1,781.56 -3,876.47 5,928,177.24 477,017.52 2.36 -2,724.16 MWD+IFR-AK-CAZ-SC (3) 6,878.78 58.49 262.31 4,669.28 4,521.98 -1,794.87 -3,956.79 5,928,164.13 476,937.17 3.19 -2,757.80 MWD+IFR-AK-CAZ-SC (3) 6,974.96 57.42 266.31 4,720.32 4,573.02 -1,802.96 -4,037.89 5,928,156.24 476,856.06 3.70 -2,786.61 MWD+IFR-AK-CAZ-SC (3) 7,068.26 56.96 269.00 4,770.88 4,623.58 -1,806.17 -4,116.23 5,928,153.23 476,777.72 2.47 -2,809.99 MWD+IFR-AK-CAZ-SC (3) 7,162.25 56.44 272.56 4,822.50 4,675.20 -1,805.11 -4,194.76 5,928,154.49 476,699.21 3.21 -2,829.29 MWD+IFR-AK-CAZ-SC (3) 7,254.28 55.85 275.87 4,873.78 4,726.48 -1,799.50 -4,270.96 5,928,160.29 476,623.02 3.05 -2,843.59 MWD+IFR-AK-CAZ-SC (3) 7,345.72 55.88 278.70 4,925.10 4,777.80 -1,789.91 -4,346.02 5,928,170.07 476,547.99 2.56 -2,853.75 MWD+IFR-AK-CAZ-SC (3) 7,441.05 55.03 280.27 4,979.15 4,831.85 -1,776.97 -4,423.47 5,928,183.20 476,470.59 1.62 -2,861.30 MWD+IFR-AK-CAZ-SC (3) 7,533.25 52.88 282.42 5,033.41 4,886.11 -1,762.33 -4,496.55 5,928,198.03 476,397.55 3.00 -2,866.07 MWD+IFR-AK-CAZ-SC (3) 7,625.94 51.57 285.38 5,090.19 4,942.89 -1,744.75 -4,567.66 5,928,215.79 476,326.49 2.89 -2,867.50 MWD+IFR-AK-CAZ-SC (3) 7,719.41 52.60 289.78 5,147.65 5,000.35 -1,722.47 -4,637.92 5,928,238.24 476,256.30 3.87 -2,864.16 MWD+IFR-AK-CAZ-SC (3) 7,811.71 53.12 292.34 5,203.38 5,056.08 -1,696.03 -4,706.57 5,928,264.86 476,187.72 2.28 -2,856.39 MWD+IFR-AK-CAZ-SC (3) 7,903.79 54.45 296.32 5,257.79 5,110.49 -1,665.41 -4,774.23 5,928,295.64 476,120.15 3.77 -2,844.33 MWD+IFR-AK-CAZ-SC (3) 2/4/2016 8:38:10AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2S Pad MD Reference: Well: 2S-13 North Reference: Wellbore: 2S-131-1 Survey Calculation Method: Design: Rig: 2S-131-1 Database: Survey MD Inc Azi TVD TVDSS +N/ -S (usft) 0 (') (usft) (usft) (usft) 7,995.87 55.41 299.86 5,310.71 5,163.41 -1,629.92 8,088.89 55.39 303.20 5,363.54 5,216.24 -1,589.89 8,181.47 55.44 306.84 5,416.11 5,268.81 -1,546.17 8,274.49 55.80 309.81 5,468.64 5,321.34 -1,498.56 8,368.67 57.04 309.97 5,520.73 5,373.43 -1,448.24 8,461.71 56.71 309.14 5,571.57 5,424.27 -1,398.62 8,553.04 55.84 310.08 5,622.28 5,474.98 -1,350.20 8,647.67 55.94 311.96 5,675.35 5,528.05 8,741.37 57.18 315.11 5,726.99 5,579.69 8,835.77 58.31 317.50 5,777.38 5,630.08 8,928.24 58.65 321.18 5,825.73 5,678.43 9,021.69 59.42 323.94 5,873.82 5,726.52 9,114.60 60.50 327.49 5,920.34 5,773.04 9,207.51 61.42 330.83 5,965.45 5,818.15 9,265.30 61.60 332.19 5,993.02 5,845.72 9,288.24 61.68 332.70 6,003.92 5,856.62 9,338.00 61.83 333.34 6,027.47 5,880.17 9,399.61 61.71 338.01 6,056.62 5,909.32 9,441.73 62.23 340.89 6,076.42 5,929.12 9,536.34 64.93 344.27 6,118.52 5,971.22 9,628.18 66.40 347.72 6,156.37 6,009.07 9,720.92 69.66 349.31 6,191.07 6,043.77 9,814.38 72.21 349.35 6,221.59 6,074.29 9,906.40 74.94 350.60 6,247.61 6,100.31 9,929.00 76.05 349.23 6,253.27 6,105.97 7-518" x 9-7/8" - Bottom of Window 9,942.83 76.74 348.40 6,256.52 6,109.22 10,037.13 87.36 349.00 6,269.55 6,122.25 10,131.87 92.06 353.76 6,270.03 6,122.73 10,161.07 90.45 354.51 6,269.39 6,122.09 10,255.59 90.00 354.23 6,269.02 6,121.72 10,351.16 88.84 354.20 6,269.98 6,122.68 10,445.97 88.53 354.39 6,272.16 6,124.86 10,540.98 89.46 354.41 6,273.82 6,126.52 10,635.74 90.35 357.30 6,273.98 6,126.68 10,700.70 90.69 357.59 6,273.39 6,126.09 10,731.14 90.84 0.12 6,272.99 6,125.69 10,824.23 90.48 2.06 6,271.91 6,124.61 10,919.63 90.62 3.55 6,271.00 6,123.70 11,013.21 91.14 3.98 6,269.56 6,122.26 -1,298.78 -1,244.92 -1,187.20 -1,127.42 -1,063.80 -997.35 Map +E/ -W Northing (usft) (ft) -4,840.69 5,928,331.29 -4,905.94 5,928,371.49 -4,968.34 5,928,415.37 -5,028.55 5,928,463.12 -5,088.76 5,928,513.58 -5,148.83 5,928,563.35 -5,207.35 5,928,611.92 -5,266.46 5,928,663.48 -5,323.12 5,928,717.48 -5,378.26 5,928,775.33 -5,429.60 5,928,835.24 -5,478.30 5,928,898.97 -997.35 -5,523.58 5,928,965.53 -927.62 -5,565.21 5,929,035.36 -882.98 -5,589.43 5,929,080.05 -865.08 -5,598.77 5,929,097.97 -826.02 -5,618.66 5,929,137.08 -776.58 -5,641.01 5,929,186.58 -741.77 -5,654.06 5,929,221.42 -660.94 -5,679.39 5,929,302.30 -579.76 -5,699.62 5,929,383.52 -495.49 -5,716.73 5,929,467.83 -408.69 -5,733.08 5,929,554.66 -321.79 -5,748.44 5,929,641.60 -300.24 -5,752.27 5,929,663.14 -287.06 -5,754.88 5,929,676.34 -195.60 -5,773.15 5,929,767.83 -101.99 -5,787.34 5,929,861.47 -72.95 -5,790.32 5,929,890.51 21.11 -5,799.59 5,929,984.59 116.19 -5,809.22 5,930,079.68 210.50 -5,818.65 5,930,174.01 305.05 -5,827.92 5,930,268.56 399.55 -5,834.76 5,930,363.07 464.44 -5,837.66 5,930,427.96 494.87 -5,838.27 5,930,458.39 587.93 -5,836.50 5,930,551.44 683.21 -5,831.83 5,930,646.70 776.58 -5,825.69 5,930,740.04 Well 2S-13 Actual: 119.8+27.5 @ 147.30usft (Doyonl41) Actual: 119.8+27.5 @ 147.30usft (Doyonl41) True Minimum Curvature OAKEDMP2 Map Vertical Easting DLS Section (ft) (°/100') (ft) Survey Tool Name 476,053.78 3.31 -2,827.25 MWD+IFR-AK-CAZ-SC (3) 475,988.64 2.96 -2,805.47 MWD+IFR-AK-CAZ-SC (3) 475,926.36 3.24 -2,779.38 MWD+IFR-AK-CAZ-SC (3) 475,866.27 2.66 -2,748.99 MWD+IFR-AK-CAZ-SC (3) 475,806.20 1.32 -2,715.96 MWD+IFR-AK-CAZ-SC (3) 475,746.26 0.83 -2,683.58 MWD+IFR-AK-CAZ-SC (3) 475,687.87 1.28 -2,651.95 MWD+IFR-AK-CAZ-SC (3) 475,628.89 1.65 -2,617.58 MWD+IFR-AK-CAZ-SC (3) 475,572.38 3.10 -2,580.23 MWD+IFR-AK-CAZ-SC (3) 475,517.39 2.45 -2,538.74 MWD+IFR-AK-CAZ-SC (3) 475,466.21 3.41 -2,494.29 MWD+IFR-AK-CAZ-SC (3) 475,417.67 2.66 -2,445.44 MWD+IFR-AK-CAZ-SC (3) 475,372.56 3.51 -2,392.98 MWD+IFR-AK-CAZ-SC (3) 475,331.12 3.30 -2,336.39 MWD+IFR-AK-CAZ-SC (3) 475,307.01 2.09 -2,299.55 MWD+IFR-AK-CAZ-SC (3) 475,297.71 1.99 -2,284.68 INC+TREND (4) 475,277.93 1.17 -2,252.09 MWD+IFR-AK-CAZ-SC (5) 475,255.70 6.68 -2,210.12 MWD+IFR-AK-CAZ-SC (5) 475,242.75 6.16 -2,179.87 MWD+IFR-AK-CAZ-SC (5) 475,217.62 4.29 -2,108.35 MWD+IFR-AK-CAZ-SC (5) 475,197.60 3.78 -2,035.18 MWD+IFR-AK-CAZ-SC (5) 475,180.71 3.86 -1,958.21 MWD+IFR-AK-CAZ-SC (5) 475,164.57 2.73 -1,878.60 MWD+IFR-AK-CAZ-SC (5) 475,149.44 3.24 -1,798.63 MWD+IFR-AK-CAZ-SC (5) 475,145.66 7.66 -1,778.8 NOT an Actual Survey 475,143.09 7.66 -1,766.75 INC+TREND (6) 475,125.05 11.28 -1,683.14 INC+TREND (6) 475,111.10 7.06 -1,596.39 INC+TREND (6) 475,108.19 6.08 -1,569.11 MWD+IFR-AK-CAZ-SC (7) 475,099.16 0.56 -1,480.65 MWD+IFR-AK-CAZ-SC (7) 475,089.77 1.21 -1,391.31 MWD+IFR-AK-CAZ-SC (7) 475,080.58 0.38 -1,302.64 MWD+IFR-AK-CAZ-SC (7) 475,071.56 0.98 -1,213.72 MWD+IFR-AK-CAZ-SC (7) 475,064.95 3.19 -1,124.22 MWD+IFR-AK-CAZ-SC (7) 475,062.22 0.69 -1,062.28 MWD+IFR-AK-CAZ-SC (7) 475,061.68 8.33 -1,033.05 MWD+IFR-AK-CAZ-SC (7) 475,063.69 2.12 -942.70 MWD+IFR-AK-CAZ-SC (7) 475,068.60 1.57 -849.46 MWD+IFR-AK-CAZ-SC (7) 475,074.98 0.72 -757.68 MWD+IFR-AK-CAZ-SC (7) 2/4/2016 8:38:10AM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Project: Kuparuk River Unit 15.91 6,258.25 Site: Kuparuk 2S Pad -5,576.58 5,932,039.13 475,327.35 Well: 2S-13 91.07 16.78 6,256.94 Wellbore: 2S -13L1 -5,549.89 5,932,130.06 475,354.27 Design: Rig: 2S-131-1 90.52 18.61 6,255.62 Survey 2,257.90 -5,521.03 5,932,220.44 475,383.35 MD Inc Azi TVD TVDSS +N/ -S (usft) (°) (°) (usft) (usft) (usft) 11,109.04 91.07 4.87 6,267.71 6,120.41 872.10 11,203.72 90.72 6.20 6,266.23 6,118.93 966.33 11,298.73 90.14 6.77 6,265.52 6,118.22 1,060.72 11,393.68 90.35 8.91 6,265.11 6,117.81 1,154.78 11,487.91 90.24 9.64 6,264.63 6,117.33 1,247.78 11,581.57 90.04 10.58 6,264.40 6,117.10 1,339.98 11,677.85 89.83 10.96 6,264.51 6,117.21 1,434.57 11,773.16 90.48 11.01 6,264.25 6,116.95 1,528.13 11,866.04 90.86 12.26 6,263.17 6,115.87 1,619.09 11,962.22 90.86 14.79 6,261.72 6,114.42 1,712.59 12,056.22 91.10 15.80 6,260.11 6,112.81 1,803.24 12,150.60 90.42 15.34 6,258.86 6,111.56 1,894.15 12,244.02 89.90 14.92 6,258.60 6,111.30 1,984.33 Local Co-ordinate Reference: Well2S-13 TVD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyonl41) MD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyonl41) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Map +E/ -W Northing (usft) (ft) -5,818.29 5,930,835.54 -5,809.16 5,930,929.73 -5,798.43 5,931,024.09 -5,785.48 5,931,118.10 -5,770.29 5,931,211.05 -5,753.85 5,931,303.20 -5,735.86 5,931,397.73 -5,717.70 5,931,491.24 -5,698.97 5,931,582.15 -5,676.48 5,931,675.58 -5,651.69 5,931,766.16 -5,626.36 5,931,856.99 -5,601.97 5,931,947.10 Map Easting DLS (ft) (°/100') 475,082.61 0.93 475,091.98 1.45 475,102.95 0.86 475,116.14 2.26 475,131.56 0.78 475,148.23 1.03 475,166.46 0.45 475,184.85 0.68 475,203.81 1.41 475,226.54 2.63 475,251.56 1.10 475,277.11 0.87 475,301.72 0.72 12,339.56 90.52 15.91 6,258.25 6,110.95 2,076.43 -5,576.58 5,932,039.13 475,327.35 1.22 12,434.41 91.07 16.78 6,256.94 6,109.64 2,167.44 -5,549.89 5,932,130.06 475,354.27 1.09 12,529.38 90.52 18.61 6,255.62 6,108.32 2,257.90 -5,521.03 5,932,220.44 475,383.35 2.01 12,624.72 91.07 18.82 6,254.29 6,106.99 2,348.19 -5,490.44 5,932,310.64 475,414.17 0.62 12,719.84 91.55 17.49 6,252.12 6,104.82 2,438.55 -5,460.81 5,932,400.92 475,444.02 1.49 12,813.56 91.34 12,907.48 91.44 13,003.04 91.55 13,096.21 91.48 13,191.72 90.89 13,286.00 91.00 13,379.04 90.86 13,475.45 91.55 13,569.02 91.72 13,662.82 91.48 13,757.69 92.58 13,852.49 92.52 13,947.88 90.83 14,042.34 90.00 14,136.63 88.32 14,231.28 85.61 14,326.47 82.79 14,421.97 84.65 14,515.58 86.61 14,610.34 87.98 14,704.49 89.15 14,799.41 89.41 18.34 6,249.76 6,102.46 2,527.70 -5,431.99 5,932,489.98 17.25 6,247.48 6,100.18 2,617.10 -5,403.30 5,932,579.30 15.76 6,244.98 6,097.68 2,708.68 -5,376.16 5,932,670.81 14.64 6,242.52 6,095.22 2,798.56 -5,351.74 5,932,760.62 14.47 6,240.55 6,093.25 2,890.99 -5,327.74 5,932,852.97 13.72 6,238.99 6,091.69 2,982.42 -5,304.79 5,932,944.33 11.12 6,237.48 6,090.18 3,073.26 -5,284.78 5,933,035.12 10.15 6,235.45 6,088.15 3,167.99 -5,266.99 5,933,129.79 8.48 6,232.78 6,085.48 3,260.28 -5,251.85 5,933,222.04 8.11 6,230.16 6,082.86 3,353.07 -5,238.32 5,933,314.78 6.51 6,226.80 6,079.50 3,447.10 -5,226.26 5,933,408.77 7.30 6,222.59 6,075.29 3,541.12 -5,214.88 5,933,502.75 7.50 6,219.80 6,072.50 3,635.67 -5,202.59 5,933,597.26 7.47 6,219.11 6,071.81 3,729.32 -5,190.29 5,933,690.88 9.07 6,220.50 6,073.20 3,822.62 -5,176.73 5,933,784.12 11.73 6,225.51 6,078.21 3,915.57 -5,159.67 5,933,877.02 15.04 6,235.13 6,087.83 4,007.67 -5,137.76 5,933,969.06 17.28 6,245.58 6,098.28 4,098.84 -5,111.34 5,934,060.15 20.50 6,252.71 6,105.41 4,187.13 -5,081.13 5,934,148.36 20.34 6,257.18 6,109.88 4,275.84 -5,048.10 5,934,236.97 19.91 6,259.54 6,112.24 4,364.21 -5,015.72 5,934,325.25 19.22 6,260.73 6,113.43 4,453.64 -4,983.94 5,934,414.60 475,473.06 0.93 475,501.98 1.17 475,529.35 1.56 475,553.99 1.20 475,578.22 0.64 475,601.41 0.80 475,621.64 2.80 475,639.67 1.23 475,655.04 1.79 475,668.80 0.47 475,681.10 2.05 475,692.72 0.83 475, 705.24 1.78 475,717.78 0.88 475,731.58 2.46 475,748.87 4.01 475,771.01 4.55 475,797.66 3.04 475,828.09 4.02 475,861.34 1.46 475,893.94 1.32 475,925.95 0.78 Vertical Section (ft) Survey Tool Name -663.50 MWD+IFR-AK-CAZ-SC (7) -570.12 MWD+IFR-AK-CAZ-SC (7) -476.16 MWD+IFR-AK-CAZ-SC (7) -381.96 MWD+IFR-AK-CAZ-SC (7) -288.20 MWD+IFR-AK-CAZ-SC (7) -194.88 MWD+IFR-AK-CAZ-SC (7) -98.87 MWD+IFR-AK-CAZ-SC (7) -3.79 MWD+IFR-AK-CAZ-SC (7) 88.92 MWD+IFR-AK-CAZ-SC (7) 185.05 MWD+IFR-AK-CAZ-SC (7) 279.03 MWD+IFR-AK-CAZ-SC (7) 373.40 MWD+IFR-AK-CAZ-SC (7) 466.82 MWD+IFR-AK-CAZ-SC (7) 562.35 MWD+IFR-AK-CAZ-SC (7) 657.17 MWD+IFR-AK-CAZ-SC (7) 752.02 MWD+IFR-AK-CAZ-SC (7) 847.15 MWD+IFR-AK-CAZ-SC (7) 942.10 MWD+IFR-AK-CAZ-SC (7) 1,035.67 MWD+IFR-AK-CAZ-SC (7) 1,129.44 MWD+IFR-AK-CAZ-SC (7) 1,224.94 MWD+IFR-AK-CAZ-SC (7) 1,318.07 MWD+IFR-AK-CAZ-SC (7) 1,413.56 MWD+IFR-AK-CAZ-SC (7) 1,507.81 MWD+IFR-AK-CAZ-SC (7) 1,600.74 MWD+IFR-AK-CAZ-SC (7) 1,696.85 MWD+IFR-AK-CAZ-SC (7) 1,789.91 MWD+IFR-AK-CAZ-SC (7) 1,883.04 MWD+IFR-AK-CAZ-SC (7) 1,976.99 MWD+IFR-AK-CAZ-SC (7) 2,070.75 MWD+IFR-AK-CAZ-SC (7) 2,165.26 MWD+IFR-AK-CAZ-SC (7) 2,258.90 MWD+IFR-AK-CAZ-SC (7) 2,352.53 MWD+IFR-AK-CAZ-SC (7) 2,446.72 MWD+IFR-AK-CAZ-SC (7) 2,541.37 MWD+IFR-AK-CAZ-SC (7) 2,636.26 MWD+IFR-AK-CAZ-SC (7) 2,729.37 MWD+IFR-AK-CAZ-SC (7) 2,823.60 MWD+IFR-AK-CAZ-SC (7) 2,917.34 MWD+IFR-AK-CAZ-SC (7) 3,011.95 MWD+IFR-AK-CAZ-SC (7) 214/2016 8.38:10AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-13 2S -13L1 Rig: 2S-131-1 Local Co-ordinate Reference: Well 2S-13 TVD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyonl41) MD Reference: Actual: 119.8+27.5 @ 147.30usft (Doyonl41) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) V) (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 14,895.32 91.25 18.38 6,260.18 6,112.88 4,544.43 -4,953.03 5,934,505.30 475,957.08 2.11 3,107.64 MWD+IFR-AK-CAZ-SC (7) 14,989.43 91.31 18.21 6,258.08 6,110.78 4,633.76 -4,923.49 5,934,594.54 475,986.84 0.19 3,201.57 MWD+IFR-AK-CAZ-SC (7) 15,083.19 91.41 17.67 6,255.85 6,108.55 4,722.94 -4,894.62 5,934,683.64 476,015.93 0.59 3,295.18 MWD+IFR-AK-CAZ-SC (7) 15,179.49 91.48 17.08 6,253.42 6,106.12 4,814.81 -4,865.87 5,934,775.43 476,044.91 0.62 3,391.37 MWD+IFR-AK-CAZ-SC (7) 15,274.31 91.44 16.03 6,251.01 6,103.71 4,905.67 -4,838.87 5,934,866.21 476,072.15 1.11 3,486.12 MWD+IFR-AK-CAZ-SC (7) 15,367.68 91.51 15.84 6,248.61 6,101.31 4,995.42 -4,813.24 5,934,955.89 476,098.00 0.22 3,579.45 MWD+IFR-AK-CAZ-SC (7) 15,462.72 91.58 15.61 6,246.04 6,098.74 5,086.87 -4,787.49 5,935,047.26 476,123.97 0.25 3,674.45 MWD+IFR-AK-CAZ-SC (7) 15,558.50 91.96 15.61 6,243.08 6,095.78 5,179.08 -4,761.73 5,935,139.39 476,149.97 0.40 3,770.18 MWD+IFR-AK-CAZ-SC (7) 15,653.21 91.48 15.24 6,240.24 6,092.94 5,270.33 -4,736.55 5,935,230.58 476,175.37 0.64 3,864.84 MWD+IFR-AK-CAZ-SC (7) 15,749.41 91.07 15.44 6,238.10 6,090.80 5,363.08 -4,711.11 5,935,323.25 476,201.05 0.47 3,961.01 MWD+IFR-AK-CAZ-SC (7) 15,844.81 91.75 15.94 6,235.75 6,088.45 5,454.90 -4,685.32 5,935,414.99 476,227.07 0.88 4,056.38 MWD+IFR-AK-CAZ-SC (7) 15,938.66 92.06 16.67 6,232.63 6,085.33 5,544.92 -4,658.98 5,935,504.94 476,253.63 0.84 4,150.15 MWD+IFR-AK-CAZ-SC (7) 16,031.05 92.51 16.66 6,228.95 6,081.65 5,633.36 -4,632.51 5,935,593.31 476,280.32 0.49 4,242.43 MWD+IFR-AK-CAZ-SC (7) 16,123.74 92.10 18.02 6,225.22 6,077.92 5,721.77 -4,604.91 5,935,681.63 476,308.15 1.53 4,334.96 MWD+IFR-AK-CAZ-SC (7) 16,220.59 91.34 19.37 6,222.31 6,075.01 5,813.46 -4,573.88 5,935,773.24 476,339.40 1.60 4,431.57 MWD+IFR-AK-CAZ-SC (7) 16,316.73 91.00 20.77 6,220.35 6,073.05 5,903.74 -4,540.89 5,935,863.43 476,372.61 1.50 4,527.31 MWD+IFR-AK-CAZ-SC (7) 16,410.44 91.17 21.14 6,218.58 6,071.28 5,991.24 -4,507.39 5,935,950.83 476,406.34 0.43 4,620.49 MWD+IFR-AK-CAZ-SC (7) 16,505.92 91.00 21.15 6,216.77 6,069.47 6,080.27 -4,472.95 5,936,039.77 476,441.00 0.18 4,715.41 MWD+IFR-AK-CAZ-SC (7) 16,599.43 91.34 21.04 6,214.86 6,067.56 6,167.50 -4,439.30 5,936,126.90 476,474.86 0.38 4,808.37 MWD+IFR-AK-CAZ-SC (7) 16,694.27 91.96 21.19 6,212.13 6,064.83 6,255.93 -4,405.15 5,936,215.24 476,509.23 0.67 4,902.63 MWD+IFR-AK-CAZ-SC (7) 16,785.89 92.34 21.77 6,208.69 6,061.39 6,341.13 -4,371.63 5,936,300.34 476,542.97 0.76 4,993.60 MWD+IFR-AK-CAZ-SC (7) 16,867.00 92.34 21.77 6,205.38 6,058.08 6,416.39 -4,341.57 5,936,375.52 476,573.22 0.00 5,074.08 PROJECTED to TD 2/4/2016 8:38:10AM Page 7 COMPASS 5000.1 Build 74 Final Definitive Survey Verified and Signed-off All targets and/or well positron objectives have been achieved. ❑ Yes ❑ No I have checked to the best of my ability that the following data is correct: (] Surface Coordinates n Declination & Convergence LJ GRS Survey Corrections � ❑ Survey Tool Codes Vincent DM.c = InCWO VrA en[flsan Dht: cn=utncent osa 0=5chimb"er, SLB DE: au=schUmb&W. Osa ra Va*'z� �� A4-09W Scott Brunswick Client Representative:% 04-Feb-2016 Date: 21 5152 RECEIVIED 25849 FEB 2 4 2011; AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S -13L1 2S -13L1 Definitive Survey Report 28 January, 2016 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-13 Wellbore: 2S-131-1 Design: Rig: 2S-131-1 Schlumberger Definitive Survey Report Local Co-ordinate Reference: Well 2S-13 TVD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyon 14 1) MD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyonl41) North Reference: True Survey Calculation Method: Minimum Curvature 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-13 Azi TVD TVDSS Well Position +N/ -S 0.00 usft Northing: 5,929,698.38 usfl Latitude: 70° 13' 10.068 N (usft) +E/ -W 0.00 usft Easting: 1,620,931.43 usfl Longitude: 150° 9'25.916 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 120.00 usft Wellbore 2S-131-1 0.03 287.05 82.68 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 238.86 107.50 (°) (°) (nT) x 42" BGGM2015 12/15/2015 18.44 80.86 57,486 Design Rig: 2S-131-1 201.50 174.86 27.56 Audit Notes: 266.90 0.54 204.98 266.90 Version: 1.0 Phase: ACTUAL Tie On Depth: 9,906.40 196.47 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 4.08 197.58 (usft) (usft) (usft) (°) 542.44 4.84 27.50 0.00 0.00 15.00 -14.87 Survey Program Date 1/28/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 82.68 1,283.58 2S-13PB1 Srvy #1 - Gyro on Battery (2S GYD-GC-SS Gyrodata gyro single shots 12/1/2015 10:2 1,304.79 2,775.54 2S-13PB1 Srvy #2 - GMAG (2S-13PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/1/2015 10:2 2,868.01 9,265.30 2S-13PB1 Srvy #3 - GMAG (2S-13PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/7/2015 8:3 9,288.24 9,288.24 2S-13PB1 Srvy#4 - Inc+trend (2S-13PB1 INC+TREND Inclinometer + known azi trend 12/16/2015 9: 9,338.00 9,906.40 2S-13 Srvy #1 - GMAG (2S-13) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/20/2015 11 9,942.83 10,131.87 2S-131-1 Srvy #1 - Inc+Trend (2S-131-1) INC+TREND Inclinometer + known azi trend 1/16/2016 8:4 10,161.07 16,785.89 2S-131-1 Srvy #2 - GMAG (2S-131-1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/18/2016 8:5 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) (°) (°) (usft) (usft) (usft) 27.50 0.00 0.00 27.50 -119.80 0.00 82.68 0.03 287.05 82.68 -64.62 0.00 107.50 0.04 238.86 107.50 -39.80 0.00 20" x 42" 5,929,698.32 1,620,931.36 0.11 -0.08 GYD-GC-SS(1) 174.86 0.10 201.50 174.86 27.56 -0.06 266.90 0.54 204.98 266.90 119.60 -0.53 358.92 2.63 196.47 358.88 211.58 -2.95 450.55 4.08 197.58 450.35 303.05 -8.07 542.44 4.84 198.23 541.96 394.66 -14.87 1/28/2016 11:12:33AM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical +E/ -W Northing Easting DLS Section (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 0.00 5,929,698.38 1,620,931.43 0.00 0.00 UNDEFINED -0.01 5,929,698.39 1,620,931.41 0.05 0.00 GYD-GC-SS (1) -0.03 5,929,698.39 1,620,931.40 0.11 0.00 I NOT an Actual Survey -0.07 5,929,698.32 1,620,931.36 0.11 -0.08 GYD-GC-SS(1) -0.28 5,929,697.85 1,620,931.15 0.48 -0.59 GYD-GC-SS (1) -1.06 5,929,695.44 1,620,930.36 2.28 -3.12 GYD-GC-SS (1) -2.64 5,929,690.32 1,620,928.76 1.58 -8.48 GYD-GC-SS(1) -4.84 5,929,683.53 1,620,926.55 0.83 -15.62 GYD-GC-SS (1) 1/28/2016 11:12:33AM Page 2 COMPASS 5000.1 Build 74 Company: Project: Site: Well: Wellbore: Design: Survey Schlumberger Definitive Survey Report ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2S-13 Kuparuk River Unit TVD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyon 14 1) Kuparuk 2S Pad MD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyonl41) 2S-13 North Reference: True 2S-131-1 Survey Calculation Method: Minimum Curvature Rig: 2S-131-1 Database: OAKEDMP2 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (0) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 634.35 5.99 202.27 633.46 486.16 -22.99 -7.87 5,929,675.41 1,620,923.49 1.32 -24.25' GYD-GC-SS (1) 726.00 6.53 203.78 724.56 577.26 -32.19 -11.79 5,929,666.23 1,620,919.56 0.62 -34.14 GYD-GC-SS (1) 817.94 8.48 201.86 815.71 668.41 -43.26 -16.42 5,929,655.17 1,620,914.90 2.14 -46.04 GYD-GC-SS (1) 910.56 9.80 205.54 907.15 759.85 -56.71 -22.36 5,929,641.73 1,620,908.92 1.56 -60.57 GYD-GC-SS (1) 1,003.86 11.08 208.23 998.91 851.61 -71.78 -30.02 5,929,626.69 1,620,901.22 1.47 -77.10 GYD-GC-SS(1) 1,096.09 12.93 209.29 1,089.12 941.82 -88.59 -39.27 5,929,609.91 1,620,891.94 2.02 -95.73 GYD-GC-SS (1) 1,188.56 15.38 208.11 1,178.77 1,031.47 -108.43 -50.11 5,929,590.09 1,620,881.04 2.67 -117.70 GYD-GC-SS (1) 1,283.58 19.22 206.89 1,269.48 1,122.18 -133.50 -63.12 5,929,565.06 1,620,867.97 4.06 -145.29 GYD-GC-SS (1) 1,304.79 20.60 207.96 1,289.42 1,142.12 -139.91 -66.45 5,929,558.66 1,620,864.62 6.73 -152.34 MWD+IFR-AK-CAZ-SC (2) 1,396.67 21.80 208.96 1,375.08 1,227.78 -169.12 -82.29 5,929,529.50 1,620,848.71 1.36 -184.65 MWD+IFR-AK-CAZ-SC (2) 1,491.21 25.56 213.09 1,461.65 1,314.35 -201.58 -101.93 5,929,497.09 1,620,828.98 4.34 -221.09 MWD+IFR-AK-CAZ-SC (2) 1,585.16 27.45 217.68 1,545.73 1,398.43 -235.70 -126.24 5,929,463.03 1,620,804.59 2.97 -260.34 MWD+IFR-AK-CAZ-SC (2) 1,677.93 29.30 221.23 1,627.36 1,480.06 -269.70 -154.27 5,929,429.11 1,620,776.47 2.70 -300.44 MWD+IFR-AK-CAZ-SC (2) 1,771.75 30.21 225.91 1,708.82 1,561.52 -303.40 -186.36 5,929,395.50 1,620,744.30 2.66 -341.29 MWD+IFR-AK-CAZ-SC (2) 1,863.74 31.06 226.45 1,787.97 1,640.67 -335.85 -220.19 5,929,363.14 1,620,710.40 0.97 -381.40 MWD+IFR-AK-CAZ-SC (2) 1,956.72 32.83 229.72 1,866.87 1,719.57 -368.68 -256.80 5,929,330.41 1,620,673.70 2.66 -422.58 MWD+IFR-AK-CAZ-SC (2) 2,050.37 33.68 233.62 1,945.19 1,797.89 -400.50 -297.08 5,929,298.70 1,620,633.34 2.46 -463.74 MWD+IFR-AK-CAZ-SC (2) 2,143.17 34.26 235.37 2,022.15 1,874.85 -430.60 -339.29 5,929,268.70 1,620,591.06 1.23 -503.75 MWD+IFR-AK-CAZ-SC (2) 2,237.57 35.48 238.69 2,099.61 1,952.31 -459.94 -384.57 5,929,239.48 1,620,545.71 2.39 -543.80 MWD+IFR-AK-CAZ-SC (2) 2,330.47 38.90 240.04 2,173.61 2,026.31 -488.53 -432.89 5,929,211.02 1,620,497.32 3.78 -583.92 MWD+IFR-AK-CAZ-SC (2) 2,423.89 39.45 242.06 2,246.03 2,098.73 -517.09 -484.53 5,929,182.60 1,620,445.62 1.49 -624.87 MWD+IFR-AK-CAZ-SC (2) 2,515.04 40.79 245.52 2,315.74 2,168.44 -543.00 -537.21 5,929,156.83 1,620,392.86 2.85 -663.54 MWD+IFR-AK-CAZ-SC (2) 2,609.16 42.70 247.70 2,385.97 2,238.67 -567.85 -594.73 5,929,132.13 1,620,335.29 2.55 -702.43 MWD+IFR-AK-CAZ-SC (2) 2,701.86 43.56 247.40 2,453.62 2,306.32 -592.05 -653.30 5,929,108.08 1,620,276.66 0.95 -740.96 MWD+IFR-AK-CAZ-SC (2) 2,775.54 45.32 247.46 2,506.22 2,358.92 -611.85 -700.94 5,929,088.41 1,620,228.98 2.39 -772.42 MWD+IFR-AK-CAZ-SC (2) 2,835.00 46.00 247.45 2,547.78 2,400.48 -628.16 -740.21 5,929,072.20 1,620,189.67 1.14 -798.33 NOT an Actual Suryey C (3) -U-3111".x-16"_ ... . _ _ _ 2,868.01 46.37 247.44 2,570.64 2,423.34 -637.29 -762.21 5,929,063.13 1,620,167.65 1.14 -812.85 MWD+IFR-AK-CAZ-SC (3) 2,961.88 45.93 246.36 2,635.67 2,488.37 -663.85 -824.47 5,929,036.73 1,620,105.32 0.95 -854.62 MWD+IFR-AK-CAZ-SC (3) 3,053.24 45.12 245.87 2,699.67 2,552.37 -690.24 -884.08 5,929,010.50 1,620,045.65 0.97 -895.54 MWD+IFR-AK-CAZ-SC (3) 3,145.12 45.68 246.79 2,764.19 2,616.89 -716.50 -944.00 5,928,984.39 1,619,985.68 0.94 -936.41 MWD+IFR-AK-CAZ-SC (3) 3,237.98 47.31 247.54 2,828.11 2,680.81 -742.63 -1,006.07 5,928,958.42 1,619,923.54 1.85 -977.72 MWD+IFR-AK-CAZ-SC (3) 3,332.72 50.46 248.03 2,890.40 2,743.10 -769.61 -1,072.14 5,928,931.62 1,619,857.41 3.35 -1,020.88 MWD+IFR-AK-CAZ-SC (3) 3,425.65 51.28 247.93 2,949.05 2,801.75 -796.64 -1,138.97 5,928,904.77 1,619,790.52 0.89 -1,064.28 MWD+IFR-AK-CAZ-SC (3) 3,518.99 55.39 247.67 3,004.77 2,857.47 -824.93 -1,208.28 5,928,876.66 1,619,721.14 4.41 -1,109.54 MWD+IFR-AK-CAZ-SC (3) 3,609.42 56.46 248.04 3,055.44 2,908.14 -853.16 -1,277.65 5,928,848.61 1,619,651.70 1.23 -1,154.77 MWD+IFR-AK-CAZ-SC (3) 3,703.27 57.86 248.01 3,106.33 2,959.03 -882.67 -1,350.77 5,928,819.30 1,619,578.51 1.49 -1,202.19 MWD+IFR-AK-CAZ-SC (3) 3,795.35 58.60 248.24 3,154.81 3,007.51 -911.83 -1,423.42 5,928,790.32 1,619,505.80 0.83 -1,249.17 MWD+IFR-AK-CAZ-SC (3) 3,888.69 62.00 248.65 3,201.05 3,053.75 -941.61 -1,498.82 5,928,760.74 1,619,430.33 3.66 -1,297.45 MWD+IFR-AK-CAZ-SC (3) 3,983.02 62.42 248.93 3,245.03 3,097.73 -971.80 -1,576.62 5,928,730.75 1,619,352.46 0.52 -1,346.75 MWD+IFR-AK-CAZ-SC (3) 112812016 11:12:33AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-13 Wellbore: 2S -13L1 Design: Rig: 2S-131-1 Survey MD Inc Azi TVD TVDSS +N1 -S (usft) 0 (1) (usft) (usft) (usft) 4,075.27 61.97 248.44 3,288.06 3,140.76 -1,001.46 4,168.33 61.01 250.91 3,332.49 3,185.19 -1,029.87 4,262.19 60.59 251.46 3,378.28 3,230.98 -1,056.29 41356.57 60.80 251.48 4,449.98 61.03 251.32 4,544.76 61.00 251.15 4,638.59 61.06 250.63 4,732.01 60.86 249.57 4,826.27 60.79 250.20 4,916.93 61.06 250.33 5,010.28 61.10 250.12 5,102.78 60.72 250.05 5,195.28 60.66 249.61 5,289.37 60.74 250.17 5,381.75 60.67 250.09 5,473.45 60.63 250.62 5,567.92 60.66 250.87 5,661.68 60.74 251.47 5,757.08 60.53 251.29 5,850.57 60.90 250.91 5,943.99 60.44 248.47 6,037.22 60.79 249.67 6,129.53 60.59 248.07 6,222.41 60.88 248.38 6,316.01 60.70 248.15 6,409.32 60.61 250.20 6,502.38 58.16 250.88 6,598.21 58.41 253.51 6,689.12 58.87 256.33 6,783.66 59.28 258.89 6,878.78 58.49 262.31 6,974.96 57.42 266.31 7,068.26 56.96 269.00 7,162.25 56.44 272.56 7,254.28 55.85 275.87 7,345.72 55.88 278.70 7,441.05 55.03 280.27 7,533.25 52.88 282.42 7,625.94 51.57 285.38 7,719.41 52.60 289.78 3,424.47 3,469.88 3,515.81 3,561.26 3,606.61 3,652.56 3,696.61 3,741.76 3,786.73 3,832.01 3,878.06 3,923.26 3,968.20 4,014.51 4,060.40 4,107.18 4,152.91 4,198.68 4,244.43 4,289.62 4,335.02 4,380.70 4,426.43 4,473.82 4,524.20 4,571.52 4,620.11 4,669.28 4,720.32 4,770.88 4,822.50 4,873.78 4,925.10 4,979.15 5,033.41 5,090.19 5,147.65 3,277.17 3,322.58 3,368.51 3,413.96 3,459.31 3,505.26 3,549.31 3,594.46 3,639.43 3,684.71 3,730.76 3,775.96 3,820.90 3,867.21 3,913.10 3,959.88 4,005.61 4,051.38 4,097.13 4,142.32 4,187.72 4,233.40 4,279.13 4,326.52 4,376.90 4,424.22 4,472.81 4,521.98 4,573.02 4,623.58 4,675.20 4,726.48 4,777.80 4,831.85 4,886.11 4,942.89 5,000.35 -1,082.45 -1,108.49 -1,135.16 -1,162.03 -1,189.83 -1,218.13 -1,244.89 -1,272.53 -1,300.07 -1,327.88 -1,356.09 -1,383.47 -1,410.35 -1,437.50 -1,463.89 -1,490.44 -1,516.85 -1,545.11 -1,574.13 -1,603.14 -1,633.20 -1,663.45 -1,692.37 -1,719.05 -1.743.97 -1,764.16 -1,781.56 -1,794.87 -1,802.96 -1,806.17 -1,805.11 -1,799.50 -1,789.91 -1,776.97 -1,762.33 -1,744.75 -1,722.47 Local Co-ordinate Reference: Well 2S-13 TVD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyon141) MD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyon 141) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 1/28/2016 11:12:33AM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical +E/ -W Northing Easting DLS Section (usft) (ft) (ft) (-1100-) (ft) Survey Tool Name -1,652.63 5,928,701.29 1,619,276.38 0.68 -1,395.07 MWD+IFR-AK-CAZ-SC (3) -1,729.30 5,928,673.09 1,619,199.64 2.55 -1,442.35 MWD+IFR-AK-CAZ-SC (3) -1,806.86 5,928,646.86 1,619,122.03 0.68 -1,487.95 MWD+IFR-AK-CAZ-SC (3) -1,884.89 5,928,620.91 1,619,043.93 0.22 -1,533.41 MWD+IFR-AK-CAZ-SC (3) -1,962.26 5,928,595.08 1,618,966.51 0.29 -1,578.59 MWD+IFR-AK-CAZ-SC (3) -2,040.76 5,928,568.61 1,618,887.94 0.16 -1,624.67 MWD+IFR-AK-CAZ-SC (3) -2,118.33 5,928,541.94 1,618,810.32 0.49 -1,670.70 MWD+IFR-AK-CAZ-SC (3) -2,195.12 5,928,514.34 1,618,733.46 1.01 -1,717.43 MWD+IFR-AK-CAZ-SC (3) -2,272.40 5,928,486.24 1,618,656.11 0.59 -1,764.77 MWD+IFR-AK-CAZ-SC (3) -2,346.99 5,928,459.68 1,618,581.47 0.32 -1,809.92 MWD+IFR-AK-CAZ-SC (3) -2,423.88 5,928,432.24 1,618,504.51 0.20 -1,856.52 MWD+IFR-AK-CAZ-SC (3) -2,499.87 5,928,404.90 1,618,428.45 0.42 -1,902.78 MWD+IFR-AK-CAZ-SC (3) -2,575.59 5,928,377.29 1,618,352.68 0.42 -1,949.24 MWD+IFR-AK-CAZ-SC (3) -2,652.64 5,928,349.28 1,618,275.56 0.53 -1,996.44 MWD+IFR-AK-CAZ-SC (3) -2,728.41 5,928,322.10 1,618,199.73 0.11 -2,042.50 MWD+IFR-AK-CAZ-SC (3) -2,803.68 5,928,295.42 1,618,124.39 0.51 -2,087.94 MWD+IFR-AK-CAZ-SC (3) -2,881.42 5,928,268.47 1,618,046.60 0.23 -2,134.28 MWD+IFR-AK-CAZ-SC (3) -2,958.80 5,928,242.28 1,617,969.15 0.56 -2,179.80 MWD+IFR-AK-CAZ-SC (3) -3,037.60 5,928,215.94 1,617,890.30 0.27 -2,225.84 MWD+IFR-AK-CAZ-SC (3) -3,114.74 5,928,189.73 1,617,813.09 0.53 -2,271.32 MWD+IFR-AK-CAZ-SC (3) -3,191.11 5,928,161.67 1,617,736.65 2.33 -2,318.38 MWD+IFR-AK-CAZ-SC (3) -3,266.99 5,928,132.85 1,617,660.71 1.18 -2,366.05 MWD+IFR-AK-CAZ-SC (3) -3,342.06 5,928,104.03 1,617,585.57 1.53 -2,413.51 MWD+IFR-AK-CAZ-SC (3) -3,417.31 5,928,074.17 1,617,510.25 0.43 -2,462.01 MWD+IFR-AK-CAZ-SC (3) -3,493.20 5,928,044.12 1,617,434.29 0.29 -2,510.88 MWD+IFR-AK-CAZ-SC (3) -3,569.22 5,928,015.40 1,617,358.21 1.92 -2,558.48 MWD+IFR-AK-CAZ-SC (3) -3,644.72 5,927,988.92 1,617,282.64 2.71 -2,603.80 MWD+IFR-AK-CAZ-SC (3) -3,722.33 5,927,964.20 1,617,204.98 2.35 -2,647.96 MWD+IFR-AK-CAZ-SC (3) -3,797.27 5,927,944.21 1,617,129.99 2.70 -2,686.86 MWD+IFR-AK-CAZ-SC (3) -3,876.47 5,927,927.02 1,617,050.75 2.36 -2,724.16 MWD+IFR-AK-CAZ-SC (3) -3,956.79 5,927,913.92 1,616,970.40 3.19 -2,757.80 MWD+IFR-AK-CAZ-SC (3) -4,037.89 5,927,906.03 1,616,889.30 3.70 -2,786.61 MWD+IFR-AK-CAZ-SC (3) -4,116.23 5,927,903.02 1,616,810.96 2.47 -2,809.99 MWD+IFR-AK-CAZ-SC (3) -4,194.76 5,927,904.29 1,616,732.44 3.21 -2,829.29 MWD+IFR-AK-CAZ-SC (3) -4,270.96 5,927,910.09 1,616,656.26 3.05 -2,843.59 MWD+IFR-AK-CAZ-SC (3) -4,346.02 5,927,919.88 1,616,581.23 2.56 -2,853.75 MWD+IFR-AK-CAZ-SC (3) -4,423.47 5,927,933.01 1,616,503.83 1.62 -2,861.30 MWD+IFR-AK-CAZ-SC (3) -4,496.55 5,927,947.84 1,616,430.79 3.00 -2,866.07 MWD+IFR-AK-CAZ-SC (3) -4,567.66 5,927,965.60 1,616,359.73 2.89 -2,867.50 MWD+IFR-AK-CAZ-SC (3) -4,637.92 5,927,988.06 1,616,289.54 3.87 -2,864.16 MWD+IFR-AK-CAZ-SC (3) 1/28/2016 11:12:33AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-13 Wellbore: 2S-131-1 Design: Rig: 2S-131-1 S u rvey MD Inc Azi TVD TVDSS +N/ -S (usft) (1) (°) (usft) (usft) (usft) 7,811.71 53.12 292.34 5,203.38 5,056.08 -1,696.03 7,903.79 54.45 296.32 5,257.79 5,110.49 -1,665.41 7,995.87 55.41 299.86 5,310.71 5,163.41 -1,629.92 8,088.89 55.39 303.20 5,363.54 5,216.24 -1,589.89 8,181.47 55.44 306.84 5,416.11 5,268.81 -1,546.17 8,274.49 55.80 309.81 5,468.64 5,321.34 -1,498.56 8,368.67 57.04 309.97 5,520.73 5,373.43 -1,448.24 8,461.71 56.71 309.14 5,571.57 5,424.27 -1,398.62 8,553.04 55.84 310.08 5,622.28 5,474.98 -1,350.20 8,647.67 55.94 311.96 5,675.35 5,528.05 -1,298.78 8,741.37 57.18 315.11 5,726.99 5,579.69 -1,244.92 8,835.77 58.31 317.50 5,777.38 5,630.08 -1,187.20 8,928.24 58.65 321.18 5,825.73 5,678.43 -1,127.42 9,021.69 59.42 323.94 5,873.82 5,726.52 -1,063.80 9,114.60 60.50 327.49 5,920.34 5,773.04 -997.35 9,207.51 61.42 330.83 5,965.45 5,818.15 -927.62 9,265.30 61.60 332.19 5,993.02 5,845.72 -882.98 9,288.24 61.68 332.70 6,003.92 5,856.62 -865.08 9,338.00 61.83 333.34 6,027.47 5,880.17 -826.02 9,399.61 61.71 338.01 6,056.62 5,909.32 -776.58 9,441.73 62.23 340.89 6,076.42 5,929.12 -741.77 9,536.34 64.93 344.27 6,118.52 5,971.22 -660.94 9,628.18 66.40 347.72 6,156.37 6,009.07 -579.76 9,720.92 69.66 349.31 6,191.07 6,043.77 -495.49 9,814.38 72.21 349.35 6,221.59 6,074.29 -408.69 9,906.40 74.94 350.60 6,247.61 6,100.31 -321.79 9,929.00 76.05 349.23 6,253.27 6,105.97 -300.24 7-5/8" x 9-7/8" - Bottom of the window 9,942.83 76.74 348.40 6,256.52 6,109.22 -287.06 10,037.13 87.36 349.00 6,269.55 6,122.25 -195.60 10,131.87 92.06 353.76 6,270.03 6,122.73 -101.99 10,161.07 90.45 354.51 6,269.39 6,122.09 -72.95 10,255.59 90.00 354.23 6,269.02 6,121.72 21.11 10,351.16 88.84 354.20 6,269.98 6,122.68 116.19 10,445.97 88.53 354.39 6,272.16 6,124.86 210.50 10,540.98 89.46 354.41 6,273.82 6,126.52 305.05 10,635.74 90.35 357.30 6,273.98 6,126.68 399.55 10,700.70 90.69 357.59 6,273.39 6,126.09 464.44 10,731.14 90.84 0.12 6,272.99 6,125.69 494.87 10,824.23 90.48 2.06 6,271.91 6,124.61 587.93 Local Co-ordinate Reference: Well 2S-13 TVD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyon141) MD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyon 141) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 1/28/2016 11:12:33AM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical +E/ -W Northing Easting DLS Section (usft) (ft) (ft) (-/100') (ft) Survey Tool Name -4,706.57 5,928,014.68 1,616,220.96 2.28 -2,856.39 MWD+IFR-AK-CAZ-SC (3) -4,774.23 5,928,045.47 1,616,153.39 3.77 -2,844.33 MWD+IFR-AK-CAZ-SC (3) -4,840.69 5,928,081.12 1,616,087.03 3.31 -2,827.25 MWD+IFR-AK-CAZ-SC (3) -4,905.94 5,928,121.32 1,616,021.89 2.96 -2,805.47 MWD+IFR-AK-CAZ-SC (3) -4,968.34 5,928,165.20 1,615,959.60 3.24 -2,779.38 MWD+IFR-AK-CAZ-SC (3) -5,028.55 5,928,212.96 1,615,899.52 2.66 -2,748.99 MWD+IFR-AK-CAZ-SC (3) -5,088.76 5,928,263.42 1,615,839.45 1.32 -2,715.96 MWD+IFR-AK-CAZ-SC (3) -5,148.83 5,928,313.20 1,615,779.51 0.83 -2,683.58 MWD+IFR-AK-CAZ-SC (3) -5,207.35 5,928,361.77 1,615,721.12 1.28 -2,651.95 MWD+IFR-AK-CAZ-SC (3) -5,266.46 5,928,413.33 1,615,662.15 1.65 -2,617.58 MWD+IFR-AK-CAZ-SC (3) -5,323.12 5,928,467.33 1,615,605.64 3.10 -2,580.23 MWD+IFR-AK-CAZ-SC (3) -5,378.26 5,928,525.19 1,615,550.66 2.45 -2,538.74 MWD+IFR-AK-CAZ-SC (3) -5,429.60 5,928,585.10 1,615,499.47 3.41 -2,494.29 MWD+IFR-AK-CAZ-SC (3) -5,478.30 5,928,648.84 1,615,450.94 2.66 -2,445.44 MWD+IFR-AK-CAZ-SC (3) -5,523.58 5,928,715.39 1,615,405.83 3.51 -2,392.98 MWD+IFR-AK-CAZ-SC (3) -5,565.21 5,928,785.23 1,615,364.40 3.30 -2,336.39 MWD+IFR-AK-CAZ-SC (3) -5,589.43 5,928,829.92 1,615,340.29 2.09 -2,299.55 MWD+IFR-AK-CAZ-SC (3) -5,598.77 5,928,847.84 1,615,331.00 1.99 -2,284.68 INC+TREND (4) -5,618.66 5,928,886.95 1,615,311.21 1.17 -2,252.09 MWD+IFR-AK-CAZ-SC (5) -5,641.01 5,928,936.45 1,615,288.99 6.68 -2,210.12 MWD+IFR-AK-CAZ-SC (5) -5,654.06 5,928,971.29 1,615,276.03 6.16 -2,179.87 MWD+IFR-AK-CAZ-SC (5) -5,679.39 5,929,052.17 1,615,250.92 4.29 -2,108.35 MWD+IFR-AK-CAZ-SC (5) -5,699.62 5,929,133.39 1,615,230.90 3.78 -2,035.18 MWD+IFR-AK-CAZ-SC (5) -5,716.73 5,929,217.70 1,615,214.01 3.86 -1,958.21 MWD+IFR-AK-CAZ-SC (5) -5,733.08 5,929,304.53 1,615,197.88 2.73 -1,878.60 MWD+IFR-AK-CAZ-SC (5) -5,748.44 5,929,391.47 1,615,182.75 3.24 -1,798.63 MWD+IFR-AK-CAZ-SC (5) -5,752.27 5,929,413.02 1,615,178.97 7.66 -1,778.81 NOT an Actual Survey -5,754.88 5,929,426.21 1,615,176.40 7.66 -1,766.75 INC+TREND (6) -5,773.15 5,929,517.70 1,615,158.37 11.28 -1,683.14 INC+TREND (6) -5,787.34 5,929,611.35 1,615,144.42 7.06 -1,596.39 INC+TREND (6) -5,790.32 5,929,640.39 1,615,141.51 6.08 -1,569.11 MWD+IFR-AK-CAZ-SC (7) -5,799.59 5,929,734.47 1,615,132.49 0.56 -1,480.65 MWD+IFR-AK-CAZ-SC (7) -5,809.22 5,929,829.56 1,615,123.10 1.21 -1,391.31 MWD+IFR-AK-CAZ-SC (7) -5,818.65 5,929,923.89 1,615,113.92 0.38 -1,302.64 MWD+IFR-AK-CAZ-SC (7) -5,827.92 5,930,018.44 1,615,104.90 0.98 -1,213.72 MWD+IFR-AK-CAZ-SC (7) -5,834.76 5,930,112.95 1,615,098.29 3.19 -1,124.22 MWD+IFR-AK-CAZ-SC (7) -5,837.66 5,930,177.85 1,615,095.57 0.69 -1,062.28 MWD+IFR-AK-CAZSC (7) -5,838.27 5,930,208.27 1,615,095.04 8.33 -1,033.05 MWD+IFR-AK-CAZ-SC (7) -5,836.50 5,930,301.32 1,615,097.05 2.12 -942.70 MWD+IFR-AK-CAZ-SC (7) 1/28/2016 11:12:33AM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2S-13 Project: Kuparuk River Unit TVD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: Rig: 119.8+27.5 @ 147.30usft (Doyon 141) Well: 2S-13 North Reference: True Wellbore: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: Rig: 2S-131-1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,919.63 90.62 3.55 6,271.00 6,123.70 683.21 -5,831.83 5,930,396.58 1,615,101.96 1.57 -849.46 MWD+IFR-AK-CAZ-SC (7) 11,013.21 91.14 3.98 6,269.56 6,122.26 776.58 -5,825.69 5,930,489.92 1,615,108.34 0.72 -757.68 MWD+IFR-AK-CAZ-SC (7) 11,109.04 91.07 4.87 6,267.71 6,120.41 872.10 -5,818.29 5,930,585.42 1,615,115.98 0.93 -663.50 MWD+IFR-AK-CAZ-SC (7) 11,203.72 90.72 6.20 6,266.23 6,118.93 966.33 -5,809.16 5,930,679.61 1,615,125.36 1.45 -570.12 MWD+IFR-AK-CAZ-SC (7) 11,298.73 90.14 6.77 6,265.52 6,118.22 1,060.72 -5,798.43 5,930,773.97 1,615,136.33 0.86 -476.16 MWD+IFR-AK-CAZ-SC (7) 11,393.68 90.35 8.91 6,265.11 6,117.81 1,154.78 -5,785.48 5,930,867.98 1,615,149.52 2.26 -381.96 MWD+IFR-AK-CAZ-SC (7) 11,487.91 90.24 9.64 6,264.63 6,117.33 1,247.78 -5,770.29 5,930,960.93 1,615,164.95 0.78 -288.20 MWD+IFR-AK-CAZ-SC (7) 11,581.57 90.04 10.58 6,264.40 6,117.10 1,339.98 -5,753.85 5,931,053.08 1,615,181.62 1.03 -194.88 MWD+IFR-AK-CAZ-SC (7) 11,677.85 89.83 10.96 6,264.51 6,117.21 1,434.57 -5,735.86 5,931,147.61 1,615,199.86 0.45 -98.87 MWD+IFR-AK-CAZ-SC (7) 11,773.16 90.48 11.01 6,264.25 6,116.95 1,528.13 -5,717.70 5,931,241.11 1,615,218.26 0.68 -3.79 MWD+IFR-AK-CAZ-SC (7) 11,866.04 90.86 12.26 6,263.17 6,115.87 1,619.09 -5,698.97 5,931,332.02 1,615,237.22 1.41 88.92 MWD+IFR-AK-CAZ-SC (7) 11,962.22 90.86 14.79 6,261.72 6,114.42 1,712.59 -5,676.48 5,931,425.45 1,615,259.95 2.63 185.05 MWD+IFR-AK-CAZ-SC (7) 12,056.22 91.10 15.80 6,260.11 6,112.81 1,803.24 -5,651.69 5,931,516.03 1,615,284.97 1.10 279.03 MWD+IFR-AK-CAZ-SC (7) 12,150.60 90.42 15.34 6,258.86 6,111.56 1,894.15 -5,626.36 5,931,606.86 1,615,310.54 0.87 373.40 MWD+IFR-AK-CAZ-SC (7) 12,244.02 89.90 14.92 6,258.60 6,111.30 1,984.33 -5,601.97 5,931,696.97 1,615,335.15 0.72 466.82 MWD+IFR-AK-CAZ-SC (7) 12,339.56 90.52 15.91 6,258.25 6,110.95 2,076.43 -5,576.58 5,931,789.00 1,615,360.78 1.22 562.35 MWD+IFR-AK-CAZ-SC (7) 12,434.41 91.07 16.78 6,256.94 6,109.64 2,167.44 -5,549.89 5,931,879.93 1,615,387.70 1.09 657.17 MWD+IFR-AK-CAZ-SC (7) 12,529.38 90.52 18.61 6,255.62 6,108.32 2,257.90 -5,521.03 5,931,970.31 1,615,416.79 2.01 752.02 MWD+IFR-AK-CAZ-SC (7) 12,624.72 91.07 18.82 6,254.29 6,106.99 2,348.19 -5,490.44 5,932,060.51 1,615,447.61 0.62 847.15 MWD+IFR-AK-CAZ-SC (7) 12,719.84 91.55 17.49 6,252.12 6,104.82 2,438.55 -5,460.81 5,932,150.78 1,615,477.47 1.49 942.10 MWD+IFR-AK-CAZ-SC (7) 12,813.56 91.34 18.34 6,249.76 6,102.46 2,527.70 -5,431.99 5,932,239.84 1,615,506.52 0.93 1,035.67 MWD+IFR-AK-CAZ-SC (7) 12,907.48 91.44 17.25 6,247.48 6,100.18 2,617.10 -5,403.30 5,932,329.16 1,615,535.44 1.17 1,129.44 MWD+IFR-AK-CAZ-SC (7) 13,003.04 91.55 15.76 6,244.98 6,097.68 2,708.68 -5,376.16 5,932,420.67 1,615,562.81 1.56 1,224.94 MWD+IFR-AK-CAZ-SC (7) 13,096.21 91.48 14.64 6,242.52 6,095.22 2,798.56 -5,351.74 5,932,510.47 1,615,587.46 1.20 1,318.07 MWD+IFR-AK-CAZ-SC (7) 13,191.72 90.89 14.47 6,240.55 6,093.25 2,890.99 -5,327.74 5,932,602.83 1,615,611.70 0.64 1,413.56 MWD+IFR-AK-CAZ-SC (7) 13,286.00 91.00 13.72 6,238.99 6,091.69 2,982.42 -5,304.79 5,932,694.19 1,615,634.89 0.80 1,507.81 MWD+IFR-AK-CAZ-SC (7) 13,379.04 90.86 11.12 6,237.48 6,090.18 3,073.26 -5,284.78 5,932,784.97 1,615,655.12 2.80 1,600.74 MWD+IFR-AK-CAZ-SC (7) 13,475.45 91.55 10.15 6,235.45 6,088.15 3,167.99 -5,266.99 5,932,879.64 1,615,673.16 1.23 1,696.85 MWD+IFR-AK-CAZ-SC (7) 13,569.02 91.72 8.48 6,232.78 6,085.48 3,260.28 -5,251.85 5,932,971.89 1,615,688.53 1.79 1,789.91 MWD+IFR-AK-CAZ-SC (7) 13,662.82 91.48 8.11 6,230.16 6,082.86 3,353.07 -5,238.32 5,933,064.63 1,615,702.30 0.47 1,883.04 MWD+IFR-AK-CAZ-SC (7) 13,757.69 92.58 6.51 6,226.80 6,079.50 3,447.10 -5,226.26 5,933,158.62 1,615,714.60 2.05 1,976.99 MWD+IFR-AK-CAZ-SC (7) 13,852.49 92.52 7.30 6,222.59 6,075.29 3,541.12 -5,214.88 5,933,252.60 1,615,726.23 0.83 2,070.75 MWD+IFR-AK-CAZ-SC (7) 13,947.88 90.83 7.50 6,219.80 6,072.50 3,635.67 -5,202.59 5,933,347.11 1,615,738.75 1.78 2,165.26 MWD+IFR-AK-CAZ-SC (7) 14,042.34 90.00 7.47 6,219.11 6,071.81 3,729.32 -5,190.29 5,933,440.72 1,615,751.30 0.88 2,258.90 MWD+IFR-AK-CAZ-SC (7) 14,136.63 88.32 9.07 6,220.50 6,073.20 3,822.62 -5,176.73 5,933,533.97 1,615,765.10 2.46 2,352.53 MWD+IFR-AK-CAZ-SC (7) 14,231.28 85.61 11.73 6,225.51 6,078.21 3,915.57 -5,159.67 5,933,626.87 1,615,782.39 4.01 2,446.72 MWD+IFR-AK-CAZ-SC (7) 14,326.47 82.79 15.04 6,235.13 6,087.83 4,007.67 -5,137.76 5,933,718.91 1,615,804.54 4.55 2,541.37 MWD+IFR-AK-CAZ-SC (7) 14,421.97 84.65 17.28 6,245.58 6,098.28 4,098.84 -5,111.34 5,933,810.00 1,615,831.19 3.04 2,636.26 MWD+IFR-AK-CAZ-SC (7) 14,515.58 86.61 20.50 6,252.71 6,105.41 4,187.13 -5,081.13 5,933,898.20 1,615,861.63 4.02 2,729.37 MWD+IFR-AK-CAZ-SC (7) 14,610.34 87.98 20.34 6,257.18 6,109.88 4,275.84 -5,048.10 5,933,986.81 1,615,894.88 1.46 2,823.60 MWD+IFR-AK-CAZ-SC (7) 1/28/2016 11:12:33AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-13 Wellbore: 2S-131-1 Design: Rig: 2S -13L1 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) (°) (1) (usft) (usft) (usft) 14,704.49 89.15 19.91 6,259.54 6,112.24 4,364.21 14,799.41 89.41 19.22 6,260.73 6,113.43 4,453.64 14,895.32 91.25 18.38 6,260.18 6,112.88 4,544.43 14,989.43 91.31 18.21 6,258.08 6,110.78 4,633.76 15,083.19 91.41 17.67 6,255.85 6,108.55 4,722.94 15,179.49 91.48 17.08 6,253.42 6,106.12 4,814.81 15,274.31 91.44 16.03 6,251.01 6,103.71 4,905.67 15,367.68 91.51 15.84 6,248.61 6,101.31 4,995.42 15,462.72 91.58 15.61 6,246.04 6,098.74 5,086.87 15,558.50 91.96 15.61 6,243.08 6,095.78 5,179.08 15,653.21 91.48 15.24 6,240.24 6,092.94 5,270.33 15,749.41 91.07 15.44 6,238.10 6,090.80 5,363.08 15,844.81 91.75 15.94 6,235.75 6,088.45 5,454.90 15,938.66 92.06 16.67 6,232.63 6,085.33 5,544.92 16,031.05 92.51 16.66 6,228.95 6,081.65 5,633.36 16,123.74 92.10 18.02 6,225.22 6,077.92 5,721.77 16,220.59 91.34 19.37 6,222.31 6,075.01 5,813.46 16,316.73 91.00 20.77 6,220.35 6,073.05 5,903.74 16,410.44 91.17 21.14 6,218.58 6,071.28 5,991.24 16,505.92 91.00 21.15 6,216.77 6,069.47 6,080.27 16,599.43 91.34 21.04 6,214.86 6,067.56 6,167.50 16,694.27 91.96 21.19 6,212.13 6,064.83 6,255.93 16,785.89 92.34 21.77 6,208.69 6,061.39 6,341.13 16,867.00 92.34 21.77 6,205.38 6,058.08 6,416.39 Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2S-13 Rig: 119.8+27.5 @ 147.30usft(Doyon 141) Rig: 119.8+27.5 @ 147.30usft (Doyon141) True Minimum Curvature OAKEDMP2 -4,894.62 5,934,433.47 1,616,049.50 -4,865.87 5,934,525.26 1,616,078.48 -4,838.87 5,934,616.04 1,616,105.72 -4,813.24 5,934,705.72 1,616,131.58 -4,787.49 5,934,797.09 1,616,157.56 -4,761.73 Map Map -4,736.55 +E/ -W Northing Easting DLS (usft) (ft) (ft) (°/100-) -5,015.72 5,934,075.09 1,615,927.49 1.32 -4,983.94 5,934,164.43 1,615,959.50 0.78 -4,953.03 5,934,255.13 1,615,990.64 2.11 -4,923.49 5,934,344.38 1,616,020.40 0.19 -4,894.62 5,934,433.47 1,616,049.50 -4,865.87 5,934,525.26 1,616,078.48 -4,838.87 5,934,616.04 1,616,105.72 -4,813.24 5,934,705.72 1,616,131.58 -4,787.49 5,934,797.09 1,616,157.56 -4,761.73 5,934,889.22 1,616,183.55 -4,736.55 5,934,980.40 1,616,208.97 -4,711.11 5,935,073.08 1,616,234.65 -4,685.32 5,935,164.82 1,616,260.67 -4,658.98 5,935,254.76 1,616,287.24 -4,632.51 5,935,343.13 1,616,313.93 -4,604.91 5,935,431.45 1,616,341.76 -4,573.88 5,935,523.05 1,616,373.03 -4,540.89 5,935,613.24 1,616,406.24 -4,507.39 5,935,700.64 1,616,439.97 -4,472.95 5,935,789.58 1,616,474.63 -4,439.30 5,935,876.71 1,616,508.50 -4,405.15 5,935,965.05 1,616,542.88 -4,371.63 5,936,050.15 1,616,576.62 -4,341.57 5,936,125.32 1,616,606.87 0.59 0.62 1.11 0.22 0.25 0.40 0.64 0.47 0.88 0.84 0.49 1.53 1.60 1.50 0.43 0.18 0.38 0.67 0.76 0.00 Vertical Section (ft) Survey Tool Name 2,917.34 MWD+IFR-AK-CAZ-SC (7) 3,011.95 MWD+IFR-AK-CAZ-SC (7) 3,107.64 MWD+IFR-AK-CAZ-SC (7) 3,201.57 MWD+IFR-AK-CAZ-SC (7) 3,295.18 MWD+IFR-AK-CAZ-SC (7) 3,391.37 MWD+IFR-AK-CAZ-SC (7) 3,486.12 MWD+IFR-AK-CAZ-SC (7) 3,579.45 MWD+IFR-AK-CAZ-SC (7) 3,674.45 MWD+IFR-AK-CAZ-SC (7) 3,770.18 MWD+IFR-AK-CAZ-SC (7) 3,864.84 MWD+IFR-AK-CAZ-SC (7) 3,961.01 MWD+IFR-AK-CAZ-SC (7) 4,056.38 MWD+IFR-AK-CAZ-SC (7) 4,150.15 MWD+IFR-AK-CAZ-SC (7) 4,242.43 MWD+IFR-AK-CAZ-SC (7) 4,334.96 MWD+IFR-AK-CAZ-SC (7) 4,431.57 MWD+IFR-AK-CAZ-SC (7) 4,527.31 MWD+IFR-AK-CAZ-SC (7) 4,620.49 MWD+IFR-AK-CAZ-SC (7) 4,715.41 MWD+IFR-AK-CAZ-SC (7) 4,808.37 MWD+IFR-AK-CAZ-SC (7) 4,902.63 MWD+IFR-AK-CAZ-SC (7) 4,993.60 MWD+IFR-AK-CAZ-SC (7) 5,074.08 PROJECTED to TD 112812016 11:12:33AM Page 7 COMPASS 5000.1 Build 74 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. [l Yes ❑ No ! have checked to the best of my ability that the following data is correct: L.] Surface Coordinates n Declination & Convergence L] GRS Survey Corrections ❑ Survey Tool Codes Vincent DlgMalir sgm7 by Vhverrt :+gn DC�- Mmra o=SchlumbvW,, ou=scfilumterye, SLB DE: Osara�=5�=.�=1g mie791y�w[@3 as-ceaa Scott Brunswick,'.m,=R" u, Client Representative.� Date: 04 -Feb -2016 04 -Feb -3016 THE STATE of ALASKA I -I GOVERNOR BILL WALKER Graham Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S -13L1 Permit to Drill Number: 215-152 Sundry Number: 316-073 Dear Mr. Alvord: Alaska Oil and Conservation Commissiol 333 West Seventh Avenue Anchorage Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov 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, Cath P. Foerster Chair DATED this /04' -day of February, 2016. RBDMS LL- FEB 11 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AA(` Sri 2Rn j 0 ?nig 7 ',`,"SGC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑� Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Exploratory ❑ Development L Stratigraphic ❑ Service AP) 215-152 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. API Number. 50-103-20720-60-00 , 7. If perforating: 8 Well Name and Number. KRU 2S -13L1' What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑� / 9. Property Designation (Lease Number): . ADL 25603, 2559 10. Field/Pool(s): Kuparuk River Field 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): Casing Length Size MD TVD Burst Collapse Structural 78' 20" 106' 106' Conductor 78' 20" 106' 106' Surface 2807.7 13.375" 2835.6 2547.8 5020 2260 Intermediate 6631.84 10.75" 9318 6018 5210 2470 Production 10407.83 7.625" 10434.22 6320 6890 4790 Liner 6860.34 4.5" 16829.61 6234 8000 6350 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 4-1/2" x 3-1/2" L-80 9800 Packers and SSSV Type: FHL retrievable Packers and SSSV MD (ft) and TVD (ft): 9700 12. Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service [�] 14. Estimated Date for 2/3/2016 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ` GAS ❑ WAG ❑ GSTOR❑ a_�SPLUG ❑ 16. Verbal Approval: Date: 2/Z// L Commission Representative: (j! C jD/Z/,9 0 5,p),2 GINJ ❑ Op Shutdown V�� Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved scott brunswick @ 2634249 herein will not be deviated from without prior written approval. Contact Email scott.a.brunswick@co�com Printed Name Gra am (Chip) Alvord Title Alaska Drilling Manager Z. ^ l fa Signature Phone 265-6120 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 1 Other. �/Y7/� ��✓�Yvi Gc✓/7 0 f C -v b��Cl�� f r�p"S aP- L1 to 10 ciCi�C e5 vrne op -r vi-�it 7'--11 P75 w f t-1 p — �a? D A - IC z S. b Z (6) i� ar , Post Initial Injection MIT Req'd? Yes [:]No [:]3 kiC7 ,PTD Spacing Exception Required? Yes ❑ No Subsequent Form Required: l0 — d o APPROVED BY �Y — Approved by:4NTHE COMMISSION Date: Z, �Q V71 7-151 l ro PIQ Form 10-403 10-403 Revised 11/2015 Approved application is valid for 12 months frome date of approval. ORIGINAL Submit Form and Attachments in Duplicate RBDMS L-�- FEB 1 1 2016 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 2nd, 2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ConocoPhillips p Re: Sundry Permit -- Request to shut down operations and suspend drilling on 2S-13 Dear Sir or Madam: ConocoPhillips encountered problems pulling the whipstock assembly out of the 7-5/8" production casing after drilling to TD of the 2S-131-1 lateral. A total of 8 days of fishing have occurred to date trying to fish the whipstock out of the hole in order to complete the well as designed to no success. Doyon 141 is scheduled to drill two exploration wells, and perform workovers are Alpine this ice road season, therefore, the rig is needed off the 2S-13 well to move west. ConocoPhillips hereby requests approval to suspend current operations, run a kill string, and suspend the wellbore for a future return to fish the whipstock, regaining access to the 2S-13 lower lateral, and attempt to run the liner in the 2S-131-1 upper lateral & complete the well as permitted under 215-152. Current discussions are under way for the plan forward, the most likely scenario will be using Doyon 25 to complete 2S-13 either after it's current surface hole, or after completion of the 2S-03 well. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10-403 2. 2S-13 Suspension Procedure 3. 2S-13 Suspension Schematic Application information already on file with 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 Scott Brunswick at 263-4249 (Scott.A.Brunswick(a)-conocophillips.com) or Chip Alvord at 265-6120. Sincerely, Scotf Brunswick Drilling Engineer Doyon 141 2S-13 Suspension Procedures The proposed scope of work for this sundry application includes: 1. TIH with clean out BHA - mills, magnets, & junk baskets 2. Circulate and condition 7-5/8" annulus with 12.2 ppg kill weight brine (MPD measured formation pressure of 11.7-11.8 ppg while drilling laterals). 3. Perform 30 minute flow check with clean out BHA 4. POOH sideways & lay down clean out BHA 5. Run 3-1/2" tubing kill string with WLEG, 275D w/RHC plug in profile, 3-1/2" x 7-5/8" retrievable packer, & GLM for freeze protecting 6. Run kill string setting at 9800' MD 7. Land tubing on hanger 8. Drop ball & rod to set packer 9. Pressure up & set packer 10. Bleed off pressure, keeping 2000 psi on tubing 11. Pressure up on 7-5/8" x 4-1/2" OA & pressure test packer 12. Bleed off the 2000 psi tubing pressure & open GLM 13. Pump diesel freeze protect & allow to u -tube 14. Set BPV & test to 1000 psi for 10 minutes in direction of flow 15. Nipple down BOPE. 16. Nipple up tree & test to 5000 psi 17. LD any remaining DP 18. RDMO to exploration wells. 2S-13 ,�- Grassroots Horizontal A -Sand Injector Conoo Phillips Proposed Wellbore Schematic Last Edited: SAB -2/2/16 1 9,318' MD / 6,018' ND 3-1/2 x 7-5/8 FHL Retrievable Packer -9700' ' MD 3-%' EUEtubin tail -9800' HRZ 9,200' MD 15,963- ND Lower Kalubik (K-1 Marker):9,639' MD / 6,162' ND 20" Conductor to - 115' a a' f ' Whipstock Top of Window 9,915' MD / 6,250' TVD 16" Surface Hole a E a o; : . ---- ----,- ,-- _ - _ ;--- :..-_---- - ---- --- Kuparuk A4 .9 959 MD / 6 260_TVD ..... ... --. .. .. .-. 7-5 8" Flex Lock Liner Hanger/ ZXP w ' . � Kuparuk A3 10 250 MD 16 312 ND -- - ---- 4 ------------------------ Or 9e Pee 1 1 4-%" IBTM kill string 25-73 A3 TD 16,849' MD / 6,23TTVD Swell Packer @ 10494' ' Intermediate Casing Swell Packer @ 14392' Surface Casing 6-3/4" Production Hole - 13-3/8" 68# L-80 HYD 563 10,303' MD / 6,586' ND 2,835.6' MD / 2,547.8' TVD 12-1/4" X 13-1/2" Intermediate #1 Hole 10-3/4" TOC: 5,480' (at minimum 500' MD above C37) Q-37.6,840'MD/4,648'TVD .. - 4-%" 1BTM XO to 8-1W ELIE tubing tail:GrowlervAA Icetier : 7,222 mb l4:856`TVD WTI Stage tool for Ck Brine & Freeze Protect - Top:Caim; 8;206` MD ! 5,432ND - ... - .... .. :' -::. .:- To :Bermuda: i 8,360' MD-/ 5,518' TVD 7-5/8 TOC: 9,167' MD / 5,946' ND (at minimum 200' inside 10-3/4" liner) i 10-3/4" INT#1 Liner - 1 9,318' MD / 6,018' ND 3-1/2 x 7-5/8 FHL Retrievable Packer -9700' ' MD 3-%' EUEtubin tail -9800' HRZ 9,200' MD 15,963- ND Lower Kalubik (K-1 Marker):9,639' MD / 6,162' ND ...... ��� Top Kuparuk C 9,922' MD / 6,252' ND . f ' Whipstock Top of Window 9,915' MD / 6,250' TVD 9-7/8" Intermediate #2 Hole . ---- ----,- ,-- _ - _ ;--- :..-_---- - ---- --- Kuparuk A4 .9 959 MD / 6 260_TVD ..... ... --. .. .. .-. 7-5 8" Flex Lock Liner Hanger/ ZXP ...... .. . -MID, . � Kuparuk A3 10 250 MD 16 312 ND -- - ---- 4 ------------------------ Or 9e Pee 1 1 - 11 25-73 A3 TD 16,849' MD / 6,23TTVD Swell Packer @ 10494' ' Intermediate Casing Swell Packer @ 14392' 7-5/8" 29.7# L-80 Hyd563 Casing 10,434' MD / 6,320' 6-3/4" Production Hole TVD (89°) 9-7/8" Intermediate #2 Pilot Hole 10,303' MD / 6,586' ND Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, February 02, 2016 4:24 AM To: Brunswick, Scott A Subject: Re: 2S-131-1 PTD 215-152 Scott, When do you plan to return to the well? This may be an operations shutdown. You have verbal approval to suspend operations if that's what you decide. Please send the sundry over this morning. Thanx, Victoria Sent from my iPhone On Feb 1, 2016, at 1:51 PM, Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> wrote: Victoria We have been fishing for the whipstock in the 2S-131-1 well for the past 8 days without success. We are preparing to run in hole with one more fishing BHA to attempt retrieval. If this run is unsuccessful we may be asking for a sundry to suspend operations and come back to finish the well at a later date. The rig is scheduled to drill 2 exploration wells out on the ice and we must release it to go there. I've attached the paperwork I drew up for the Sundry, and wanted to give you a chance to look at it as we will probably be making the call to suspend tonight. Given the attached, would we have permission to move forward with the attached suspending procedure? I'd rather not have to wake any of you up in the middle of the night. Once the call is made, I've got the paperwork printed & signed here and can have a currier bring it over to you after we choose the suspend, or if we get the whipstock and can attempt to complete the well as permitted. Thanks Scott <2S-13 Sundry to suspend 10-403.pdf> <2S-13 Sundry to Suspend Schematic.pdf> <2S-13 - Sundry to Suspend Operations Feb 2016.pdf> PT -0 2 Loepp, Victoria T (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, February 04, 2016 4:53 PM To: Brunswick, Scott A Cc: Bearden, J Daniel; Loepp, Victoria T (DOA) Subject: RE: 2S-131_1 PTD 215-152 (sundry to suspend) Follow Up Flag: Follow up Flag Status: Flagged Scott, As per our phone call AOGCC will approve moving off well as proposed with tubing and packer installed. The Packer appears to leaking but there is KWF present in both IA and tubing . As condition of approval have OA and IA monitored daily and forward pressures to the Commission ( Victoria and myself) on a weekly basis. A 10-407 report should be submitted within 30 days unless you move back on the well before that time. Victoria may request a new sundry with your plans to fix well and finish the completion phase. At the least notify us of your intent to move back on the well by email. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.aov). From: Brunswick, Scott A [mailto:Scott.A.BrunswickC@conocophillips.com] Sent: Thursday, February 04, 2016 2:59 PM To: Schwartz, Guy L (DOA) Cc: Bearden, J Daniel Subject: FW: 2S-131_1 PTD 215-152 (sundry to suspend) Importance: High Hi Guy I don't want to bypass Victoria, but I've not been able to speak with her and need to make sure this is OK before we move forward. We're filling the time cleaning & scrubbing the rig in the mean time. Thanks Scott From: Brunswick, Scott A Sent: Thursday, February 04, 2016 12:40 PM To: Loepp, Victoria T (DOA) (victoria.loepp@alaskagov) Cc: Alvord, Chip; Bearden, J Daniel; Hayden, Philip; Simek, Jill Subject: 2S-131-1 PTD 215-152 (sundry to suspend) Importance: High Victoria We ran our tubing kill string with the FHL packer though the night, set the tubing on the hanger, tested the seals, dropped the ball & rod and set the packer. All indications are the packer was set properly. We pressured up on the tubing and got a good test. We bled the tubing pressure down to —2000 psi and pressured up the tubing x 7-5/8" annulus to test the packer, it leaked off at about 1500 psi in one hour. I've attached the chart of the test to this e- mail. All indications are that the packer is leaking off into the open upper lateral. With pressure on the tubing x 7-5/8" annulus we have checked the 7-5/8" x 10-3/4"/13-3/8" annulus and see no pressure; this further indicates the pressure is not in communication with other annuli. In order to nipple down the BOP & nipple up the tree we will have two barriers, the kill weight fluid flow checked, and the BPV tested in the direction of flow through the shear out valve. Our analysis shows that there is no compromise to reservoir containment and that we have not been able to identify any significant risk in leaving the well this way or any regulation that we are not adhering to. Our question is regarding the packer leak. This well will not be used for production or injection in its current state. The current plan of work is to run a camera on coil tubing while the rig is off to get a look at the fish in hole. After that the plan is to bring a rig back to pull the tubing and packer for remedial work to repair the well, and complete it as originally permitted. If there are any issues that you would like to discuss please give me a call. Thanks Scott 907-227-8499 The maximum potential surface pressure (MPSP) while drilling 2S-13 is calculated using an MPD measured reservoir pressure of 3,806 psi (11.6 ppg,), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A3 sand at 6,310' TVD: A Sand Estimated. BHP = 3,806 psi A Sand estimated depth = 6,310' TVD Gas Gradient = 0. 10 psi/ft as per 20 AA 25.005 (c)(4)(A) Hydrostatic of full gas column = 631 psi (6,310' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 3,175 psi (3,806 psi — 631 psi) 13-3/8" Surface FIT = 15.0 ppg w/9.8 ppg mud @ 2550' TVD 10-3/4" Liner FIT = 15.0 ppg w/10.0 ppg mud @ 6018' TVD 7-5/8" LOT = 14.6 ppg w/10.5 ppg mud @ 6320' TVD 7-5/8" Window LOT = 13.4 ppg w/12.0 ppg brine @ 6250' TVD Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Tuesday, February 02, 2016 6:32 AM To: Loepp, Victoria T (DOA) Subject: RE: 2S-131-1 PTD 215-152 Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria, we have a few choices that are in discussion 1. Finish the surface hole with Doyon 25 and come to the 13 well this weekend 2. Finish the well Doyon 25 is one and come to 13 in 3 weeks 3. Wait until the end of the 2S program to finish 13 4. We will also be looking to see if we could bring Nabors 7ES over to pull the fish, then complete the well with Doyon 25. From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.gov] Sent: Tuesday, February 02, 2016 4:24 AM To: Brunswick, Scott A Subject: [EXTERNAL]Re: 2S-131-1 PTD 215-152 Scott, When do you plan to return to the well? This may be an operations shutdown. You have verbal approval to suspend operations if that's what you decide. Please send the sundry over this morning. Thanx, Victoria Sent from my iPhone On Feb 1, 2016, at 1:51 PM, Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> wrote: Victoria We have been fishing for the whipstock in the 2S-131-1 well for the past 8 days without success. We are preparing to run in hole with one more fishing BHA to attempt retrieval. If this run is unsuccessful we may be asking for a sundry to suspend operations and come back to finish the well at a later date. The rig is scheduled to drill 2 exploration wells out on the ice and we must release it to go there. I've attached the paperwork I drew up for the Sundry, and wanted to give you a chance to look at it as we will probably be making the call to suspend tonight. Given the attached, would we have permission to move forward with the attached suspending procedure? I'd rather not have to wake any of you up in the middle of the night. Once the call is made, I've got the paperwork printed & signed here and can have a currier bring it over to you after we choose the suspend, or if we get the whipstock and can attempt to complete the well as permitted. Thanks Scott <2S-13 Sundry to suspend 10-403.pdf> <2S-13 Sundry to Suspend Schematic.pdf5 <2S-13 - Sundry to Suspend Operations Feb 2016.pdf> Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, February 03, 2016 9:09 AM To: Loepp, Victoria T (DOA) Cc: Bearden, J Daniel Subject: 2S-13 Operations Shutdown Attachments: 2S-13 - Sundry to Suspend Operations Feb 2016.pdf, 2S-13 Sundry to suspend 10-403.pdf, 2S-13 Sundry to Suspend Schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria We changed the shutdown/suspension plan slightly so that we can use coil to try to get a camera picture of the whipstock while the rig is gone and I have attached the updated paperwork here. Ann has the signed hard copies and will be sending them over to you today. We should start running the tubing kill string today. My cell is 227-8499 if you have any questions. Thanks Scott 2S-13 Grassroots Horizontal A -Sand Injector Proposed Wellbore Schematic 20" Conductor to - 115' 4-f' IBTM kill string Surface Casino 133/8" 68# L 80 HYD 563 2,835.6' MD / 2,547.8' TVD 10-3/4" TOC: 5,480' (at minimum 500' MD above C37) ConocoPhillips Last Edited: SAB -2/2/16 16" Surface Hole 12-1/4" X 13-1/2" Intermediate #1 Hole 4-h" IBTM XO to 3-W EUE tubing tail WTI Stage tool for Cl Brine & Freeze Protect 7-5/8 TOC: 9,167' MD / 5,946' TVD (at minimum 200' inside 10-3/4" liner) 103/4"INT #1 Liner I n-114" AS 59 1 -80 Hyd521 9,318' MD / 6,018' TVD 3-% x 7-5/8 FHL Retrievable Packer -9700' S MD i 3-14' EUE tubing tail 0 -9800' Top Kuparuk C 9,922' MD / 6,252' TVD } Whipstock Top of Window 9,915' MD / 6,250' TVD C-37:6,840' MD /4,648' TVD Top Caim: 8,206' MD / 5,432' TVD )o Bermuda: 8.360' MD / 5.518' TVD HRZ: 9,200' MD / 5,963' TVD Lower Kalubik (K-1 Marker):9,639' MD / 6,162' TVD 9-7/8" Intermediate #2 Hole ' - _ Kuparuk A3: 10,250' MD / 6,312' TVD a- - --- -------------- — -- - - ---'--------.--------------------- ---moo V� -' snoe ---- - - ----- - 2S-13 A3 70:16,849' MD / 6,233' TVD Swell Packer Q 10164' Swell Piker � 11992 Intermediate Casino 7-5/8" 29.7# L-80 Hyd563 Casing 10,434' MD / 6,320' 6-3/4" Production Hole I TVD (890) 9-7/8" Intermediate #2 Pilot Hole 10,303' MD / 6,586' TVD ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 2nd, 2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ConocoPhillips Re: Sundry Permit -- Request to shut down operations and suspend drilling on 2S-13 Dear Sir or Madam: ConocoPhillips encountered problems pulling the whipstock assembly out of the 7-5/8" production casing after drilling to TD of the 2S-131-1 lateral. A total of 8 days of fishing have occurred to date trying to fish the whipstock out of the hole in order to complete the well as designed to no success. Doyon 141 is scheduled to drill two exploration wells, and perform workovers are Alpine this ice road season, therefore, the rig is needed off the 2S-13 well to move west. ConocoPhillips hereby requests approval to suspend current operations, run a kill string, and suspend the wellbore for a future return to fish the whipstock, regaining access to the 2S-13 lower lateral, and attempt to run the liner in the 2S-131-1 upper lateral & complete the well as permitted under 215-152. Current discussions are under way for the plan forward, the most likely scenario will be using Doyon 25 to complete 2S-13 either after it's current surface hole, or after completion of the 2S-03 well. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10-403 2. 2S-13 Suspension Procedure 3. 2S-13 Suspension Schematic Application information already on file with 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 Scott Brunswick at 263-4249 (Scott.A.Brunswick(&-conocophillips.com) or Chip Alvord at 265-6120. Sincerely, Scott Brunswick Drilling Engineer Doyon 141 2S-13 Suspension Procedures The proposed scope of work for this sundry application includes: 1. TIH with clean out BHA - mills, magnets, & junk baskets 2. Circulate and condition 7-5/8" annulus with 12.2 ppg kill weight brine (MPD measured formation pressure of 11.7-11.8 ppg while drilling laterals). 3. Perform 30 minute flow check with clean out BHA 4. POOH sideways & lay down clean out BHA 5. Run 3-1/2" tubing kill string with WLEG, 275D w/RHC plug in profile, 3-1/2" x 7-5/8" retrievable packer, & GLM for freeze protecting 6. Run kill string setting at 9800' MD 7. Land tubing on hanger 8. Drop ball & rod to set packer 9. Pressure up & set packer 10. Bleed off pressure, keeping 2000 psi on tubing 11. Pressure up on 7-5/8" x 4-1/2" OA & pressure test packer 12. Bleed off the 2000 psi tubing pressure & open GLM 13. Pump diesel freeze protect & allow to u -tube 14. Set BPV & test to 1000 psi for 10 minutes in direction of flow 15. Nipple down BOPE. 16. Nipple up tree & test to 5000 psi 17. LD any remaining DP 18. RDMO to exploration wells. Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Friday, January 15, 201610:35 AM To: Loepp, Victoria T (DOA) Cc: Bearden, J Daniel; Klem, Adam Subject: 2S-13 PTD 215-151 & 2S-131_1 PTD 215-152 Follow Up Flag: Follow up Flag Status: Flagged Good morning Victoria A quick update of the operations on 2S-13 (PTD 215-151). We've completed the lower lateral and have set the liner successfully. We are currently dressing off the window for the upper, lateral (2S -13L1 PTD 215-152). I've attached a schematic to show the current well status. One item that was asked of me last night is if there is an issue that the top of the window is exposed to a small amount of lower Kalubik/Upper C sand interface with regards to the injection; as with this multi -lateral system the 7' section will be exposed to injection pressure. My answer was I didn't think so as the shale is part of the confining layer, and the lower 10' TVD of shale is affected by injection pressure whenever injecting into the Kuparuk sands. The final completion design will install a packer within 200' MD of the top of the window. Thanks Scott 1 �'Ar•M' TM•rV rers!' l. . rrr....rrr. "" Conowphillips ,II.lei- ttAi.E 1ANIM iNi' Sharktooth 7.518" Injector B,4 • CVk Tsai ... 2S-13 As Planned Dual -Lateral Completion .. .... LstttYi tntri MONO 044) With .. c?rvMnt pfd IwiatoR �.�� nl. rAn ,.q.�-tea..:-aw e✓wae M 4!.s+rW (m,wvy t, br6 ♦a. q,..,u t+Itcrol.Entr N*dwhr1LEM1 W � r br• dr f r+rrr�. tgidlylrlRRt Trf9f11iClt!7R3 �, ... erfa ss.¢N owns. J-� y rrxr \ sW X�se e' kH.yr.. /Y"te 'r't`P•' �_�., � �` •Yr.jar ..ys r w... .ra.tivae a is..rr.e.«a ...wr.ww.r. •. ,.r.•M ar+r. anZwwr. xr Fa'+vwr .4prwwgA J,r �+qw+ ,�` �._�• ��� r+asu...orrr m. a.. .r.w,. r.....,l.r.... sw-craw s_aR .,� .. ..r.. � sYmr ' rw�..w�, urs b `A3' Sand Latrni i,.•rw�--rw,.l.,t......c. Mw.ew. �*'"dy +:�-,M,MnewrMurs �rY ri.y wars Y w';.... .YY ...wxw f Mi I irr iw }i.Naa W Iwr ...1ifo M S - 64�' T�+�l rr+. tFul �rtY Ar.maasYl wiwYt 1.1 � N1r10S \+f'1w m11n'w'C _'_.,+.rywrrr++ r•w• ""r" �rawo�.rrw _ _ _ _—_ _ r�.. �r ___.— �• _—_ 1 25-13 Recorded memory log from Intermed+ate 2 section showing Lower Kalubik, Kuparuk C, and A4 Sand Top of L1 window= 9,915' and Top of Kuparuk C = 9,922' and Approximately 7' of Lower Kalubik (shale) open to the top of the window. 2 THE STATE of .. c x L A S -K—A- GOVERNOR BILL WALKER Graham (Chip) Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S -13L1 ConocoPhillips Alaska, Inc. Permit No: 215-152 Surface Location: 3099.9' FNL, 1672.2' FEL, SEC. 17, TION, R8E, UM Bottomhole Location: 1978.8' FNL, 575.75' FEL, SEC. 7, T1ON, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 215-151, API No. 50-103- 20720-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, dW44.1 / 44414� Cathy V Foerster Chair DATED this 23 day of October, 2015. I�CVCI v cv OCT 12 2015 STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMM ON PERMIT TO DRILL N 'z0 AAC 25.005 ,u% 1a. Type of Work: 1b. Proposed Well Class: Development -Oil r Service - Winj 0. Single Zone ' 1c. Specify if well is proposed for: Drill 1 o- Lateral ❑� Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone L Coalbed Gas ❑ Gas Hydrates ❑ Redrill [J Reentry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q , Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 + KRU 2S -13L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16839, TVD: 6318 Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 3099.9' FNL, 1672.2' FEL, SEC17, T10N, R8E, UM ° ADL 25603, 25590 , Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3186.8' FNL, 2171.4' FEL, Sec18, T10N, R8E, UM 2677, 2678, 2675 9/18/2015 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1978.8' FNL, 575.75' FEL, Sec7, T10N, R8E, UM 2512, 2501 , 3000' to ADL386051 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above A 148 feet 15. Distance to Nearest Well Open Surface: x-480,898.10' y-5,929,948.79' Zone- 4 - GL Elevation above I\ 120 feet to Same Pool: 2681' To 2M-34 16. Deviated wells: Kickoff depth: ,10150 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90.7 degrees Downhole: 3751 , Surface: 3119 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 20" 78.7# H-40 Welded 78' 28' 28' 106' 106' Pre-installed & cemented 16" 13.375" 68# L-80 Hydril 563 2939' 28' 28' 2967' 2650.0' 222 sx 12 ppg 1420 sx 11 ppg 12.25"x13.5" 10.75" 45.5# L-80 Hydril 521 6732' 2767' 2504' 9499' 6091' 1235 sx 15.8 ppg Class G 9.875" 7.625" 1 29.7# L-80 Hydril 563 10854' 28' 28' 10882' 6368' 1 410 sx 15.8 Class G 6.75" 4.5" 11.6# 1 L-80 JIBTM 16811' 28' 28' 16839' 6318' 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): N/A Perforation Depth TVD (ft): N/A 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and correct. Scott Brunswick @ 263-4249 Contact Scott. a. bru nswick(ab-cop. com Email Printed Name Graham (Chip) Alvord Title Alaska Drilling Manager Signature Phone 265-6120 Date 10 (I L' 24 I15 - Commission Use Only Permit to Drill is API Number: Permit Approval See cover letter for other Number: a 5- 50- (0 Date: )O 1 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: Other: 1-3 p P ¢7-S 71 /-a d? 51} D /2 5 /_9 Samples req'd: Yes No 4 Mud log req'd: Ye s❑ No[✓f ff h ✓t U! Gl r' p VC VC "fiY " to 2- b C? P51jH2S measures: Yes No ❑ Directional svy req'd: Yes[. No❑ -5-ta trw w I fn z 5 5 �d J� t T - I h Spacing exception req'd: Yes ❑ No [J� Inclination -only svy req'd: Yes No[ r APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date:/O V'rL /ZO/! �� aK� /0//3/I�S 0 Submit Form and Form 10-401 (Revised 10/2012) e AL onths from the date of pproval (20 AAC 25.005(g)) Attachments in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 263-4249 Email: scott.a.brunswick(a)-conocophillips.com October 12, 2015 Alaska Oil and Gas Conservation Commission Application for Permit to Drill, Well 2S-131-1 Saved: 12 -Oct -15 ECEM 333 West 7t' Avenue, Suite 100 OCT 12 2015 Anchorage, Alaska 99501 Re: Application for revised Permit to Drill Well 2S -13L1 A4 Sand Pre -Produced Injector. ZAOGCV Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a revised permit to drill an onshore pre -produced injector well from the 2S pad. The expected spud date for this well is November 15, 2015. It is planned to use rig Doyon 141 This request for a revision to the previously submitted permit application is due changing the casing design to address the weak overburden that has been encountered on the 2S pad. 2S -13L1 is planned to be the upper lateral horizontal well in the Kuparuk A4 sand in parent well 2S -13.2S-13, & 2S- 13PB 1 submitted on a previous revised permit to drill, will have be drilled to determine A4 sand presence and determination to complete the well as a dual lateral; if the A4 pay is absent the well will be completed as a single lateral in the A3 sand. When 2S -13L1 is commenced the lower A3 lateral will have been drilled & liner run to TD. A whipstock exist will have been commenced at the end of the 2S-13 PTD. The 2S -13L1 lateral will be a 6-3/4" hole geo-steered to 16,839' MD / 6,318' TVD in the A4 & completed with a 4-1/2" slotted liner. A LEM will be run for upper lateral access & 4-1/2" tubing will tie the liners back to surface. 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 (scott.a.brunswick Conoco hi or Chip Alvord at 265-6120. Sincerely,� Scott Brunswick Drilling Engineer contact Scott Brunswick at 263-4249 Application for Permit to Dill Document Kuparuk Well 2S-131-1 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 2S -13L1 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 identifying 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 3099.9' FNL, 1672.22 FEL, Sec 17, T ION, R008E, UM NGS Coordinates Northings: 5,929,948.8' Eastings: 480,898.1 ' RKB Elevation 148' AMSL Pad Elevation 120' AMSL Location at Surface Casing 3773.4' FNL, 2481.9' FEL, Sec 17, T10N, R008E, UM NGS Coordinates Northings: 5,929,277.4' Eastings: 480,088.9' Measured Depth, RKB: 2,967' Total Vertical Depth, RKB: 2,650' Total Vertical Depth, SS. 2,502' Location at Intermediate #1 10-3/4" Liner 3783.6' FNL, 2056.9' FEL, Sec 18, T10N, R008E, UM NGS Coordinates Northings: 5,929,281.61' Eastings: 475,234.27' Measured Depth, RKB: 9,499' Total Vertical Depth, RKB: 6,091' Total Vertical Depth, SS: 5,943' Location at Top of 3186.8' FNL, 2171.4' FEL, Sec 18, T10N, R008E, UM Productive Interval (Ku aruk C Sand) NGS Coordinates Measured Depth, RKB: 10,150' Northings: 5,929,878.74' Eastings: 475,119.52' Total Vertical Depth, RKB: 6,311' Total Vertical Depth, SS: 6,163' Location at Intermediate #2 7-5/8" Casing 2461.77' FNL, 2106.9' FEL, Sec 18, TION, R008E, UM NGS Coordinates Northings: 5,930,603.48' Eastings: 475,183.72' Measured Depth, RKB: 10,882' Total Vertical Depth, RKB: 6,368' Total Vertical Depth, SS. 6,220' Location at Total Depth 1978.8' FNL, 575.75' FEL, Sec 7, T10N, R008E, UM NGS Coordinates Northings: 5,936,361.03' Eastings: 476,711.89' Measured Depth, RKB: 16,839' Total Vertical Depth, RKB: 6,318' Total Vertical Depth, SS. 6,170' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be 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 wells 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) 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: (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 141. 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, except for 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 -13L1 is calculated using an estimated maximum reservoir pressure of 3,751 psi (11.5 ppg, based on Shark Tooth #1 appraisal well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,324' TVD: A Sand Estimated. BHP = 3 751 psi 'r A Sand estimated depth = 6,324' TVD Gas Gradient = 0.10 psi/ft Hydrostatic of full gas column = 632 psi MPSP = BHP — gas column = 3,119 psi (B) data on potential gas .-ones; as per 20 AAC 25.005 (c)(4)(A) (6,324' TVD * 0.10 psi/ft) (3,751 psi — 632 psi) The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; See attached 2S -13L1 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 conducting formation integrity tests, as required under 20 AAC 25.03069; 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 be 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 arty slotted liner, pre perforated liner, or screen to be installed Casing and Cement Program Casing and Cementin Y, Program Csg/Tbg Hole Size Weigh Grade Conn. Length Top MD/TVD Btm MD/TVD Cement Program OD (in) (in) t (Ibfft) 10.5-11.8 PV (ft) (ft) (ft) 25-30 20 36 78.7 H-40 Welded 78 Surf 106/106 Pre-installed & cemented 5-8 10 minute Gel 30-50 10-18 Hydril 5-12 API Filtrate NC Cement to Surface with 13-3/8 16 68 L-80 563 2,939 Surf 2,967 / 2,650 1,420 sx DeepCRETE Lead 11.0 ppg, 9.0-10.0 9.0-10.0 9.5-10.0 222 sx Dee CRETE Tail Slurry 12.0 ppg 10-3/4 12-1/4 x 13- 45.5 L-80 HydrilCement 6,732 2,767 / 2,504' 9,499 / 6,091 to above C-37 1/2 521 1235 sx 15.8 ppg Class G w/Gasblok 7-5/8 9-7/8 29.7 L-80 Hydril 10,854 Surf 10,882 / 6,368 Cement to inside 10-3/4" liner 563 410 sx 15.8 ppg Class G 4-1/2 6-3/4 11.6 L-80 IBTM 6,672 10,167 / 6,314 16,839 / 6,318 N/A 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 d/vetter system as required by 20 AAC 25.035, unless this requirement /s waived by the commission under 20 AAC 25.035(h)(2); Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033, Mud Program Summary Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Surface 16" Hole 13-3/8" Casing Intermediate #I 12-1/4" x 13-1/2" Hole 10-3/4" Liner Intermediate 42 & Pilot Hole 9-7/8" Hole 7-5/8" Casing Production 6-3/4" Hole 4-1/2" Liner Mud System Spud Mud LSND (WBM) LSND (WBM) Flo-Thru (WBM) Density 9.3-9.8 ✓ 9.6-10.5 10.5-11.8 10.5-11.8 PV 30-50 10-20 10-20 25-30 YP 40-80 16-24 16-24 16-24 Initial Gel 30-50 10-12 10-12 5-8 10 minute Gel 30-50 10-18 10-18 5-12 API Filtrate NC < 6 < 6 < 6 HTHP Fluid Loss at 160F N/A < 10 <10 <10 pH 9.0-10.0 9.0-10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 141 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, exceptfor an item already on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. 1. End PTD for 25-13 & begin PTD for 2S -13L1 once on bottom with 6-3/4" drilling assembly. 2. Directionally drill 6-3/4" hole geosteering though the Kuparuk A4 sand to TD 16,839' MD as per directional plan (wp13). 3. Circulate hole clean and POOH. 4. Lay down Production BHA. 5. Pick up & make up hook (lug retrieving tool), string magnet, bumper sub, jars, float sub and MWD (directional only). 6. TIH 7. Break circulation & orient whipstock retrieving hook with MWD & hook the whipstock. 8. Pull whipstock free. 9. CBU X2. 10. Monitor well for flow. 11. POOH & lay down BHA & whipstock. 12. Make up bent joint to 2 joints of blank liner. 13. Run remainder of slotted liner in hole. 14. Rig up false rotary. 15. Pick up HOOK hanger assembly & make up lower pup joint to MWD. 16. Remove false rotary table & make up hook hanger to liner. 17. Slowly pick up w/out pulling the slips & verify that the running assembly is fully engaged. 18. Run liner assembly in hole on 4" DP. 19. With liner shoe 45 ft above the casing exit, record the up & down weights & torque required to rotate. 20. Slowly lower the liner into the well & watch for increase in drag to confirm liner entered the 2S -13L1 lateral. 3.20.1. If tag top of liner in 25-13, pullback, rotate to adjust bend into 2S -13L1. 21. Run the liner to bottom until the hook hanger is 45 ft above the casing exit. 22. Orient with the MWD & rotate the string until the hook on the hook hanger is 180° from the casing exit. 23. Run in hole slowly & engage the hook hanger on the casing exit. 24. Set down 20 Klbs on the hook hanger. 25. Drop the ball & pump down getting ball on seat, don't exceed 1.5 bbl/min or 500 psi to prevent premature release of the HRD-E. 26. Increase the pressure & shear out the ball seat. 27. Shut down the pumps. 28. Pick up 3-5 ft., if no over pull this confirms HRD-E running tool has released. 29. Slowly retrieve the running string until it has cleared the hanger. 30. Flow check well, POOH, & lay down running gear. 31. Rig up & run the lower seal assembly to the tubing string. 32. Make up LEM running string, liner top packer, & running tool. 33. Run assembly in hole on 4" DP to -50 ft. above setting. 34. Take torque reading, pick up, slack off weights. 35. Break circulation & orient LEM with S1imPulse MWD. 36. With LEM aligned properly run in slowly stabbing in seal assembly and latch LEM. 37. Drop ball for liner top packer setting. 38. Increase pressure & set packer. 39. Release running tool. 40. Check Pick up weight to confirm LEM located on the hook hanger. 41. Pressure test casing. 42. Flow check well, POOH, & lay down running gear. 43. Rig up & run upper completions string. 44. Land hanger & run in lock down screws. 45. Test upper & lower seals to 250 psi & 5000 psi for 10 minutes. 46. Monitor well for flow for 15 minutes 47. Nipple down BOPE, nipple up tree and test. 48. Freeze protect well with diesel and install BPV. 49. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal _Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) 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 authorisation under 20 AAC 25.080 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 Cement Summaries 2S-13 Grassroots Horizontal A -Sand Injector Proposed Wellbore Schematic 4-1/V tree, top joint is 4-1/:" 12.6# IBTM 20" Conductor to — 115' Surface Casino 13-3/8" 68# L-80 HYD 563 2,967' MD / 2,650' TVD ConocoPhillips Last Edited: SAB -10/7/15 16" Surface Hole 12-1/4" X 13-112" Intermediate #1 Hole 10-3/4" TOC: 6,700' MD / 4,571' TVD (at minimum 500' MD above C37) C-37:8854'MD/4654'TVD �� Gtdwler-AA lceber .7085"MD/4781TVD WTI Stage tool for ClI Brine & Freeze Protect Top Catm; 6,226M015,40TV0 988E), MB Top Bermudw:8;425'1VID-15554'TVD 7-5/8 TOC: 9,200' MD / 5,957' TVD (-200' inside 10-3/4" liner) 10-3/4" INT #1 Liner -_ 10-3/4"45:5# L-80 Hyd521 9,499 hiBi6691'-Ta - HRZ 9,383' MD / 6;041' TVD Lateral Entry Module (LEM): Baker, w/seal assembly & ZXP Lower Kalubik (K-1 Marker) 9,876' MO / 6,238' TVD packer above Top Kuparuk C predicted @ 10,149.75' MD / 6,310.8' TVD -�-, Whipstock Top of Window 10,150' MD / 6,311' TVD 9-7/8" Intermediate #2 Hole _ _.,`- _ `------- ---- '---- KuparukA4 10216'_'MO/6324_TVD ----- - ---- -- - - " 7-5 8" Flex Lock Liner Han er / ZXP - - "- Kuparuk:A31070)!MBI8364'TVD , sno. 2S-.13A3TD 16,849 MD/0,358 TVD I I 6.88"•4 -'/."swell Packer Intermediate Casino J 7-5/8" 29.7# L-80 Hyd563 Casing 10,882' MD / 6,368' 6-3/4" Production Hole I TVD (90) NOTE: Swell Packer will be adjusted as necessary using microscope and periscope data 9-7/8" Intermediate #2 Pilot Hole 10.303' MD / 6.573' TVD Attachment 2 — 2S-13 Diverter Layout Diagram Attachment 3 — 2S-13L1 Directional Plan DI S-1 3LI w13[Megalodonl- 6.879 Plan Summap �v Upperbik (base HRZ) 5 L I �i�1p¢Ca1kr) 5 I Permit Pack i Top WCS810(W c ak.D) 0230wle �.-2 mkr) a C -4Q rn K- J314` otopC 50 " by 3 " 0 0"x42' � � 0 1 4000 8000 12000 16000 2 x42 13 3/8"x16' Measured Depth o^3/8"x16' Geodetic Datum: North American Datum 1983 Depth Reference: Plan: 119.8+28 @ 147.80usft (Doyon141) Rig: Doyon141 A N 0 O '., �D 6°° °O 10 3/4"x12-1/4" by 13. I 0 1500 3000 4500 6000 750 00 01050 1'000 8.13960 torso LL' lasso ° 10590 - 1078 Horizontal Departure p 330 •, ......._ 72..:.... 30 10780 - 10960 - - 10960 - 11150 0 9 11150 - 1134 m 60 11340 - 1153 300_ 60 11530 - 11710 CO 6,--11710 - -'1190C Cf)_. ; ; ; - --; �'..,,' ,.'�. .-' 11900 1211 °��' 2- 3 13[Me al'odo : - 12110 1233 E U 30- )0 T 12330 - 12540 o 270 }avS• g° 12540 - 12750 -:: a0n . 12750 - 1296 c •- - <,; 12960 - 13170 U --. - 13170 - 13390 oao D ( i ` . _ ; 13390 - 1360 13600 - 14040 10450 11400 12350 13300 14250 15200 16150 1710 240 120 14040 - taaso SURVEY PROGRAM 9--'" 14480 - 14920 ___ 14920 - 1536 Depth From Depth To Survey/Plan Tool 180 -------- 28.00 1000.00 2S-13PB1wp13[Megalodon](Plan:2S-13PI3V)D-GC-SS 210 ]' 160 15360 - 15800 1000.00 2967.32 2S-13PB1wp13 [Megalodon] (PISA+43fF8�Vj-CAZ-SC 12 15800 1624° 2967.32 9498.92 2S-13PB1wp13 [Megalodon] (PlMW0 +0R�IWK-CAZ-SC 16240 ' 16680 9498.92 9500.00 2S-13PB1wp13[Megalodon](Plan:2S-13PB1) MWD CASING DETAILS 9500.00 10150.00 2S-13wp13[Megalodon](Plan :25MIFR-AK-CAZ-SC 16680 - 1711 10150.00 10500.00 2S-13L1wp13[Megalodon] (Plan: 25-131-1) MWD TVD MD Name 10500.00 12000.00 2S-13L1wp13[Megalodon] (Plan: 2S -13L1) MWD 6317.80 16838.84 4 1/2" x 6-3/4" Magnetic Model: BGGM2015 T 10500.00 16838.84 2S-13L1wp13[Megalodon] PlanAW4J-AK-CAZ-SC Magnetic Model Date: 15 -Dec -15 Magnetic Declination: 18.44° To convert a Magnetic Direction to a True Direction, Add 18.44° East SECTION DETAILS g,g, Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target Annotation 369.`8' T-3 Sand 1 10150.00 77.91 357.57 6310.85 -84.83 -5778.84 0.00 0.00 -1577.61 KOP: 13.56°/100' DLS, 0° TF, for 16.5' 2 10166.50 80.14 357.57 6313.99 -68.64 -5779.53 13.56 0.00 -1562.16 Hold for 20' K-15 Marker 3 10186.50 80.14 357.57 6317.42 -48.96 -5780.36 0.00 0,00 -1543.36 Start 6°/100' OILS, 52.59° TF, for 285.53' 4 10472.03 90.73 11,11 6340.20 233.77 -5758.66 6.00 52.59 -1264.65 Hold for 964.37' 5 11436.40 90.73 11.11 6327.92 1180.00 -5572.94 0.00 0.00 -30259 Start 4°/100' DLS, -177.25° TF, for 18.27' 1357.8 6 11454.67 90.00 11.07 6327.80 1197.93 -5569.42 4.00 -177.25 -284.36 2S-MegalodonL2 1.Heel 081115 PB Start 0.14°/100' DLS, 88.32° TF, for 5384.17' 7 16838.84 90.21 18.35 6317.80 6402.11 -4203.18 0.14 88.32 5096.11 2S-MegalodonL2 2,Toe 081115 PB TO 16838.84' MD, 6317.8' TVD Base permafrost (? 1923.8 Top W Sak (W Sak ) .... ... ._ .. ,.. base W Sak 2773.8 Failed Anti -Collision`` C-80 4097.8 C-50 4405���� Minor Risked 47 . 5g55gqrGGp Growler -AA Failed AC against Motherbore and first lateral 2S-13wp13 at sidetrack Point C-358 RKZI 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 Ilision avoidance Ian asset out in the audit Pack. I approve it as the basis for the final well plan and wellsite drawings. I also acknowled a that unless notified otherwse all tar ets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: [ Approved by: I Brij Potnis Nate Beck [feenyi Ifesie Easting (3000 usft/in) 2M-34 2S-14wp07 [Whale]214�3�1L1 2S-11wp06 [Great White] -- 2S -13L1 wp13[Megalodon] 2S-13wp13[Megalodon] _ - - _ - - -/2TVI-35 - ___--- ---- �'"---------------- 2S-11L1w 0 --------------- - -------------------------- 2S-04wp12 2S-09wp06 [Tiger] 2L-03 2S-07 2S-05wp06 [ e AL 2S-13PB1wp13 [Megalodon] Kuparuk 2S } 2S-02 2S-01wp07 -314PB1 �' 2L-306PB1 Rig: 2S 1 2L- 08P61wp06 2L-319 10 ft -01" 2L 2L-308 2L-316 p06 2 2L-30 2L-302 (wp01 325 L-323 2L -317A L-320 21--302 (wp01) 2L-321 � /2S-10 2L-330 $09 2S-08wp09 L6 W�Salmon] 2N-322 2N-3 1 (wpO�) 2S-03wp07[Bamboo] 2M--§ wp05 Prelim: Faruk Cairn Pad2 2N- 02 2S-17 06 [Hybodus]2S-12wp07 [Bull] -322PB1 2N-301PB1 (WP03) -322PB2 2L_31_8 p08 Prelim,i aruk 2L-32Cairn Pd Easting (3000 usft/in) t ShhrkVodlh #1 21-10-8 203AL2 1 1A Z 0 s 3 c0 w 0 0 0 c U) 2S-1 31.1 wp13[Megalodon] Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4 1/2" x 6-3/4"- S ------------------- _�w 3 6000 ----------- ------ 3 A7 ltije9alod 1,34ot. ,tv o i,3�Nje9 4500 alodonl 2S-MegalodonL22.Toe081115 PIB c 41 CO p000 2S-MegalodonL2 1.Hee 0081115 B " " z zl 500 Mega�odor� . � 3 P�1�p13` ° CO 25,1 20"x42" 10 3/4"x12-1 /4" by 13.5" 0- 13 3/8"x16" 7000 -1500 CD O o d 0 0 -9000 -7500 -6000 -4500 -3000 -1500 0 1500 3000 West( -)/East(+) (1500 usft/in) 2S -1 3L1 wp13[Megalodon] U 1500 n m W m 03000 4500 Section View 0 0 0 0 m -cow -iyuu -you u 950 1900 2850 3800 4750 Vertical Section at 15.000 2S-1 X1 wp13[Megalodon] Section View 6200- 2006240 6240— w r -1 Q.) W 06280 lV cn v � ,a o 236320 ' �- O a, -- o' 4 92" x 6-3/4" CO w O o00 0 0 O 0 0o co O O O O O N Cn 360 6360- 6400— 6400 CL -1800 -900 0 900 1800 2700 3600 4500 5400 Vertical Section at 15.00° ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-13 Plan: 2S-131-1 Plan: 2S-13L1wp13[Megalodon] Report - Basic 07 October, 2015 Permit Pack Failed Anti -Collision'; Minor Risked Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan. 2S-13 Wellbore: Plan. 2S-131_1 Design: 2S -13L1 wp13[Megalodon] ConocoPhillips Report - Basic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2S-13 Plan: 119.8+28 @ 147.80usft (Doyonl41) Plan: 119 8+28 @ 147.80usft (Doyonl41) True Minimum Curvature EDM Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad From Site Position: Northing: usft Latitude: (usft) Survey (Wellbore) From: Map Easting: usft Longitude: GYD-GC-SS Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° 9,498.92 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P MWD+IFR-AK-CAZ-SC 9,498.92 9,500.00 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P Well Plan: 2S-13 10,150.00 2S-13wpl3[Megalodon] (Plan: 2S-13) MWD+IFR-AK-CAZ-SC Well Position +N/ -S 0.00 usft Northing: usft Latitude: 10,500.00 12,000.00 2S-13L1wpl3[Megalodon] (Plan: 2S-131_1 +E/ -W 0.00 usft Easting: usft Longitude: 16,838.84 2S-13L1wp13[Megalodon] (Plan: 2S-131_1 Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan: 2S-131_1 Magnetics Model Name Sample Date Declination Dip Angle (°) (°) Field Strength (nT) BGGM2015 12/15/2015 18.44 80.86 57,486 Design 2S-13L1wpl3[Megalodon] Audit Notes: Version: Phase: PLAN Tie On Depth: 10,150.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 28.00 0.00 0.00 15.00 Survey Tool Program Date 10/7/2015 From To (usft) (usft) Survey (Wellbore) Tool Name 28.00 1,000.00 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P GYD-GC-SS 1,000.00 2,967.32 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P MWD+IFR-AK-CAZ-SC 2,967.32 9,498.92 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P MWD+IFR-AK-CAZ-SC 9,498.92 9,500.00 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P MWD 9,500.00 10,150.00 2S-13wpl3[Megalodon] (Plan: 2S-13) MWD+IFR-AK-CAZ-SC 10,150.00 10,500.00 2S-13L1wp13[Megalodon] (Plan: 2S -13L1 MWD 10,500.00 12,000.00 2S-13L1wpl3[Megalodon] (Plan: 2S-131_1 MWD 10,500.00 16,838.84 2S-13L1wp13[Megalodon] (Plan: 2S-131_1 MWD+IFR-AK-CAZ-SC Planned Survey MD Inc Azi (usft) (°) (true_north_azim 10,150.00 77.91 357.57 KOP: 13.56°/100' DLS, 0° TF, for 16.5' 10,166.50 80.14 357.57 Hold for 20' 10,186.50 80.14 357.57 Start 6°/100' DLS, 52.59° TF, for 285.53' Description Gyrodata gyro single shots MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC MWD - Standard MWD+IFR AK CAZ SCC MWD - Standard MWD - Standard MWD+IFR AK CAZ SCC TVD TVDSS DLeg TFace Lat. Error (usft) (usft) (°1100usft) (°) (usft) 6,310.85 6,163.05 0.00 0.00 10.75 6,313.99 6,166.19 13.56 0.00 10.77 6,317.42 6,169.62 0.00 0.00 10.80 1017/2015 12:46:41PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Report - Basic Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-13 Project: Kuparuk River Unit TVD Reference: Plan: 119.8+28 @ 147.80usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: Plan: 119.8+28 @ 147.80usft (Doyonl41) Well: Plan: 2S-13 North Reference: True Wellbore: Plan: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-13L1wpl3[Megalodon] Database: EDM Production Planned Survey i MD Inc Azi TVD TVDSS DLeg TFace Lat. Error (usft) (°) (true_north_azim (usft) (usft) (°/100usft) (°) (usft) 10,200.00 80.64 358.22 6,319.67 6,171.87 6.00 52.59 10.83 10,226.77 81.62 359.51 6,323.80 6,176.00 6.00 52.48 11.02 A4 10,300.00 84.32 3.00 6,332.77 6,184.97 6.00 52.28 11.30 10,400.00 88.04 7.72 6,339.43 6,191.63 6.00 51.85 12.08 10,472.03 90.73 11.11 6,340.20 6,192.40 6.00 51.54 12.80 Hold for 964.37' 10,500.00 90.73 11.11 6,339.85 6,192.05 0.00 0.00 12.85 10,600.00 90.73 11.11 6,338.57 6,190.77 0.00 0.00 12.96 10,700.00 90.73 11.11 6,337.30 6,189.50 0.00 0.00 13.24 10,800.00 90.73 11.11 6,336.03 6,188.23 0.00 0.00 13.67 10,900.00 90.73 11.11 6,334.75 6,186.95 0.00 0.00 14.24 11,000.00 90.73 11.11 6,333.48 6,185.68 0.00 0.00 14.93 11,100.00 90.73 11.11 6,332.20 6,184.40 0.00 0.00 15.74 11,200.00 90.73 11.11 6,330.93 6,183.13 0.00 0.00 16.63 11,300.00 90.73 11.11 6,329.65 6,181.85 0.00 0.00 17.61 11,400.00 90.73 11.11 6,328.38 6,180.58 0.00 0.00 18.65 11,436.40 90.73 11.11 6,327.92 6,180.12 0.00 0.00 19.04 Start 4°/100' DLS, -177.25° TF, for 18.27' 11,454.67 90.00 11.07 6,327.80 6,180.00 4.00 -177.25 19.18 Start0.14°/100' DLS, 88.32° TF, for 6384.17'- 2S-MegalodonL2 1.Heel 080415 PB - 2S-MegalodonL2 1.Heel 031114 PB - 2S-MegalodonL2 1.Heel 081115 11,500.00 90.00 11.13 6,327.80 6,180.00 0.14 88.37 19.47 11,600.00 90.01 11.27 6,327.79 6,179.99 0.14 88.32 20.31 11,700.00 90.01 11.40 6,327.78 6,179.98 0.14 88.32 21.21 11,800.00 90.01 11.54 6,327.76 6,179.96 0.14 88.32 22.17 11,900.00 90.02 11.67 6,327.73 6,179.93 0.14 88.32 23.18 12,000.00 90.02 11.81 6,327.70 6,179.90 0.14 88.32 14.82 12,100.00 90.03 11.94 6,327.66 6,179.86 0.14 88.32 15.04 12,200.00 90.03 12.08 6,327.61 6,179.81 0.14 88.32 15.27 12,300.00 90.03 12.21 6,327.55 6,179.75 0.14 88.32 15.52 12,400.00 90.04 12.35 6,327.49 6,179.69 0.14 88.32 15.79 12,500.00 90.04 12.48 6,327.42 6,179.62 0.14 88.32 16.07 12,600.00 90.05 12.62 6,327.35 6,179.55 0.14 88.32 16.36 12,700.00 90.05 12.75 6,327.26 6,179.46 0.14 88.32 16.67 12,800.00 90.05 12.89 6,327.17 6,179.37 0.14 88.32 16.99 12,900.00 90.06 13.02 6,327.08 6,179.28 0.14 88.32 17.32 13,000.00 90.06 13.16 6,326.98 6,179.18 0.14 88.32 17.66 13,100.00 90.07 13.29 6,326.87 6,179.07 0.14 88.32 18.02 13,200.00 90.07 13.43 6,326.75 6,178.95 0.14 88.32 18.38 13,300.00 90.07 13.56 6,326.62 6,178.82 0.14 88.32 18.75 13,400.00 90.08 13.70 6,326.49 6,178.69 0.14 88.32 19.13 13,500.00 90.08 13.84 6,326.36 6,178.56 0.14 88.32 19.52 13,600.00 90.08 13.97 6,326.21 6,178.41 0.14 88.33 19.92 13,700.00 90.09 14.11 6,326.06 6,178.26 0.14 88.33 20.33 13,800.00 90.09 14.24 6,325.90 6,178.10 0.14 88.33 20.74 1017/2015 12:46 41 PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Report - Basic Company: ConocoPhillips (Alaska) Inc -Kup2 Local Co-ordinate Reference: Well Plan: 2S-13 Project: Kuparuk River Unit TVD Reference: Plan: 119.8+28 @ 147.80usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: Plan: 119.8+28 @ 147.80usft (Doyon 141) Well: Plan: 2S-13 North Reference: True Wellbore: Plan: 2S -13L1 Survey Calculation Method: Minimum Curvature Design: 2S-13L1wp13[Megalodon) Database: EDM Production Planned Survey MD Inc Azi TVD TVDSS DLeg TFace Lat. Error (usft) {°) (true_north_azim (usft) (usft) (°1100usft) (°} (usft) 13,900.00 90.10 14.38 6,325.74 6,177.94 0.14 88.33 21.15 14,000.00 90.10 14.51 6,325.56 6,177.76 0.14 88.33 21.58 14,100.00 90.10 14.65 6,325.38 6,177.58 0.14 88.33 22.01 14,200.00 90.11 14.78 6,325.20 6,177.40 0.14 88.33 22.44 14,300.00 90.11 14.92 6,325.00 6,177.20 0.14 88.33 22.88 14,400.00 90.12 15.05 6,324.80 6,177.00 0.14 88.33 23.33 14,500.00 90.12 15.19 6,324.60 6,176.80 0.14 88.33 23.78 14,600.00 90.12 15.32 6,324.38 6,176.58 0.14 88.33 24.23 14,700.00 90.13 15.46 6,324.16 6,176.36 0.14 88.33 24.69 14,800.00 90.13 15.59 6,323.94 6,176.14 0.14 88.33 25.15 14,900.00 90.14 15.73 6,323.70 6,175.90 0.14 88.33 25.61 15,000.00 90.14 15.86 6,323.46 6,175.66 0.14 88.33 26.08 15,100.00 90.14 16.00 6,323.21 6,175.41 0.14 88.33 26.55 15,200.00 90.15 16.13 6,322.96 6,175.16 0.14 88.33 27.02 15,300.00 90.15 16.27 6,322.70 6,174.90 0.14 88.33 27.50 15,400.00 90.16 16.40 6,322.43 6,174.63 0.14 88.33 27.98 15,500.00 90.16 16.54 6,322.15 6,174.35 0.14 88.33 28.46 15,600.00 90.16 16.67 6,321.87 6,174.07 0.14 88.33 28.95 15,700.00 90.17 16.81 6,321.58 6,173.78 0.14 88.33 29.43 15,800.00 90.17 16.95 6,321.28 6,173.48 0.14 88.33 29.92 15,900.00 90.18 17.08 6,320.98 6,173.18 0.14 88.33 30.41 16,000.00 90.18 17.22 6,320.67 6,172.87 0.14 88.33 30.90 16,100.00 90.18 17.35 6,320.35 6,172.55 0.14 88.33 31.40 16,200.00 90.19 17.49 6,320.03 6,172.23 0.14 88.33 31.89 16,300.00 90.19 17.62 6,319.70 6,171.90 0.14 88.33 32.39 16,400.00 90.20 17.76 6,319.36 6,171.56 0.14 88.33 32.89 16,500.00 90.20 17.89 6,319.02 6,171.22 0.14 88.33 33.39 16,600.00 90.20 18.03 6,318.67 6,170.87 0.14 88.33 33.89 16,700.00 90.21 18.16 6,318.31 6,170.51 0.14 88.34 34.39 16,800.00 90.21 18.30 6,317.94 6,170.14 0.14 88.34 34.90 16,838.69 90.21 18.35 6,317.80 6,170.00 0.14 88.34 35.09 2S-13 Megalodon 11-112. Toe 081116 PB circle 16,838.84 90.21 18.35 6,317.80 6,170.00 0.14 88.34 35.09 TD: 16838:84' MD, 6317.8' TVD - 2S-MegalodonL2 2.Toe 080415 PS - 2S-MegalodonL2 2.Toe 031114 PB - 2S-MegalodonL2 2. Toe 081115 PB - 2S-Megal4 10/7/2015 12:46.41PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips Report - Basic Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-13 Project: Kuparuk River Unit ND Reference: Plan: 119.8+28 @ 147.80usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: Plan. 119.8+28 @ 147.80usft (Doyonl41) Well: Plan 2S-13 North Reference: True Wellbore: Plan 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-13L1wpl3[Megalodon] Database: EDM Production 10,226.77 16,838.84 6,317.80 4 1/2" x 6-3/4" A4 4-1/2 6-3/4 Formations Measured Vertical Local Coordinates Depth Depth +N/ -S (usft) (usft) Name 7,084.92 4,780.80 Growler -AA 8,225.79 5,440.80 Top Cairn 9,382.90 6,040.80 Top HRZ (K-2 mkr) 8,425.29 5,553.80 Top Bermuda 8,504.33 5,597.80 Base Bermuda 10,226.77 6,323.80 A4 8,587.97 5,643.80 C-35 10,149.75 6,310.80 Kuparuk C (Top C4) 9,876.36 6,237.80 Lower Kalubik (K-1 mkr) 9,616.83 6,140.80 Upper Kalubik (base HRZ) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) 10,150.00 6,310.85 -84.83 -5,778.84 10,166.50 6,313.99 -68.64 -5,779.53 10,186.50 6,317.42 -48.96 -5,780.36 10,472.03 6,340.20 233.77 -5,758.66 11,436.40 6,327.92 1,180.00 -5,572.94 11,454.67 6,327.80 1,197.93 -5,569.42 16,838.84 6,317.80 6,402.11 -4,203.18 Dip Dip Direction Lithology (I (I Comment KOP: 13.56°/100' DLS, 00 TF, for 16.5' Hold for 20' Start 6°/100' DLS, 52.59° TF, for 285.53' Hold for 964.37' Start 4°/100' DLS, -177.25° TF, for 18.27' Start 0.14°/100' DLS, 88.32° TF, for 5384.17' TD: 16838.84' MD, 6317.8' TVD Checked By: Approved By: Date: 101712015 12:46:41PM Page 5 COMPASS 5000.1 Build 74 10 TVDSS �miy �w i t7 ("• I 'u<_m I {ustt) I i sff I Mft)jusft) {usft) Secfl-T%'� Target j°%100usft) i�! 0.00 .50 20A0 80.14. 357.57 6317.42 6169.62 -48.96 -5780.36. 5929664.35 1615151.53 0.00 000 Straight MD 4 1047203 285.53 90.73 iL 1t 6340.20 6192.40 - 233.77 , _ -5758.66 5929946.99 1615173.96 6.00. 52.59 CPT AL DL 5 11436.40 964.37 90.73 . -SQ.00 11.11 6327192., 6180.12 _ Im 00 5572.94 593089165 1615362.11 0.00 0.00 jditto} - 6 11154,67 18,27. 11.07 6327.80: 6180.00 1197.93 -5569.42 5930410.57 1615365.67 - 1.00 -- - -177.25 dtto - j ) 2S-MegalodaK2 I.Meel 081115PB 7 16838.84." Ce" 5384.17. 90.21 18.35' 6317.80' 6170.00 640211, 1203.18; 5936110.69 1616745,21 Q.34 8832 OT6 Curve-25i+kpnlodpY-22Toe 081115 PB _...... _. .. _.. .__.. ..__ ...,.,_._. ......... ... Insert LZ- ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-13 Plan: 2S-131_1 2S-13L1wp13[Megalodon] Clearance Summary Anticollision Report 07 October, 2015 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-13 - Plan: 2S -13L1 - 2S-13L1wp13[Megalodon] Datum Height: Plan: 119.8+28 @ 147.80usft (Doyon141) Scan Range: 0.00 to 16,838.84 usft. Measured Depth. Scan Radius is 1,881.08 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Permit Pack Failed Anti -Collision ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-13 - 2S-13L1wp13[Megalodon] Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-13 - Plan: 2S-131-1 - 2S-13L1wp13[Megalodon] Scan Range: 0.00 to 16,838.84 usft. Measured Depth. Scan Radius is 1,881.08 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2S Pad 2S-07 - 2S-07 - 2S-07 373.68 239.75 373.68 226.84 375.00 18.578 Centre Distance Pass - Major Risk 2S-07 - 2S-07 - 2S-07 446.23 240.12 446.23 226.27 450.00 17.340 Clearance Factor Pass - Major Risk 2S-10 - 2S-10 - 2S-10 28.00 149.28 28.00 146.86 27.50 61.758 Centre Distance Pass - Major Risk 2S-10 - 2S-10 - 2S-10 349.77 152.06 349.77 145.71 350.00 23.945 Clearance Factor Pass - Major Risk Plan: 2S-08 - Plan: 2S-08 - 2S-08wp09 [Hammerhead] 325.30 210.00 325.30 203.96 325.00 34.769 Centre Distance Pass - Major Risk Plan: 2S-08 - Plan: 2S-08 - 2S-08wp09 [Hammerhead] 422.44 210.67 422.44 203.10 425.00 27.818 Clearance Factor Pass - Major Risk Plan: 2S-09 - Plan: 2S-09 - 2S-09wp06 [Tiger] 324.80 180.03 324.80 174.00 325.00 29.846 Centre Distance Pass - Major Risk Plan: 2S-09 - Plan: 2S-09 - 2S-09wp06 [Tiger] 422.36 180.70 422.36 173.13 425.00 23.866 Clearance Factor Pass - Major Risk Plan: 2S-11 - Plan: 2S-11 - 2S-11 wp06 [Great White] 324.80 120.02 324.80 113.99 325.00 19.898 Centre Distance Pass - Major Risk Plan: 25-11 - Plan: 2S-11 - 2S-11 wp06 [Great White] 546.06 121.96 546.06 112.91 550.00 13.470 Clearance Factor Pass - Major Risk Plan: 2S-11 - Plan: 2S-11 L1 - 2S-11 L1wp06 [Great Wh 324.80 120.02 324.80 113.99 325.00 19.898 Centre Distance Pass - Major Risk Plan: 2S-11 - Plan: 2S-11 L1 - 2S-11 L1 wp06 (Great Wh 546.06 121.96 546.06 112.91 550.00 13.470 Clearance Factor Pass - Major Risk Plan: 2S-12 - Plan: 2S-12 - 2S-12wp07 [Bull] 324.80 90.02 324.80 83.99 325.00 14.924 Centre Distance Pass - Major Risk Plan: 2S-12 - Plan: 2S-12 - 2S-12wp07 [Bull] 619.84 90.75 619.84 80.19 625.00 8.592 Clearance Factor Pass - Major Risk Plan: 2S-13 - Plan: 2S-13 - 2S-13wp13[Megalodon] - Plan: 2S-13 - Plan: 2S-13 - 2S-13wp13[Megalodon] -Major Risk Plan: 2S-13 -Plan: 2S -13P61 - 2S-13PB1wp13 [Mega IL - Major Risk Plan: 2S-13 - Plan: 2S-13PB1 - 2S-13PB1wp13 [Mega r Plan: 2S-14 - Plan: 2S-14 - 2S-14wp07 [Whale] 648.41 28.99 648.41 18.42 650.00 2.743 Centre Distance Pass - Major Risk Plan: 2S-14 - Plan: 2S-14 - 2S-14wp07 [Whale] 921.43 31.58 921.43 16.31 925.00 2.068 Clearance Factor Pass - Major Risk Plan: 2S-16 - Plan: 2S-16 - 2S-16wp06 [Squalicorax] 249.80 30.02 249.80 25.30 250.00 6.357 Centre Distance Pass - Major Risk Plan: 2S-16 - Plan: 2S-16 - 2S-16wp06 [Squalicorax] 324.80 30.61 324.8D 24.70 325.00 5.181 Clearance Factor Pass - Major Risk Plan: 2S-17 - Plan: 2S-17 - 2S-17wp06 [Hybodus] 224.80 60.01 224.80 55.73 225.00 14.006 Centre Distance Pass - Major Risk Plan: 2S-17 - Plan: 2S-17 - 2S-17wp06 [Hybodus] 299.80 60.60 299.80 55.11 300.00 11.039 Clearance Factor Pass - Major Risk Rig: 25-04 - 2S-04 - 2S-04wp12 397.01 327.64 397.01 320.42 400.00 45.372 Centre Distance Pass - Major Risk Rig: 2S-04 - 2S-04 - 2S-04wp12 468.68 328.10 468.68 319.84 475.00 39.722 Clearance Factor Pass - Major Risk Rig: 2S-04 - Rig: 2S-04PB1 - Rig: 2S-04PB1 397.01 327.64 397.01 320.42 400.00 45.372 Centre Distance Pass - Major Risk Rig: 2S-04 - Rig: 2S-04PB1 - Rig: 2S-04PB1 468.68 328.10 468.68 319.84 475.00 39.722 Clearance Factor Pass - Major Risk 07 October, 2015 - 12:45 Page 2 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-13 - 2S-131-1wp13[Megalodon] Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-13 - Plan: 2S -13L1 - 2S-13L1wp13[Megalodon] Scan Range: 0.00 to 16,838.84 usft. Measured Depth. Scan Radius is 1,881.08 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Survey fool program From To (usft) (usft) 28.00 1,000.00 1,000.00 2,967.32 2,967.32 9,498.92 9,498.92 9,500.00 9,500.00 10,150.00 10,150.00 10,500.00 2S-13L1wp13[Megalodon] 10,500.00 12,000.00 2S-13L1wp13[Megalodon] 10,500.00 16,838.84 2S-1311wp13[Megalodon] Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan Survey Tool GYD-GC-SS M W D+I F R -A K-CAZ-SC M W D+I F R -A K-CAZ-SC MWD M W D+I F R-AK-CAZ-SC MWD MWD M W D+I F R -A K-CAZ-SC Separation Warning 07 October, 2015 - 12.45 Page 3 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-13 Plan: 2S-131-1 2S-13L1wp13[Megalodon] Clearance Summary Anticollision Report 07 October, 2015 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-13 - Plan: 2S-131-1 - 2S-13L1wp13[Megalodon] Datum Height: Plan: 119.8+28 @ 147.80usft (Doyon141) Scan Range: 0.00 to 16,838.84 usft. Measured Depth. Scan Radius is 1,881.08 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Minor Risked ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-13 - 2S-13L1wp13[Megalodon] Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-13 - Plan: 2S-131-1 - 2S-13L1wp13[Megalodon] Scan Range: 0.00 to 16,838.84 usft. Measured Depth. Scan Radius is 1,881.08 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2S Pad 2S-07 - 2S-07 - 2S-07 373.68 239.75 373.68 226.84 375.00 18.578 Centre Distance Pass - Major Risk 2S-07 - 2S-07 - 2S-07 446.23 240.12 446.23 226.27 450.00 17.340 Clearance Factor Pass - Major Risk 2S-10 - 2S-10 - 2S-10 28.00 149.28 28.00 146.86 27.50 61.758 Centre Distance Pass - Major Risk 2S-10 - 2S-10 - 2S-10 349.77 152.06 349.77 145.71 350.00 23.945 Clearance Factor Pass - Major Risk Plan: 2S-08 - Plan: 2S-08 - 2S-08wp09 [Hammerhead] 325.30 210.00 325.30 203.96 325.00 34.769 Centre Distance Pass - Major Risk Plan: 2S-08 - Plan: 2S-08 - 2S-08wp09 [Hammerhead] 422.44 210.67 422.44 203.10 425.00 27.818 Clearance Factor Pass - Major Risk Plan: 2S-09 - Plan: 2S-09 - 2S-09wp06 [Tiger] 324.80 180.03 324.80 174.00 325.00 29.846 Centre Distance Pass - Major Risk Plan: 2S-09 - Plan: 2S-09 - 2S-09wp06 [Tiger] 422.36 180.70 422.36 173.13 425.00 23.866 Clearance Factor Pass - Major Risk Plan: 2S-11 - Plan: 2S-11 - 2S-11wp06 [Great White] 324.80 120.02 324.80 113.99 325.00 19.898 Centre Distance Pass - Major Risk Plan: 2S-11 - Plan: 2S-11 - 2S-11 wp06 [Great White] 546.06 121.96 546.06 112.91 550.00 13.470 Clearance Factor Pass - Major Risk Plan: 2S-11 - Plan: 2S-11 L1 - 2S-11 L1wp06 [Great Wh 324.80 120.02 324.80 113.99 325.00 19.898 Centre Distance Pass - Major Risk Plan: 2S-11 - Plan: 2S-11 L1 - 2S-11 L1 wp06 [Great Wh 546.06 121.96 546.06 112.91 550.00 13.470 Clearance Factor Pass - Major Risk Plan: 2S-12 - Plan: 2S-12 - 2S-12wp07 [Bull] 324.80 90.02 324.80 83.99 325.00 14.924 Centre Distance Pass - Major Risk Plan: 2S-12 - Plan: 2S-12 - 2S-12wp07 [Bull] 619.84 90.75 619.84 80.19 625.00 8.592 Clearance Factor Pass - Major Risk Plan: 2S-13 - Plan: 2S-13 - 2S-13wp13[Megalodon] - Plan: 2S-13 - Plan: 2S-13PB1 - 2S-13PB1wp13 [Mega 1111111111011111111L` -tenor 11200 Plan: 2S-13 - Plan: 2S-13PB1 - 2S-13PB1wp13 [Mega - Plan: 2S-14 - Plan: 2S-14 - 2S-14wp07 [Whale] 648.41 28.99 648.41 18.42 650.00 2.743 Centre Distance Pass - Major Risk Plan: 2S-14 - Plan: 2S-14 - 2S-14wp07 [Whale] 921.43 31.58 921.43 16.31 925.00 2.068 Clearance Factor Pass - Major Risk Plan: 2S-16 - Plan: 2S-16 - 2S-16wp06 [Squalicorax] 249.80 30.02 249.80 25.30 250.00 6.357 Centre Distance Pass - Major Risk Plan: 2S-16 - Plan: 2S-16 - 2S-16wp06 [Squalicorax] 324.80 30.61 324.80 24.70 325.00 5.181 Clearance Factor Pass - Major Risk Plan: 2S-17 - Plan: 2S-17 - 2S-17wp06 [Hybodus] 224.80 60.01 224.80 55.73 225.00 14.006 Centre Distance Pass - Major Risk Plan: 2S-17 - Plan: 2S-17 - 2S-17wp06 [Hybodus] 299.80 60.60 299.80 55.11 300.00 11.039 Clearance Factor Pass - Major Risk Rig: 2S-04 - 2S-04 - 2S-04wp12 397.01 327.64 397.01 320.42 400.00 45.372 Centre Distance Pass - Major Risk Rig: 2S-04 - 2S-04 - 2S-04wp12 468.68 328.10 468.68 319.84 475.00 39.722 Clearance Factor Pass - Major Risk Rig: 2S-04 - Rig: 2S-04PB1 - Rig: 2S-04PB1 397.01 327.64 397.01 320.42 400.00 45.372 Centre Distance Pass - Major Risk Rig: 2S-04 - Rig: 2S-04PB1 - Rig: 2S-04PB1 468.68 328.10 468.68 319.84 475.00 39.722 Clearance Factor Pass - Major Risk 07 October, 2015 - 12:48 Page 2 of 5 COMPASS Anticollision Report for Plan: 2S-13 - 2S-13L1wp13[Megalodon] Survey tool program From To (usft) (usft) 28.00 1,000.00 1,000.00 2,967.32 2,967.32 9,498.92 9,498.92 9,500.00 9,500.00 10,150.00 10,150.00 10,500.00 2S-131-1wp13[Megalodon] 10,500.00 12,000.00 2S-131-1wp13[Megalodon] 10,500.00 16,838.84 2S-131-1wp13[Megalodon] Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan Survey Tool GYD-GC-SS M W D+I FR-AK-CAZ-SC M WD+I FR-AK-CAZ-SC MWD M WD+I F R-AK-CAZ-SC MWD MWD M WD+I FR-AK-CAZ-SC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit 07 October, 2015 - 12:48 Page 3 of 5 COMPASS Partial Measured Depth I El Ladder View 12:57, October 87 2 2S-1 3L1 wp13[Megalodo The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. a a 0 .Failed Anti -Colli 3 m _ 300- 00 0 O Q O U I 150---- 50 - C) Uoc V J-+ m (D Equivelant Magnetic Distance ! U - N N Q 10450 11400 12350 13300 14250 15200 16150 17100 Displayed interval could be less than entire well:Measured Dept190150.00 To 16838.84 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 28.00 1000.00 2S-13PB1wpl3 [Megalodon] (Plan.aYD4G BSP 6317.'EB38.84 4 1/2" x 6-3/4" 1000.00 2967.32 2S-13PB1wpl3 [Megalodon] (PIanAW-D-8FflRtAK-CAZ-SC 2967.32 9498.92 2S-13PB1wpl3 [Megalodon] (Plants-J$IFRT)\K-CAZ-SC 9498.92 9500.00 2S-13PB1wpl3 [Megalodon] (PlaniVA. -D3PB1) 9500.0010150.00 2S-13wpl3[Megalodon] (Plan: 2S-WD+IFR-AK-CAZ-SC 10150.0010500.00 2S-13L1wpl3[Megalodon] (Plan: 29VM1) 10500.0012000.00 2S-13L1wpl3[Megalodon] (Plan: 29VMI) 10500 0016838 84 2,';-13I-1wn13[MPaaIodonl (Plan- 2&kAn-ArFR-AK-(A7-S(' 60 111111a p 0 rn a Q H I N 30 I U 0 a� E W U 1)I 0 II 10450 11400 12350 13300 14250 15200 16150 17100 Partial Measured Depth I El Partial Measured Depth 12:54, October 07 20 Ladder View S-13L1w 13 3[Megalodon] L 7 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 0 8 Minor Risked a 3 m 300 n i O t t1 N '.. O N 15o— D e o X C f f n U ! EquiA ani Magnetic Distances 1 I 0 10450 11400 12350 13300 14250 15200 16150 17100 Displayed interval could be less than entire well:Measured DeptN0150.00 To 16838.84 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 28.00 1000.00 2S-13PB1wpl3 [Megalodon] (PlanGffi1CZEBSP 6317'18838.84 4 1/2" x 6-3/4" 1000.00 2967.32 2S-13PB1wpl3 [Megalodon] (PlanIVA&-D$ff9BnAK-CAZ-SC 2967.32 9498.92 2S-13PB1wp13 [Megalodon] (PlanMW{7 BFWAK-CAZ-SC 9498.92 9500.00 2S-13PB1wpl3 [Megalodon] (PlaniW-03PB1) 9500.0010150.00 2S-13wpl3[Megalodon] (Plan: 2S-UNVD+IFR-AK-CAZ-SC 10150.0010500.00 2S-13L1wpl3[Megalodon] (Plan: 219MAal) 10500.0012000.00 2S-13L1wp13[Megalodon] (Plan: 26WAt I) 60--- 0 o .LD M co L 3' c>3 N .. Qi 30- N 00 0—) 10450 11400 12350 13300 14250 15200 16150 17100 Partial Measured Depth M-13L1wp13[Megalodon .) ..... From Oep.M To Survey/Plan Tool 28.68 1B BB.BB 28-13P81 wp13 [Megalodon] 1868.80 2967.32 25-13PB1 wp13 [Meg.--) .0.00 Target 10150.00 77I91 357.57 6310.85 0100 -IFR-AK-LA2-SL (P1an:M1ffi-13L1) 10150.00 To 16838.84 10166.50 10186.50 80 14 80.14 357.57 357.57 63 1 3.9910.00 6317.42 3.56 0.00 0.00 10472.03 11436.40 90.73 90.73 11 .116340.20 11.11 6327.92 6.00 0.00 52.59 0.00 It 68, 950ber 07 201-5 11454.67 90.00 11.07 6327.80 4.00 -177.25 2S-MegalodonL2 1.Heel 081115 PB 16838.84 90.21 18.35 6317.80 0.14 88.32 2S-MegalodonL2 2.Toe 081115 PB CASING DETAILS TVD MD Name 6317.80 16838.84 4 112" x 6-3/4" SDRVEY PROGRAM .) ..... From Oep.M To Survey/Plan Tool 28.68 1B BB.BB 28-13P81 wp13 [Megalodon] 1868.80 2967.32 25-13PB1 wp13 [Meg.--) (P1 BYO �449B1) (P-DPIiA,-QX Z -SL 2967.32 9498.92 25-13P.1wp13 [Megalodon) 9490.92 9588.88 25-13PB1 wP13 [Megalodon] (P1 dYiDi2BAJl18-t14Z-SL (PltlW025-t3PB1) �����d Anti- ®I�i�lon 9588.88 tB15B.BB 25-13wp13 [Mega lotlon] (Plan: 18158.88 185 BB.BB 25-13Ltw113[Megal otlon] -IFR-AK-LA2-SL (P1an:M1ffi-13L1) 18588.88 128 BB.BB 25-13Ltwp13[Megalodon] (PI an:M4ffi-13L1) i 8888.8816838. 04 28-13L,.pl3[M,.,.d.n] (Plan:Y4%L43L-1qK-LAZ-BC -90/270 -12 0/360 10590 10780 10960 11150 11340 11530 11710 11900 12110 12330 12540 12750 12960 13170 13390 13600 14040 480 320 360 300 240 380 -180/180 .E 10780 - 10960 - 11150 - 11340 -- 11530 11710 11900 - 12110 12330 12540 - 12750 12960 - 13170 -W._ 13390 - 13600 - 14040 - 14480 14920 15360 15800 16240 16680 17119 S-13L1W 13 Me alodon D Inc Azi TVD Dleg TFace Target 10590 10780 P g 10150.00 77.91 357.57 6310.85 0.00 0.00 10166.50 80 4 357.57 633.9910150.00 To 16838.84 10186.50 80.14 357.57 6317.42 10.00 0.00 .56 0.0010780 10960 10472.03 90.73 11.116340.20 6.00 52.59 10960 11150 11436.40 90.73 11.11 6327.92 0.00 0.00 12:59, October 07 2015 11454.67 90.00 11.07 6327.80 4.00 -177.25 2S-MegalodonL2 1.Heel 081115 PB 11150 11340 16838.84 90.21 18.35 6317.80 0.14 88.32 2S-MegalodonL2 2.Toe 081115 PB CASING DETAILS 11340 11530 TVD MD Name 11530 11710 6317.80 16838.84 4 1/2" x 6-3/4" 11710 _-® 11900 11900 12110 SURVEY PROGRAM 12110 12330 Depth From OcptM To SUr'V6PI lan Tool 1 2330 12540 28.88 1060. BB 28-13P81wp13 [Megalotlon] (P1 �YD�i99O1) 1800.00 296).32 25-13Pfitwpl] [Megalotlon] (P1�bIDQSA."AZ-SC 296].32 9698.92 2S-13PBiwp13 [Megal otlon] (P1dWD�R3g6,QAZ-SD 9498.92 9588.88 2S-13PBiwp13 [Megalodan] (PI -25-13P61) 12540 12750 9566. BB 18156. BB 2S-,3wp13[Megalodon] (Plan: 2OdDe1IFR-AK-GAZ-56 ,6,56.66 18588.68 25-13L1wP13[Megal otlon] (P1an:M- 13L1) 6506.66126 86.88 2S-13L,wp,3[MegeloLon] (Plan:Mlffi-13L1) Minor Risked 12750 - 12960 18588.88 16838.84 25-13L1wp13 [Megal otlon] (Pl an'.MI6bR3l.-1)K-fiAZ-56 12960 13170 13170 " 13390 13390 13600 13600 14040 0/360 14040 14480 - = 14480 "" " "" 14920 225.. -30/330 / + _ 1 ii 30 14920 15360 15360 15800 r 15800 16240 16240 16680 16680 1711 -60/300 60 -90/27 90 \\\ \\\ 2S-13wp13[Megalodon] -120 / 240 120 \ 92II- �� \ -1501210 „ - 2a = �'� 150 -180/180 c 2S-13PB1wp13 [Megalodon] 2S-17wp06 [Hybod Easting (3000 usft/in) 2S-13L1wp13[Megalodon] 2S-14wp07 [Whaiej 2S-13wp13[Megalodon] _2S-11wp06 [Great White] _ - - - ------------ 2S-11 L1 wp06 [Great White] ------------------------ -------------------------- 2S-04wpl2 Ir 2S-07 2S-09wp06 [Tiger] up r 2S Pad ,Zig: 2S B1 / 2S-10 2S-08wp09 [Hammerhead] r li p rt k Cairn Pad2 2S-12wp07 [Bull] / 2S-16wp06 [Squalicorax] Easting (3000 usft/in) Z 0 7' AC Flipbook ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-13 Plan: 2S-131-1 Plan: 2S-13L1wp13[Megalodon] Report - Errors 07 October, 2015 Permit Pack Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan. 2S-13 Wellbore: Plan: 2S-131-1 Design: 2S-13 L 1 wp 13 [Megalodon] ConocoPhillips Report - Errors Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2S-13 Plan 119.8+28 @ 147.80usft (Doyonl41) Plan. 119.8+28 @ 147.80usft (Doyonl41) True Minimum Curvature EDM Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan 2S-13 Well Position +Nl-S 0.00 usft Northing: usft Latitude: +E/ -W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan 2S -13L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength From To (') (°) (nT) (usft) BGGM2015 12/15/2015 Tool Name 18.44 80.86 57,486 28.00 1,000.00 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P GYD-GC-SS Gyrodata gyro single shots Design 2S-13L1wp13[Megalodon] MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Audit Notes: 9,498.92 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Version: Phase: PLAN Tie On Depth: 10,150.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 10,150.00 (usft) (usft) (usft) (°) 10,500.00 28.00 0.00 0.00 15.00 Planned Survey Survey Tool Program Date 10/7/2015 TVDSS Vert. Error Lat. Error Horz. Error From To (usft) (usft) (usft) (usft) (usft) (usft) Survey (Wellbore) Tool Name Description 28.00 1,000.00 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,967.32 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,967.32 9,498.92 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,498.92 9,500.00 2S-13PB1wpl3 [Megalodon] (Plan: 2S -13P MWD MWD - Standard 9,500.00 10,150.00 2S-1 3wpl 3[Megalodon] (Plan: 2S-13) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,150.00 10,500.00 2S-1311wpl3[Megalodon] (Plan: 2S -13L1 MWD MWD - Standard 10,500.00 12,000.00 2S-13L1wpl3[Megalodon] (Plan: 2S-1311 MWD MWD - Standard 10,500.00 16,838.84 2S-1311wpl3[Megalodon] (Plan: 2S-131-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 10,150.00 28.95 77.91 86.18 6,163.05 9.27 10.75 11.51 KOP: 13.56°/100' DLS, 0° TF, for 16.5' 10,166.50 29.20 80.14 86.48 6,166.19 9.24 10.77 10.90 Hold for 20' 10,186.50 29.20 80.14 86.80 6,169.62 9.24 10.80 10.90 Start 6°/100' DLS, 52.59° TF, for 285.53' 10/7/2015 12:46:22PM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-13 Project: Kuparuk River Unit TVD Reference: Plan: 119.8+28 @ 147.80usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: Plan: 119.8+28 @ 147.80usft (Doyonl41) Well: Plan: 25-13 North Reference: True Wellbore: Plan: 25-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-13L1wpl3[Megalodon] Database: EDM Production Planned Survey - MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 10,200.00 29.24 80.64 87.02 6,171.87 9.24 10.83 10.77 10,226.77 29.37 81.62 87.83 6,176.00 9.25 1102 10.31 A4 10,300.00 29.44 84.32 88.64 6,184.97 9.25 11.30 9.92 10,400.00 29.40 88.04 90.26 6,191.63 9.28 12.08 9.41 10,472.03 29.23 90.73 91.42 6,192.40 9.31 12.80 9.29 Hold for 964.37' 10,500.00 29.24 90.73 91.98 6,192.05 9.32 12.85 9.30 10,600.00 29.24 90.73 93.65 6,190.77 9.33 12.96 9.31 10,700.00 29.25 90.73 95.34 6,189.50 9.35 13.24 9.33 10,800.00 29.25 90.73 97.09 6,188.23 9.39 13.67 9.37 10,900.00 29.25 90.73 98.92 6,186.95 9.44 14.24 9.42 11,000.00 29.25 90.73 100.86 6,185.68 9.51 14.93 9.49 11,100.00 29.26 90.73 102.94 6,184.40 9.59 15.74 9.57 11,200.00 29.26 90.73 105.20 6,183.13 9.68 16.63 9.66 11,300.00 29.26 90.73 107.69 6,181.85 9.78 17.61 9.77 11,400.00 29.26 90.73 110.46 6,180.58 9.90 18.65 9.88 11,436.40 29.26 90.73 111.55 6,180.12 9.95 19.04 9.93 Start 4°/100' DLS, -177.25° TF, for 18.27' 11,454.67 29.26 90.00 112.07 6,180.00 9.97 19.18 9.97 Start 0.14°/100' DLS, 88.32° TF, for 6384.17'- 2S-MegalodonL2 1.Heel 080415 PB - 2S-MegalodonL2 1.Heel 031114 PB - 2S-MegalodonL21.Heel 081115 11,500.00 29.26 90.00 113.32 6,180.00 10.03 19.47 10.03 11,600.00 29.27 90.01 116.35 6,179.99 10.17 20.31 10.17 11,700.00 29.29 90.01 119.62 6,179.98 10.33 21.21 10.33 11,800.00 29.30 90.01 123.10 6,179.96 10.49 22.17 10.49 11,900.00 29.32 90.02 126.78 6,179.93 10.66 23.18 10.66 12,000.00 29.25 90.02 99.47 6,179.90 9.71 14.82 9.70 12,100.00 29.25 90.03 100.04 6,179.86 9.76 15.04 9.76 12,200.00 29.25 90.03 100.62 6,179.81 9.81 15.27 9.81 12,300.00 29.26 90.03 101.21 6,179.75 9.87 15.52 9.87 12,400.00 29.26 90.04 101.82 6,179.69 9.93 15.79 9.93 12,500.00 29.26 90.04 102.44 6,179.62 9.99 16.07 9.99 12,600.00 29.26 90.05 103.08 6,179.55 10.06 16.36 10.06 12,700.00 29.27 90.05 103.74 6,179.46 10.13 16.67 10.13 12,800.00 29.27 90.05 104.42 6,179.37 10.20 16.99 10.20 12,900.00 29.27 90.06 105.13 6,179.28 10.27 17.32 10.27 13,000.00 29.28 90.06 105.87 6,179.18 10.35 17.66 10.35 13,100.00 29.28 90.07 106.64 6,179.07 10.43 18.02 10.43 13,200.00 29.29 90.07 107.45 6,178.95 10.51 18.38 10.51 13,300.00 29.29 90.07 108.30 6,178.82 10.60 18.75 10.59 13,400.00 29.30 90.08 109.19 6,178.69 10.68 19.13 10.68 13,500.00 29.31 90.08 110.13 6,178.56 10.77 19.52 10.77 13,600.00 29.31 90.08 111.12 6,178.41 10.86 19.92 10.86 13,700.00 29.32 90.09 112.18 6,178.26 10.96 20.33 10.95 13,800.00 29.33 90.09 113.30 6,178.10 11.05 20.74 11.05 10!7/2015 12:46.22PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-13 Project: Kuparuk River Unit TVD Reference: Plan: 119.8+28 @ 147.80usft (Doyon141) Site: Kuparuk 2S Pad MD Reference: Plan: 119.8+28 @ 147.80usft (Doyon141) Well: Plan: 2S-13 North Reference: True Wellbore: Plan: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-131-1wp13[Megalodon] Database: EDM Production Planned Survey 90.10 115.78 6,177.76 MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (I V) (usft) (usft) (usft) (usft) 13,900.00 29.34 90.10 114.50 6,177.94 11.15 21.15 11.15 14,000.00 29.35 90.10 115.78 6,177.76 11.25 21.58 11.24 14,100.00 29.36 90.10 117.15 6,177.58 11.35 22.01 11.35 14,200.00 29.37 90.11 118.61 6,177.40 11.45 22.44 11.45 14,300.00 29.38 90.11 120.18 6,177.20 11.56 22.88 11.55 14,400.00 29.39 90.12 121.86 6,177.00 11.66 23.33 11.66 14,500.00 29.40 90.12 123.66 6,176.80 11.77 23.78 11.77 14,600.00 29.41 90.12 125.57 6,176.58 11.88 24.23 11.88 14,700.00 29.43 90.13 127.61 6,176.36 11.99 24.69 11.99 14,800.00 29.44 90.13 129.75 6,176.14 12.11 25.15 12.11 14,900.00 29.45 90.14 132.01 6,175.90 12.22 25.61 12.22 15,000.00 29.47 90.14 134.35 6,175.66 12.34 26.08 12.34 15,100.00 29.48 90.14 136.76 6,175.41 12.46 26.55 12.46 15,200.00 29.50 90.15 139.22 6,175.16 12.58 27.02 12.58 15,300.00 29.51 90.15 141.69 6,174.90 12.70 27.50 12.70 15,400.00 29.53 90.16 144.15 6,174.63 12.82 27.98 12.82 15,500.00 29.55 90.16 146.56 6,174.35 12.95 28.46 12.94 15,600.00 29.56 90.16 148.91 6,174.07 13.07 28.95 13.07 15,700.00 29.58 90.17 151.16 6,173.78 13.20 29.43 13.19 15,800.00 29.60 90.17 153.31 6,173.48 13.32 29.92 13.32 15,900.00 29.62 90.18 155.34 6,173.18 13.45 30.41 13.45 16,000.00 29.64 90.18 157.25 6,172.87 13.58 30.90 13.58 16,100.00 29.66 90.18 159.03 6,172.55 13.71 31.40 13.71 16,200.00 29.68 90.19 160.70 6,172.23 13.85 31.89 13.84 16,300.00 29.70 90.19 162.24 6,171.90 13.98 32.39 13.98 16,400.00 29.73 90.20 163.68 6,171.56 14.11 32.89 14.11 16,500.00 29.75 90.20 165.02 6,171.22 14.25 33.39 14.25 16,600.00 29.77 90.20 166.26 6,170.87 14.38 33.89 14.38 16,700.00 29.80 90.21 167.42 6,170.51 14.52 34.39 14.52 16,800.00 29.82 90.21 168.49 6,170.14 14.66 34.90 14.66 16,838.69 29.83 90.21 168.89 6,170.00 14.71 35.09 14.71 2S-13 Megalodon L1 2. Toe 081115 PB circle 16,838.84 29.83 90.21 168.89 6,170.00 14.71 35.09 14.71 TD: 16838.84' MD, 6317.8' TVD - 2S-MegalodonL2 2.Toe 080415 PB - 2S-MegalodonL2 2.Toe 031114 PB - 2S-MegalodonL2 2. Toe 081115 PB - 2S-Megah 10/7/2015 12:46.22PM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 25-13 Project: Kuparuk River Unit TVD Reference: Plan: 119.8+28 @ 147.80usft (Doyonl41) Site: Kuparuk 2S Pad MD Reference: Plan: 119.8+28 @ 147.80usft (Doyonl41) Well: Plan: 2S-13 North Reference: True Wellbore: Plan: 25-131-1 Survey Calculation Method: Minimum Curvature Design: 2S-13L1wpl3[Megalodon] Database: EDM Production 10,226.77 16,838.84 6,317.80 4 1/2" x6 A4 4-1/2 6-3/4 —71 Formations Measured Vertical Depth Depth Measured (usft) (usft) Name 7,084.92 4,780.80 Growler -AA 8,225.79 5,440.80 Top Cairn 9,382.90 6,040.80 Top HRZ (K-2 mkr) 8,425.29 5,553.80 Top Bermuda 8,504.33 5,597.80 Base Bermuda 10,226.77 6,323.80 A4 8,587.97 5,643.80 C-35 10,149.75 6,310.80 Kuparuk C (Top C4) 9,876.36 6,237.80 Lower Kalubik (K-1 mkr) 9,616.83 6,140.80 Upper Kalubik (base HRZ) Lithology Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +El -W (usft) (usft) (usft) (usft) Comment 10,150.00 6,310.85 -84.83 -5,778.84 KOP: 13.56°/100' DLS, 0° TF, for 16.5' 10,166.50 6,313.99 -68.64 -5,779.53 Hold for 20' 10,186.50 6,317.42 -48.96 -5,780.36 Start 6°/100' DLS, 52.59° TF, for 285.53' 10,472.03 6,340.20 233.77 -5,758.66 Hold for 964.37' 11,436.40 6,327.92 1,180.00 -5,572.94 Start 4°/100' DLS, -177.25° TF, for 18.27' 11,454.67 6,327.80 1,197.93 -5,569.42 Start 0.14°/100' DLS, 88.32° TF, for 5384.17' 16,838.84 6,317.80 6,402.11 -4,203.18 TD: 16838.84' MD, 6317.8' TVD Checked By: Approved By: Date: 10/7/2015 12:46.22PM Page 5 COMPASS 5000.1 Build 74 Permit Pack 11.38, October 072015 12S-1 X1 wp13[Megalodon] Quarter Mile View 10500 7000 U) I 03500 LO M 11. L 0 Q Z i1 1 O X3500 -7000 Name TVD Shape 2S-Megalodonl2 1.Heel 081115 PS 6327.8D Circle (Radius: 100.00) 2S-MegalodonL2 2.Toe 081115 PS 6317.80 Circle (Radius: 100.00) 25-13 Megalodon Lt 2. Toe 081115 PBU MM Circle (Radius: 1320.00) 2S•MegolodonL2 1. Heel 081115 PE_�.80 Circle (Ratlius: 1320.00) -14000 -10500 -7000 -3500 0 3500 7000 10500 14000 11:43, October 072015 2S-131-1wp13[Megalodon] Quarter Mile View 10500 7000 c Cn I 03500 M L 0 0 Z 0 U3500 -7000 Name TVD Shape 2S-MegalodonL2 1.Heel 081115 PB 6327.80 Circle (Radius: 100.00) 2S-MegalodonL2 2.Toe 081115 PS 6317.80 Circle (Radius: 100.00) 25.13 Megalodon Lt 2. Toe 081115 PBUME80 Circle (Radius: 1320.00) 2S-MegolodonL2 1. Heel 081115 PB C@W.80 Circle (Radius: 1320.00) -14000 -10500 -7000 -3500 0 3500 7000 10500 14000 2S-13L1 wp13[Megalodon] Section View 20"x42" 0 1000 1500 03000 13 3/8"x16' -FuO0 00 L-301 ® D C/) L , 1 ~ 4500 O 1 OQ vj cc N in O 6000 w N 0 `. 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TopC4 State Plane 'Fmm--�------- ------- -- — } uomm {w�D83 `J Region: ' ~_* /---_ IDecimal Degrees r UTM Zone: South State Plane Zone: Units: us -ft r Legal Description (NAD27 only) 5tartingConrdinutes: X: 11615152.97 Y; 5929628.24 -Tu -------- Dumm Region: Latitude/Longitude Decimal Degrees (~ UTN Zone: G-���ue r -South «� StatoPlom, Zone: Units: f- Legal Description (NAD27only) Ending Coordinates: X: 475119.517887972 Y-' 5929878.74026167 CPAI Coordinate Converter LE� To: --- Dumm Region: r UTN Zone: [T�--rue r - South C State Plane Zone:T Units: ^---_� 6'Legal Description (NA027only) Legal Description -- if.... . ........... m TD State Plane M CPA.t Coordinate Converter rF From. I Datum: Nppgg Region: alaska {" Latitude/Longitude Decimal Degrees r UTM Zone: `-" r South t.' 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Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. 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. Attachment 5 — 2S -13L1 Cement Summary No cement is planned to be pumped under the 2S -13L1 PTD. STATE OF ALASKA ALS ,A OIL AND GAS CONSERVATION COMMI ON PERMIT TO DRILL 20 AAC 25.005 GLeG® V 1_.w AUG 24 ?015 1 a. Type of Work: 1b. Proposed Well Class: Development -Oil ❑✓ Service - Winj Q Single Zone 1c. Specify if well' proposed for: Drill • 0 Lateral ❑✓ Stratigraphic Test ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone L 1 Coalbed Gas Gas Hydrates ❑ Redril ❑ Reentry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Single Well ❑ 11. Well Na e and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2S-131_1 3. Address: 6. Proposed Depth: 12. Fie! /Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 17120 ` TVD: 6318 Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 3087.1' FNL, 1613.8' FEL, SEC 17, T1 ON, R8E, UM - ADL 25603, 25590 Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3007.6' FNL, 2168.3' FEL, Sec 18, To10N, R8E, UM 2677, 2678, 2675 9/18/2015 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1978.8' FNL, 575.7' FEL, Sec7, T10N, R8E, UM • 2512, 2501 3000' to ADL386051 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above N 148 'et 15. Distance to Nearest Well Open Surface: x-480,956.55' y-5,929,961.45' Zone- 4 GL Elevation above N , 120 /feet to Same Pool: 2681' To 2M-34 16. Deviated wells: Kickoff depth: , 10590 feet 17. Maximum Anticipated Pressures in sig (see 20 AAC 25.035) Maximum Hole Angle: - 90.8 degrees Downhole: 3751 Surface: 3129 18. Casing Program: Specifications Top - Setting Depth - yottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD M TVD (including stage data) 24" 16" 62.5# H-40 Welded 78' 28' 28' 106' 106' 111163' pre -driven 13.5" 10.75" 45.5# L-80 Hydril 563 2988' 28' 28' 3016.14' 2650.0' 200 sx 12 ppg / 1098 sx ASL 11 ppg 9.875" 7.625" 29.7# L-80 Hydril 563 11135' 28' 28' 6368' 701 sx 1st stage, 257 sx 2nd 15.8 G 6.75" 4.5" 11.6# L-80 IBTM 17092' 28' 28' 17120' 6318' N/A 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill Od Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. D i6th MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Ce ent Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): N/A P rforation Depth TVD (ft): N/A 20. Attachments: Property Plat ❑ BOP Sketchfilling Program Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ✓ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requuiremmeents0 21. Verbal Approval: Commission Representative: Ur Date 22. 1 hereby certify that the foregoing is true and correct. Scott Brunswick @ 263-4249 Contact scott. a. bru nswick(akop. com Email Printed Name Graham (Chip) Alvord Title Alaska Drilling Manager Signature _ lA.� Phone 265-6120 Date & (Z.A (i a 1cS Commission Use Only Permit to Drill Number: S_ /S2 API Number: ^ > Permit Approval See cover letter for other p� 5 - Qc7 Date: requirements. Conditions of approval : If box is chec d, well may not be used to explore for, test, or produce coalbed metha e, gas hydrates, or gas contained in shales: Other: Samples req'd: Yes N0 [� Mud log req'd: Yes❑ Noif H2S measures: Yes No Directional svy req'd: Yes[/ No❑ Spacing exception req'd: Yes ❑ No [A Inclination -only svy req'd: Yes❑ Nol?r APPROVED BY Approved by: COMMISSIONER THE OMMISSION Date: _/� M �� Submit Form and Form 10-401 (Revised 10/2012) T i r iLVis v li r nths from the date of rova 20 AAC 25.005(g)) Attachments in Duplicate l� RECEIVED AUG 2 4 2015 Post Office Box 100360 Anchorage, Alaska 99510-0360 AOGCC Phone (907) 263-4249 Email: scott.a.brunswick(a)conocophillips.com August 18, 2015 Alaska Oil and Gas Conservation Commission 333 West 7`1' Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 2S-131-1 Saved: 20 -Aug -15 ori coPhllli +C o ps Re: Application for Permit to Drill Well 2S -13L1 A4 Sand Pre -Produced Injector.✓ Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore pre -produced injector ell from the 2S pad. The expected spud date for this well is September 15, 2015. It is planned to use rig Doyon 141. 2S -13L1 is planned to be the upper lateral horizontal well in the Kuparuk A4 sand in parent well 2S-13. A pilot hole (2S- 13PB1, & 2S-13, both permitted on separate PTDs) will have be drilled to determine A4 sand presence and determination to complete the well as a dual lateral; if the A4 pay is absent the well will be completed as a single lateral in the A3 sand. When 2S -13L1 is commenced 10-3/4" casing will have been run to +/-3,016'MD / 2,650'TVD. The intermediate pilot hole section will have been drilled with a 9-7/8" bit to a depth of +/-10,529' MD / 6,448' TVD & plugged back to the 2S - 13L1 kick off point. The 2S -13L1 lateral in the A3 sand will have been drilled & completed with a 4-1/2" liner, a whipstock exist will have been commenced at the end of the 2S-13 PTD. 2S -13L1. The L1 lateral will be a 6-3/4" hole geo-steered to 17,120' MD / 6,318' TVD in the A4 & completed with a 4-1/2" slotted liner. 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: Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). Pressure information as required by 20 ACC 25.035 (d) (2). Casing and Cementing program. A drilling fluids program summary. A proposed drilling program. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 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 Scott Brunswick at 263-4249 (scott.a.brunswickgconocophillips.com) or Chip Alvord at 265-6120. Sincerely, Sco Drilling Engineer Application for Permit to Drill Document Kuparuk Well 2S-131-1 ConocoPhillip Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 2S -13L1 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 identifying 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 3087.1' FNL, 1613.8' FEL, Sec 17, T ION, ROOM, UM . NGS Coordinates Northings: 5,929,961.45' Eastings: 480,956.55' RKB Elevation 148' AMSL Pad Elevation 120' AMSL Location at Intermediate Casing 2464.75' FNL, 2107.4' FEL, Sec 18, TION, R008E, UM NGS Coordinates Northings: 5,930,600.52' Eastings: 475,183.23' Measured Depth, RKB: 11,163' Total Vertical Depth, RKB: 6,368' Total Vertical Depth, SS: 6,220' Location at Top of 3007.6' FNL, 2168.3' FEL, Sec 18, TION, ROME, UM Productive Interval (Ku aruk A Sand) NGS Coordinates Measured Depth, RKB: 10,612' Northings: 5,930,057.91' Eastings: 475,122.54' Total Vertical Depth, RKB: 6,324' Total Vertical Depth, SS: 6,176' Location at Total Depth 1978.8' FNL, 575.75' FEL, Sec 7, TION, ROME, UM L NGS Coordinates Northings: 5,936,361.03' Eastings: 476,711.89' Measured Depth, RKB: 17,120' Total Vertical Depth, RKB: 6,318' Total Vertical Depth, SS: 6,170' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be 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 wells 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) 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: (3) a diagram and description of the blowout prevention equipment (BOPE) 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 141. 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, except for 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 -13L1 is calculated using an estimated maximum reservoir pressure of 3,751 psi (11.5 ppg, based on Shark Tooth #1 appraisal well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,324' TVD: A Sand Estimated. BHP = 3,751 psi A Sand estimated depth = 6,324' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 632 psi (6,324' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 3,119 psi (3,751 psi — 632 psi) (B) data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation .:ones, and _ones that have a propensity for differential rerential sticking; See attached 2S -13L1 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 conducting formation integrity tests, as required under 20 AAC 25.03069; 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 be 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 Cementin 4 Program Csg/Tbg Hole iz WeighLength Grade Conn. Top MD/TVD Btm MDlTVD Cement Program OD (in) (in16 t (Ibfft) (ft) (ft) (ft) 24 62.5 H-40 Welded 78 Surf 106/106 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,988 Surf 3,016 / 2,650 1,098 sx DeepCRETE Lead 11.0 ppg, 200 sx Dee CRETE Tail Slurry 12.0 ppg Hydril 5c 2 stage cement job 7-5/8 9-7/8 29.7 L-80 563 11,135 Surf 11,163 / 6,368 1 701 sx 15.8 ppg Class G 2nd — 257 sx 15.8 ppg Class G 4-1/2 6-3/4 11.6 L-80 IBTM 17,092 Surf 17,120 / 6,318 N/A 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, exceptfor an item already on file with the commission and identified in the application: (7) a diagram and description of the divetter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,• Mud Program Summary Diagram of Doyon 141 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. Intermediate 9-7/8" Hole 7-5/8" Casing Production 6-3/4" Hole Mud System LSND (WBM) Flo-Thru (WBM) Density 9.5-11.5 10.5-12.2 Pv 10-20 25-30 YP 16-24 16-24 Initial Gel 10-12 5-8 10 minute Gel 10-18 5-12 API Filtrate < 6 < 6 HTHP Fluid Loss at 160F <10 <10 pH 9.0-10.0 9.5-10.0 Diagram of Doyon 141 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 follows. Please refer to attachment for proposed well schematic. 1. End PTD for 2S-13 & begin PTD for 2S-13L1 once on bottom with 6-3/4" drilling assembly. 2. Directionally drill 6-3/4" hole geosteering though the Kuparuk A4 sand to TD 17,120' MD as per directional plan (wp09). 3. Circulate hole clean and POOH. 4. Lay down Production BHA. 5. Pick up & make up hook (lug retrieving tool), string magnet, bumper sub, jars, float sub and MWD (directional only). 6. TIH 7. Break circulation & orient whipstock retrieving hook with MWD & hook the whipstock. 8. Pull whipstock free. 9. CBU X2. 10. Monitor well for flow. 11. POOH & lay down BHA & whipstock. 12. Make up bent joint to 2 joints of blank liner. 13. Run remainder of slotted liner in hole. 14. Rig up false rotary/ 15. Pick up HOOK hanger assembly & make up lower pup joint to S1imPulse MWD. 16. Remove false rotary table & make up hook hanger to liner. 17. Slowly pick up w/out pulling the slips & verify that the running assembly is fully engaged. 18. Run liner assembly in hole on 4" DP. 19. With liner shoe 45 ft above the casing exit, record the up & down weights & torque required to rotate. 20. Slowly lower the liner into the well & watch for increase in drag to confirm liner entered the 2S-13L1 lateral. 3.20.1. If tag top of liner in 25-13, pullback, rotate to adjust bend into 2S-13L1. 21. Run the liner to bottom until the hook hanger is 45 ft above the casing exit. 22. Orient with the MWD & rotate the string until the hook on the hook hanger is 180° from the casing exit. 23. Run in hole slowly & engage the hook hanger on the casing exit. 24. Set down 20 Klbs on the hook hanger. 25. Drop the ball & pump down getting ball on seat, don't exceed 1.5 bbFmin or 500 psi to prevent premature release of the HRD-E. 26. Increase the pressure & shear out the ball seat. 27. Shut down the pumps. 28. Pick up 3-5 ft., if no over pull this confirms HRD-E running tool has released. 29. Slowly retrieve the running string until it has cleared the hanger. 30. Flow check well, POOH, & lay down running gear. 31. Rig up & run the lower seal assembly to the tubing string. 32. Make up LEM running string, liner top packer, & running tool. 33. Run assembly in hole on 4" DP to -50 ft. above setting. 34. Take torque reading, pick up, slack off weights. 35. Break circulation & orient LEM with S1imPulse MWD. 36. With LEM aligned properly run in slowly stabbing in seal assembly and latch LEM. 37. Drop ball & rod for liner top packer setting. 38. Increase pressure & set packer. 39. Release running tool. 40. Check Pick up weight to confirm LEM located on the hook hanger. 41. Flow check well, POOH, & lay down running gear. 42. Rig up & run upper completions string. 43. Land hanger & run in lock down screws. 44. Test upper & lower seals to 250 psi & 5000 psi for 10 minutes. 45. Monitor well for flow for 15 minutes 46. Nipple down BOPE, nipple up tree and test. 47. Freeze protect well with diesel and install BPV. 48. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) 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 authorisation under 20 AAC 25.080for 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 Cement Summaries Attachment 1— Proposed Well Schematic 2-13L1 Grassroots Horizontal A -Sand Iffiector Proposed Wellbore Schematic (A4 Lateral) CC-AMEF40N 4-M-bft,IMjC#I 1: 4-,1' IZS*STM 19"CarxUftio-It5 Surface Casing 1"14- 45,58 L-80 HydI11543 UVIVID d2,65VTVD 2- Stage TCX-- fi.3W MW42119f TVD (I nftwn SW MID aliave C3T1 I I 11111 11 lWattler CC11317 7,X& MD 4,aZV Tla� -1 4x M"Mcn) 7-7 ConociPhillips Last Edited- SAMM9115 I 13.5" Surface Hole 9-7,18" Intermediate Hole C-37'1,177 VIIDB4,65e rM Ttp CAM: 1:,897 MD 15.441' V-11pawk BM'.4n CrI.MWA 10-W LU! C'MI, T -j-:1 KuMMlcA-':10.612'l.77i6-=n'D ------ ------ 7-%2—m Lx# LrFenger s t.. 2S-13Ll A4 TD -17.120' #9U 5,119 TVD KWanAA3-. lagW MW f.3W'TVD - -- ---E 7 ------------ ----------- ------- ------- --I- -- - _- - 7z7-- Intermediate Casing far., 7-5f8"253i L -EO Hyd593 Casing 11,163- MID 16,366 6-314" Production Hole TJC j 90' 1 MOTE- Swell Packer will be adjusted as necessary using intros ar,4 periscope data 111 Q 1. 1111 ro o h IIII 1111 I IIII IIII 6 HH 1111 1111 IIII Ili 111 IIII 1111 Itll 1111 1111 Illf 111 111 III III 111 1111 IIII 1111 1111 yl 111 111 111 III IIII 1111 IIII � IIII � 1111 c 1111 o III c III 111 � 111 III IIII nl 1111 � IIII IIII IIII m lIl 111 qI 1111 11111 p4 111 r"� 111 ti it M IIII gg IIII .:f IIII 111 �� b Ilt u � w o VIII iiiil 111 it 1j1 r»° m �• 111 III aA� III i IIII (IIII 11111 � 111 m p� 'r' VIII 1111 111 a tll "Q� \\\.y 1jI eo 111 �a' EC'. 111 111 IIII Illlt Itll I t I I 111 x 111 111 � 111 111 r III 1 f � G 11 I 1 v p' ^ Iw D t1i � S H i+ H e 8 � o l'J 1 d fifi 1 0 A „Wj �, 8 ,� � 2.Yf3 AbgrdcvS:+r 1�� .k�rimvtic a _UF rJ.f ConocoPhiHips Sharktooth Multi latteral Injector n.pa rJh-'fib. Kl,. Alaska -1'o1J MLL Drill Site 2S *.TER "to 7 TOE OF PAD T TOE OF PAD EDGE T PAD EOCE OF PAD EES o J J ELL F - lit DRILL SITE PLOT PLAN (8.5.1 ACRES) 30* -T Val SPACING TY- 'Aal HOUSE 25 50 Do Ft. W -T. IV -O" ConocoPhillips TITLE: DOWN 141 ON 2S-13 SCALE! I'- rte' -D" Alaskajnc, FORLIAT. 11".17'1 1 DRAWN BY: ALKET W1 f1ATE: 0T-27-2015 RES; t 91-2 Attachment 3 — 2S-13L1 Directional Plan DI 2S-1 311 p09 [Megalodon] 6.975 Plan Summary Top W Sak (W SakDJ C 37 Growler AAS C- 35_ _ p HRZ (K-2 mkr) 5 r_-=---HaseBer op -B r da Kuparuk C (Top C4) 5 I' Top Cairn [ top -3-Sand 1--C-80 C-40 _, ` 5 - Lower Kalubik (K-1 mkr) ,• cunt ( \ - rnr Upper Kalubik (base H Z) = " - " at K-'5 I o s erm rot (2) o Bae Sa C-50 0 0 0 4000 8000 12000 16000 10-3/4" x 13-1/2' Measured Depth 0 0° 10-3/4" x 13-1/2' Geodetic Datum: North American Datum 1983 >0 Depth Reference: Plan: 120+28 @ 148.00usft (Doyon 141) '} Rig: Doyon 141 o ' C4 o ,goo o I 4 112" x 6-3/4' o � °i 0 0 00 o tc�P I { 0 1500 3000 4500 O Zi 6 12-000 re III,.,,m��nnnIIIIIIIIIIIIl�1010epI IuIIIlutlIIIIIIII�IIIIIIIIIIIIIIIIIIuIIIIIIIIIIIIIIIIIIIII'IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIiiIllllll ill�ll�i�l�lill!INIIIIII��N IIII ,IIIIIiIIIIIpIIIII � __ IIII . , !.I �I�� o10"0 0 11.0 107 12 10780 - 109 330 -._ - 30 ;'-. 10960 y 11150 11340 300 60 11530 - 117 _ 11710 119 _ 11900 - 121 12110 123 12330 - 125 270 90 12540 - 127 50 12750 - 129 12960 - 131 13170 - 133 g3 vabeon ` 13390 - 136 13600 - 140 10800 11700 12600 13500 14400 15300 16200 17100 240 120 -- - - ---- 14040 - 144 14480 -- 149. SURVEY PROGRAM Surface Location Pad Elevation: 120.00 ,'l, 9 - :•, - -- 14920 - 153 15360 - 158 Depth From Depth To Surveyy/Plan Tool 28.00 1000.00 2S-13P61wp08 2S Y)D-GC-SS [Megalodon] (Plan: -13P(3 1000.00 3043.70 2S-13PB1wp08 [Megalodon] (PI&W9S9S M4AI,5-CAZ-SC 210 -- --- 150 12 -' 15800 162 3043.70 9400.00 2S-13PB1wp08 [Megalodon] (PIMr1H$i-ID9R815-CAZ-SC 180 16240 166 9400.00 9750.00 2S-13wp10.1 [Megalodon] (Plan: 2S-13) MWD CASING DETAILS 9750.00 10590.00 2S-13wp10.1 [Megalodon] (PlanAM-D-S)FR-AK-CAZ-SC 16680 - 171 10590.00 10940.00 2S-13L1p09 [Megalodon] (Plan: 2S-1311) MWD TVD MD Name 10940.00 12440.00 2S-13L1p09 Megalodon Plan: 2S -13L1 MWD [Megalodon] 6321.10 10591.00 7-5/8" x 9-7/8" Magnetic Model: BGGM2015 T 10940.00 17119.40 2S-13L1p09 Plan: I?3VCK F;R-AK-CAZ-SC 6318.00 17119.40 4 1/2" x 6-3/4" Magnetic Model Date: 15 -Oct -15 Magnetic Declination: Tp To convert a Magnetic Direction to a True Direction, a True Add 18.54° East SECTION DETAILS j,p, 330`$ T-3 Sand Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target Annotation 1 10590.00 80.64 356.92 6320.94 59.53 -5833.51 0.00 0.00 -1452.32 KOP: 13.56°/100' DLS, 0° TF, for 16.5' 2 10606.50 82.87 356.92 6323.31 75.83 -5834.39 13.56 0.00 -1436.80 Hold for 20' K-15 Marker 3 10626.5o82.87 356.92 6325.79 95.65 -5835.45 0.00 0.00 -1417.94 Start 7°/100' DLS, 63.54° TF, for 248.59' 4 10875.09 90.79 12.45 6339.60 342.07 -5815.14 7.00 63.54 -1174.66 Hold for 804.67' 5 11679.76 90.79 12.45 6328.46 1127.74 -5641.70 0.00 0.00 -370.86 Start 4°/100' DLS, 106.87° TF, for 59.09' 1358.0 6 11738.85 90.11 14.71 6328.00 1185.18 -5627.83 4.00 106.87 -311.80 2S-MegalodonL2 1.Heel 081115 PS Hold for 5380.54' 7 17119.40 90.11 1 4.7 16318.00 6389.35 4261.54 0.00 0.00 5068.67 2S-MegalodonL2 2.Toe 081115 PB TD: 17119.4' MD, 6318' TVD Base permafrost 1924.0 Top W Sak (V1/ & ., 258.0 ase W Sak 2774.0 Permit Pac c Failed Anti- ollisr C-80 4096.0 C-50 44 Minor Risked 47� Growler -AA yg��l'flHHaa C-35 assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack. I approve k as the basis for the final well ...._____________________-___-..........._--______-____________________--__-_-_______ [are repared by: Checked by: Accepted by: [ Approved by:yincent Osara Nate Beck IfeanIfesie S w N 3 0 LO M_ rn c t• i= 0 z August 18 2L-03 L-314PB12 2L-306PB1 2L-31 154111 10 -2 Easting (3500 usft/in) 2M- / 2M-02 ///M-07 --"2M-33 W�,�K 15 /2 -04 2M -32L1 PB1 2M-08 2S-14wp07 [Whale 2M-321-1 PB2 2M-34 2-2R4-1-�U1 2S-13L1wp09 [Megalo on] 2M-35 2S -13w7 11 --2K--2`Z 9wp08 [Tiger] ftJ�-02*m.1 [Goblin] PBlwtO6iupruk 2 Pad P61w 062S-13d p08 [Mlalocl,y - 2L-308 2L -3D4' - SlYark Tdoth #1 2L-31 wp06.L-3 2L-302 (w 1) 32 L-32 2L -317A 2L-320 2 -22 fE(v$01) /2s-IOWP12 [Wobbegong] 2L-32 2S-08wp 2S-03wp06 [Bamboo] 2L-33 L 1 09 a0i-oft Almon] 2N-322 � gwp05 2N Prelim: up ruk Cairn Pad2 J 302 iF „-322PB1 2N -301P 1 (WP03) Easting (3500 usft/in) U 21-10-8 1• 1 �,� 11 AL1 z2K-19 /2K-20 2 K -21A- 21 2K -22A z 0 3 2K-2 a ca W 0 0 c 2K-22 1 2 K-22 1 2S-13LlwpO9 [Megalodon] Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 6000 4 1/2" x 6-3/4" = 78 ----------- 25�13L1wp0 � 9lMegalod °nI 2S_ �3 w p�0 !Mega/orlon 2S MegalodonL2 2.Toe 081115 PB 4500 c 83000 L 71500 ,1 7-5/8"x9-7/8"-- _---_----- 0 2S-MegalodonL2 1.Heel 081115 B U) 2S-13PB1wP08 [Megalodon] 1000 600 10-3/4" x 13-1/ " oO -1500 0 �o 00 d 00 -9000 -7500 -6000 -4500 -3000 -1500 0 1500 3000 West( -)/East(+) (1500 usft/in) F2S--13L1p09 [Megalodon] Section View -1500- 150000° 0- 00 1000 -1500- U)0 :30 C) o 3000 10-3/4" x 13-1/2" �� Q ai Foo° N U)_ U 4500- O 0 (D000 '100, CD Q N O U) Ce 7-5/8" x 9-7/8" o CA) 6000 o00 ° a a o D00 0 0 ° 0 4 1/�x 6-3/4"0 2-13PB1wp08 [Megalodon] o 0 0 0 0 o CD v qxO Q 7500 2S-MegalodonL2 1. Heel 081115 PSB 2S-MegalodonL2 2.Toe 081115 PB o u -4500 -3000 -1500 0 1500 3000 4500 6000 7500 Vertical Section at 15.000 (1500 usft/in) 2S -13L1 p09 [Megalodon] Section View 6120- 6180- 0 a) 0 7-5/8" x 9-7/8" 2S-MegalodonL2 2.Tbe 081115 P 2S-MegalodonL2 1.Heel N1115 �B j6300 — ----------- 0 A40) C) C> C) C) b 4 1/2" x 6-3/4tD,, C) CD o C> 0 0(0 6360---- A3 S-13wp10.1 [Megalodon] 6420— 2 -13PB1wp08 [Megalodon] -1700 -850 0 850 1700 2550 3400 4250 5100 Vertical Section at 15.000 (850 usft/in) ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-13 Plan: 2S-131_1 Plan: 2S -13L1 p09 [Megalodon] Report 19 August, 2015 Permit Pack Failed Anti -Collision Minor Risked Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-13 Wellbore: Plan: 2S-131-1 Design: 2S-1311 p09 [Megalodon] Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: From: Map Position Uncertainty: Well Plan: 2S-13 Well Position +N/ -S +E/ -W Position Uncertainty Northing: Easting: 0.00 usft Slot Radius: Wellbore Plam 2S-131-1 Magnetics Model Name Design Audit Notes: Version: Vertical Section Northing: usft Easting: usft Wellhead Elevation BGGM2015 2S -131-1p09 [Megalodon] usft Latitude: usft Longitude: 13-3/16" Grid Convergence: Sample Date Declination 10/15/2015 18.54 Phase: PLAN Depth From (TVD) +N/ -S (usft) (usft) 28.00 0.00 usft Latitude: usft Longitude: usft Ground Level: Dip Angle 80.87 -0.14 ° 120.00 usft Field Strength (nT) 57,488 Tie On Depth: 10,590.00 +E/ -W Direction (usft) (°) 0.00 15.00 Survey Tool Program Date 8/19/2015 Schlumberger apply to =1�mne Report ore it. Local Co-ordinate Reference: Well Plan: 2S-13 TVD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) MD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: From: Map Position Uncertainty: Well Plan: 2S-13 Well Position +N/ -S +E/ -W Position Uncertainty Northing: Easting: 0.00 usft Slot Radius: Wellbore Plam 2S-131-1 Magnetics Model Name Design Audit Notes: Version: Vertical Section Northing: usft Easting: usft Wellhead Elevation BGGM2015 2S -131-1p09 [Megalodon] usft Latitude: usft Longitude: 13-3/16" Grid Convergence: Sample Date Declination 10/15/2015 18.54 Phase: PLAN Depth From (TVD) +N/ -S (usft) (usft) 28.00 0.00 usft Latitude: usft Longitude: usft Ground Level: Dip Angle 80.87 -0.14 ° 120.00 usft Field Strength (nT) 57,488 Tie On Depth: 10,590.00 +E/ -W Direction (usft) (°) 0.00 15.00 Survey Tool Program Date 8/19/2015 From To (usft) (usft) Survey (Wellbore) Tool Name Description 28.00 1,000.00 2S-13PB1wp08 [Megalodon] (Plan: 2S-131 GYD-GC-SS Gyrodata gyro single shots 1,000.00 3,043.70 2S-13PB1wp08 [Megalodon] (Plan: 2S-131 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,043.70 9,400.00 2S-13PB1wp08 [Megalodon] (Plan: 2S-131 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,400.00 9,750.00 2S-13wp10.1 [Megalodon] (Plan: 2S-13) MWD MWD - Standard 9,750.00 10,590.00 2S-13wp10.1 [Megalodon] (Plan: 2S-13) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,590.00 10,940.00 2S -131-1p09 [Megalodon] (Plan: 2S -13L1) MWD MWD - Standard 10,940.00 12,440.00 2S -131-1p09 [Megalodon] (Plan: 2S-131-1) MWD MWD - Standard 10,940.00 17,119.40 2S-13L1p09 [Megalodon] (Plan: 2S-131-1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (1/100usft) (°) (usft) 10,590.00 80.64 356.92 6,320.94 6,172.94 0.00 0.00 10.90 KOP: 13.56°/100' DLS, 0° TF, for 16.5' 10,591.00 80.77 356.92 6,321.10 6,173.10 13.56 0.00 10.93 7-5/8" x 9-7/8" 10,600.00 81.99 356.92 6,322.45 6,174.45 13.56 0.00 10.93 8/192015 10:54:58AM Page 2 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-13 Wellbore: Plan: 2S-1311 Design: 2S-1311 p09 [Megalodon] Planned Survey Schlumberger Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2S-13 Plan: 120+28 @ 148.00usft (Doyon 141) Plan: 120+28 @ 148.00usft (Doyon 141) True Minimum Curvature OAKEDMP2 MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) V) V) (usft) (usft) (°/100usft) V) (usft) 10,606.50 82.87 356.92 6,323.31 6,175.31 13.56 0.00 10.9E Hold for 20' 10,612.09 82.87 356.92 6,324.00 6,176.00 0.00 0.00 11.04 A4 10,626.50 82.87 356.92 6,325.79 6,177.79 0.00 0.00 11.04 Start 7°/100' DLS, 63.54° TF, for 248.59' 10,700.00 85.19 1.54 6,333.44 6,185.44 7.00 63.54 11.22 10,800.00 88.38 7.78 6,339.05 6,191.05 7.00 63.06 11.95 10,875.09 90.79 12.45 6,339.60 6,191.60 7.00 62.71 12.78 Hold for 804.67' 10,900.00 90.79 12.45 6,339.25 6,191.25 0.00 0.00 12.86 11,000.00 90.79 12.45 6,337.87 6,189.87 0.00 0.00 13.12 11,100.00 90.79 12.45 6,336.48 6,188.48 0.00 0.00 13.46 11,200.00 90.79 12.45 6,335.10 6,187.10 0.00 0.00 13.95 11,300.00 90.79 12.45 6,333.72 6,185.72 0.00 0.00 14.57 11,400.00 90.79 12.45 6,332.33 6,184.33 0.00 0.00 15.31 11,500.00 90.79 12.45 6,330.95 6,182.95 0.00 0.00 16.15 11,600.00 90.79 12.45 6,329.57 6,181.57 0.00 0.00 17.07 11,679.76 90.79 12.45 6,328.46 6,180.46 0.00 0.00 17.87 Start 4°/100' DLS, 106.87° TF, for 59.09' 11,700.00 90.56 13.22 6,328.23 6,180.23 4.00 106.87 17.97 11,738.85 90.11 14.71 6,328.00 6,180.00 4.00 106.88 18.12 Hold for 5380.54'- 2S-MegalodonL2 1.Heel 081115 PB - 2S-MegolodonL2 1. Heel 081115 PB_Cirlce - 2S-MegalodonL2 1. Heel 08111 11,738.97 90.11 14.71 6,328.00 6,180.00 0.00 0.00 18.12 2S-MegalodonL2 1.Heel 080415 PB 11,739.01 90.11 14.71 6,328.00 6,180.00 0.00 0.00 18.12 2S-MegalodonL2 1.Heel 031114 PB 11,800.00 90.11 14.71 6,327.89 6,179.89 0.00 0.00 18.64 11,900.00 90.11 14.71 6,327.70 6,179.70 0.00 0.00 19.70 12,000.00 90.11 14.71 6,327.51 6,179.51 0.00 0.00 20.81 12,100.00 90.11 14.71 6,327.33 6,179.33 0.00 0.00 21.96 12,200.00 90.11 14.71 6,327.14 6,179.14 0.00 0.00 23.14 12,300.00 90.11 14.71 6,326.96 6,178.96 0.00 0.00 24.36 12,400.00 90.11 14.71 6,326.77 6,178.77 0.00 0.00 25.60 12,500.00 90.11 14.71 6,326.59 6,178.59 0.00 0.00 16.26 12,600.00 90.11 14.71 6,326.40 6,178.40 0.00 0.00 16.60 12,700.00 90.11 14.71 6,326.21 6,178.21 0.00 0.00 16.96 12,800.00 90.11 14.71 6,326.03 6,178.03 0.00 0.00 17.32 12,900.00 90.11 14.71 6,325.84 6,177.84 0.00 0.00 17.69 13,000.00 90.11 14.71 6,325.66 6,177.66 0.00 0.00 18.08 13,100.00 90.11 14.71 6,325.47 6,177.47 0.00 0.00 18.48 13,200.00 90.11 14.71 6,325.28 6,177.28 0.00 0.00 18.88 13,300.00 90.11 14.71 6,325.10 6,177.10 0.00 0.00 19.30 13,400.00 90.11 14.71 6,324.91 6,176.91 0.00 0.00 19.72 13,500.00 90.11 14.71 6,324.73 6,176.73 0.00 0.00 20.15 8/192015 10:54:58AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-13 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) Well: Plan: 2S-13 North Reference: True Wellbore: Plan: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S -131-1p09 [Megalodon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°11OOusft) (°) (usft) 13,600.00 90.11 14.71 6,324.54 6,176.54 0.00 0.00 20.59 13,700.00 90.11 14.71 6,324.36 6,176.36 0.00 0.00 21.03 13,800.00 90.11 14.71 6,324.17 6,176.17 0.00 0.00 21.49 13,900.00 90.11 14.71 6,323.98 6,175.98 0.00 0.00 21.94 14,000.00 90.11 14.71 6,323.80 6,175.80 0.00 0.00 22.41 14,100.00 90.11 14.71 6,323.61 6,175.61 0.00 0.00 22.87 14,200.00 90.11 14.71 6,323.43 6,175.43 0.00 0.00 23.35 14,300.00 90.11 14.71 6,323.24 6,175.24 0.00 0.00 23.83 14,400.00 90.11 14.71 6,323.05 6,175.05 0.00 0.00 24.31 14,500.00 90.11 14.71 6,322.87 6,174.87 0.00 0.00 24.79 14,600.00 90.11 14.71 6,322.68 6,174.68 0.00 0.00 25.28 14,700.00 90.11 14.71 6,322.50 6,174.50 0.00 0.00 25.78 14,800.00 90.11 14.71 6,322.31 6,174.31 0.00 0.00 26.28 14,900.00 90.11 14.71 6,322.12 6,174.12 0.00 0.00 26.78 15,000.00 90.11 14.71 6,321.94 6,173.94 0.00 0.00 27.28 15,100.00 90.11 14.71 6,321.75 6,173.75 0.00 0.00 27.79 15,200.00 90.11 14.71 6,321.57 6,173.57 0.00 0.00 28.30 15,300.00 90.11 14.71 6,321.38 6,173.38 0.00 0.00 28.81 15,400.00 90.11 14.71 6,321.20 6,173.20 0.00 0.00 29.32 15,500.00 90.11 14.71 6,321.01 6,173.01 0.00 0.00 29.84 15,600.00 90.11 14.71 6,320.82 6,172.82 0.00 0.00 30.36 15,700.00 90.11 14.71 6,320.64 6,172.64 0.00 0.00 30.88 15,800.00 90.11 14.71 6,320.45 6,172.45 0.00 0.00 31.40 15,900.00 90.11 14.71 6,320.27 6,172.27 0.00 0.00 31.93 16,000.00 90.11 14.71 6,320.08 6,172.08 0.00 0.00 32.46 16,100.00 90.11 14.71 6,319.89 6,171.89 0.00 0.00 32.98 16,200.00 90.11 14.71 6,319.71 6,171.71 0.00 0.00 33.52 16,300.00 90.11 14.71 6,319.52 6,171.52 0.00 0.00 34.05 16,400.00 90.11 14.71 6,319.34 6,171.34 0.00 0.00 34.58 16,500.00 90.11 14.71 6,319.15 6,171.15 0.00 0.00 35.12 16,600.00 90.11 14.71 6,318.97 6,170.97 0.00 0.00 35.65 16,700.00 90.11 14.71 6,318.78 6,170.78 0.00 0.00 36.19 16,800.00 90.11 14.71 6,318.59 6,170.59 0.00 0.00 36.73 16,900.00 90.11 14.71 6,318.41 6,170.41 0.00 0.00 37.27 17,000.00 90.11 14.71 6,318.22 6,170.22 0.00 0.00 37.81 17,100.00 90.11 14.71 6,318.04 6,170.04 0.00 0.00 38.35 17,119.40 90.11 14.71 6,318.00 6,170.00 0.00 0.00 38.46 TD: 17119.4' MD, 6318' TVD - 2S-MegalodonL2 2.Toe 080415 PB - 2S-MegalodonL2 2.Toe 031114 PB - 2S-MegalodonL2 2. Toe 0811 8/1912015 10:54:58AM Page 4 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-13 Wellbore: Plan: 2S-131-1 Design: 2S -131-1p09 [Megalodon] Formations 10,591.00 6,321.10 7-5/8" x 9-7/8" 17,119.40 6,318.00 4 1/2" x 6-3/4" Schlumberger Report Local Co-ordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Measured Vertical Depth Depth Vertical (usft) (usft) Name Lithology 8,902.87 5,598.00 Base Bermuda 9,909.78 6,141.00 Upper Kalubik (base HRZ) 10,531.74 6,311.00 Kuparuk C (Top C4) 7,404.34 4,781.00 Growler -AA 10,194.38 6,238.00 Lower Kalubik (K-1 mkr) 10,612.09 6,324.00 A4 8,597.52 5,441.00 Top Cairn 7,172.13 4,654.00 C-37 8,994.08 5,644.00 C-35 9,699.82 6,041.00 Top HRZ (K-2 mkr) 8,815.44 5,554.00 Top Bermuda Well Plan: 2S-13 Plan: 120+28 @ 148.00usft (Doyon 141) Plan: 120+28 @ 148.00usft (Doyon 141) True Minimum Curvature OAKEDMP2 7-5/8 9-7/8 4-1/2 6-3/4 Dip Dip Direction (0) (0) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 10,590.00 6,320.94 59.53 -5,833.51 KOP: 13.56°/100' DLS, 0° TF, for 16.5' 10,606.50 6,323.31 75.83 -5,834.39 Hold for 20' 10,626.50 6,325.79 95.65 -5,835.45 Start 7°/100' DLS, 63.54° TF, for 248.59' 10,875.09 6,339.60 342.07 -5,815.14 Hold for 804.67' 11,679.76 6,328.46 1,127.74 -5,641.70 Start 4°/100' DLS, 106.87° TF, for 59.09' 11,738.85 6,328.00 1,185.18 -5,627.83 Hold for 5380.54' 17,119.40 6,318.00 6,389.35 -4,261.54 TD: 17119.4' MD, 6318' TVD Checked By: Approved By: Date: 8/1912015 10:54:58AM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-13 Plan: 2S-131_1 2S-131_1 p09 [Megalodon] Clearance Summary Anticollision Report 19 August, 2015 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-13 - Plan: 2S -13L1 - 2S -13L1 p09 [Megalodon] Well Coordinates: Datum Height: Plan: 120+28 @ 148.00usft (Doyon 141) Scan Range: 10,590.00 to 17,119.40 usft. Measured Depth. Scan Radius is 1,909.14 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 FFailednti-Collision ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-13 - 2S-131-1 pO9 [Megalodon] To Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) (usft) Reference Design: Kuparuk 2S Pad - Plan: 2S-13 - Plan: 2S -13L1 - 2S-131_1 p09 [Megalodon] Scan Range: 10,590.00 to 17,119.40 usft. Measured Depth. 1,000.00 Scan Radius is 1,909.14 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 1,000.00 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2S Pad Plan: 2S-12 - Plan: 2S-12 - 2S-12wp07 [Bull] 11,011.09 1,782.06 11,011.09 1,667.52 8,325.00 15.558 Clearance Factor Pass - Major Risk Plan: 2S-13 - Plan: 2S-13 - 2S-13wp10.1 [Megalodon] 10,590.00 Plan: 2S-13 - Plan: 2S-13 - 2S-13wp10.1 [Megalodon] ® ®®® ® ®® Survey tool program From To Survey/Plan (usft) (usft) 28.00 1,000.00 1,000.00 3,043.70 3,043.70 9,400.00 9,400.00 9,750.00 9,750.00 10, 590.00 10,590.00 10,940.00 2S-13L1p09 [Megalodon] 10,940.00 12,440.00 2S-131_1 p09 [Megalodon] 10,940.00 17,119.40 2S -131_1p09 [Megalodon] Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool GYD-GC-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD MWD+IFR-AK-CAZ-SC 19 August, 2015 - 10:53 Page 2 of 4 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-13 Plan: 2S-131-1 2S-131-1 p09 [Megalodon] Clearance Summary Anticollision Report 19 August, 2015 Minor Risked Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-13 - Plan: 2S -13L1 - 2S -13L1 p09 [Megalodon] Well Coordinates: Datum Height: Plan: 120+28 @ 148.00usft (Doyon 141) Scan Range: 10,590.00 to 17,119.40 usft. Measured Depth. Scan Radius is 1,909.14 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-13 - 2S-131-1 p09 [Megalodon] Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-13 - Plan: 2S-131_1 - 2S-13L1p09 [Megalodon] Scan Range: 10,590.00 to 17,119.40 usft. Measured Depth. Scan Radius is 1,909.14 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 28.00 Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2S Pad 10,590.00 10,590.00 10,940.00 2S -131-1p09 [Megalodon] Plan: 2S-12 - Plan: 2S-12 - 2S-12wp07 [Bull] 11,011.09 1,782.06 11,011.09 1,667.52 8,325.00 15.558 Clearance Factor Pass - Major Risk Plan: 2S-13 - Plan: 2S-13 - 2S-13wp10.1 [Megalodon] ® ®® Plan: 2S-13 - Plan: 2S-13 - 2S-13wp10.1 [Megalodon] Survey tool program From To Survey/Plan (usft) (usft) 28.00 1,000.00 1,000.00 3,043.70 3,043.70 9,400.00 9,400.00 9,750.00 9,750.00 10,590.00 10,590.00 10,940.00 2S -131-1p09 [Megalodon] 10,940.00 12,440.00 2S-131-1 p09 [Megalodon] 10,940.00 17,119.40 2S -131-1p09 [Megalodon] Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool GYD-GC-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD MWD+IFR-AK-CAZ-SC 19 August, 2015 - 10:58 Page 2 of 4 COMPASS ConotoPhillips 2S-13L1 p09 [Megalodon] Schlumberger Alaska 7iled"Anti-C ollisil 9 W 0 60— O .0 : iA i Q N Equivelant Magnetic Distance r r N C Q) 0 30- O 0 0 11400 12350 13300 14250 15200 16150 17100 Displayed interval could be less than entire range: Measured DeK9b590.00 To 17119.40 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 10590.00 To 17119.40 Results Limited By: Centre Distance: 1909.14 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1000.00 2S-13PB1wp08 [Megalodon] (Plan: 2S-13PB1) GYD-GC-SS 1000.00 3043.70 2S-13PB1wp08 [Megalodon] (Plan: 2S-13PB1) MWD+IFR-AK-CAZ-SC 3043.70 9400.00 2S-13PB1wp08 [Megalodon] (Plan: 2S-13PB1) MWD+IFR-AK-CAZ-SC 9400.00 9750.00 2S-13wp10.1 [Megalodon] (Plan: 2S-13) MWD 9750.00 10590.00 2S-13wp10.1 [Megalodon] (Plan: 2S-13) MWD+IFR-AK-CAZ-SC 10590.00 10940.00 2S-13L1p09 [Megalodon] (Plan: 2S-13L1) MWD 10940.00 12440.00 2S-13L1p09 [Megalodon] (Plan: 2S-13L1) MWD 10940.00 17119.40 2S-13L1p09 [Megalodon] (Plan: 2S-13L1) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 6321.10 10591.00 7-5/8" x 9-7/8" 7-5/8 6318.00 17119.40 4 1/2" x 6-3/4" 4-1/2 LEGEND -� Plan: 25-04, Plan: 2S-04, 2S-04wpO9 [Lemon] VO - - Plan: 25-11, Plan: 2S-11, 2S-11wp06 [Great White] VO Plan: 2S-15, Plan: 2S-15, 2S-15wpO6 [Helicoprion] VO -�-- Plan: 2S-05, Plan: 2S-05, 2S-05wpO6 [Nurse] VO Plan: 2S-11, Plan: 2S-11Li, 2S-11L1wp06 [Great White] VO Plan: 2S-16, Plan: 2S-16, 2S-16wpO6 [Squalicorax] VO -�- Plan: 2S-06, Plan: 2S-06, 2S-06wpO6 [Salmon] VO -3- Plan: 2S-12, Plan: 2S-12, 2S-12wpO7 [Bull] VO Plan: 2S-17, Plan: 2S-17, 2S-17wpO6 [Hybodus] VO -� Plan: 2S-08, Plan: 2S-08, 2S-08wpO7 [Hammerhead] VO Plan: 2S-13, Plan: 2S-13, 2S-13wp10.1 (Megalodon] VO Rig: 2S-07, Rig: 2S-07, 2S-07wp12.1 [Goblin] VO -A- Plan 2S-09, Plan: 2S-09, 2S-09wp06 [Tiger] VO Plan: 2S-13, Plan 2S-13PB7, 2S-13PB1wpO8 [Megalodon] VO--O-- Rig: 2S-07, Rig: 2S-07, Rig: 2S-07 VO -e- Plan: 2S-10, Plan: 2S-10, 2S-tOwpl2 [Wobbegong] VO - Plan. 2S-14, Plan: 2S-14, 2S-14wp07 [Whale] VO -f3- 23-13Lip09 [Megalodon] �/ Conoco Phillips Alaska 2S -13L1 p09 [Megalodon] Schlumberger Minor Risked 60— I , o a a .2 N / (n Equivelant Magnetic Distance j C N UO 30- 0 L U I 0 11400 12350 13300 14250 15200 16150 17100 Displayed interval could be less than entire range: Measured Depit)59O.O0 To 17119.40 ANTI -COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 10590.00 To 17119.40 Results Limited By: Centre Distance: 1909.14 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1000.00 2S-13PB1wp08 [Megalodon] (Plan: 2S-13PB1) GYD-GC-SS 1000.00 3043.70 2S-13PB1wp08 [Megalodon] (Plan: 2S-13PB1) MWD+IFR-AK-CAZ-SC 3043.70 9400.00 2S-13PB1wp08 [Megalodon] (Plan: 2S-13PB1) MWD+IFR-AK-CAZ-SC 9400.00 9750.00 2S-13wpl0.1 [Megalodonj (Plan: 2S-13) MWD 9750.00 10590.00 2S-13wpl0.1 [Megalodon] (Plan: 2S-13) MWD+IFR-AK-CAZ-SC 10590.00 10940.00 2S-13L1p09 [Megalodon] (Plan: 2S -13L1) MWD 10940.00 12440.00 2S-13L1p09 [Megalodon] (Plan: 2S -13L1) MWD 10940.00 17119.40 2S-13L1p09 [Megalodon] (Plan: 2S -13L1) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 6321.10 10591.00 7-5/8" x 9-7/8" 7-5/8 6318.00 17119.40 4 1/2" x 6-3/4" 4-1/2 LEGEND -� Plan: 25-04, Plan: 2S-04, 2S-04wp09 [Lemon] VO- Plan: 25-11, Plan: 25-11, 25-11wp06 [Great While] VO Plan: 25-15, Plan: 25-15, 2S-15wp06 [Helicoprion] VO -�- Plan: 25-05, Plan: 25-05, 2S-05wp06 [Nurse] VO Plan: 25-11, Plan: 2S-111-1, 25-11 L1wp06 [Great White] VO Plan 25-16, Plan: 2S-16, 2S-16wp06 [Squalicorax] VO Plan: 2S-06, Plan: 25-06, 2S-06wp06 [Salmon] VO Plan: 25-12, Plan. 25-12, 2S-12wp07 [Bull] VO Plan: 2S-17, Plan: 2S-17, 2S-17wp06 [Hybodus] VO -� Plan. 2S-08, Plan. 2S-08, 2S-08wp07 [Hammerhead] VO $- Plan: 25-13, Plan: 25-13, 2S-13wp10.1 [Megalodon] VO Rig: 25-07, Rig: 25-07, 2S-07wp12.1 [Goblin] VO --A--- Plan: 25-09, Plan: 2S-09, 2S-09wp06 [Tiger] VO Plan: 2S-13, Plan: 2S-13PB1, 2S-13PB1wp08 [Megalodon] V04�)-- Rig: 2S-07, Rig: 25-07, Rig: 25-07 VO -� Plan: 2S-10, Plan: 25-10, 2S-10wp12 ]Wobbegong] VO Plan: 25-14, Plan: 2S-14, 2S-14wp07 [Whalej VO -f3-- 2S-1311 p09 [Megalodon] MD Azi TVD +N/ -S +E/ -W Dleg TFace Target uJ 10590.00 356.92 6320.94 59.53 -5833.51 0.00 0.00 -14 S -13L1 p09 [Megalodon] 10606.50 b- . 356.92 6323.31 75.83 -5834.39 13.56 0.00 -143- 10590 10780 10626.50 82.87 356.92 6325.79 95.65 -5835.45 0.00 0.00 -1417.94 10590.00 To 17119.40 10875.09 90.79 12.45 6339.60 342.07 5815.14 7.00 6354 174.66 10780 10960 11679.76 90.79 12.45 6328.46 1127.74 -5641.70 0.00 0.00 -370.86 11738.85 90.11 14.71 6328.00 1185.18 -5627.83 4.00 106.87 -311.80 2S-Megalodon L2 I.Heel 081115 PB 17119.40 90.11 14.71 6318.00 6389.35 -4261.54 0.00 0.00 5068.67 2S-MegalodonL2 2.Toe 081115 PB 10960 11150 90:55, August 19 2#315 11150 11340 S -Y PPOGFPM 11340 11530 pth From Depth T Survey/Plan Tool 29 UO 1000.00 2S -13P-08 [Megalodon] [BI'RSia S-) 11530 11710 1000 00 3043.]0 25-13PBiwp09 [Megalodon] M1N@f8tH1 3 -SC 3043.70 9600.00 2S-13Pa1 wp09 (Megalodon] )IIIA4M--AZSC 9750.00 1059000 2S 13wp10.1 [Meo.l�gal eonj(PlMri'B9M35 P --SC 11710 Am 11900 10590.00 10940.00 2S-13L1p09[M1legalodon])PImYI®-13L1) 10940.00 12440.00 25-13L1p09[Megalodon])PI-13L1) 11900 12110 1094000 17119.40 2S-13L1p09[Megalotlon](PIfIS78NB"KCp- CASING DETAILS 12110 12330 TVDMD Name Sae 12330 12540 6321.10 10591.00 7-5/8" x 9-7/8" 7-5/8 .. - 6318.00 17119.40 41/2"x6-3/4" 4-1/2' 12540 12750 Failed Anti-Collisio 1 12750 12960 12960 13170 0/360 13170 """ "-" 13390 --------_.__ 13390 13600 y Y 13600 14040 -30/330 *`Y,30 14040 14480 14480 14920 4W`%,, 14920 15360 �\ x \y< 15360 15800 j h4t x/ �\ \ 15800 16240-9- 16240 16680 -60/300 60 16680 17119 Y -90/27 90 -120/240 \� 1 Ii3NW)r' j 120 2S-13 10.1 a alodon 1 r -150/210= J �3 _ i- $150 -- = -180/180 -�- a " an soawpos lt•moNva -� a ". " 09++We lTgerlv0 $ a " ".5,iwW7iewilvo -j(- v n. n. ,swpos lNe„cewlvp $ a so,va $ P " .,, soswpos iH"n,iw $ P ". zs,ow,zrv+ooxso"el vo $ P ". ," pl iM<9.e�"Ivo -� P ". ,awaisa"aK�a.rvp $ z9-u� wslMemnm"Ig 3a1..wa)sao�avp -*- P1.11Pe,.wa ro,..�am"rvp $ P " " - za,M1010veaam vp xsoe. -3ue. asoew,o; lenmm.m.aal vo $ Pian asn,Pao.3suu, zsnuwttt lama, wnnelvp -} Pim".u-vv¢".zs,.. es �,a.,porlwxaklv0 � qq is0i ag. asa,'zsm.p¢,�rmonyvo 2S-13wp10.1 [Megalodon] 150/210 •�- c e. an =2 o..-�- aae. an oa.WaI1,111 21.:a� sos.am'Mersal vp �' vas e. p,x fwo5�N�91 ve -fr- 11.1 5a5wW¢Isa-j" -{- aan an. i We�c,<z, wnrze�v0 via�.xsw. Pn�358e. 35oewpo;I»zmew�rozelv0 -� vu�1s,,.aue. 35.,,11. 3s„t,.F89Ierex wnrt.l v0 -180/180 $ >1111 2112 13 7I1»p i- van ae1.,Wsluwaio0onlvo 2-4 Pae u,.. zs�,a�ollwnaelvo 150 �. -s-,SLAWS lneieopm�ive �- 8i oa salve -9- n. - - 3s,ay05l3aezaoa.)ve,as7 By 2-1 zeNellae0ximo�,g z a �< �- ey asa. Vzsoz 3sa w,3,I0ocm)w 10780 10960 11150 11340 11530 11710 11900 12110 12330 12540 12750 12960 13170 13390 13600 14040 14480 14920 15360 15800 16240 16680 17119 MD Ali TVD +N/ -S +E/ -W Dleg TFa.. Target 10590.00 356.92 6320.9459.53 -5833.51 0.00 0.00 -1 S-13L1p09 [Megalodon] 10606.50 356.92 632331 75.83 -5834.39 13.56 0.00 -14- 1 10590 10590.00 To 17119.40 10626.50 82.87 356.92 6325.79 95.65 -5835.45 0.00 0.00 -1417.94 10875.09 90.79 12.45 6339.60 342.07 -5815.14 7.00 63.54 1174.66 11679.76 90.79 12.45 6328.46 1127.74 0.00 10780 -5641.70 0 -370.86 .00 11738.85 90.11 14.71 6328.00 1185.18 -5627.83 4.00 106.87 -311.80 2S-MegalodonL2 1.Heel 08111 5PB 17119.40 90.11 14.71 6318.00 6389.35 -4261.54 0.00 0.00 5068.67 2S-MegalodonL2 2.Toe 081115 PB 10960 x.59 1,2 20�15 1 11150 SURVEY PRpGRPM 11340 pth From Depth T--ylPlan Tool 28.00 1080.0025-13Patwp08 [M---] V - S-) 11530 1000.00 3043.70 2S-1-81wp08 [Megalodon] ].M4blB11.11®n- 3063.]09080.00 25-13Patwp08 [Megalodon] (NlOh,IEO•il ®+- 9000.00 9]50.00 2813wp10.1[Megalodonj(P-.-13) 9]5000 10590.00 25-13wp10.1 [Megalodon] )PIYWatZgM�PXLA29C 11710 10590.00 10960.00 25-13L1p09[Megalodon] (PIa1V®-13L1) 10960.00 1206000 25-13L1p09 [Megalodon] (PI:tlY®-13L1) 10960.00 17119.40 25.13Lip09 [Megalodonj (PIatlL®N966p- -SG 11900 CASING DETAILS 12110 TVDMD Name Size 12330 6321.10 10591.00 7-5/8" x 9-7/8" 7-5/8 6318.00 17119.40 41/2"x6-3/4" 4-1/2 12540 Minor Risked 12750 erent . 12960 =&Y 13170 es Scales ' 0/360 - _-- --------_----:, 13390 - 13600 -30/330 = _ _' 30 14040 ,. $� �� �� 14480 14920 \ \ 15360 �x r- 15800 16240 -60/300 60 16680 \\ -90/27 90 -120/240 120 2S-13wp10.1 [Megalodon] 150/210 •�- c e. an =2 o..-�- aae. an oa.WaI1,111 21.:a� sos.am'Mersal vp �' vas e. p,x fwo5�N�91 ve -fr- 11.1 5a5wW¢Isa-j" -{- aan an. i We�c,<z, wnrze�v0 via�.xsw. Pn�358e. 35oewpo;I»zmew�rozelv0 -� vu�1s,,.aue. 35.,,11. 3s„t,.F89Ierex wnrt.l v0 -180/180 $ >1111 2112 13 7I1»p i- van ae1.,Wsluwaio0onlvo 2-4 Pae u,.. zs�,a�ollwnaelvo 150 �. -s-,SLAWS lneieopm�ive �- 8i oa salve -9- n. - - 3s,ay05l3aezaoa.)ve,as7 By 2-1 zeNellae0ximo�,g z a �< �- ey asa. Vzsoz 3sa w,3,I0ocm)w 10780 10960 11150 11340 11530 11710 11900 12110 12330 12540 12750 12960 13170 13390 13600 14040 14480 14920 15360 15800 16240 16680 17119 AC wens ONLY (NOT a Spider) P Easting (3500 usft/in) 2S-14wp07 [Whale] 2S-13L1p09 [Megalo on] f-2S-13wp1p.ZqA0"0j 2S-13pEpwp08 2S-12wg0j [Bull] 6 [Tiger] lR%-102W.1 [Goblin] 2S-10wp12 [Wobbegong] I 2S-08wpW YAa0""fdIImon] Prelim: Kuparuk Cairn P Prelim: Kuparuk Cairn Pad co- i r vvN LI 'Yuuuua �2S-16wp [Squalicorax] 2S-15wp06 [Helicoprion] Easting (3500 usft/in) 2S-05wp06 [Nurse] Prrors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-13 Plan: 2S-131-1 Plan: 2S -13L1 p09 [Megalodon] Error Ellipse Report 19 August, 2015 W. Utlp�y Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-13 Wellbore: Plan: 2S-131-1 Design: 2S-131-1 p09 [Megalodon] Schlumberger Error Ellipse Report Local Co-ordinate Reference: Well Plan: 2S-13 TVD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) MD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: From: Map Position Uncertainty: Northing: Easting: 0.00 usft Slot Radius: usft Latitude: usft Longitude: 13-3/16" Grid Convergence: -0.14 ° Well Plam 2S-13 Well Position +N/ -S usft Northing: usfi Latitude: +E/ -W usft Easting: usfi Longitude: Position Uncertainty usft Wellhead Elevation: usfi Ground Level: 120.00 usft Wellbore Plan: 2S-131-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1) (nT) BGGM2015 10/15/2015 18.54 80.87 57,488 Design 2S-1311 p09 [Megalodon] Audit Notes: Version: Phase: PLAN Tie On Depth: 10,590.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 28.00 0.00 0.00 15.00 Survey Tool Program Date 8/19/2015 From To (usft) (usft) Survey (Wellbore) Tool Name Description 28.00 1,000.00 2S-13PB1wp08 [Megalodon] (Plan: 2S-131 GYD-GC-SS Gyrodata gyro single shots 1,000.00 3,043.70 2S-13PB1wp08 [Megalodon] (Plan: 2S-131 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,043.70 9,400.00 2S-13PB1wp08 [Megalodon] (Plan: 2S -13f MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,400.00 9,750.00 2S-13wp10.1 [Megalodon] (Plan: 2S-13) MWD MWD - Standard 9,750.00 10,590.00 2S-13wp10.1 [Megalodon] (Plan: 2S-13) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,590.00 10,940.00 2S -131-1p09 [Megalodon] (Plan: 2S-131-1) MWD MWD - Standard 10,940.00 12,440.00 2S -13I -1p09 [Megalodon] (Plan: 2S-131-1) MWD MWD - Standard 10,940.00 17,119.40 2S -131-1p09 [Megalodon] (Plan: 2S-131-1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (1 (°) (usft) (usft) (usft) (usft) 10,590.00 29.19 80.64 89.12 6,172.94 9.36 10.90 10.80 KOP: 13.56°/100' DLS, 0° TF, for 16.5' 10,591.00 29.32 80.77 89.30 6,173.10 9.32 10.93 10.49 7-5/8" x 9-7/8" 10,600.00 29.32 81.99 89.30 6,174.45 9.32 10.93 10.49 8/19/2015 10:55:19AM Page 2 COMPASS 5000.1 Build 74 Schlumberger Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-13 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.O0usft (Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.O0usft (Doyon 141) Well: Plan: 2S-13 North Reference: True Wellbore: Plan: 2S-131-1 Survey Calculation Method: Minimum Curvature Design: 2S -131-1p09 [Megalodon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 10,606.50 29.39 82.87 89.41 6,175.31 9.32 10.96 10.29 Hold for 20' 10,612.09 29.39 82.87 89.76 6,176.00 9.32 11.04 10.29 A4 10,626.50 29.39 82.87 89.76 6,177.79 9.32 11.04 10.29 Start 7°/100' DLS, 63.54° TF, for 248.59' 10,700.00 29.59 85.19 91.03 6,185.44 9.33 11.22 9.83 10,800.00 29.60 88.38 92.77 6,191.05 9.35 11.95 9.44 10,875.09 29.39 90.79 94.07 6,191.60 9.38 12.78 9.36 Hold for 804.67' 10,900.00 29.40 90.79 94.50 6,191.25 9.39 12.86 9.37 11,000.00 29.41 90.79 96.41 6,189.87 9.41 13.12 9.40 11,100.00 29.41 90.79 98.24 6,188.48 9.43 13.46 9.41 11,200.00 29.41 90.79 100.14 6,187.10 9.46 13.95 9.44 11,300.00 29.42 90.79 102.14 6,185.72 9.50 14.57 9.48 11,400.00 29.42 90.79 104.27 6,184.33 9.56 15.31 9.54 11,500.00 29.42 90.79 106.55 6,182.95 9.63 16.15 9.61 11,600.00 29.42 90.79 109.03 6,181.57 9.71 17.07 9.69 11,679.76 29.42 90.79 111.17 6,180.46 9.79 17.87 9.77 Start 4°/100' DLS, 106.87° TF, for 59.09' 11,700.00 29.46 90.56 111.72 6,180.23 9.81 17.97 9.79 11,738.85 29.53 90.11 112.76 6,180.00 9.85 18.12 9.84 Hold for 5380.54'- 2S-MegalodonL2 1.Heel 081115 PB - 2S-MegolodonL2 1. Heel 081115 PB_CirIce, - 2S-MegalodonL2 1. Heel 08111 11,738.97 29.53 90.11 112.76 6,180.00 9.85 18.12 9.84 2S-MegalodonL2 1.Heel 080415 PB 11,739.01 29.53 90.11 112.76 6,180.00 9.85 18.12 9.84 2S-MegalodonL2 1.Heel 031114 PB 11,800.00 29.53 90.11 114.50 6,179.89 9.91 18.64 9.91 11,900.00 29.53 90.11 117.65 6,179.70 10.04 19.70 10.03 12,000.00 29.54 90.11 121.12 6,179.51 10.17 20.81 10.17 12,100.00 29.54 90.11 124.90 6,179.33 10.31 21.96 10.31 12,200.00 29.54 90.11 128.94 6,179.14 10.47 23.14 10.47 12,300.00 29.54 90.11 133.17 6,178.96 10.63 24.36 10.63 12,400.00 29.55 90.11 137.47 6,178.77 10.81 25.60 10.81 12,500.00 29.38 90.11 104.32 6,178.59 9.81 16.26 9.81 12,600.00 29.38 90.11 105.00 6,178.40 9.87 16.60 9.86 12,700.00 29.38 90.11 105.71 6,178.21 9.92 16.96 9.92 12,800.00 29.38 90.11 106.44 6,178.03 9.98 17.32 9.98 12,900.00 29.39 90.11 107.21 6,177.84 10.04 17.69 10.04 13,000.00 29.39 90.11 108.02 6,177.66 10.10 18.08 10.10 13,100.00 29.39 90.11 108.86 6,177.47 10.17 18.48 10.17 13,200.00 29.39 90.11 109.76 6,177.28 10.24 18.88 10.24 13,300.00 29.40 90.11 110.70 6,177.10 10.31 19.30 10.31 13,400.00 29.40 90.11 111.71 6,176.91 10.39 19.72 10.38 13,500.00 29.40 90.11 112.77 6,176.73 10.46 20.15 10.46 8/19/2015 10:55:19AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-13 Project: Kuparuk River Unit TVD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) Well: Plan: 2S-13 North Reference: True Wellbore: Plan: 2S-1311 Survey Calculation Method: Minimum Curvature Design: 2S -131-1p09 [Megalodon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 13,600.00 29.40 90.11 113.91 6,176.54 10.54 20.59 10.54 13,700.00 29.41 90.11 115.12 6,176.36 10.62 21.03 10.62 13,800.00 29.41 90.11 116.42 6,176.17 10.71 21.49 10.71 13,900.00 29.41 90.11 117.81 6,175.98 10.80 21.94 10.79 14,000.00 29.41 90.11 119.30 6,175.80 10.88 22.41 10.88 14,100.00 29.42 90.11 120.89 6,175.61 10.98 22.87 10.97 14,200.00 29.42 90.11 122.60 6,175.43 11.07 23.35 11.07 14,300.00 29.42 90.11 124.42 6,175.24 11.16 23.83 11.16 14,400.00 29.43 90.11 126.35 6,175.05 11.26 24.31 11.26 14,500.00 29.43 90.11 128.40 6,174.87 11.36 24.79 11.36 14,600.00 29.43 90.11 130.55 6,174.68 11.46 25.28 11.46 14,700.00 29.43 90.11 132.80 6,174.50 11.57 25.78 11.56 14,800.00 29.44 90.11 135.12 6,174.31 11.67 26.28 11.67 14,900.00 29.44 90.11 137.49 6,174.12 11.78 26.78 11.78 15,000.00 29.44 90.11 139.88 6,173.94 11.89 27.28 11.88 15,100.00 29.45 90.11 142.27 6,173.75 12.00 27.79 11.99 15,200.00 29.45 90.11 144.63 6,173.57 12.11 28.30 12.11 15,300.00 29.45 90.11 146.94 6,173.38 12.22 28.81 12.22 15,400.00 29.45 90.11 149.16 6,173.20 12.34 29.32 12.34 15,500.00 29.46 90.11 151.28 6,173.01 12.45 29.84 12.45 15,600.00 29.46 90.11 153.29 6,172.82 12.57 30.36 12.57 15,700.00 29.46 90.11 155.19 6,172.64 12.69 30.88 12.69 15,800.00 29.47 90.11 156.96 6,172.45 12.81 31.40 12.81 15,900.00 29.47 90.11 158.62 6,172.27 12.93 31.93 12.93 16,000.00 29.47 90.11 160.16 6,172.08 13.06 32.46 13.06 16,100.00 29.48 90.11 161.59 6,171.89 13.18 32.98 13.18 16,200.00 29.48 90.11 162.92 6,171.71 13.31 33.52 13.31 16,300.00 29.48 90.11 164.15 6,171.52 13.44 34.05 13.43 16,400.00 29.49 90.11 165.29 6,171.34 13.56 34.58 13.56 16,500.00 29.49 90.11 166.35 6,171.15 13.69 35.12 13.69 16,600.00 29.49 90.11 167.33 6,170.97 13.83 35.65 13.82 16,700.00 29.49 90.11 168.24 6,170.78 13.96 36.19 13.96 16,800.00 29.50 90.11 169.09 6,170.59 14.09 36.73 14.09 16,900.00 29.50 90.11 169.89 6,170.41 14.22 37.27 14.22 17,000.00 29.50 90.11 170.63 6,170.22 14.36 37.81 14.36 17,100.00 29.51 90.11 171.33 6,170.04 14.49 38.35 14.49 17,119.40 29.51 90.11 171.46 6,170.00 14.52 38.46 14.52 TD: 17119.4' MD, 6318' TVD - 2S-MegalodonL2 2.Toe 080415 PB - 2S-MegalodonL2 2.Toe 031114 PB - 2S-MegalodonL2 2. Toe 0811 8/19/2015 10:55:19AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-13 Project: Kuparuk River Unit Local Coordinates TVD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) Site: Kuparuk 2S Pad MD Reference: Plan: 120+28 @ 148.00usft (Doyon 141) Well: Plan: 2S-13 10,590.00 North Reference: True Wellbore: Plan: 2S-131_1 6,323.31 Survey Calculation Method: Minimum Curvature Design: 2S-131_1 p09 [Megalodon] 95.65 -5,835.45 Database: OAKEDMP2 6,339.60 10,591.00 6,321.10 7-5/8"x9-7/8" Hold for 804.67' 7-5/8 9-7/8 6,328.46 17,119.40 6,318.00 4 1/2" x 6-3/4" Start 4°/100' DLS, 106.87° TF, for 59.09' 4-1/2 6-3/4 Formations 1,185.18 -5,627.83 Hold for 5380.54' 17,119.40 6,318.00 6,389.35 -4,261.54 Measured Vertical Checked By: Dip Date: Depth Depth Dip Direction (usft) (usft) Name Lithology 0 (') 8,902.87 5,598.00 Base Bermuda 9,909.78 6,141.00 Upper Kalubik (base HRZ) 10,531.74 6,311.00 Kuparuk C (Top C4) 7,404.34 4,781.00 Growler -AA 10,194.38 6,238.00 Lower Kalubik (K-1 mkr) 10,612.09 6,324.00 A4 8,597.52 5,441.00 Top Cairn 7,172.13 4,654.00 C-37 8,994.08 5,644.00 C-35 9,699.82 6,041.00 Top HRZ (K-2 mkr) 8,815.44 5,554.00 Top Bermuda Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 10,590.00 6,320.94 59.53 -5,833.51 KOP: 13.56°/100' DLS, 0° TF, for 16.5' 10,606.50 6,323.31 75.83 -5,834.39 Hold for 20' 10,626.50 6,325.79 95.65 -5,835.45 Start 7°/100' DLS, 63.54° TF, for 248.59' 10,875.09 6,339.60 342.07 -5,815.14 Hold for 804.67' 11,679.76 6,328.46 1,127.74 -5,641.70 Start 4°/100' DLS, 106.87° TF, for 59.09' 11,738.85 6,328.00 1,185.18 -5,627.83 Hold for 5380.54' 17,119.40 6,318.00 6,389.35 -4,261.54 TD: 17119.4' MD, 6318' TVD Checked By: Approved By: Date: 8/1912015 10:55:19AM Page 5 COMPASS 5000.1 Build 74 Permit Pack 11:33, August 19 2015WELLBORE TARGET DETAILS (MAP CO-ORDINATES) 2 S -13 L 1 wp 0 9[ M e g a l o d o n] 2Name S-MegalodonL2 2 Toe 081115 PB TVD Circlee(Ratlius 100.00) Quarter Mile View 2S-MegolodonL2 2. Toe 081115 PB Cidce 6318.00 Circle (Ratlius: 1320.00) 2S-MegalodonL2 1.Heel 081115 PB 6328.00 Circle (Ratlius: 100.00) 2S-MegoI.donL2 1. Heel 081115 PB Cirlce 6328.00 Circle (Radius: 1320.00) 8000 - "O' 2S. 13C7wpOgfMe9al°aOn 6000 - - - s.'3o l s oaOnl 4vo bOg fCe ons O9wp06lTiger �t w C 2��Y2.1 [Goblin) OOOO - - -- 21'OSWP06fNgrse 00 I X000 - - - O I � O O _ alodon] - U) 3PB1wp L 5 - - -2000 - - - I 2S.»w S.12w S.16w S.08 S.JSw 2S.0 w S. 0 OOOO -$ -6000 P06fh 11 P06 Hp06lHe PO6fS �? O00 4 ' S 1 � o aX"erhea° i°n a/Mon120T6 lwwbeg4000 6000 West( -)/East(+) (20001usft/in) X91 2S-13L1wp09 Surface Location CPAI Coordinate Converter , From: Datum NAD83 Region: alaska a d ` Latitude/Longitude IDecimal Degrees r UTM Zone: — i- Soukh t State Plane Zone:4 Units: us -ft r Legal Description (NAD27 only) i -Starting Coordinates: — ----- — X: 1620989.87 i Y: 15929711.03 _ ----- To: Datum: P 27 . Region: alaska f Latitude/Longitude IDecimal Degrees r UTM Zone: True— r Soukh 0' State Plane Zone:F4, Units: us -ft C Legal Description (NAD27 only) -Ending Coordinates: X 480956.546015626 Y: 15929961.44508763 Transform Quit Help 2S-13L1wp09 Intermediate Casino I j Ll. CPA1 Coordinate Converter L E I" `IX` -From:-- Datum:NAD83 Region: alaska Latitude/Longitude Decimal Degrees t UTM Zone: "u F South State Plane Zone:4 Units: us ft +: r Legal Description (NAD27 only) Starting Coordinates: X: 11615157.11 Y: 5929785.57 Datum: NAD27 . Region: alaska f- Latitude/Longitude Decimal Degrees . UTM Zone: True South i State Plane Zone: 4 Units: Fu s -ft R Legal Description (NAD27 only) I Ending Coordinates: ---.-__- __- X: 475123.660635737 Y: 5930036.06699726 j Transform Quit Help 2S-13L1wp09 Top of Productive Horizon thy. CPAI Coordinate Converter From: _ ......._ To: _. Datum NAp83 Region: alaska Datum N,4D27 Region: alaska r Latitude/Longitude Decimal Degrees r Latitude/Longitude Decimal Degrees r UTM Zone: — ) South ! UTM Zone: True r South I'% State Plane Zone: 11 q Units:us Ft �: State Plane Zone: q Units: us ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates:- -- -- --- -- -- X: 1615155.99 Ending Coordinates: X: 475122.540980404 Y: 5929807.41 Y: 5930457.90656838 Transform Quit Help 2S-13L1wp09 TD CPA[ Coordinate Coni rt From: __. To:.._� �._._ Datum: NAD83 T Region: �alas"k'a 9 Datum: NAD27 Region: alaska r Latitude/Lon itude 9 Decimal Degrees l` Latitude/Longitude itude 9 Decimal Degrees r UTM Zone: )` South r UTM Zone: True F South State Plane Zone: Units:sft. r StatePlane Zone:d Units: ft • r Legal Description (NAD27 only) t " Legal Description (NAD27 only) Starting Coordinates: -- Ending Coordinates: — -- X: 1616745.21 X 476711.897771052 Y: 5936110.69 Y: r5936361.03358721 I Transform Quit Help W I 2S-13L1wp09 Surface Location CPA1 Coordinate Converter -From: Datum: .NNAA,D8g Region: jalaska r Latitude/Longitude Decimal Degrees (- UTM Zone: F— r South do State Plane Zone:4 Units: us ft + r Lt gal I,NAD2;, orrl�; ) Starting Coordinates: -- -- -- - --- -- - X: 1620989.87 Y: F5929711.03 To: Datum: INAD27 Region: falaska i Latitude/Longitude t Decimal Degrees l UTM Zone: True South r State Plane Zone: q + Units: us ft Legal Description (NAD27 only) Legal Description Township: 010 Range: 008 E Meridian: U Section: F17 FNL 3087.1039 FEL 1613.7715 Transform Quit Help I 2S-13L1wp09 Intermediate Casina I M. CPA1 Coordinate Converter From: Datum: Ngpg - Region: alaska r:"` Latitude/Longitude Decimal Degrees r"" UTM Zone: South ice' State Plane Zone: 4 Units: us ft r Legal (W*27 only) Starting Coordinate: X: 1615157.11 Y: 15929785.57 To: — ---- -- -- -- — Datum: NAD27 Region: alaska i Latitude/Longitude iDecimaiDegrees UTM Zone: True South t State Plane Zone: q Units: us -ft Co Legal Description (NAD27 only) Legal Description - --- — - — --- Township: 010 FN—, -1 Range:.008 E + Meridian: I" ,- Section: 118 FNL 3029.4495 FEL 2167.2305 € Transform ( Quit Help 2S-13L1wp09 Top of Productive Horizon [� CPAI Coordinate Converter �= From:.. - - _._, - —i To: --- _ - - --- - r Datum: NAD83 Region: alaska DatumpD27 Region: alaska f r Latitude/Longitude Decimal Degrees f' LatitudelLongitudeDecimal Degrees ' r UTM Zone: f- South UTM Zone: True F South f: State Plane Zone: 4 Units: us ft . f- State Plane Zone: f-47--.1 Units: us-ft i" Lr-g•> t r i'i .` arall, l 0- Legal Description (NAD27 only) Starting Coordinates: Legal Description---_.._ 4 X: 1615155.99 - Township: 010 N Range: 00$ E T Y:5929807.41 i Meridian: U � Section:lg f FNL 3007.5962 FEL 2168.3411 . _ Transform r Quit Help _r 2S-13L1wp09 TD (� CPAii Coordinate Converter - From:-_ _. _ __ __ __�_ FTo: - -- — Datum: NAD83 Region: alaska 3 Datum: INAD27 T Region: jalaska r Latitude/Longitude Decimal Degrees r Latitude/Longitude Decimal Degrees r UTM Zone: v F South C' UTM Zone: True South ro State Plane Zone: q Units: , us-ft . t"' State Plane Zone:14 Units: us-ft Legal Cr* an (t^1.GD2 of rIJ) r- Legal Description (NAD27 only) Starting Coordinates __. __ LegalDescription - X: ,1616745.21 Township: 010 N Range: 00$ 1 E Y: 5936110.69 Meridian:- � Section: 7— FNL 1978.7957 IFEL I JF79:7j66_6 Transform Quit Help Tollerable Collision Risk Worksheet Conoco hillips Alaska Tolerable Collision Risk Worksheet based on Rev. 1 - 29 Jul 99 Use this sheet to describe a well interference scenario where ORA may be applicable. Check first [hal the scenario really is different from those described on existing worksheets. Prepared by: Scott Brunswick _ (P Authorized by: Dan Bearden ConocoPhillips Alaska, Inc Drilling Anti -Collision Management Generic name of scenario: Collision with other laterals in multi -lateral well (A3 Sand with A4 Sand) f Description: (Be specific. Include all factors which affect either the cost of collision or the cost of reducing the risk Well 2S-13 A3 & A4 laterals fail anti collision with one another in the horizontal legs of the well base on WPXX. The laterals will be geosteered using periscope so risk of leaving the zone is minimal. There is no immediate danger to life or impact on the environment if the laterals of 2S-13 intersects itself, If 2S-13 intersects Itself (here would be damage to the liner & swell packers. No risk of a well control issue exists because well 2S-131_2 lateral that is being drilled is above the previous placed lateral (upper lateral have the same or slightly higher PP) and is being drilled from [he main bore with kill weight mud In the hole. accordingly. This would be very time Do the consequences @No of collision include a eves Are the Arlo risk to personnel or the consequences environment? of collision y List all the consequences of Ores collision and the necessary remedial action: cost of collision: No HSE risks exist with 2S-13 Intersecting Itself while drilling the lalerals. An economic concern exists and it would be the cost of damage to the completion $10,000,000 equipment that has already been placed in the lower lateral prior to drilling the upper lateral and the impact it may have on future production/injection from the well. If necessary the lateral that had been drilled into can be isolated and production shut off (loss of lateral) which is worst case scenario. The biggest chance of getting "lost" is when crossing faults, there is one fault crossing in 2S-13 (30-50' throw estimated), but since the lower lateral will have already drilled across the fault the exact throw of the fault will be known so the fault crossing can be planned for, if we do get out of zone we can determine what zone we are In based on real time logs and cuttings and then steer back into the correct zone. How could the probability of collision or the severity of the consequences be reduced? How might this impact the drilling operation? Cost: The main practical way to avoid collision $1,000,000 Is to stay in zone with use of geo- steering. One could run active/passive magentic ranging determining distance from the L1 lateral and steering accordingly. This would be very time consuming and costly with regards to operations & risk to downhole BHA failure. For the purposes of this excercise the estimated cost of $1 MM is related only to the cost of LWD such as Periscope/Microscope. Estimate the total cost of substantially reducing V = $1,000,000 the risk Given the uncertainty in the above estimates, by how many times must the savings made from not reducing the risk outweigh he risk itself? (Guideline = 20) M = 20 F=1/M= 0.05 I Estimate the total cost ofI C = $10,000,000 I collision iof theearacticawayoyes substantially reduce Estimate the NPV of her the probability of No the lanned well llision or the severity V = $10,800,000 the consequences? Accepting a finite risk of collision will reduce the NPV of the planned well. What reduction, as a fraction of the total NPV, are you prepared to tolerate? (Guideline = 0.05) r--1 F = 0.01 VF/C= 0.005 If V F 1 Men close approach tule;rancas o cd not be sct C If VF C I Ih�m I olerahie coili<:ion Risk = 1 in G 1 V F Tolerable Collision Risk = 1 in 200 As -built REV DATE BY CK APP DESCRIPTION 1 5/28/15 SZ I JAH I Created Drawing Per K140173ACS NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS2S MONUMENTATION PER LOUNSBURY & ASSOC. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, UMIAT MERIDIAN. 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS L15-28, L15-29, L15-32, L15-35 6. ALL DISTANCES SHOWN ARE TRUE. N ] W, is IJ--- 1515 14 F Ds2A 4 1u1�- 20 },! iNS i} 2] 14 19 _.. _� CPF2 �} --US28, I 39 1 j X29 If .,\� J 126 75 y3.9.."- 29 0 . JJJJJJ S2H D F }V a[i^-'PS20 l T11N `.._ •' ¢ ..0 yy - .tics ,. m m yy i )'. + TION 3 ?CSC<: •t-. c },J i J2J i `j,As ] 18 14 13 IBY 171 1y�` ]2 ,PROJECT 1 LOCATION i ) I. 3 �Jr]0 J " ( } \, 2�.k 27 }5 j]p 2B t0 I X77 � 6 311.y^ 32,.-"` VICINITY MAP NTS LEGEND O AS—BUILT CONDUCTOR LOCATION 17 16 20 , 21 GRAPHIC SCALE 0 100 200 400 11 LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS & ASSOCIATES, INC. I inch = 200 ft. SURVEYORS ENGINEERS PLANNERS AJ)- AREA: 2S MODULE: XXXX UNIT: D2 Conoco hifflis DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING N0. I PART: REV: LK6219d24 5/28/15 1 CEA—D2SX-6219D24 1 OF 2 1 1 15/28/151 SZ I JAH I Icreoted Drawing Per K140173ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset. Elev. Y X Lat. Long. F.S.L F.E.L. O.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150' 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' 13 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' `® OF A AV 49th .................... ................... 6 %JEREMIAH F. CORNELL.. �.& iP LS -12663 ♦®®®� �-/�,,, /fir. P�®® AV %`®® b ESSIONA SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 27, 2015. 0 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: 2S MODULE: XXXX UNIT: D2 � Cori C Philli DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 CEA-D2SX-6219D24 2 of 2 1 Attachment 4 - 2S -13L1 Drilling Hazards Summary 6-3/4" Production Hole / 4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Backream out on trips as a last resort. 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. Attachment 5 — 2S -13L1 Cement Summary No cement is planned to be pumped under the 2S -13L1 PTD. Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, September 08, 2015 10:54 AM To: 'Brunswick, Scott A' Cc: Bettis, Patricia K (DOA) Subject: KRU 2S-13(PTD 215-151); 2S-13L1(PTD 215-152) Scott, Withdrawal of these PTDs is not necessary. Please submit the revised PTD application as revisions under the existing PTD numbers. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp(@alaska.gov 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 Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.aov From: Brunswick, Scott A [mailto:Scott.A.Brunswick(abconocophillips.com] Sent: Tuesday, September 08, 2015 8:21 AM To: Loepp, Victoria T (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: 2S-13 PTD Application One more item, we will finish the current well we are on, drill 2 more, than go to the multi -lateral to ensure we have time to plan & execute properly. From: Brunswick, Scott A Sent: Tuesday, September 08, 2015 8:12 AM To: 'Loepp, Victoria T (DOA)' Cc: Bettis, Patricia K (DOA) Subject: RE: 2S-13 PTD Application The BHL targets will remain the same, the directional will change slightly (mainly in the surface hole) as the surface location will change since we can't pull the existing 16". I've still got to finalize how far from the current slot we need to move to make it work, 5-10' depending on the current cellar diameter (trying to save the conductor for upside wells in the future). I attached the new proposed schematic we'll work with. From: Loepp, Victoria T (DOA) [ma iIto: victoria. loeppcabalaska.gov] Sent: Tuesday, September 08, 2015 7:20 AM To: Brunswick, Scott A Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]RE: 2S-13 PTD Application Will you be changing the surface location or BHL of either lateral or will you only be changing the casing design? From: Brunswick, Scott A [ma iIto: Scott.A.Bru nswick@conocophiIIips.com] Sent: Tuesday, September 08, 2015 6:53 AM To: Loepp, Victoria T (DOA); Bettis, Patricia K (DOA) Subject: 2S-13 PTD Application Patricia &/or Victoria We would like to withdraw the PTD application for 25-13 & 2S-131-1. This change is due to the first 3 wells having to top set the Kuparuk. We will be installing a 20" conductor in order to up size the casing design in order to achieve the dual lateral completion. We'll re -submit the PTD application for the well. Thanks Scott Bettis, Patricia K (DOA)I� From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Thursday, August 27, 2015 7:15 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2S-13 and KRU 2S-131_1 Patricia I've been told that the primary purpose of the pre -production is to draw down the pressure to assist in drilling the future wells in the program safer. I've also been told that if the pressure remains high they intend to keep production on for the 6 month period, but if pressure declines too quickly they will discontinue pressure to avoid formation damage/reaching bubble point). I can ask the production team to further explain if this isn't sufficient. Thanks Scott From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, August 26, 2015 1:33 PM To: Brunswick, Scott A Subject: [EXTERNAL]KRU 2S-13 and KRU 2S -13L1 Scott, ConocoPhillips should provide justification on why these injections wells will be pre -produced for more than 3 months. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. if you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or palrlcia,.bettis_L@alaskarov. TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development ervice _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. AIE- %s� API No. 50- -�_- (DO- d� . V/ (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) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST nField & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT_2S-13L1 Program SER Well bore seg PTD#: 2151520 Company CONOCOPHILLIPS ALASKA INC _ Initial Class/Type SER / PEND GeoArea 890 Unit 11160 On/Off Shore On _ Annular Disposal ❑ Administration 1 Permit fee attached_ - - _ - _ - - - _ _ - - - - - - - - INA_ _ - _ 2 Lease number appropriate. - - - - - - - - - - . - - - - - Yes - ADL0025603, Surf Loc & Top Prod l_nterv, --------------------- - - - - - - 35 3 Uniquewell name and number -------- _______________--------------- Yes KRU 2S -13L1 ---------------------- -------- 4 Well located in_a_deiined_pool-------------------- - Yes - - - - - KUPARUK RIVER,.KUPARUK RIV OIL _- 4901.00,_governed_by Conservation_ Order No. 432C 5 Well located proper distance from drilling unit -boundary - - - _ - - - - - - - - . - - - - - - - Yes . - - - CO 432C contains no spacing restrictions with respect to drilling unit boundaries. - - 6 Well located proper distance from other wells- - - - - - - - - - - - - - ------ ------- - Yes - . - _ _ CO 432C has no interwell spacing restrictions._ - _ - _ - - - - - - 7 Sufficient acreage available in -drilling unit_ - - - - - - - - - - - - - - - - - Yes - . . . - - - - - - - - - - . - - - - - - - _ - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - 8 -If deviated, is wellbore plat -included - - - - - . - - - - - - - - - - - - - - - -- - - - - - Yes - - - _ _ - - - - - - - - - - _ _ - - 9 Operator only affected party_ - - - - - - _ - . - - - - - - Yes - - - _ _ - Wellbore_will be more than 500' from an external property line where_ ownership or landownership_ changes._ 10 Operator has_appropriate bond in force - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit can be issued without conservation order- - - - - - - - - - - - - - - - - - - - Yes . _ _ - - - - - - _ - - - _ _ - - - - - _ - - - - - - - - _ - - - - _ . - _ - - - - - - - - - - - - - - - - - - - - - _ - - - _ - - - - - - - Appr Date 12 Permit -can beissuedwithout administrativ_e_approval ------------ - - - - - - - - - - - Yes. _ - - - - - - - - - - - - - - - - - - - - - - - - - - - -- -- - - - - - - - 13 Can permit be approved before 15 -day wait -- ---------------- -- ------ Yes---------------------------------------------- PKB 10!13/2015 14 Well located within area and -strata authorized by Injection Order # (put_ 10# in_comments)_(For_ Yes - - - - - A10-2_GKuparuk River_Unit- - - - - - - - - - - - - - - - - - - - - - - 15 All wells -within -1/4_mile area of review identified (For service well only)_ - - - - _ Yes - - - - - - - KRU 25-13 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre -produced injector. duration of preproduction less than 3 months_(For_service well only) - - Yes - - - - - - - Pr_eproduce_to draw down pressure to assist in drilling future wells_safely; if the pressure remains high - - - - 17 Nonconven. gas conforms to AS31.05.030([.1_.A),(y2.A-D) - - - - _ - - - - - - - NA_ - - - - - - - intend to produce _for_6_months - - - - - - - - - - - - - - - - - _ 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - _ .. NA_ - - - - - - - Conductorset KRU 25-13 - - - - _ _ - - - - - .. _ Engineering 19 Surface casing protects all known_ USDWs _ _ NA_ Surface casing set in_ KRU 2S-1 3 - - - - - - - - - - - - - - - - - 20 CMT_vol_ adequate to circulate on conductor & surf_csg - - - - _ - - - - - _ - - - - - N_A--- - - _ -- - Surface casing will be set and fully cemented - - - - - - - - - - - - - 21 CMT_vol _adequate _to tie -in -long string to -surf csg - - - - N_A_ - - - - - - - - - - - - - - - 22 CMT_will coverall known -productive horizons - - - - - - - - - - - - - - - - - - - - - - No - - _ .. - Productive interval will be completed with -slotted liner - . - - - _ - - - - - - - - - - 23 Casing designs adequate for C, T, B &_permafrost_ Yes - 24 Adequate tankage -or reserve pit - - - - - - - - - - - -- --- Yes - - Rig has steel tanks; all. waste -to approved disposal wells_ - - 25 -If _a -re -drill, has - a-107403 for abandonment been approved _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 Adequate wellbore separation -proposed- - - - - - Yes - - - - - - - Anti -collision analysis complete; no major risk failures - - - - - - - - _ - - 27 If_diverter required, does it meet regulations- - - - - - - - - - - - - - _ N -A---------------------- --------- _ _ _ _ _ _ _ _ _ - . - - - - _ - _ . Appr Date 28 _ -Drilling fluid- program schematic & equip -list-ad equate - - - - Yes - - - - - - - Max formation_pres_is 3751 psi(11,5_ppg EMW);_will drill w/ 9.3-11.5ppg EMW- 29 BOPEs,_do they meet regulation - _ - - - - Yes _ - - ------------- 30 BOPE_press rating appropriate; test to_(put psig in comments)_ - - - - - - - - - - Yes _ - - - - MPSP is 3129 psig; will test BOPs_to 3500_psig - - 31 Choke -manifold complies w/API-RP-53 (May 84)_ Yes - - - - - - - - - - - - - - - 32 Work will occur without -operation -shutdown ---------------------- - - - - - - - Yes - - - - -- - -- - - - -- - --- - - - - - - - - - --- -- - - - - - 33 Is presenceofH2S as probable 9 P- ---------- -- ----- Yes - H2S measures required. _ _ 34 Mechanical_ condition of wells within AOR verified (For service well only) - - - - - _ Yes - - _ AOR complete; no wells within a_1/4 mile- radius -- - - _ - 35 Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - No - - H2S measures required. - - - - - - - - - - - - Geology 36 Data -presented on potential overpressure zones_ - - - - - _ _ - - - - Yes _ - Expected reservoir pressure is 11.6 EMW; will drill 9.3 to 11_.8 PP9 - 9 pP-9-mu Appr Date 37 -Seismic-analysis of shallow gas_zones- - - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - - _ - - - - - - - - - - PKB 10/13/2015 38 Seabed condition survey (if off -shore) - - - - - - - - - - - - - - NA_ - - - - - - - - - _ - - - - - - - - - 39 Contact name/phone for weekly -progress reports [exploratory only] - - - - - - - - - - - - - - - - INA Onshore service well to be drilled.- - - - - _ - - - - - - - - - .. - - - - - - - - - - - - - - - - - Geologic Engineering Public Commissioner: Date: Commission Date Commissioner Date ��� �b�_✓s- WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 2S -13L1 _ Program SER Well bore seg PTD#:2151520 Company CO_NOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 17 Nonconven, gas conforms to AS31.05.030(L1_.A),Q.2.A-D) - - - - - - - - - - - - - - - - - - - - N_A_ . _ - - intend to produce _for_6_months ---------- - - - - - - - - - - - - - - - - - - - . 1 Permitfee attached_ NA_ - 2 Lease number appropriate_ - - - - - - - - - - _ - - - - - - - - Yes - - ADL0025603, Surf Loc & Top Prod Intem, ADI0025590,-TD. 3 Unique well -name and number - - - - Yes - . _ _ - KRU 2S -13L1 _ - 4 Well located in a_ defined_ pool_ -- - - - - - - - - - - - - - -- - - - Yes - - - - - - KUPARUK RIVER,_KUPARUK.RIV 0IL_-490100,_ governed_ by_ servation -Order No,.432C 5 Well located proper distance from drilling unit _boundary ---------- -- ---- - - - - - - - Yes - _ - - - - CO 432C contains no spacing restrictions with respect to dr' '_ g unit boundaries. - . _ - - -------------- 6 Well located proper distance- from other wells- - - - - - - - - - - - - - - - -- - - Yes CO 4320 has no interwell spacing_restriction_s- - - - - - - - - - - - - - - _ - - - - 7 Sufficient acreage -available in -drilling unit - - _ . - Yes - - - - - _ _ 8 -if deviated, is -wellbore plat included - - - - - Yes --- Operator only affected party - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - Wellbore -will be more than 500' from an - _ernal property line where ownership or landownership_ changes._ 10 Operator has -appropriate bond in force -- -------- -- - -- Yes_ - -- - ----- --------------------------------- Appr Date 11 Permit can be issued without conservation order_ - _ - - - - - _ - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 12 Permit can be issued without administrative approval - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ - - - - - - - - - -- - - - - - - - _ - - - - - - - - - - - - - _ _ - - - - - - - - - - - - - PKB 8/27/2015 13 Can permit be approved before 15-daywait- ___--- Yes_ ---- _----- _---------- ______----- _ ----------------------- 14 Well located within area and -strata authorized by. Injection Order # (put 10# in_comments)_(For_ Yes - - - AIO-2C-Kuparuk - er_Unit - - - - - - - - - - - - - - - - - - - - - - 15 All wells within 114_ mile -area -of review identified (For service well only)_ - - - - Yes - - - - - _ KRU 2S-13 - - - - _ _ _ _ - - _ - - - - - - 16 Pre -produced injector: duration of pre production less than 3 months_ (For -service well only) - Yes - Prepro - ce_to draw down pressure to assist in drilling future wells -safely', if the pressure remains high _ _ _ _ - - 18 Conductor string -provided - - - - - - - - NA_ C ductor set in KRU 2S-13 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 19 Surface casing_ protects all -known USDWs - - - - - - - - - - - - - - N_A_ Surface casing set in KRU 2S-13 20 CMT vol adequate to circul_ate_on conductor & surf _csg -- _ - - - - - - - - _ - - - - - N_A_ - _ - _ _ _ Surface casing will be set and fully cemented - - - - - - - - - - - - - - - - - - - - - - - . - - _ _ - - - - - - - - 21 CMT -vol adequateto tie -in -long string to.surf csg------ NA - - - - - - - - - - - _ - - - - - - - - - - - 22 CMT -will cover -all -known -productive horizons_ - - - - - - - - - - - o_ - - - Productive_ interval will_be completed with slotted liner - -- - - - - - 23 Casing designs adequate for C,_T, B &_ permafrost- - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - 24 Adequate -tankage or reserve pit - - - - - - - - - - _ - - Yes - - - - Rig has steel tanks; all_waste_to approved disposal wells_ 25 -If-a- re -drill, has_a 1.0-403 for abandonment been approved - - - - - - -- - - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - .. - - - - - -- - - - - - - - - - - - 26 Adequate wellbore separation.proposed- - - - - - - - Yes - - - - - - - Anti -collision analysis complete; no major risk failures 27 If_diverter required, does it meet regulations_ - - - - - - - - - - - - ------------- NA_ - - - - - - - - - - - - - - - -- - Appr Date 28 Drilling fluid_ program schematic_& equip list adequate- - - - - - - - - - Yes - - - - - - - Max formation_ pres_ is 3751 psi(11.5_ppg EMW );-will drill w/ 9.2-11.5 ppg EMW. VTL 9/1/2015 29 BOPEs,_do they meet regulation - - - - - - Yes - - _ - -- - - - - - - 30 BOPE_press rating appropriate; test to -(put psig in comm s)_ Yes - - MPSP is 3119 psig; will test BOPs_to 3500_psig- - - - - - - - - - - - - - - - -- -31 31 Choke_manifold complies w/API_RP-53 (May 84)_ - Yes - - . - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown _n - _ - - _ - - - - _ - - - - - - -- Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - _ - - - - - - - 33 Is presence of H2S gas probable- - - - - - - - - - - Yes - - . . H2S measures required- - - . - - - - - - - 34 Mechanical -condition of wells within A verified (For service well only) - - - - - NA_ - - - - - - - - - I - - - - - - - - - - - - - - - - 35 Permit can be issued w/o hydro _ _sulfide measures - - - - No_ H2S measures required. Geology 36 fp Data_presented on_ potentia _ verpressur_e zones - - Yes - - _Expected r_eservoirpressure is 11.5 ppg EMW; will drill lateral using 9.5-50 12.2 ppg mud. Date 37 Seismicanalysisofsh-owgas_zones_ - - - - - NA- - - - - - - - - -- - - - - - - - -- -- - -- - - - - -- - - - - - - - - - - - - - - - - PKB 8/27/2015 38 Seabed condition _ _rvey_(if off_ -shore) - - - - - - - - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - - - - 39 Contaot nam hone for weekly_p_rogress reports_ [exploratory only] - . - - - - - - - NA_ - _ Onshore service well_to be drilled- - - - - - - - - - - - - - - - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date d❑
