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218-151
! "##$ % & '()'(' )) " ( )'*"+,-'( )'* +,-.& ) ) ' ' ' ./ ' )' )''' 0 !' ( ) ! (.(( ! '(' ) (' 1 )) 23 3 +( ) '4( ./ '(' ( ( ) '( ( )!' ' ' . 5+ ! + ! # 26$#2$ 6 )4 41 . 4 + ! 5( 7 ! 48' ( By Samantha Carlisle at 8:48 am, Mar 30, 2021 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.03.27 06:40:14-08'00' Foxit PhantomPDF Version: 10.1.0 Roger Mouser !"# $#$%& '( #)*+,*+" "( "' "- +. +/ + ($ ! "!#!$%%&'&&'()%!&%*%!(*+%'*,- !& &%&!-#- &- &%&!!"!'$%%&'&&((%%%!'(%$&'+!#*,- !& &%&!(- &- &%&!!."!!*$%%&'&---)%%&%(!)('$&-*,- !& &%&!$!- &- &%&!&/"-!-$%!%-&%&))%%!'*&!'0 &!,# &* &%!'*- &# &%&!&1"#!$%!%-&%)'%%%&!*!$!%-#,$ !%,) -! &%&%&- &# &%&!& "&%*$%!%-&%$!*%%&%$!*))(,%$!&,- &- &%&!*!- &- &%&!& "-)$%!%-&%&&)%%!'$!%!-%,%&%&(,- &- &%&!')- &- &%&! #"-%# $%!%-&%$$$%% &%)!-& &%+$%2 #*, - &# &%&! !% - &# &%&! DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2181510 Well Name/No. KUPARUK RIV UNIT 2M-41 MD 18926 TVD 6036 Completion Date 1/30/2019 REQUIRED INFORMATION Mud Log No Operator ConocoPhillips Alaska, Inc. API No. 50-103-20790-00-00 Completion Statues 1-0I1 Current Status 1-0I1 UIC No/ Samples No ✓ Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res/Neu/Den/CBL (from Master Well Data/Logs) 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 ED C 30448 Digital Data 48 590 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41_VISION_Resistivity_LW D001_RM_LAS.las ED C 30448 Digital Data 474 3096 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41_VISION_Resistivity_LW D002_RM_LAS.las ED C 30448 Digital Data 2980 8978 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41 _VI SION_Resistivity_LW D003_RM_LAS.Ias ED C 30448 Digital Data 8903 13140 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41_VISION_Resistivity_L W D004_RM_LAS.Ias ED C 30448 Digital Data 13008 14449 5/28/2019 Electronic Data Set, Filename: CPAI 2M- 41_VISION_Resistivity_LW D005_RM_LAS.las ED C 30448 Digital Data 14244 18926 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41 _VIS ION_Resistivity_LW D006_RM_LAS.las ED C 30448 Digital Data 87 18926 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41 _V I S I O N_Resistivity_R M_LAS.las ED C 30448 Digital Data 86 18926 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41 _VISION_Resistivity_Simplified.las ED C 30448 Digital Data 86 18926 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41 _VISI ON_Resistivity_RM_23 May 19.las ED C 30448 Digital Data 48 590 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41_VISION_Resistivity_LW D001_RM_LAS.las ED C 30448 Digital Data 474 3096 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41 _VI SION_Resistivity_LW D002_RM_LAS.las ED C 30448 Digital Data 2980 8978 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41_VISION_Resistivity_L W D003_RM_LAS.Ias ED C 30448 Digital Data 8903 13140 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41_VISION_Resistivity_LW D004_RM_LAS.las AOGCC Page I of6 Monday, lune 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2181510 Well Name/No. KUPARUK RIV UNIT 21VI-41 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20790-00-00 MD 18926 TVD 6036 Completion Date 1/30/2019 Completion Status 1-0I1 Current Status 1-011- UIC No ED C 30448 Digital Data 13008 14449 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41_VISION_Resistivily_LW D005_RM_LAS.Ias ED C 30448 Digital Data 14244 18926 5/28/2019 Electronic Data Set, Filename: CPAI 2M- 41_VISION_Resistivity_LW D006_RM_LAS.Ias ED C 30448 Digital Data 87 18926 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41_V ISION_Resistivily_RM_LAS.Ias ED C 30448 Digital Data 86 18926 5/28/2019 Electronic Data Set, Filename: CPAI_2M- 41 _VIS ION_Resistivity_RM_23May19.las ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_VISION_Resistivity_RM_DLIS_LW D001.dIIs ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW D001.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW D002.diis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_V ISION_Resistivity_RM_DLIS_LW 0002.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_VISION_Resistivity_RM_DLIS_LW D003.dlis ED C 30448 Digital Data 528/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW D003.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_VISION_Resistivity_RM_DLIS_LW D004.diis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_ DLIS_LW D004.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_VISION_Resistivity_RM_DLIS_LW D005.dlis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_VISION_Resistivity_RM_DLIS_LWDD05.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_VISION_Resistivity_RM_DLIS_LW D006.dlis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW D006.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_VISION_Resistivity_RM_DLIS.dlis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M - 41_V I S I ON_Resistivity_RM_OLIS. html AOGCC Page 2 of 6 Monday, June 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2181510 Well Name/No. KUPARUK RIV UNIT 2M-41 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20790-00-00 MD 18926 TVD 6036 Completion Date 1/30/2019 Completion Status 1-0IL Current Status 1-0I1. UIC No ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41 _VISI ON_Resislivity_2MD_RM. pdf ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41 _VIS ION_Resistivity_2TVD_RM. pdf ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41 _VIS ION_Resistivity_5MD_RM.pdf ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41 _V I SION_Resistivity_ST V D_RM.pdf ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41_MMSSurvey.txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41_PrintSurveyUst.csv ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD27 EOW Compass Surveys [Canvas].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD27 EOW Compass Surveys [Macro].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD27 EOW Compass Surveys [Petrel].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NA027 EOW Compass Surveys [Survey].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD27 EOW Compass Surveys.pdf ED C 30448 Digital Data 5/28/2019 Electronic File: 21V141 NAD83 EOW Compass Surveys [Canvas].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD83 EOW Compass Surveys [Macro].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD83 EOW Compass Surveys [Petrel].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD83 EOW Compass Surveys [Survey].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M41 NAD83 EOW Compass Surveys.pdf ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_VISION_Resistivity_RM_DLIS_LW D001.dlis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW D001.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW D002.dlis AOGCC Page 3 of 6 Monday, lune 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2181510 Well Name/No. KUPARUK RIV UNIT 2M-41 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20790-00-00 MD 18926 TVD 6036 Completion Date 1/30/2019 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW D002.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW D003.diis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_ DLIS_LW D003.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI _2M- 41_VISION_Resistivity_RM_ DLIS_LW D004.diis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_VISION_Resistivity_RM_DLIS_LW D004.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI-2M- PAI2M- 41—VISION — Resistivity_RM — DLIS—LW 41_VISION_Resistivity_RM_DLIS_LW D005.d1is ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW 0005.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41_VISION_Resistivity_RM_DLIS_LW D006.dlis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI _2M- 41_VISION_Resistivity_RM_DLIS_LW D006.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41 _VIS ION_Resistivity_RM_DLI S.dlis ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41 _VIS ION_Resistivity_RM_DLI S.html ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M- 41 _VISI ON_Resistivity_2MD_RM.pdf ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41_V I SI ON_Resistivity_2TVD_RM.pdf ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI 2M - 41_V I SI ON_Resistivity_SMD_RM. pdf ED C 30448 Digital Data 5/28/2019 Electronic File: CPAI_2M- 41 _VISI ON_Resislivity_5TVD_RM.pdf ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41_MMSSurvey.txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41_PrintSurveyList.csv ED C 30448 Digital Data 5/28/2019 Electronic File: 21VI-41 NAD27 EOW Compass Surveys [Canvas].t# ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD27 EOW Compass Surveys [Macro].t# AOGCC Page 4 of 6 Monday, June 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2181510 Well Name/No. KUPARUK RIV UNIT 2M-41 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20790-00-00 MD 18926 TVD 6036 Completion Date 1/30/2019 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD27 EOW Compass Surveys [Petrel].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD27 EOW Compass Surveys [Survey]Axt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD27 EOW Compass Surveys.pdf ED C 30448 Digital Data 5/28/2019 Electronic File: 2M41 NAD83 EOW Compass Surveys [Canvas].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD83 EOW Compass Surveys (Macro].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD83 EOW Compass Surveys [Petrel].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD83 EOW Compass Surveys [Survey].txt ED C 30448 Digital Data 5/28/2019 Electronic File: 2M-41 NAD83 EOW Compass Surveys.pdf Log C 30448 Log Header Scans 0 0 2181510 KUPARUK RIV UNIT 2M-41 LOG HEADERS Log C 30893 Log Header Scans 0 0 2181510 KUPARUK RIV UNIT 2M-41 LOG HEADERS ED C 30893 Digital Data 12684 14302 6/12/2019 Electronic Data Set, Filename: CPAI_2M- 41_MAIN_PASS_SCMT_PSP_026PUC.las ED C 30893 Digital Data 6/12/2019 Electronic File: CPAI2M- 41_MAIN_PASS_SC_MT_PSP_026PUC.DLIS ED C 30893 Digital Data 6/12/2019 Electronic File: CPAI_2M- 41 MEMORY SCMT_29-JAN-2019.PDF Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED A00 ( Pape i ui 6 Monday, June 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2181510 Well Name/No. KUPARUK RIV UNIT 2M-41 MD 18926 TVD 6036 Completion Report 0 Production Test Information Y /A Geologic Markers/Tops COMPLIANCE HISTORY Completion Date: 1/30/2019 Release Date: 12/6/2018 Description Comments: Operator ConocoPhillips Alaska, Inc. API No. 50-103.20790-00-00 Completion Date 1/30/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No Directional / Inclination Data l -i Mud Logs, Image Files, Digital Data Y /6 Core Chips Y Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y Daily Operations Summary 6�) Cuttings Samples Y V Laboratory Analyses Y NA Date Comments Compliance Reviewed By: Date: (,;' / t :7- � I AOGCC Page 6 of 6 Monday, June 17, 2019 218151 30 44 8 Schlumberger -Private Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: It AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 �ft Anchorage, AK 99501 1181 5 30 89 3 TRANSMITTALDATE t TRANSMITTALp SERVICE ORDER SERVICE Color WELL NAME J91060& p FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATATYPE DATE LOGGED Prints CD's ME Date return via courier or sign/scan and email a copy to lefilumberger and CPA[. Sch lum berger-Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. 21815; 30448 Schlumberger -Private STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION •ir!i 1 2P-15 WELL COMPLETION OR RECOMPLETION REPORT.b 1 a. Well Status: Oil [Z • Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1 1b. Well Class: Development E Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: .1/30/3019 14. Permit to Drill Number / Sundry: 218-151 . 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: • 12/16/2018 15. API Number: 50-103-20790.00-00 4a. Location of Well (Governmental Section): Surface: 5165' FNL, 4839' FEL, Sec 27, T11N, R8E, UM • Top of Productive Interval: 1416' FNL, 4404' FEL, Sec 29, T71 N, R8E, UM Total Depth: 831' FNL, 3681' FEL, Sec 30, T11N, RBE, UM 8. Date TD Reached: ,1/23/2019 16. Well Name and Number: KRU 2M-41 9. Ref Elevations: KB:140.t GLA00.5 BF: 17. Field / Pool(s): Kupawk River Fiek1/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: NIA 18. Property Designation: ADL 25586, ADL 25585 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 488282 • y- 5948986 Zone- 4 TPI: x- 478155 y- 5952758 Zone- 4 Total Depth: x- 473599 y- 5953357 Zone- 4 11. Total Depth MD/TVD: 118926/6036 • 19. DNR Approval Number: 931894000, 931893000 12. SSSV Depth MD/TVD: NONE 20. Thickness of Permafrost MDITVD: 1495/1483 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (tt MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Neu/Den/CBL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 H-40 39 166 39 166 42 Installed 13318 68 L-80 39 3088 39 2676 16 589 sx 11.Oppg Class G, 77 sx 12.Oppg Class G 95/8 47 L-80 36 13131 36 5772 121/4 727 sx 15.8ppg Class G 7 26 L-80 12959 14449 5724 6045 8 1/2x9 7/8 419 sx 15.8ppg Class G 41/2 12.6 L-80 14340 18918 6040 6036 61/8 N/A Uncemented 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MDfrVD of Top and Bottom; Perforation Size and Number; Date Perfd): t0. PERFORATED LINER: t 14576.18712 MD and 6045-6031 TVD (g. COMPLETION DATE if ° I I ZI 3"11 VERIFIED Wi' 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 14350 14182/6029 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes EJ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): WAITING FOR HOOKUP Date of Test: Hours Tested: Production for Test Period Oil-Bbl:Gas-MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casinq Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 vrz- `F14Kele CONTINUED ON PAGE 2 RBUS 0. Y Pp 0 5 20ITubmit ORIGINAL onjy` 28. CORE DATA Conventional Core(s): Yes ❑ No [D Sidewall Cores: Yes ❑ No 21 . If Yes, list formations and intervals cored (MDf rVD, 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 1495 1483 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 14308 6037 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C West Sak 2095 2010 C-50 7389 4169 C-37 9260 4692 C-35 11527 5323 HRZ 13115 5767 Kalubik 13560 5890 TD 18926 6034 Formation at total de the Ku ruk C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical report, production r well test results, per 20 AAC 25,070 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G. Alvord Contact Name: Madeline Woodard W4 Authorized Title: Alaska Drilling Manager Contact Email: madeline.e.woodard & co .com Authorized A Contact Phone: 265-6086 (Zet v SignatureDate: 2(2� 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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and 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 5/2017 Submit ORIGINAL Only 2M-4. inal Wellbore Schematic Producer — Non -Frac ConocoPhillips 16" Surface Hole 74`Tangent intermediate I Hole M;. Updated: 2/14/19 by H. Sylte Conductor: 20" driven to +/-119' Landing nipple, 2.813" X, 2,136' MD Surface Casine: Below West Sak 13-3/8" 68# L-80 Hydril 563 3,088' MD / 2,676' TVD, 57° deg INC • M• -W x 1" KBM #12,717' MD—SOV Installed #25,190' MD—DV #3 8,256' MD — OV #410,584' MD—DV (Cl brine spotted to 10,176' MD) #512,346' MD—DV #6 13,671' MD - DV Tuhine: 3-Y" 9.3# L-80 8RD EUE Intermediate 1:9 5/8" 47#, L80, Hydril 563 13,131' MD/5,781' TVD 7" x 9 5/8" Flex-Lmk liner hanger and HRD-E Packer @ 12,959' MD / 5,724' TVD, 74° INC Downhole gauge, 14,100' MD Production Packer, 14,182' MD Landing nipple, 2.813" X, 14,237' MD Landing nipple, 2.813" XN w/ dual flapper installed, 14,289' MD HRD-E ZXP Packer and liner hanger, 14,339' MD . Intermediate 2:7" 26#, LSO, Hydn156314,449 MD/Iib& TVDI 86" INC 000 000 000 00 000 000 q•y^xs-s�sweh varkets for faVID l:olan Pre -Perforated Joints l every3 - Production Liner: 4-1/2" 12.6# L-80 HYD563 18,918' MD/6,036' TVD Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stah Depm start Time I End Time Our(hr)__ Phase Op Code Acfivhy Cale Time P-T-x Operabon (WB) End DepN (flKB) 12/13/2018 12/13/2018 1.00 MIRU MOVE MOB P Move pit, pump, pipe shed and rock 0.0 0.0 16:30 17:30 washer to 2M pad. 12/13/2018 12/13/2018 1.00 MIRU MOVE MOB P Skid rig floor to moving position. Raise 0.0 0.0 17:30 18:30 stompers. 12/13/2018 12/13/2018 0.50 MIRU MOVE MOB P Pull sub off 2S-315. 0.0 0.0 18:30 19:00 12/13/2018 12/13/2018 1.75 MIRU MOVE WAIT T Brakes locked up on Peak grader. 0.0 0.0 19:00 20:45 Change out graders. Clean up around well and pad. Load out dg mats and equipment 12/13/2018 12/13/2018 1.25 MIRU MOVE MOB P Move sub from 28 pad to 2M pad. 0.0 0.0 20:45 22:00 12/13/2018 12/14/2018 2.00 MIRU MOVE MOB P Stage sub for spotting over well. Set 0.0 0.0 22:00 00:00 nig mats for sub. 12/14/2018 12/1412018 2.00 MIRU MOVE MOB P Spot and set sub over 2M-41. 0.0 0.0 00:00 02:00 12114/2018 12114/2018 2.00 MIRU MOVE MOB P Set stompers. Remove tow bar from 0.0 0.0 02:00 04:00 sub. Skid rig floor to drilling position 12/14/2018 12/14/2018 1.00 MIRU MOVE MOB P Spot pit module to sub. 0.0 0.0 04:00 05:00 12/14/2018 12/14/2018 1.50 MIRU MOVE MOB P Spot pump module. 0.0 0.0 05:00 06:30 12/14/2018 12/14/2018 0.75 MIRU MOVE MOB P Spot power module. 0.0 0.0 06:30 07:15 12/14/2018 12/14/2018 1.25 MIRU MOVE MOB P Spot pipeshed. 0.0 0.0 07:15 08:30 12/14/2018 12/14/2018 0.50 MIRU MOVE MOB P Spot rockwasher and cuttings tank. 0.0 0.0 08:30 09:00 Berm cuttings lank and set super sucker landing. Sim-ops/Hook up electrical lines in innerconnects. 12/14/2018 12/14/2018 3.00 MIRU MOVE RURD P Rig up high pressure mud lines, 0.0 0.0 09:00 12:00 steam, water and air lines. Rig up skate rail. Work on rig acceptance check list. Swap to rig gen power at 11:15 hrs. 12/14/2018 12/1412018 3.00 MIRU MOVE RURD P Calibrate and test TOTCO system. 0.0 0.0 12:00 15:00 Berm cellar. Hook up geronimo line. Apply steam to cellar heaters. Work on rig acceptance check list. 12/14/2018 12114/2018 2.00 MIRU MOVE RURD P Go on high-line power at 1500 hrs. 0.0 0.0 15:00 17:00 Mobilize surface riser to cellar. Sim- ops/Work on installation of DEEP spacer sub on TD. Accept rig at 1700 hrs 12/14/18 12/14/2018 12114/2018 1.00 MIRU MOVE NUND P Nipple up surface riser for diverter. 0.0 0.0 17:00 18:00 12/14/2018 12/14/2018 3.00 MIRU MOVE RGRP T Take damaged accumulator triplex 0.0 0.0 18:00 21:00 pump out of service. Change out air regulator. Sim-ops/Install saver sub on TD. 12/14/2018 12/14/2018 1.00 MIRU MOVE BOPE P Perform diverter test witnessed by 0.0 0.0 21:00 22:00 AOGCC rep Jeff Jones. Knife valve open in 8 sec's, annular closed in 43 sec. Perform accumulator test. Starting system pressure =3050 psi. Pressure after closure=1925 psi. Time to 200 psi=15 secs. Full recharge time=76 sec's. 6 nitrogen bottles at 2400 psi. Tested gas, PVT and flow alarms Page 1147 Report Printed: 211312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur(hr) Phase op code Activity r:ede Time P-T-X Operation (ftKB) End Depth(fIKB) 12/14/2018 12/14/2018 0.50 MIRU MOVE SFTY P Perform safety stand down with both 0.0 0.0 22:00 22:30 crews discussing recent incidents, personnel and operational changes that could distract crew members. 12/14/2018 12/15/2018 1.50 MIRU MOVE RURD P Make up 13 3/8" hanger to landing 0.0 0.0 22:30 00:00 joint and perform dummy run with hanger. 12/15/2018 12/1512018 3.00 MIRU MOVE RURD P Continue to make up landing joint and 0.0 0.0 00:00 03:00 hanger. Perform dummy run. Hanger landed at 39.33' MD. Lay down hanger and landing joint. 12/15/2018 12/1512018 1.50 MIRU MOVE RURD P Work on installation of DEEP spacer 0.0 0.0 03:00 04:30 sub on TD. Sim-ops/Mobilize BHA components to dg floor and pipe shed. 12/15/2018 12/15/2018 0.50 MIRU MOVE SFTY P Conduct pre spud meeting with night 0.0 0.0 04:30 05:00 crew. 12/15/2018 12/15/2018 1.00 MIRU MOVE RURD P Work on installation of DEEP spacer 0.0 0.0 05:00 06:00 sub on TD. 12/15/2018 12/1512018 4.00 MIRU MOVE RURD P Complete installation of DEEP spacer 0.0 0.0 06:00 10:00 sub on TD. Calibrate block height, install 5 7/8" elevators and mousehole. Service crown sheaves. Adjust link tilt clamps. 12115/2018 12/1512018 1.00 MIRU MOVE SFTY P Conduct pre spud meeting with day 0.0 0.0 10:00 11:00 crew. 12115/2018 12/1512018 1.00 MIRU MOVE BHAH P Make up conductor clean out BHA as 0.0 0.0 11:00 12:00 per SLB DD. 1211512018 12/1512018 0.50 MIRU MOVE SEQP P Tag bottom at 45.14' MD. Fill 0.0 45.0 12:00 12:30 conductor with 8.7 ppg spud mud. 4" ball valve on conductor leaking. 12115/2018 12/15/2018 1.00 MIRU MOVE SEQP T Drain riser. Change out 4" conductor 45.0 45.0 12:30 13:30 ball valve. 12/15/2018 12/1512018 0.50 MIRU MOVE SEQP P Fill conductor with 8.7 ppg spud mud. 45.0 45.0 13:30 14:00 Test surface lines to 3500 psi. Riser air boot leaking. Drain riser. 12/15/2018 12/1512018 1.50 MIRU MOVE RGRP T Attempt to break out of HWDP with 45.0 45.0 1400 15:30 TD. 6 5/8" Reg connection above saver sub broke. Lay down mud motor with bit. 1/2" gap evident between 5 7/8" XT-m57 HWDP and saver sub connection. 12/15/2018 12!1512018 2.50 MIRU MOVE RGRP T Remove TO quill shaft torque rings. 45.0 45.0 15:30 18:00 Torque up quill shaft connections to 47.4K ft/lbs. Use iron roughneck to back out saver sub from HWDP. Severe galling present in box of HWDP and pin of saver sub. Lay down damaged joint of HWDP. Install new XT-m57 saver sub, Install and torque to spec torque rings. 12/15/2018 12/15/2018 3.75 MIRU MOVE RGRP T Continue to install torque rings on quill 45.0 45.0 16:00 21:45 shaft of TO. 12/15/2018 12/1512018 0.50 MIRU MOVE RGRP T Change out air boot on riser. 45.0 45.0 21:45 22:15 12/15/2018 12/16/2018 1.75 MIRU MOVE RGRP T Make up saver sub to joint of OR At 45.0 45.0 22:15 00:00 3/8" from being shoulder up torqued up to 5K. Back out saver sub and inspect. Slight galling on starter threads. Bring up new saver sub and screw into DP by hand. No problems. Make TO back up to DP and torque to . K. Back out saver sub and inspect. No additional galling. Make up TO and torque to 30K. Back out and inspect. Page 2/47 Report Printed: 211312019 Operations Summary (with Timelog Depths) 2M-41 Qog: DOYON 142 Job: DRILLING ORIGINAL Time Log Sian Depth Start Time End Time our (hp Phase Op Code Acmity Cade Time P -T -X Operation (ftKa) End Depth (flKB) 12/16/2018 12/16/2018 0.50 MIRU MOVE RGRP T Torque up saver sub to 43.5K. Back 45.0 45.0 00:00 00:30 out and inspect. No additional galling. 12/16/2018 12/16/2018 2.25 MIRU MOVE BHAH P Make up cleanout BHA.. 45.0 45.0 00:30 02:45 12/16/2018 12/16/2018 0.75 MIRU MOVE RGRP T Troubleshoot TD encoder. Stand back 45.0 45.0 02:45 03:30 HWDP and bring TO to rig floor. 12/16/2018 12/16/2018 0.75 MIRU MOVE WASH P Clean out conductor from 45' MD to 45.0 58.0 03:30 04:15 58' MD. 470 gpm, 500 psi, 25% FO, 40 rpm, 1 K tq, 1 K WOB 12/16/2018 12/16/2018 0.75 MIRU MOVE RGRP T Stand back HWDP and bring TD to rig 58.0 58.0 04:15 05:00 floor. Troubleshoot TO encoder. RIH with HWDP. 12/16/2018 12/16/2018 2.00 MIRU MOVE WASH P Clean out conductor from 58' MD to 58.0 166.0 05:00 07:00 166' MD. 470 gpm, 500 psi, 26% FO, 40 rpm, 1Ktq, 1K WOB 12/16/2018 12/16/2018 3.00 MIRU MOVE BHAH P Stand back 2 stds of HWDP. PU 166.0 166.0 07:00 10:00 remaing BHA 1 components as per SLB DD. Scribe mud motor and load SDI gyro. 12/16/2018 12/16/2018 0.50 MIRU MOVE SRW P Acquire SDI gyro survey. 500 gpm, 166.0 166.0 10:00 10:30 387 psi, 26% FO. PU=64K SO=63K 12/16/2018 12/16/2018 1.50 SURFAC DRILL DDRL P Directional drill 16" surface hole 166.0 223.0 10:30 12:00 section from 166' MD to 223' MD, 223' TVD, 504 gpm, 415 psi, FO 27%, 40 rpm, Tq 1 K, WOB 8-1 OKI, PU 68K, SO 78K, ROT 69K, , ADT .33 him, Bit hrs=.33, Jars hrs=N/A. Total footage 57'. Take gyro surveys every 30' drilled and drill with singles to keep TD below windwalls. 12/16/2018 12/16/2018 2.50 SURFAC DRILL DDRL P Directional drill 16" surface hole 223.0 313.0 12:00 14:30 section from 223' MD to 313' MD, 313' TVD, 496 gpm, 460 psi, FO 26%, 40 rpm, Tq 1.8K, WOB 5-7K, PU 69K, SO 80K, ROT 70K, , ADT .8 him, Bit hrs=1.13, Jars hrs=N/A. Total footage 90'. Take gyro surveys every 30' drilled and drill with singles to keep TO below windwalls. 12/16/2018 12/16/2018 0.50 SURFAC DRILL SVRG P Service TD. 313.0 313.0 14:30 15:00 12/16/2018 12/16/2018 3.00 SURFAC DRILL DDRL P Directional drill 16" surface hole 313.0 496.0 15:00 18:00 section from 313' MD to 496' MD, 496' TVD, 504 gpm, 540 psi, FO 27%, 40 rpm, Tq 3.4K, WOB 13-15K, PU 68K, SO 80K, ROT 74K, , ADT .6 hrs, AST=.11 hrs Bit hrs=1.73, Jars hrs=N/A. Total footage 183'. Take gyro surveys every 30' drilled and drill with singles to keep TD below windwalls. Page 3147 Report Printed: 2/13120191 Uperations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth start Time End Time Dur tho Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftRB) 12/16/2018 12/16/2018 1.50 SURFAC DRILL DDRL P Directional drill 16" surface hole 496.0 591.0 18:00 19:30 section from 496' MD to 591' MD, 591' TVD, 500 gpm, 587 psi, FO 26%, 40 rpm, Tq 3K, WOB 10K, Off Btm 428 psi, 1K tq PU 80K, SO 88K, ROT 82K, ADT ..46 hrs, Bit hrs=.2.19, Jars hrs=N/A. Total footage 105'. Take gyro surveys every 30' drilled. 12/16/2018 12/16/2018 0.25 SURFAC DRILL CIRC P CBU. Acquire gyro survey. Monitor 591.0 591.0 19:30 19:45 well 5/mins. Fluid level dropped Vin riser. 12/16/2018 1211612018 0.25 SURFAC DRILL BKRM P BROOH from 591' MD to 500' MD. 591.0 500.0 19:45 20:00 500 gpm, 438 psi, 40 rpm, 1 K tq, PU 80K S088K Rot 82K. 12/1612018 12/16/2018 0.50 SURFAC DRILL TRIP P Monitor well. Static. POOH from 500' 500.0 130.0 20:00 20:30 MD to 130' MD. 1211612018 12/16/2018 0.25 SURFAC DRILL OWFF P Monitor well. Static. 130.0 130.0 20:30 20:45 12/16/2018 12/16/2018 1.25 SURFAC DRILL BHAH P Lay down BHA#1. 130.0 30.0 20:45 22:00 12/16/2018 12117/2018 2.00 SURFAC DRILL BHAH P Make up BHA#2. Scribe and load 30.0 199.0 22:00 00:00 tools as per SLB/SDI 12/17/2018 12/17/2018 1.50 SURFAC DRILL BHAH P Make up BHA#2. Scribe and load 199.0 230.0 00:00 01:30 tools as per SLB/SDI 12/17/2018 12/17/2018 0.75 SURFAC DRILL TRIP P RIH from 230' MD to 591' MD. 230.0 591.0 01:30 02:15 12117/2018 1211712018 3.00 SURFAC DRILL DDRL P Directional drill 16" surface hole 591.0 805.0 02:15 05:15 section from 591' MD to 805' MD, 799' TVD, 500 gpm, 690 psi, FO 26%, 40 rpm, Tq 4K, WOB 20K, Off Btm 526 psi, 1 K tq PU 88K, SO 99K, ROT 94K, ADT 1.45 hrs, AST .34 Bit hrs=.3.64, Jars hrs=1.45. Total footage 214'. 12/17/2018 12/17/2018 1.25 SURFAC DRILL OWFF T Observed decrease in flow out. 805.0 805.0 05:15 06:30 Monitor well. Calculate 56-60 bph loss rate. 12/17/2018 12/17/2018 1.00 SURFAC DRILL CIRC T Pump 20 bbl LCM pill consisting of 20 805.0 805.0 06:30 07:30 ppb Pro V+, 10 ppb SB Superseal and 5 ppb Pro Tightseal medium. 180 gpm, 140 psi, 8% FO, 10 rpm, 1.5K tq. Lost all returns 15 bbls after LCM pill exited the bit. Sim-ops/Build 110 bbl 45 ppb LCM pill. 12/17/2018 12/17/2018 1.00 SURFAC DRILL CIRC T Monitor well. 74.5 bph static losses. 805.0 805.0 07:30 08:30 Pump at 59 gpm, 87 psi, 3% FO with 15.3 bph loss rate. 12117/2018 12/17/2018 0.50 SURFAC DRILL TRIP T POOH from 805' MD to 726' MD. 805.0 726.0 08:30 09:00 Encounter 20K overpull at 726' MD. 12/17/2018 12/17/2018 1.00 SURFAC DRILL BKRM T Establish parameters. BROOH from 726.0 708.0 09:00 10:00 726' MD to 708' MD. Stage pump rate up from 254 gpm, 190 psi to 500 gpm, 24% FO, 506 psi. 20 rpm, 1 K tq 12/17/2018 12/17/2018 0.50 SURFAC DRILL TRIP T POOH from 708' Md to 634' MD. 708.0 634.0 10:00 10:30 12/17/2018 12/17/2018 3.50 SURFAC DRILL BHAH T Stand back and lay down BHA#2. 634.0 0.0 10:30 14:00 I Clean sevedy balled up motor stab antl bit. 12/17/2018 12/17/2018 1.00 SURFAC DRILL BHAH T Clean rig floor 0.0 0.0 14:00 1500 1 Page 4/47 Report Printed: 211312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Ac9vity Code Time P -T -X Operation (WIR) End Depth(flK0) 12/17/2018 12/17/2018 0.50 SURFAC DRILL SVRG P Service rig. Sim-ops/NOV tech enable 0.0 0.0 15:00 15:30 anti -collision software. 12/17/2018 12/17/2018 1.50 SURFAC DRILL BHAH T Make up BHA to 634' MD. PU=83K 0.0 634.0 15:30 17:00 SO=97K 12/17/2018 12/17/2018 0.50 SURFAC DRILL TRIP T RIH form 634' MD to 728' MD. 634.0 728.0 17:00 17:30 12/17/2018 12/1712018 0.50 SURFAC DRILL REAM T Wash and ream from 728' Md to 805' 728.0 805.0 17:30 18:00 MD. 375 gpm, 345 psi, 24% FO, 20 rpm, 1.21K tq. PU 87K SO 103K Sim- ops/Initialize NOVOS software. 12/17/2018 12/18/2018 6.00 SURFAC DRILL DDRL P Directional drill 16" surface hole 805.0 1,181.0 18:00 00:00 section from 805' MD to 1181' MD, 1179' TVD, 500 gpm, 735 psi, FO 26%,40 rpm, Tq 5K, WOB 20K, Off Btm 560 psi, 1K tq PU 100K, SO 106K, ROT 102K, ADT 3.25 hrs, AST 1.73 Bit hrs=.6.89, Jars hrs=4.70. Total footage 376'. Pump 10 bbl 35 ppb LCM pill at 926' MD. 10 bph loss rate while drilling. 12/18/2018 12/18/2018 6.00 SURFAC DRILL DDRL P Directional drill 16" surface hole 1,181.0 1,384.0 00:00 06:00 section from 1181' MD to 1384' MD, 1378' TVD, 500 gpm, 640 psi, FO 26%,40 rpm, Tq 5K, WOB 20K, Off Btm 545 psi, 1 K tq PU 118K, SO 116K, ROT 110K, ADT 3.74 hrs, AST 3.57 ART .17, Bit hrs=. 10.63, Jars hrs=8.44. 12/18/2018 12/18/2018 6.00 SURFAC DRILL DDRL P Directional drill 16" surface hole 1,384.0 1,761.0 06:00 12:00 section from 1384' MD to 1761' MD, 1729' TVD, 500 gpm, 650 psi, FO 31%,60 rpm, Tq 6.71K, WOB 25K, Off Btm 865 psi, 3K tq PU 120K SO 122K, ROT 117K, ADT 4.13 hrs, AST 2.56, ART1.57, Bit hrs=.14.76, Jars hrs= 12.57. 12/18/2018 12/18/2016 6.00 SURFAC DRILL DDRL P Directional drill 16" surface hole 1,761.0 2,272.0 12:00 18:00 section from 1761 MD to 2272' MD, 2152' TVD, 551 gpm, 1050 psi, FO 29%,60 rpm, Tq 6.71K, WOB 23K, Off Btm 825 psi, 3.61K tq PU 130K SO 122K, ROT 120K, ADT3.94 hrs, AST 2.27, ART1.67, Bit hrs=. 18.70, Jars hrs= 16.51, Pumped 20 bbl LCM pill @1855' MD, Pumped LCM pill 30 bbls @ 1979' MD. 12/18/2018 12/19/2018 6.00 SURFAC DRILL DDRL P Directional drill 16" surface hole 2,272.0 2,670.0 18:00 00:00 section from 2272 MD to 2670' MD, 2435' TVD, 550 gpm, 1055 psi, FO 29%,60 rpm, Tq 8K, WOB 25K, Off Bim 870 psi, 6K tq PU 132K SO 125K, ROT 125K, ADT 4.65 hrs, AST 3.03, ART1.62, Bit hrs=.23.35, Jars hrs= 21.16, Pumped 15 bbl LCM pill @2515' MD. Losses for the day= 270 bbls Total for the well 698 Wis. Page 5/47 Report Printed: 2/1 312 01 9 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Dur(hr) Phase Op Code Aaydy Code Time P -T -x Operation (fIRB) End Depth(flKB) 12/19/2018 12/19/2018 6.00 SURFAC DRILL DDRL P Directional drill 16" surface hole 2,670.0 2,918.0 00:00 06:00 section from 2670 MD to 2918' MD, 2589' TVD, 550 gpm, 1055 psi, FO 29%,60 rpm, Tq 8K, WOB 30K, Off Btm 895 psi, 5K tq PU 138K SO 131, ROT 131 K, ADT 3.96 hrs, AST 1.63, ART2.33, Bit hrs=.27.31, Jars hrs= 25.12, 12/19/2018 12/19/2018 4.25 SURFAC DRILL DDRL P Directional drill 16" surface hole 2,918.0 3,096.0 06:00 10:15 section from 2918 MD to3096' MD, 2680 TVD, 550 gpm, 1190 psi, FO 30%,60 rpm, Tq 9.8K, WOB 30K, Off Btm 969 psi, 6.85K tq PU 145K SO 127, ROT 133K, ADT 3.06 hrs, AST .96, ART 2.13, Bit hrs=.28.21, Jars hrs= 28.21, 12/19/2018 12/19/2018 1.75 SURFAC CASING CIRC P Circ 25 bbl LCM pill, work pipe F/3096' 3,096.0 3,012.0 10:15 12:00 T/3012' MD staging pumps up 550 gpm, 969 psi, 29% FO, 600 gpm, 1000 psi, 30% FO, 800 gpm, 1535 psi, 37% FO, reducepump rte to 600 gpm,due to clay cuttings. 12/19/2018 12/19/2018 1.00 SURFAC CASING CIRC P CBU, work pipe F/3012' MD, T/2988', 3,012.0 2,988.0 12:00 13:00 staged up pumps to 750gpm=1390 psi, 35% F/O, 60 RPM=6.6 TIC, ROT= 126K, Flow check 10 min=17.04bbl/hr. static loss rate 12/19/2018 12/19/2018 5.00 SURFAC CASING BKRM P BROOH F/ 2,988'MD-T/2,334'@ 2,988.0 2,334.0 13:00 18:00 800gpm 1456psi. 36% F/O, 80rpm = 5.21k TO, PUW= 136K, SOW=124k, ROT=125k, Flow Check 10min, 14.91 bbllhr. static loss rate 12/19/2018 12/19/2018 4.00 SURFAC CASING BKRM P BROOH 2,334.0 1,500.0 18:00 22:00 F/2,334'T/1,500',800gpm=1347psi. 36%F/O, 80rpm= 3k TO PUW= 116k, SOW=113k, ROT=117k 12/19/2018 12/20/2018 2.00 SURFAC CASING BKRM P BROOH F/1,500'—T/1,010', 550gpm= 1,500.0 1,010.0 22:00 00:00 773psi. 30%F/0, 80rpm= 3k TO PUW= 98k, SOW= 105k, ROT=102k 12/20/2018 12/20/2018 1.00 SURFAC CASING BKRM P BROOH F/1,010'—T/913', 1,010.0 913.0 00:00 01:00 550gpm=773psi. 30% F/L, 80rpm= 3k To PUW= 105k, SOW= 98k, ROT - 102k 12/20/2018 12/20/2018 0.50 SURFAC CASING WAIT P Wait on super sucker to empty rock 01:00 01:30 washer 12/20/2018 12/20/2018 0.50 SURFAC CASING CIRC P Spot 55bbl. 45ppg. LCM pill @ 913' 01:30 02:00 MD pumping @ 250gpm 290 psi. 16% F/, chase with 27bbis of LSND mud. 12/20/2018 12/20/2018 1.00 SURFAC CASING TRIP P Pull 3 stands of DP above spotted pill. 913.0 632.0 02:00 03:00 12/20/2018 12/20/2018 0.50 SURFAC CASING CIRC P Circ. hole clean 2x B/U @ 632.0 632.0 03:00 03:30 5009pm,515 psi.25% F/O, 2917strks total. flow check well 2bph static loss rate 12/20/2018 12/20/2018 2.75 SURFAC CASING TRIP P POOH on elevators F/632' T/337' 632.0 337.0 03:30 06:15 12/20/2018 12/20/2018 6.00 SURFAC CASING SHAH P Laydown HWDP, MWD ,LWD, NM DC, 337.0 0.0 06:15 12:15 MOTOR & BIT 12/20/2018 12/20/2018 1.00 SURFAC CASING BHAH P Clean up rig floor 0.0 0.0 12:15 13:15 Page 6/47 Report Printed: 2113/2019 operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time our(M) Phase Op Coda Activity Code Time P -T -X Operation (Wlt) End Depth(ftKB) 12/20/2018 12/20/2018 3.00 SURFAC CASING RURD P Mobilize 13 3/8 handling equipment, 0.0 644.0 13:15 16:15 monitor well= 1.59bbi. loss/hr. . m/u volant to top drive, r/u GBR power tongs/ function test, PJSM 12/20/2018 12/20/2018 1.75 SURFAC CASING PUTB P P/U 13 3/8 L-80 563 Hydril casing, 644.0 1,160.0 16:15 18:00 bakerloc shoe track assy. , GBR torque rasing to 25k. install bow spring cent. and stop rings,fill casing @ 160' 246gpm=32psi.15%F/L, check floats (good) continue RIH F/ 160' T/ 12/20/2018 12/20/2018 2.25 SURFAC CASING PUTB P Continue RIH with 13 3/8 68# L-80 1,160.0 1,571.0 18:00 20:15 Hydril 563 rasing, cbu each jnt. Due to increase in return cuttings, F/644'— T/1,160', PUW=142k SOW=70k pumping @ 210gpm= 128psi. 22%F/O 12/20/2018 12/2012018 2.75 SURFAC CASING PUTB P At 1161' encountered tight hole, set 1,571.0 1,571.0 20:15 23:00 40k on fight hole (no go) continue working pipe until it broke free. Continue RIH with 13 3/8 68# L-80 Hydril 563 casing,Working through tight hole F/1,160'—T1571' , PUW=188k SOW=70k filling pipe every jnt. 12/20/2018 12/20/2018 0.50 SURFAC CASING CIRC P Chic B/U @ 1,571' 169 gpm 139psi. 9- 1,571.0 1,571.0 23:00 23:30 12%F/L,1170 strks. seeing some losses whie working the pipe. static loss rate 5bbl. 12/20/2018 12/21/2018 0.50 SURFAC CASING PUTB P Continue RIH with 13 3/8 68# L-80 1,571.0 1,731.0 23:30 00:00 Hydril 563 casing F/1,571'—T/ 1,731' working pipe through tight spots. Filling each jnt. W/ volant, filling annulus with hole fill to help monitor returns. And adjust running speed accordingly. 12/21/2018 12/21/2018 6.00 SURFAC CASING PUTB P CONTINUE RIH W/13.37568#L-80 1,731.0 3,036.0 00:00 06:00 HYDRIL 563 CASING, F/1,731' MD - T/3036' MD P/U 231K, S/O 118K, WORK PIPE THROUGH TIGHT SPOTS, FILL PIPE WITH VOLANT TOOL, FILLANNUALS WITH HOLE FILL, MONITOR RETURNS, RUNNING SPEED 2MIN A JNT. 12/21/2018 12/21/2018 2.00 SURFAC CASING PUTB P P/U JNT. # 76 AND WASH DOWN 3,036.0 3,036.0 06:00 08:00 PUMPING @f 2BPM 351 PSI. EASING RATE 4.5BPM 240PSI. 2054 TOTAL STRK PUMPED 12/21/2018 12/21/2018 3.00 SURFAC CASING PUTB T PJSM W/ CAMERON WELLHEAD 3,036.0 3,036.0 08:00 11:00 TECH, P/U 6 -FLUTE HANGER, CONSTANT HOLE FILL WHILE M/U HANGER, LOWER LANDING JT X -O TO ACME ADAPTER UN-TQ'ED, WELD X -O ADAPTER IN PLACE, REPLACE ACME O -RING'S, 12/21/2018 12/21/2018 1.00 SURFAC CASING HOSO P LAND HANGER, SOW 136K, PUW 3,036.0 3,036.0 11:00 1200 266K, HANGER FLUTE UNABLE TO PULL THROUGH ANNULAR W1 30K P/U, ATTEMPT TO CENTER UP ANNULAR STACK, CIRC 3 BPM=206PSI, 10%F/O Page 7147 ReportPrinted: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth BtenTene End Time Dur(hr) Phase Op Code Aa%iy Code Time P -T -X Operation (11KB) End De"(N(B) 12/21/2018 12/21/2018 2.50 SURFING CEMENT CIRC P STAGE UP PUMPS PRIOR TO CMT 3,036.0 3,036.0 12:00 14:30 JOB, RECIPROCATE PIPE F/ 3088' TO 3081', 3BPM=206PSI, 10%F/0, 4BPM=180PSI, 10%F/0, 5.5BPM=150PSI,14%F/O, SIMOPS; R/U HOSES IN CELLAR/ RIG FLOOR FOR CMT JOB, RID GBR PWR TONGS, 12/21/2018 12/21/20182.00 SURFAC CEMENT RURD P B/D TOP DRIVE, ISOLATE, R/U 3,036.0 3,036.0 14:30 16:30 2"CEMENT CIRC HOSE TO VOLANT CRT, CIRC 8BPM=27OPSI, 18%F/O, PUW=263K, SOW 148K, CIRC 8817STKS Q 8-BPM=2.9 BOTTOMS UP, SIMOPS; PJSM W/ SCHULMBERGER CEMENTERS, 12/21/2018 12/21/2018 5.00 SURFAC CEMENT CMNT P 3,036.0 3,036.0 16:30 21:30 LINE UP & SLB PUMP 5 BBLS WATER. PRESSURE TEST LINES TO 3500 PSI, GOOD. PUMP 40.2 BBLS OF CW100 @ 4.1 BPM, 228 PSI, FO 11%, PU 271K, SO 150K. PUMP 80 BBLS OF 10.5 PPG MP II @ 6 BPM, 148 PSI, FO 18-19%. DROP BOTTOM PLUG & START BATCHING LEAD. PUMP 569 BBLS OF 11.0 PPG LEAD CEMENT AT 4-6 BPM, 172-349 PSI, FO 13%. PU 245K, SO 96K. BATCH AND PUMP 76.7 BBLS OF 12 PPG TAIL CEMENT (03 6 BPM, 204- 360 PSI, FO 10%/12%CW100/MP LL AT SURFACE WITH 41 BBLS OF TAIL AWAY. LAND ON HANGER WITH 76.7 BBLS. TAIL AWAY. DROP TOP PLUG & KICK OUT WITH 10 BBLS OF FRESH H2O. SWAP TO RIG & DISPLACE W/ 9.5 PPG SPUD MUD @ 8 BPM, 298-660 PSI, FO 18%.11 PPG LEAD CEMENT AT SURFACE AT 196 BBLS OF DISPLACEMENT AWAY. REDUCED RATE TO 5BPM. BUMP PLUG WITH 4352 STROKES (438 BBLS), PRESSURE UP TO 950 PSI & HOLD FOR 5 MINUTES. BLEED OFF PRESSURE, FLOATS HELD. CIP 21:08 HRS 12/21/2018. 241 BBL 11 PPG CEMENT TO SURFACE. LOST 153.7 BBLS TOTAL DURING JOB. 12/21/2018 12/22/2018 2.50 SURFAC CEMENT RURD P BLOW DOWN SLB. BLOW DOWN 3,036.0 3,036.0 21:30 00:00 CEMENT LINE DRAIN CEMENT FROM STACK. RID CRT. RIG DOWN LANDING JNT. FLUSH BOP STACK WITH CEMENT RETATER WATER, JET FLOW LINE, CLEAR FLOOR OF CASING RUNNING TOOLS AND EQUIPMENT. 12/22/2018 12/22/2018 0.50 SURFAC CEMENT RURD P CLEAN AND CLEAR RIG FLOOR OF 0.0 0.0 00:00 00:30 1 1 CASING RUNNING TOOLS. 12/22/2018 12/22/2018 3.50 SURFAC CEMENT NUND P REMOVE FLOW RISER, REMOVE 0.0 0.0 00:30 04:00 SURFACE ANNULAR AND NIPPLE. LAY DOWN DIVERTER T. CLEAN CEMENT VALVES AND EQUIPMENT ON RIG FLOOR. Page 8147 ReportPrinted: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (flK6) End Depth (rKB) 12/22/2018 12/22/2018 2.00 SURFAC CEMENT NUND P ATTEMPT TO PULL DIVERTER 0.0 0.0 04:00 06:00 SPOOL. SPLIT SECTIONS AND REMOVE TOP HALF OF DIVERTER SPOOL, CLEAN AROUND CASING HANGER AND CELLAR BOX. 1212212018 12/22/2018 1.50 SURFAC CEMENT NUND P REMOVE SPLIT SECTIONS ON 0.0 0.0 06:00 07:30 DIVERTER STARTING HEAD PER CAMERON WELLHEAD TECH, INSTALL 4"THREADED CAPS ON CONDUCTOR SIDE OUTLETS 12/2212018 12/2212018 3.50 SURFAC WHDBOP NUND P P/U CAMERON MBS SYSTEM TGB 0.0 0.0 07:30 11:00 SPOOL, ORIENTATE PER CPAI DRILL SITE OPERATOR, INSTALL, M/U SAME, C/O O-RING ON SURFACE HANGER ADAPTER, SIMOPS; LOAD PIPE SHED W/ 9- 5/8"CASING, CLEAN ROCKWASHER PITS 1-2, 12/22/2018 12/22/2018 0.50 SURFAC WHDBOP NUND P CAMERON WELL HEAD TEST 10MIN 0.0 0.0 11:00 11:30 @ 5,000PSI, CO -MAN WITNESS, PICK UP 3' 13-5/8 SPACER SPOOL FOR SPACE OUT ON BOP RKB. MEASUREMENTS, TOP OF TBG SPOOL=35.04, ULDS=35.18, LLDS=36.09 12/22/2018 12/22/2018 0.50 SURFAC WHDBOP NUND P PICK UP 3' 13-5/8 SPACER SPOOL 0.0 0.0 11:30 12:00 FOR SPACE OUT ON BOP RKB, 12/22/2018 12/22/2018 1.00 SURFAC WHDBOP NUND P NIU 13-5/8 4 -RAM PREVENTOR 0.0 0.0 12:00 13:00 STACK, 12/22/2018 12/22/2018 1.00 SURFAC WHDBOP MPDA P NIU MPD RCD SPOOL, AIR 0.0 0.0 13:00 14:00 ACTUATOR 12/22/2018 12/22/2018 7.50 SURFAC WHDBOP NUND P SWEENEY WRENCH ALL FLANGE 0.0 0.0 14:00 21:30 CONNECTIONS, SET UP SCAFOLDING AROUND TOP DRIVE, SIMOPS; SERVICE MUD PUMPS #1/2, LOAD 9-5/8"CASING INTO PIPESHED, INSTALL 18"-13-5/8 SPACER SPOOL TO BOP STACK, INSTALL KILL/CHOKE HOSE/FLOW RISER NIPPLE. SET TEST PLUG AND TEST JT. PURGE AIR FROM SYSTEM 12/22/2018 12/22/2018 0.50 SURFAC WHDBOP BOPE P TEST PVT &GAS ALARMS WITH 0.0 0.0 21:30 22:00 STATE REP. 12/22/2018 12/22/2018 1.00 SURFAC WHDBOP BOPE T PREFORMED FULL BODY TEST, 0.0 0.o 22:00 23:00 KILL CONNECTION LEAK. ATTEMPT TO TIGHTEN. RETEST (FAIL). BLOW DOWN AND REPLACING RING GASKET. 12/22/2018 12/23/2018 1.00 SURFAC WHDBOP BOPE P FILL BOP. PURGE AIR FROM BOP 0.0 0.0 23:00 00:00 AND RETEST FULL BODY TEST (GOOD) Page 9147 Report Printed: 2/13/2019 operations Summary (with Timelog Depths) 2M-41 ..a. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan7mre End 7me our (hr) Phase Op code A vM1y Gotle Time P -T -X Operation (nK8) End Depth (aK8) 12123/2018 12/23/2018 5.00 SURFAC WHDBOP BOPE P CONTINUE TESTING WITH 57/8 0.0 0.0 00:00 05:00 TEST JT. 250 LOW, 3500 HIGH. 5 MIN EACH. TEST CHOKE VALVES - 1-14. TEST 5 7/8 DART AND TIW, UPPER AND LOWER IBOP. ANNULAR, UPPER 4 112 x 7 PIPE RAMS, LOWER 3 112 x 6 PIPE RAMS AND BLINDS. TEST RIG FLOOR, MEZZANINE, HCR AND MANUAL KILL LINE VALVES. TEST MANUAL AND HCR CHOKE. TEST MANUAL AND SUPER CHOKE TO 2000 PSI AND SHOW BLEED OFF. PERFORM ACCUMULATOR TEST. SYSTEM PRESSURE- 3000 PSI, PRESURE AFTER CLOSURE -1800 PSI, 200 PSI ATTAINED- 8 SEC, FULL PRESSURE ATTAINED- 52 SEC. NITGN BOTTLE AVERAGE- 2275 PSI. TEST WITNESSED BY STATE REP. 12/2312018 12123/2018 2.00 SURFAC WHDBOP MPDA P RIG UPAND TEST MPD SYSTEM TO 0.0 0.0 05:00 07:00 250PSI. FOR 5 MIN, 120OPSI. FOR 1 OMIN PER MPD REP. 12/23/2018 12/23/2018 1.00 SURFAC WHDBOP RURD P R/D TEST EQUIP, INSTALL TRIP 0.0 0.0 07:00 08:00 NIPPLE, PULL TEST PLUG, DRAIN BOP STACK, BID CHK/KILL LINES, INSTALL MOUSE HOLE, INSTALL 9- 5/8 SIDE DOOR ELEVATORS, 12/23/2018 12/23/2018 1.50 SURFAC WHDBOP OTHR P MAKE DUMMY RUN W/ CAMERON 0.0 0.0 08:00 09:30 HANGER, DRIFT BOTH HANGER AND LANDING JT W/ 8.525 RABBIT, Mu LANDING JT TO HANGER W/ 16 -L.H. TURNS, LAND HANGER ON SEAT @ 38.00' W/ 5 -STICK ACROSS TABLE, CAMERON WELLHEAD TECH VERIFY ON SEAT LOOKING THROUGH ANN VALVE, LID LANDING JT/HANGER, INSTALL 5- 7/8 DP ELEVATORS, 12/23/2018 12/23/2018 1.50 SURFAC WHDBOP OTHR P INSTALL LOWER WEAR BUSHING, 0.0 0.0 09:30 11:00 I.D =12.3125, O.D.=13.52, L=3.17', RUN IN 2 -LDS AS PER CAMERON WELLHEAD TECH ON SEAT, L/D 5- 7/8 DP LANDING JT, 12/23/2018 12/23/2018 3.00 SURFAC CEMENT SHAH P PIU 12.25"DRILLING BHA TO 0.0 412.0 11:00 14:00 FLOOR, M/U 12.25"DRILLING BHA AS PER SLB D I RECTIONAUSC IENTI F I C DRILLING, TO 48', PUW 52K, SOW 52K, 12/23/2018 12/23/2018 3.50 SURFAC CEMENT PULD P P/U DP OUT OF SHED F/ 412' T/ 412.0 2,850.0 14:00 17:30 2,850' MD, PUW 138K, SOW 115K 12/23/2018 12/23/2018 2.50 SURFAC CEMENT DHEQ P CONDITION MUD, PULSE TEST 2,850.0 2,850.0 17:30 20:00 MWD, 2850'MD, PUW 138K, SOW 115K, 7.5BBLS TO FILL, 400GPM=375PSI, 21%F/0, 600GPM=70OPSI, 31%F/O. 9.5 PPG MW IN AND OUT, 19000 STKS PUMPED 12/23/2018 12/23/2018 2.50 SURFAC CEMENT PRTS P RIG UP AND TEST CASING 3000 PSI 2,850.0 2,850.0 20:00 22:30 FOR 30 MIN. 5.8 BBL PUMPEDAND RECIEVED. RIG DOWN AND BLOW DOWN ASSEMBLY. 12/23/2016 12/24/2018 1.50 SURFAC CEMENT SLPC P SLIP AND CUT OF 43'OF DRILLING 2,850.0 2,850.0 2230 00:00 LINE Page 10/47 Report Printed: 2113/2019 Uperations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sled Depth Start Tune End Time Dur (hr) Phase Op Cafe Aavily Code Time P -T -X Operation (ftKB) End Depth (WS) 12/24/2018 12/24/2018 0.50 SURFAC CEMENT TRIP P TRIP IN HOLE F/2,850 T/2,997'. 2,850.0 2,997.0 00:00 00:30 TAGGED TOP OF PLUGS. 138K UP, 120 K D, SET DOWN 8K. PICK UP AND ENGAGE MUD PUMP. 12/24/2018 12/24/2018 2.00 SURFAC CEMENT COCF P DRILL OUT PLUGS.F/2,997' T/3,053' 2,997.0 3,053.0 00:30 02:30 400 GPM, 340 PSI. INCREASE PUMP RATE ONCE THROUGH FLOAT COLLAR TO 750 GPM, 980 PSI. 40 RPM, 12K TQ. 139K UP, 120K ON, 125K RT. REAM OUT CEMENT TO 3053. 53% FLOW. 4K WOB. 12/24/2018 12/24/2018 4.00 SURFAC CEMENT COCF T FLOW LINE PLUGGING OFF WITH 3,053.0 3,053.0 02:30 06:30 THICK CEMENT CONTAMINATED MUD INTERMITTENTLY. ATTEMPT TO CLEAR WITH FLOW LINE JETS. REMOVE INSPECTION HATCHES. FLUSH WITH WATER AND JETS. LARGE PIECE OF CEMENT PLUG FOUND. REPLACE HATCHES. ENGAGE PUMP AND STAGE UP TO FULL DRILLING RATE. 12/24/2018 12/24/2018 1.00 SURFAC CEMENT CIRC P CIRC BOTTOMS UP, WORK PIPE F/ 3,053.0 2,995.0 06:30 07:30 3048' MD TO 2995'MD, 750GPM=96OPSI, 32%F/0, 40RPM=7.2K TQ, PUW 139K, SOW 120K, RWT 133K, 12/24/2018 12/24/2018 1.00 SURFAC CEMENT DRLG P WASHED & REAMED THROUGH 2,995.0 3,087.0 07:30 08:30 CMT F/ 3053'MD - T/ 3087'MD, 750GPM=975PSI, 32%F/O, 60RPM=8.3K TQ, 12/24/2018 12/24/2018 0.50 SURFAC CEMENT DREG P DRILL SHOE T F/ 3087'- T/ 3088', 3,087.0 3,096.0 08:30 09:00 DRILL CMT F/ 3088'-T/ 3096'750GPM= 1000PSI, 32%F/0, 60RPM=9.2K TQ, 4K WOB, 12/24/2018 12/24/2018 1.00 SURFAC CEMENT CIRC P CIRC, RECIPROCATE PIPE F/ 3087' 3,096.0 3,096.0 09:00 10:00 TO 3048', 750GPM=1140PSI, 32% F/0, 20RPM=9K TQ, RWT 132K, 12/24/2018 12/24/2018 2.00 SURFAC CEMENT DISP P PUMP MUD SPACER, DISPLACE 3,096.0 3,045.0 10:00 12:00 WELL WI 9.5PPG LSND MUD AS PER MUD MAN, RECIP PIPE F/ 3116' MD, T/ 3052 'MD, 800GPM=929PSI, 32%F/O, 20RPM=8.4K TO, RWT=123K, SUFFICIENT 9.5PPG IN/OUT, POOH TO 3045', PUW 142K, SOW 115K, 12/24/2018 12/24/2018 0.50 SURFAC CEMENT TRIP P POOH TO 3045', PUW 142K, SOW 3,045.0 3,045.0 12:00 12:30 115K, B/D T/D, R/U 12/24/2018 12/24/2018 2.50 SURFAC CEMENT LOT P CIRC 18BBLS DOWN DRILL PIPE, 3,045.0 3,045.0 12:30 15:00 CIRC 15BBLS DOWN KILL LINE, CLOSE 4.5X7UPR'S, - MUD WEIGHT: 9.5 PPG, 2691' TVD, 3048' MD. @ 7SPM PUMPED 1.3BBLS TO 795 PSI. PUMPED IBEL. INTO FORMATION. PRESURE DROPPED TO 460PSI. SHUT WELL IN, PRESURE BLED OFF TO 405PSI. IN 10 MIN. OPEN WELLAND BLED BACK 1.8BBL. (EMW = 15.2 PPG 12/24/2018 12/24/2018 0.50 SURFAC CEMENT WASH P WASH DOWN F/ 3045'MD -T/ 3,045.0 3,116.0 15:00 15:30 3116'MD, PUW 144K, SOW 115K, Page 11147 Report Printed: 211 312 01 9 operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log San Depth Sart Time End Time our (m) Phase Op cod. Activity Ccoe Time P -T -X Operaton (ftKB) End Depth(ftKB) 1212412018 12/24/2018 2.50 INTRM1 DRILL DDRL P DRILL 12.25" HOLE F/ 3116' MD T/ 3,116.0 3,310.0 15:30 18:00 3310' MD,2792' TVD @ 800 GPM, 905 PSI, 32% F/O, 120 RPM, 6K TO, 8K WOB, ECD'S = 9.98, OFF BTM = 90OPSI, PIU =134 K,S/O =119 K, ROT =122 K, 8.11K TO, MAX GAS= 4 UNITS, ADT=2.00, BIT HRS=2.00 , JAR HRS=31.43 12/24/2018 12/2512018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 3310' MD T/ 3,310.0 3,857.0 18:00 00:00 3857' MD, 3068' TVD @ 800 GPM, 966 PSI, 32% F/O, 140 RPM, 91K TO, 1 O WOB, ECD'S- 10.2, OFF BTM- 940PSI, P/U- 150K, S/0-129 K, ROT - 133 K, 71K TO, MAX GAS- 6 UNITS, ADT -4.42, BIT HRS -6.42, JAR HRS - 35.85 12/25/2018 12/25/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/3,857'MD T/ 3,857.0 4,454.0 00:00 06:00 4,454' MD, 3,338' TVD @ 800 GPM, 966 PSI, 32% F/0, 140 RPM, 9K TO, 1 OK WOB, ECD'S- 10.22, OFF BTM - 1,020 PSI, PIU- 165K, S/O- 129 K, ROT- 139 K, 81K TO, MAX GAS- 6 UNITS, ADT -4.29, BIT HRS- 10.71, JAR HRS- 40.14 12/25/2018 12/25/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 4,454' MD, 4,454.0 5,069.0 06:00 12:00 3,338' TVD - 5,069' MD 3,527' TVD @ 800 GPM, 1,450 PSI, 32% F/O, 200 RPM, 1 O TO, 1 O WOB, ECD'S- 10.56, OFF BTM- 1,449 PSI, PIU - 165K, S/0- 131 K, ROT- 136 K, 81K TO, MAX GAS- 6 UNITS, ADT- 4.59, BIT HRS- 15.30, JAR HRS- 44.73 Pump 11.5 PPG 50 BBL Nut plug sweep @ 4,554' MD w/40% inc in cuttings Pump 11.5 PPG 30 BBL Nut plug sweep @ 4,970' MD w/150% inc in cuttings SPR 4,641' MD 3,064' TVD MW = 9.5 PPG HRS = 0753 MP -#1) 30 SPM 120- PSI 40 SPM 140 PSI MP42) 30 SPM 120 - PSI 40 SPM 140 PSI 12/25/2018 12/25/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/5,069' MD - 5,069.0 5,634.0 12:00 18:00 T/5634' MD, 3,679' TVD@ 925 GPM, 1620 PSI. 36% F/O, 200 RPM, 1 OK TO, 10K WOB, ECD -10.64, OFF BTM -1631 PSI, PIU- 170K, S/0 -132K, ROT- 14-K, 81K T0, GAS- 6 UNITS MAX, ADT- 3.75, BIT HRS- 19.05 JAR HRS -4848. Pump 11.5 PPG 35 BBL. NUT PLUG SWEEP @ 5,435' MD W/200% INC. IN CUTTINGS Page 12/47 Report Printed: 2/1 312 01 9 Uperations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stad Mme End Time Dur (hr) Phase Op Code Activity Coda Time P -T -X Operation (fiKB) End Depen (RKB) 12/25/2018 12/26/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 5,634' MD- 5,634.0 6,250.0 18:00 00:00 T/6,250'- 3,857' TVD @ 925 GPM, 1,732 PSI, 32% F/O, 200 RPM, 14K TO, 12K WOB, ECD'S- 10.82, OFF BTM- 1,620 PSI, PIU- 180K, S/O- 136 K, ROT- 151 K, 10K TO, GAS- 6 UNITS MAX, ADT- 4.22, BIT HRS - 23.27, JAR HRS- 52.77 SPR'S @ 5,772" MD 3,719' TVD MW= 9.6 PPG HRS=19:15 MP #1 30 SPM- 180 PSI 40 SPM- 220 PSI. #2 30 SPM- 180 PSI 40 SPM- 220 PSI. 12/26/2018 12/26/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 6,250' MD T/ 6,250.0 6,904.0 00:00 06:00 6,904' MD,2792' 4,037 ND @ 925 GPM, 1700 PSI, 37% F/O, 200 RPM, 14K TO, 12K WOB, ECD'S = 10.75, OFF BTM = 1667PSI, PIU =195 K, S/O =139K, ROT =158K, IOK TO, ADT=4.52, BIT HRS=27.79, JAR HRS=57.29 12/2612018 12/26/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 6,904' MD T/ 6,904.0 7,491.0 06:00 12:00 7,491' MD, 4,198' TVD Q 925 GPM, 1750 PSI, 37% F/O, 200 RPM, 14K TO, 12K WOB, ECD'S- 10.68, OFF BTM- 1757PSI, P/U- 204K, S/O- 139 K, ROT- 158 K, 10K TO, MAX PUMP 30BBL. 2 PPG. NUTPLUG SWEEP 7,004' MD W/ 50% INCREACE IN CUTTINGS ADT- 4.42, BIT HRS - 27.79 JAR HRS- 61.50 SPR'S @17,184'MD 4.114'TVD MW= 9.7 PPG HRS= 08:30 MP #1) 30 SPM 200 -PSI 40 SPM 230 - PSI MP #2) 30 SPM 210 -PSI 40 SPM 230 - PSI 12/26/2018 12/26/2018 1.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 7,491' MD T/ 7,491.0 7.565.0 12:00 13:00 7,565' MD, 4,200' TVD @ 925 GPM, 1900 PSI, 37% F/O, 200 RPM, 14K TO, 12K WOB, ECD'S = 10.72, OFF BTM = 1867PSI, PIU =195K, BID =139K, ROT =158K, 10K TO, ADT= .15, BIT HRS=34.00 JAR HRS=61.65 12/26/2018 12/26/2018 0.50 INTRMI DRILL RGRP T POOH F/7,565' -T/7,471' MD, BLOW 7,565.0 7,471.0 13:00 13:30 DOWN TOP DRIVE, PUW 200K, SOW 140K 12/26/2018 12/26/2018 0.50 INTRMI DRILL RGRP T R/U TIW/ CIRCHOSE, CIRC 7,471.0 7,471.0 13:30 14:00 336GPM= 517, F/O 19% @ 7,471' MD, SERVICE THE TOPDRIVE 12/2612018 12/26/2018 1.00 INTRMI DRILL RGRP T SERVICE TOP DRIVE, MECH/ELECT 7,471.0 7,471.0 14:00 15:00 TROUBLESHOOT, REPLACE ENCODER HYD. PULLEY RETAINER SPRING 12/26/2018 12/26/2018 0.50 INTRMI DRILL WASH T WASH DOWN F77,474' -T/7,565'7,471.0 7,565.0 15:00 15:30 650GPM 1070PSI. 33% F/O 100RPM 9K TO RWT 160K Page 13147 Report Printed: 211312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activit' Code Time P -T -X Operation (MB) End Depth(11R8) 12/26/2018 12/26/2018 2.50 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 7,565" MD T/ 7,565.0 7,714.0 15:30 18:00 7,714' MD, 4,260' TVD @ 925 GPM, 1930 PSI, 37% F/O, 200 RPM, 14K TQ, 12K WOB, ECD'S = 10.63, OFF BTM = 1867PSI, P/U =195K, S/O =139K, ROT=158K, 10KTQ, ADT=2.0, BIT HRS=34.15, JAR HRS=63.65 CIRC. TANDEM SWEEP 30 LOW -VIS 2PPG HI -VIS NUTPLUG SWEEP @7,564', W/ 75% INCREACE IN CUTTINGS 12/26/2018 12/27/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 7,714" MD T/ 7,714.0 8,215.0 18:00 00:00 8,215' MD, 4,399' TVD @ 900 GPM, 1720 PSI, 37% F/O, 200 RPM, 14K TQ, 10K WOB, ECD'S = 10.62, OFF BTM = 1600PSI, P/U =202 K, SIO =149K, ROT =164K, 10K TO. ADT=4.63, BIT HRS=38.78, JAR HRS=68.28 SPR'S @ 7,939'MD 4,324'TVD MW= 9.7 PPG HRS= 21:00 MP #1) 30 SPM 230 -PSI 40 SPM 260 - PSI MP #2) 30 SPM 220 -PSI 40 SPM 250 - PSI 12/27/2018 12/27/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 8215' MD T/ 8,215.0 8,670.0 00:00 06:00 8670' MD, 4527' TVD @ 900 GPM, 1900 PSI, 37% F1O, 200 RPM, 13K TQ, 8K WOB, ECD'S- 10.77, OFF BTM- 1870 PSI, PIU- 210K, S10- 161 K, ROT- 172K, 11 K TO, ADT- 4.36, BIT HRS- 43.14, JAR HRS- 72.64. 12/27/2016 12/27/2018 4.50 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 8670' MD T/ 8,670.0 8,978.0 06:00 10:30 8978' MD, 4604' TVD @ 900 GPM, 1900 PSI, 37% F/0, 200 RPM, 13K TQ, 8K WOB, ECD'S- 10.77, OFF BTM- 1870 PSI, PIU- 212K, 510- 161 K, ROT- 174K, 11 K TQ, ADT- 3.89, BIT HRS- 47.03, JAR HRS- 76.53. 12/27/2018 12/27/2018 1.50 INTRMI DRILL CIRC P CIRC B/U @ 900 GPM, 1970PSI.,36% 8,978.0 8,978.0 10:30 12:00 F/0, 200 RPM, IOK SPR'S @ 7939'MD, 4324' TVD, MW - 9.6 PPG, HRS- 21:00 MP #1) 30 SPM-230PSI, 40 SPM- 260PSI. MP #2) 30 SPM-220PSI, 40 SPM- 25OPSI. 12/27/2018 12/27/2018 2.00 INTRMI DRILL CIRC P WEIGHT UP MUD SYSTEM TO 8,978.0 8,978.0 12:00 14:00 10.3PPG, 900 GPM, 1850 PSI, 37% F/O, ECD-11.26PPG; 200 RPM, 10K TRQ; ENCOUNTER DYNAMIC LOSSES @ 20870 STKS AWAY: INITAL LOSS RATE 180BPH; SLOW PARAMETERS T/ 705GPM 1225PSI 120RPM IOK TRQ ECD 11.10PPG, LOSS RATE 90BPH 12/27/2018 12/27/2018 0.50 INTRMI DRILL CIRC P MONITOR WELLMELLWAS 8,978.0 8,978.0 14:00 14:30 BREATHING) Page 14147 Report Printed: 2113/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stun Depth Start Time End Time Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (%(B) 12/27/2018 12/27/2018 INTRMI DRILL CIRC T ROTATE & RECIPROCATE F/8,972'- 8,978.0 8,882.0 14:30 15:30 T/8,882' RECIPROCATE SPEED 50'A MIN. @ 705 GPM 1,225PSI. 120 RPM r3.00 10K TO SLOWING PUMP RATE TO 400 GPM 540PSI. DUE TO EXCESSIVE LOSSES. 12/27/2018 12/27/2018 INTRMI DRILL CIRC T CIRC. 8,882'-T/8972'@50 8,882.0 8,872.0 15:30 18:30 MIN,250-300 GPM 230-330 PSI. 100RPM 11 K TO. (SIMOPS: MIXING A30 PPB LCM PILL) 12/27/2018 12/27/2018 0.50 INTRMI DRILL CIRC T PUMP 30BBL. 10APPG 40PPB 8,872.0 8,978.0 18:30 19:00 MIX2/NUT PLUG PILL @ 450GPM UNTIL THE LCM PILL STARTED OUT OF THE BIT, INCREASED RATE TO 900 GPM TO HELP SQUEEZE LCM INTO FORMATION, PUMPED AN ADDITIONAL 1000 STRK. SLOW RATE DOWN TO 450 GPM AND MONITOR DYNAMIC LOSSES (DYNAMIC LOSS RATE BBPH @ 450GPM @ 900GPM LOSS RATE 126PH) 12/27/2018 12/28/2018 5.00 INTRMI DRILL CIRC T CONTINUE ROTATE & 8,872.0 8,978.0 19:00 00:00 RECIPROCATE PIPE F/ 8972'MD - T/ 8882 @ 50'MIN, 420GPM 450PSI, 30RPM 10K TRQ, DROP MUD WEIGHT F/ 10.4 PPG. -T/ 9.5 PPG SPR'S @8978'MD, 4599' TVD, MW- 10.3PPG, HRS- 15:30 MP #1) 30 SPM- 190PSI, 40 SPM- 212PSI MP #2) 30 SPM- 175PSI, 40 SPM- 205PSI 12/28/2018 12/28/2018 2.00 INTRMI DRILL CIRC T CIRC. AND CONDITION MUD F/ 8,872.0 8,792.0 00:00 02:00 8,792'- T/8,597" 420-575 GPM, 450- 570 PSI, 12 TQ, DROPPING MUD WEIGHT FROM 10.3 TO 9.5 35000 STRK PUMPED. 197K POW, 160 SOW, 168 ROT TOATAL OF 170BBL. LOSSED SPR'S @8,872'MD, 4592' TVD, MW- 9.5PPG, HRS- 00:30 MP #1) 30 SPM- 120PSI, 40 SPM- 140PSI. MP #2) 30 SPM- 120PSI, 40 SPM- 150PSI. 12/28/2018 12/28/2018 0.751NTRM1 DRILL TRIP P BKRM F/ 8,792'- T/8,597' STOPED, 8,792.0 8,597.0 02:00 02:45 MONITOR WELL OBSERVED @ 3.613PH FLOW BACK, BUT QUICKLY SLOWED DOWN TO 2.713PH, 2.OBPH, 1.613PH. ROT DRILL STRING 4 RPM. 9K TQ. (BREATHING) 170BBL. WAS LOST DURING WHILE REDUCEING MUD WEIGHT FROM 10.3 TO 9.5 Page 15/47 Report Printed: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Cade Activity CMe Time P-T-X Operation (fiKS) End Depm(RKB) 12/28/2018 12/28/2018 9.25 INTRMI DRILL BKRM P BROOH STANDING BACK 5 7/8 DP 8,597.0 6,155.0 02:45 12:00 F/ 8,597'- T/6,155' 120 RPM 9-11 K TQ. 900 GPM, 1550-1468 PSI. 35% F/O 143K ROT UP WEIGHT. STARTING RUNNING SPEED 200FPH EASING SPEED UP TO 500 FPH. 12/28/2018 12/28/2018 6.00 INTRMI DRILL BKRM P BROOH @ 500' FPH, STANDING 6,155.0 4,389.0 1200 18:00 BACK 5 7/8" DP F/6.155'- 4,389'. 120 RPM 7-11 K TQ. 900 GPM, 1393 PSI. 35% F/O 134K ROT UP WEIGHT. ATTEMPTED TO INCREACE RUNNING SPEED TO 700FPH, BUT ERRATIC PRESURE SPIKE WOULD NOT ALLOW US TO PULL ATTHAT SPEED. BACK RUNNING SPEED DOWN TO 500FPH 12/28/2018 12/28/2018 3.25 INTRMI DRILL BKRM P BROOH @ 500'FPH STANDING 4,389.0 3,538.0 18:00 21:15 BACK 5 7/8" DP F/4,389'— T/ 3,538'. 120 RPM 5-7K TQ 9000PM, 1342 PSI. 35% Flo ECD 10.34 124K ROT UP WEIGHT. @ 3,538' OBSERVE 100 PSI. INCREASE IN PRESURE, INCREASE IN CUTTING AT THE SHAKERS. DROPPED STAND DOWN, REDUCED PULLING SPEED AND CBU AT FULL DRILLING RATE. 1311 PSI. 5K TQ. 2 B/U ECD WAS AT 10.09 12/28/2018 12/2912018 2.75 INTRMI DRILL BKRM P BROOH 250-500'FPH STANDING 3,538.0 3,022.0 21:15 00:00 BACK 5 7/8" DP F/3,538' - T/3.022'. 120 RPM, 6K TQ 900 GPM, 1270 PSI. 35% F/O ROT UP WEIGHT 117K. 12/29/2018 12/29/2018 6.00 INTRMI DRILL BKRM P BROOH @ 500' FPH, STANDING 3,022.0 1,200.0 00:00 06:00 BACK 5 7/8" DP F/3,022'—T/1,200'. 80 RPM 4K TQ. 800-900 GPM, 1270 PSI. 35% F/O 94K ROT UP WEIGHT. 12/2912018 12129/2018 2.75 INTRMI DRILL BKRM P BROOH @ 250- 500' FPH, 1,200.0 412.0 06:00 08:45 STANDING BACK 5 7/8" DP F/1,200' — T/ 412'. 80 RPM 2K TQ. 800 GPM, 1270 PSI. 35% F/O 75K ROT UP WEIGHT PUW= 91K, SOW= 103K 12/29/2018 12/29/2018 0.25 INTRMI DRILL OWFF P MONITOR WELL FOR STATIC 412.0 412.0 08:45 09:00 LOSSES, PJSM ON L/D BHA (WELL IS STATIC) 12/29/2018 12/29/2018 3.25 INTRMI DRILL BHAH P RACK BACK HWDP AND A STAND 412.0 0.0 09:00 12:15 OF NM DC. L/D BHA WITH DD. REMOVE PORTED FLOAT AND INSTALL NON PORTED FLOAT, PULL SCIENTIFIC TOOL AND RE- DRESS IN PIPESHED, CHANGE OUT TOP STAB. 12129/2018 12/29/2018 0.50 INTRMI DRILL BHAH P CLEAN AND CLEAR FLOOR. CLEAN 0.0 0.0 12:15 12:45 I ROTARY TABLE DRIP PAN OF CLAY AND SOLIDS. 12/29/2018 12129/2018 1.75 INTRMI DRILL BHAH P M/U BHA#5, RIH FROM SURFACE 0.0 503.0 12:45 14:30 I I 503', PUW= 82K SOW= 80K Page 16/47 Report Printed: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tim I End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (WB) End Depth (fixe) 12/29/2018 12/29/2018 1.00 INTRMI DRILL SVRG P SERVICE TOP DRIVE- CHANGE 503.0 503.0 14:30 15:30 HYDRAULIC FILTER, ADD OIL, GREASE TRACTION MOTORS, INSPECT BOLTS AND ENCODER. SERVICE BLOCKS, DRAW WORKS- CHECK BREAKS. MONITOR WELL VIA TRIP TANK. 12/29/2018 12/29/2018 1.50 INTRMI DRILL TRIP P RIH WITH 5 7/8" DP FROM 503'- 503.0 1,823.0 15:30 17:00 1,823' MONITOR WELL VIA PIT #1. P/U WT = 109K 8/0 WT = 114K 12/29/2018 12/29/2018 0.50 INTRMI DRILL DHEQ P FILL PIPE @ 1823- AND SHALLOW 1,823.0 1,823.0 17:00 17:30 PULS TEST MWD AT 700 GPM, 728 PSI, 32 % F/O STKS TTL = 1618. (GOOD TEST) 12/29/2018 12/29/2018 0.50 INTRMI DRILL TRIP P RIH WITH 5 7/8" DP FROM 1,823' - 1,823.0 2,856.0 17:30 18:00 2,856'. MONITOR WELL VIAPIT #1 FILLING PIPE EVERY 15 STDS. P/U WT=121K, S/O WT=114K 12/29/2018 12/29/2018 1.25 INTRMI DRILL TRIP P RIH WITH 5 7/8" DP FROM 2,856'- 2,856.0 4,085.0 18:00 19:15 4,085'. MONITOR WELL VIA PIT#1 FILLING PIPE EVERY 15 STDS. P/U WT- 146K, S/O WT- 130K. 12/29/2018 12/29/2018 0.50 INTRMI DRILL REAM P RIH WHILE CIRCULATING 4,085.0 4,180.0 19:15 19:45 BOTTOMS UP FROM 4,085,'- 4,180'. P/U WT- 146K, S/O WT- 130K, 142K RT. 1300 PSI, 890 GPM. 80 RPM, 5K TO, 4700 STKS PUMPED TOTAL. 12/29/2018 12/29/2018 1.25 INTRMI DRILL TRIP P RIH WITH 5 7/8" DP FROM 4,185'- 4,180.0 5,970.0 19:45 21:00 5,970'. MONITOR WELL VIA PIT#1 FILLING PIPE EVERY 15 STDS. P/U WT- 182K, S/O WT- 140K. 12/29/2018 12/29/2018 0.75 INTRMI DRILL REAM P RIH WHILE CIRCULATING 5,970.0 6,060.0 21:00 21:45 BOTTOMS UP FROM 5,970'- T/6,060'. P/U WT- 182K, S/O WT- 140K, 156K RT. 1500 PSI, 900 GPM. 80 RPM, 8K TO, 7000 STKS PUMPEDTOTAL. 12/29/2018 12/30/2018 2.25 INTRMI DRILL TRIP P RIH WITH 5 7/8" DP FROM 6,060'- 6,060.0 8,500.0 21:45 00:00 T/8,500'. MONITOR WELL VIA PIT #1 FILLING PIPE EVERY 15 STDS. P/U WT- 191 K, S/O WT- 136K. 12/30/2018 12/3012018 1.00 INTRMI DRILL CIRC P CIRC. B/U FROM 8,418'—T/8,510' 8,418.0 8,510.0 00:00 01:00 POW= 204 SOW=145K ROW=160K 900 GPM 1750 PSI. 80 RPM, 8K TO. 10,000 STRK PUMPED TOTAL 12/30/2018 12/30/2018 0.75 INTRMI DRILL MPDA P PULL TRIP NIPPLE. INSTALL RCD 8,510.0 8,510.0 01:00 01:45 BEARING AND DRILL NIPPLE. ALIGN AND FLOOD CHOKE. 12/30/2018 12/30/2018 3.00 INTRMI DRILL REAM P WASH DOWN 12.25" HOLE F/ 8,510' 8,510.0 8,978.0 01:45 04:45 MD T/ 8,978' MD, @ 900 GPM, 1820 PSI. 30% F/0, 120 RPM, 11 K TO, 12K P/U =204K, S/0 =145K, ROT =160K, SEND DOWN LINK PRIOR TO TAGGING BOTTOM. Page 17147 Report Printed: 211312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siert Depth Start Tim Eno Time Dur (hr) Phase Op Cade Ad city Code Time P -T -X Operation (fIKB) Ertl Depth (WS) 12/30/2018 12/30/2018 1.25 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 8,978' MD T/ 8,978.0 9,074.0 04:45 06:00 9,074" MD, 4,638' TVD @ 900 GPM, 1800 PSI, 30% F/O, 120 RPM, 14K TQ, 10K WOB, ECUS = 10.6, OFF BTM = 1780PSI, P/U =204 K, SIO =145K, ROT =162K, 11K TO, ADT=1, BIT HRS=48.03, JAR HRS=77.53. 12/30/2018 12/30/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 9,074' MD T/ 9,074.0 9.313.0 06:00 12:00 9,313' MD, 4,709' TVD @ 900 GPM, 1650 PSI, 25% F/O, 120 RPM, 14K TQ, IOK WOB, ECUS = 10.44, OFF BTM = 1600PSI, P/U =204 K, SIO =145K, ROT =170K, 11K TQ, ADT=3.18, BIT HRS=51.21, JAR HRS=80.71. SPR'S @ 9,165'MD 4,667'TVD MW= 9.6 PPG HRS=07:15 MP #1) 30 SPM 400 -PSI 40 SPM 420 - PSI MP #2) 30 SPM 380 -PSI 40 SPM 400 - PSI 12/30/2018 12/30/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/ 9,313' MD T/ 9,313.0 9,690.0 1200 18:00 9,690' MD, 4,815' TVD @ 900 GPM, 1739 PSI, 26% F/O, 140 RPM, 17K TO, 8K WOB, ECD'S = 10.66, OFF BTM = 1700PSI, PIU =204 K, SIO =150K, ROT=174K, 12KTQ, ADT=4.92, BIT HRS=56.13, JAR HRS=85.63. 12/30/2018 12/31/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/9,690'MID T/ 9,690.0 10,104.0 18:00 00:00 10,104' MD, 4,925' TVD @ 900 GPM, 1841 PSI, 26% F/O, 140 RPM, 17K TQ, 8K WOB, ECUS = 10.78, OFF BTM = 1700PSI, P/U =213 K, SIO =147K, ROT=176K, 14KTQ, ADT=4.79, BIT HRS=60.92, JAR HRS=90.42. SPR'S @ 9,732'MD 4,827 -TVD MW= 9.6 PPG HRS=24:00 MP #1) 30 SPM 400 -PSI 40 SPM 420 - PSI MP #2) 30 SPM 380 -PSI 40 SPM 400 - PSI MPD BACK PRESURE 200 PSI. @ 30spm/170 psi. 40spm 12131/2018 12/31/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/10,104'- 10,104.0 10,580.0 00:00 06:00 T/10,580' MD, 5,058' TVD @ 900 GPM, 1873 PSI, 26% F/O, 140 RPM, 20K TO, 13K WOB, ECUS = 10.66, OFF BTM = 1,866PSI, P/U =220 K, SIO =154K, ROT =175K, 17K TQ, ADT=3.24, BIT HRS=64.16, JAR HRS=93.66. Page 18147 Report Printed: 211312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stag Time End Time Our (hr) Phase Op Code Activity Code Time P -T -x Operation (ftKB) Erd Depth(ftKB) 12/31/2018 12/31/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/10,580'— 10,580.0 11,113.0 0600 12:00 T/11,113' MD, 5,208' TVD @ 900 GPM, 1959 PSI, 26% F/0, 140 RPM, 21K TQ, 8K WOB, ECD'S = 10.79, OFF BTM = 1,938PSI, P/U =221 K. S/O =154K, ROT =175K, 17K TQ, ADT=4.60, BIT HRS=68.75, JAR HRS=98.18. SPR'S @ 10,671'MD 5,086'TVD MW= 9.5 PPG MP #1) 30 SPM 230 -PSI 40 SPM 265 - PSI MP #2) 30 SPM 220 -PSI 40 SPM 265 - PSI 12/31/2018 12/31/2018 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/11,113'— 11,113.0 11,618.0 12:00 18:00 T/11,618' MD, 5,348' TVD @ 900 GPM, 2062 PSI, 26% F/O, 140 RPM, 22K TO, 15K WOB, ECD'S = 10.83, OFF BTM = 2044PSI, P/U =240K, S/O =149K, ROT=180K, 17KTQ, ADT=4.12, BIT HRS=72.87, JAR HRS=102.3. 12/31/2018 1/1/2019 6.00 INTRMI DRILL DDRL P DRILL 12.25" HOLE F/11,618'— 11,618.0 12,090.0 1800 0000 T/12,090' MD, 5,480' TVD @ 900 GPM, 2120 PSI, 26% F/O, 140 RPM, 25K TO, 13K WOB, ECD'S = 10.9, OFF BTM = 2100PSI, P/U =245K, S/O =156K, ROT =183 K, 17K TQ,19 ADT=4.66, BIT HRS=77.53, JAR HRS=106.96. SPITS @ 11,900'MD 5,429'TVD MW= 9.6PPG MP #1) 30 SPM 330 -PSI 40 SPM 360 - PSI MP #2) 30 SPM 330 -PSI 40 SPM 360 - PSI 1/1/2019 1/1/2019 6.00 INTRMI DRILL DDRL P Drill 12.25" hole from 12090' MD to 12,090.0 12,550.0 0000 0600 12550' MD, 5610' TVD @ 900 gpm, 2139 psi, 26% FO, 140 rpm, 25K TO, 13K WOB, ECUS = 10.91, Off Btm = 2110 psi, P/U =250K, S/O =155K, ROT =186K, 23K TQ,Max gas=O units ADT=4.54, BIT HRS=82.07, JAR HRS=111.50. Page 19147 Report Printed: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stam Depth Stent Time End Tire Dur (hr) Phase Op Cod. Activity Cade Time P -T -X Operation (ftKB) End Depth(ftKS) 1/1/2019 1/1/2019 6.00 INTRMI DRILL DDRL P Drill 12.25" hole from 12550' MD to 12,550.0 13,035.0 06:00 12:00 13035' MD, 5745' TVD @ 900 gpm, 2065 psi, 26% FO, 140 rpm, 24K TQ, 12K WOB, ECUS = 10.95, Off Btm = 2060 psi, P/U =259K, S/O =155K, ROT =188K, 23K TQ,Max gas=0 units ADT=4.46, BIT HRS=86.53, JAR HRS=115.96. SPR'S @ 12652 -MD 5639'TVD MW= 9.6 PPG MP #1) 30 SPM 250 -PSI 40 SPM 270 - PSI MP #2) 30 SPM 240 -PSI 40 SPM 260 - PSI 1/1/2019 1/1/2019 1.50 INTRMI DRILL DDRL P Drill 12.25" hole from 13035' MD to 13,035.0 13,140.0 12:00 13:30 13140' MD, 5775' TVD @ 900 gpm, 2120 psi, 26% FO, 140 rpm, 25K TQ, 13K WOB, ECUS = 10.96, Off Btm = 2111 psi, P/U =252K, SIO =154K, ROT =191 K, 24K TQ,Max gas=0 units ADT=1.12, BIT HRS=87.65, JAR HRS=117.08. SPR'S @ 13138'MD 5775'TVD MW= 9.7 PPG MP #1) 30 SPM 295 -PSI 40 SPM 325 - PSI MP #2) 30 SPM 255 -PSI 40 SPM 325 - PSI 1/1/2019 1/1/2019 3.75 INTRMI CASING CIRC P CBU x2. Rotate and reciprocate from 13,140.0 13,138.0 13:30 17:15 13138' MD to 13056' MD. 900 gpm, 2140 psi, 140 rpm, 21 K lq, 10.94 ECD, 24% FO. Reduce flow rate to 700 gpm on down stroke=1382 psi. 1/1/2019 1/1/2019 0.25 INTRMI CASING RURD P Blow down top drive. 13,138.0 13,124.0 17:15 17:30 1/1/2019 1/1/2019 1.00 INTRMI CASING OWFF P Perform draw down test as per 13,124.0 13,124.0 17:30 18:30 procedure. Starting pressure=200 psi. Bleed for 15 sec's/3.6 bbls. Shut in for 5 mins and build to 132 psi. Bleed for 15 sec's/1.7 Wis. Shut in for 5 mins and build to 102 psi. Bleed for 15 sec's/.9 bbls. Shut in for 5 mins and build to 86 psi. Bleed for 30 sec's/.6 bbls. Shut in for 5 mins and build to 68 psi. Bleed for 30 sec's/.3 bbls. Shut in for 5 mins and build to 50 psi. Bleed for 30 sec's/.8 bbls. Shut in for 5 mins and build to 50 psi. Bleed for 30 seCs/.2 Wis. Shut in for 5 mins and build to 45 psi. Results indicate a pore pressure of 9.95 ppg EMW. 1/1/2019 1/1/2019 2.00 INTRMI CASING CIRC P CBU with 9.8 ppg mud. 900 gpm, on 13,124.0 13,138.0 1830 2030 upstroke and 700 gpm on downstroke. 2120 psi/1440 psi. Rotate and reciprocate from 13138' MD to 13056' MD. Did not observe gas on bottoms up. Page 20147 Report Printed: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Sten Tim End Ttm our (hr) Phase Dp Code Activity Code Time P -T -X operation (ttK3) End Depth (ftKB) 1/1/2019 1/2/2019 3.50 INTRMI CASING CIRC P Circulate and weight up to 10.2 ppg 13,138.0 12,938.0 20:30 00:00 using 11.9 ppg spike Fluid in .2 ppg increments. Initial rate 800 gpm, 1750 psi. Final rate 500 gpm, 896 psi. BROOH from 13138' MD to 12938' MD after 10.2 ppg mud exited bit. 1/2/2019 1/2/2019 1.50 INTRMI CASING CIRC P Circulate and weight up to 10.2 ppg 12,938.0 12,938.0 00:00 01:30 using 11.9 ppg spike Fluid in .2 ppg increments. Initial rate 800 gpm, 1750 psi. Final rate 500 gpm, 896 psi. BROOH from 13138' MD to 12938' MD after 10.2 ppg mud exited bit. 1/2/2019 1/212019 1.00 INTRMI CASING OWFF P Monitor well. Slight Flow starting at 2 12,938.0 12,938.0 01:30 02:30 bph diminishing to static. 1/2/2019 1/2/2019 1.75 INTRMI CASING SMPD P Strip OOH on elevators from 12938' 12,938.0 12,395.0 02:30 04:15 MD to 12395' MD as per stripping schedule. PU=260K S0=1 53K. 60K overpull observed at 12395' MD. 1/2/2019 112/2019 1.75 INTRMI CASING SMPD T Attempt to work through tight hole 3 12,395.0 12,216.0 04:15 06:00 limes. Slack off to neutral weight. Make up lop drive and pump at 10 bpm, 650 psi. Work through tight spot. Slack off and work through section with 2 bpm, 240 psi. Pull to 12216' MD. 40K overpull observed at 12216' MD. 1/2/2019 1/2/2019 2.00 INTRMI CASING SMPD T Slack off and break over to neutral 12.216.0 11,999.0 06:00 08:00 weight. Attempt to pull through tight hole 3 times. Make up top drive and pump at 10 bpm, 720 psi. Attempt to pull through tight hole. Slack off to neutral weight and engage rotary at 100 rpm, 22K tq. Rot=190K. Ream through tight hole. Shut down rotary and pump. Slack off and strip OOH from 12216' MD to 12089' MD with 10- 15K overpull. At 12089' MD observe 40K overpull. Attempt to pull through tight hole 3 times. Make up lop drive and pump at 10 bpm, 720 psi. Attempt to pull through tight hole. Slack off to neutral weight and engage rotary at 100 rpm, 22K tq. Ream through tight hole. Shut down rotary and pump. Slack off and strip OOH from12089' MD to 11999' MD. 1/2/2019 1/2/2019 2.50 INTRMI CASING SMPD P Strip OOH on elevators from 11999' 11,999.0 11,118.0 08:00 10:30 MD to 11118' MD as per stripping schedule. PU=241K S0=1 36K. 40K overpull observed at11118' MD. Attempt to work through tight hole 5 times. 1/2/2019 1/2/2019 3.50 INTRMI CASING BKRM P Make up top drive. BROOH from 11,118.0 10,394.0 10:30 14:00 11118' MD to 10394' MD. 426 gpm, 673 psi, 15% FO, 100 rpm, 15-17K tq. PU=233K SO=140K Rot=177K. 1/2/2019 1/2/2019 0.25 INTRMI CASING SMPD P Strip OOH from 10394' MD to 10301' 10,394.0 10,301.0 14:00 14:15 MD with 10-40K overpull. 1/2/2019 112/2019 3.75 INTRMI CASING CIRC P CBU x2. Stage pump up to 500 gpm, 10,301.0 10,209.0 14:15 18:00 867 psi. 11.25 ECD dropping to 11.17. Lost PWD signal. Stage pump up to 575 gpm, 1013 psi. 11.22 ECD. Reduce rate to 500 gpm while POOH from 10301' MD to 10209' MD. Page 21/47 Report Printed: 211312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) phase Op Code Activity Code Time P -T -x Openmm (flKB) End Depth (flKB) 1/2/2019 1/312019 6.00 INTRMI CASING SMPD P Strip OOH from 10209' MD to 5831' 10,209.0 5,831.0 18:00 00:00 MD as per stripping schedule. PU=223 -160K 5O=138 -102K. Max operpull observed 25K. 1/3/2019 1/3/2019 3.75 INTRMI CASING SMPD P Strip OOH from 5831' MD to 2956' MD 5,831.0 2,956.0 00:00 03:45 as per stripping schedule. PU=117K S0=107K.. 1/3/2019 1/3/2019 1.25 INTRM1 CASING CIRC P Pump weighted/hi vis sweep (11.5 2,956.0 3,051.0 03:45 05:00 ppg/140 vis) 570-700 gpm, 920-1020 psi, 80 rpm, 41K tq, reciprocate from 3051' MD to 2956' MD. Pump total of 2 surface to surface circulations. 1/3/2019 113/2019 0.50 INTRMI CASING OWFF P Monitor well. Flow at 4.3 bph 3,051.0 3,051.0 05:00 05:30 1 diminishing to .12 bph. 1/3/2019 1/3/2019 0.50 INTRMI CASING SVRG P Service to drive. Line up MPD to strip 3,051.0 3,051.0 05:30 06:00 OOH. 1/3/2019 1/3/2019 2.50 INTRMI CASING SMPD P Strip OOH from 3051' MD to 415' MD 3,051.0 415.0 06:00 08:30 as per stripping schedule. 1/3/2019 1/3/2019 0.50 INTRMI CASING OWFF P Monitor well. Flow at 3 bph 415.0 415.0 08:30 09:00 diminishing to static. 113/2019 1/3/2019 1.00 INTRMI CASING MPDA P Pull RCD bearing and install trip 415.0 415.0 09:00 10:00 nipple. 1/3/2019 1/3/2019 3.25 INTRMI CASING BHAH P Lay down BHA as per SLB DD. 415.0 0.0 10:00 13:15 1/3/2019 1/3/2019 1.00 INTRMI CASING SHAH P Clean and clear rig floor. 0.0 0.0 13:15 14:15 1/3/2019 1/3/2019 1.00 INTRMI CASING WWWH P Make up slack washer and flush 0.0 0.0 14:15 15:15 BOPE. 1/3/2019 1/3/2019 1.50 INTRMI CASING BOPE P Change upper pipe rams to 9 5/8" 0.0 0.0 15:15 16:45 solid body rams. 1/3/2019 1/3/2019 0.75 INTRMI WHDBOP RURD P Pull wear ring and set test plug. Fill 0.0 0.0 16:45 17:30 BOPE with water and purge air. 1/3/2019 113/2019 4.50 INTRM1 WHDBOP BOPE P Perform body test. Perform bi-weekly 0.0 0.0 17:30 22:00 BOPE test. All tests at 250/3500 psi. Test with 9 5/8", 5 7/8" and 4" test joints. Test annular preventer with all 3 sizes. Test upper pipe rams with 9 5/8' test joint and lower VBR's with 4" and 5 718" test joints. Test choke valves #1 to #14, upper and lower top drive IBOP's, lest 4" and 5 7/8" dart and TIW valves, lest rig floor, mezzanine, HCR and manual kill valves, test HCR and manual choke valves, blind rams, hydraulic and manual chokes to 2000 psi and demonstrate bleed off. Perform accumulator test. Starting pressure=3000 psi, after function=1900 psi, 200 psi attained=6 sec's, full recovery=50 sec. 6 nitrogen bottles at 2008 psi. Test gas alarms, PVF and flow show. Test witnessed by AOGCC Rep Adam Earl 1/3/2019 1/3/2019 0.50 INTRMI WHDBOP RURD P Blow down lines. Rig down test 0.0 0.0 22:00 22:30 equipment 1/3/2019 1/3/2019 1.25 INTRMI CASING RURD P Rig up casing running equipment 0.0 0.0 22:30 23:45 1/3/2019 1/4/2019 0.25 INTRMI CASING SFTY P PJSM on running Casing. 0.0 0.0 23:45 00:00 Page 22147 Report Printed: 2/1 312 01 9 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log seen Depth start Time Eat Time Our (hr) Phase Op Cade Activity Cade Time P -T -X Operation (MB) End Depth (KKB) 1/4/2019 1/4/2019 6.00 INTRMI CASING PUTB P Make up shoe track. Thread lock first 0.0 2,275.0 00:00 06:00 4 connections. Pump through floats at 3 bpm, 0 psi. Pick up and RIH with 9 5/8', 47#, L-80 Hyd 563 doped casing to 2275' MD. Fill every joint and top off every 10. Torque connecctions to 15,800 ft/lbs and dope with Jet Lube Seal Guard. PU=129K S0=1 29K. 1/4/2019 1/4/2019 1.75 INTRMI CASING PUTB P Pick up and RIH with 9 5/8", 47#, L-80 2,275.0 3,074.0 06:00 07:45 Hyd 563 doped casing from 2275' MD to 3074' MD. Fill every joint and top off every 10. Torque connecctions to 15,800 ft/lbs and dope with Jet Lube Seal Guard. PU=153K SO=149K. 1/4/2019 1/4/2019 1.00 INTRMI CASING CIRC P CBU prior to exiting shoe. Reciprocate 3,074.0 3,074.0 07:45 08:45 from 3074' MD to 3032' MD. Stage pump rate up from 2 bpm, 61 psi, 5% FO to 8 bpm, 120 psi, 15% FO. PU=151K S0=148K. 1/4/2019 1/4/2019 5.25 INTRMI CASING PUTB P Pick up and RIH with 9 5/8", 47#, L-80 3,074.0 5,471.0 0845 1400 Hyd 563 doped rasing from 3074' MD to 5471' MD. Fill every joint and top off every 10. Torque connecctions to 15,800 fVibs and dope with Jet Lube Seal Guard. PU=203K S0=1 53K. 1/4/2019 1/4/2019 2.50 INTRMI CASING CIRC P CBU. Reciprocate from 5471' MD to 5,471.0 5,471.0 14:00 16:30 5431' MD. Stage pump rate up from 2 bpm, 212 psi, 3% FO to 6 bpm, 180 psi, 13% FO, Losses slowed after 200 bbls pumped to 0. Max mud wt out= 10.6 ppg. Pump total of 4904 strokes. PU=195K SO=165K. Loss of 66 bbis while circulating 1/4/2019 1/4/2019 3.00 INTRMI CASING PUTB P Pick up and RIH with 9 5/8", 47#, L-80 5,471.0 6,958.0 16:30 19:30 Hyd 563 doped casing from 5471' MD to 6958' MD. Fill every joint and top off every 10. Torque connecctions to 15,800 ftllbs and dope with Jet Lube Seal Guard. PU=238K S0=1 68K. 1/412019 1/4/2019 2.25 INTRMI CASING CIRC P CBU. Reciprocate from 6915'MD to 6,958.0 6,958.0 19:30 21:45 6958' MD. Stage pump rale up from 3 bpm, 187 psi, 6% FO to 5 bpm, 198 psi, 10% FO, Losses slowed after 300 bbls pumped to 0. Max mud wt out= 10.3+ ppg. Pump total of 4524 strokes. PU=228K S0=1 73K. Loss of 96 bbls while circulating 1/4/2019 1/5/2019 2.25 INTRMI CASING PUTB P Pick up and RIH with 9 5/8", 47#, L-80 6,958.0 8,020.0 21:45 00:00 Hyd 563 doped casing from 6958' MD to 8020' MD. Fill every joint and lop off every 10. Torque connecctions to 15,800 ft/lbs and dope with Jet Lube Seal Guard. PU=270K S0=1 70K. 1/5/2019 1/5/2019 3.50 INTRMI CASING PUTB P Pick up and RIH with 9 5/8", 47#, L-80 8,020.0 9,331.0 00:00 03:30 Hyd 563 doped casing from 8020' MD to 9331' MD. Fill every joint and top off every 10. Torque connecctions to 15,800 ft/lbs and dope with Jet Lube Seal Guard. PU=273K SO=171 K. 1/5/2019 1/5/2019 4.75 INTRMI CASING CIRC P CBU. Reciprocate from 9290' MD to 9,331.0 9,331.0 03:30 08:15 9331' MD. Stage pump rate up from 2 bpm, 369 psi, 7% FO to 3 bpm, 300 psi, 6% FO. Max mud wt out= 10.7 ppg. Pump total of 7441 strokes. PU=280K S0=1 70K. Loss of 340 bbls while circulating Page 23/47 ReportPrinted: 2113/2019 Operations Summary (with Timelog Depths) A& 2M-41 4 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start True End Time Dur (hr) Phase Op Code A Yfiy Code Time P -T -X OpereMon (MKS) End Depth (MKB) 1/5/2019 1/5/2019 3.50 INTRMI CASING PUTS P Pick up and RIH with 9 5/8", 47#, L-80 9,331.0 10,079.0 08:15 11:45 Hyd 563 doped casing from 9331 MD to 10079' MD. Pump each joint down at 1.5 bpm, 380-460 psi, 1000 fain running speed. Torque connecctions to 15,800 ftllbs and dope with Jet Lube Seal Guard. PU=305K S0=170K. 1/5/2019 1/5/2019 0.50 INTRMI CASING EQRP T Attempt to change out packer cup on 10,079.0 10,079.0 11:45 12:15 CRT. Upon disassembly it was discovered that back up cup was dressed with an incorrect internal bushing. Inspect and reinstall original packercup. 1/5/2019 1/5/2019 1.75 INTRMI CASING PUTB P Pick up and RIH with 9 5/8", 47#, L-80 10,079.0 10,541.0 12:15 14:00 Hyd 563 doped casing from 10079 MD to 10541' MD. Pump each joint down at 1.5 bpm, 380-460 psi, 1000 fph running speed. Torque connecctions to 15,800 ft/lbs and dope with Jet Lube Seal Guard. PU=320K S0=166K. 1/5/2019 1/5/2019 4.75 INTRMI CASING CIRC P CBU. Reciprocate from 10541' MD to 10,541.0 10,541.0 14:00 18:45 10501' MD. Stage pump rate up from 1.5 bpm, 349 psi, 1% FO to 5 bpm, 265 psi, 12% FO. Max mud wt out= 10.7 ppg. Initial loss rate at 70 bph. At 5496 strokes pumped loss rate slowed to 28 bph and continued to slow to 0 bph. Pump total of 10025 strokes. PU=308K S0=1 78K. Loss of 221 bbls while circulating 1/5/2019 1/5/2019 2.50 INTRMI CASING PUTB P Pick up and RIH with 9 5/8", 47#, L-80 10,541.0 11,387.0 1845 21:15 Hyd 563 doped casing from 10541' MD to 11387' MD. Fill everyjoint and top off every 10. Torque connections to 15,800 ft/Ibs and dope with Jet Lube Seal Guard. 1/5/2019 1/5/2019 1.25 INTRMI CASING CIRC P Break circulation. Reciprocate from 11,387.0 11,3820 21:15 22:30 11 345'MD to 11 387'MD. Stage pump rate up from 2 bpm, 288 psi, 3% FO to 7 bpm, 363 psi, 11 % FO. Pump total of 3012 strokes. PU=355K SO=167K. Loss of 12 bbls while circulating 1/5/2019 1/6/2019 1.50 INTRMI CASING PUTS P Pick up and RIH with 9 5/8", 47#, L-80 11,387.0 12,024.0 22:30 00:00 Hyd 563 doped casing from 11387' MD to 12024' MD. Fill every joint and top off every 10. Torque connecctions to 15,800 WIDE and dope with Jet Lube Seal Guard. 1/6/2019 1/6/2019 0.50 INTRMI CASING PUTB P Pick up and RIHwith9 5/8", 47#, L-80 12,024.0 12.234.0 00:00 00:30 Hyd 563 doped casing from 12024' MD to 12234' MD. Fill every joint and top off every 10. Torque connecctions to 15,800 ft/lbs and dope with Jet Lube Seal Guard. 1/6/2019 1/6/2019 1.75 INTRMI CASING CIRC P Break circulation. Reciprocate from 12,234.0 12,234.0 00:30 02:15 12194' MD to 12234' MD. Stage pump rale up from 2 bpm, 456 psi, 5% FO to 6 bpm, 426 psi, 11% FO. Pump total of 4578 strokes. PU=347K S0=1 74K. Loss of 63 bbls while circulating Page 24/47 Report Printed: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Cafe Activity Code Time P -T -x Operation (flKB) EM Depth (flKe) 1/6/2019 1/6/2019 1.00 INTRMI CASING PUTB P Pick up and RIH with 9 5/8", 47#, L-80 12,234.0 12,550.0 02:15 03:15 Hyd 563 doped casing from 12234' MD to 12550' MD. Fill every joint and top off every 10. Torque connecctions to 15,800 ft/lbs and dope with Jet Lube Seal Guard. 1/6/2019 1/6/2019 3.25 INTRMI CASING PUTB P Pick up and RIH with 9 5/8", 47#, L-80 12,550.0 13,090.0 03:15 06:30 Hyd 563 doped casing from 12550 MD to 13090' MD. Pump each joint down at 2 bpm, 430-530 psi, Torque conneoctions to 15,800 fVlbs and dope with Jet Lube Seal Guard. Work through tight hole at 12550' MD and 12625' MD. PU=389K 5O=170K. 1/6/2019 1/6/2019 0.50 INTRMI CASING HOSO P Make up hanger and landing joint. 13,090.0 13,131.0 06:30 07:00 Wash down from 13090' MD and land hanger at 13131.37' MD. 1/6/2019 1/6/2019 5.00 INTRMI CEMENT CIRC P Circulate and condition mud for 13,131.0 13,131.0 07:00 12:00 cementjob. Reciprocate 15'. Stage pump rate up from 2 bpm, 364 psi, 5% FO to 7 bph, 370 psi, 13% FO. Initial loss rate at 27 bph reducing to 0 after 14010 stks pumped.. 1/6/2019 1/6/2019 0.25 INTRMI CEMENT RURD P Blow down TD. Rig up cement hose. 13,131.0 13,131.0 12:00 12:15 1/6/2019 1/6/2019 1.25 INTRMI CEMENT CIRC P Circulate and condition mud for 13,131.0 13,131.0 12:15 13:30 cementjob. Reciprocate 15'. Stage pump rate up from 2 bpm, 161 psi, 5% FO to 7 bph, 435 psi, 12% FO. PU=373K SO=182K. 1/6/2019 1/6/2019 0.50 INTRMI CEMENT EQRP T Change out CRT packer cup. 13,131.0 13,131.0 13:30 14:00 1/6/2019 1/6/2019 0.25 INTRMI CEMENT CIRC P Circulate and condition mud for 13,131.0 13,131.0 14:00 14:15 cement job. Reciprocate 15'. 6 bpm, 385 psi, 12% FO. PU=388K 5C=180K. 1/6/2019 1/6/2019 4.25 INTRMI CEMENT CMNT P Pump 5.5 bbls water. Test lines to 13,131.0 13,131.0 14:15 18:30 3500 psi. Mix and pump 66.9 bbls 13 ppg Mud Push II at 5 bpm, 300 psi, 13% FO. Drop bottom plug. Mix and pump 150.2 bbls of 15.8 ppg cement at 5 bpm, 250 psi, 10-15% FO. Drop top plug. Pump 10 bbls water. Displace with dg pumps 10.2 ppg LSND mud at 6 bpm, 245 psi, Reciprocate in 15' strokes. Land hanger at 3000 slks pumped. reduce rale to 5 bpm at 8280 stks and to 3 bpm at 9235 stks, 688 psi, 6% FO. Bump plugs at 9421 stks. Pressure up to 1425 psi and hold for 5 mins. CIP at 18:25 hrs. 1/6/2019 1/6/2019 3.00 INTRMI CEMENT OWFF P Bleed off pressure. Check floats. 13,131.0 13,131.0 18:30 21:30 Good. Slight flow out of annulus at 1.5 bph diminishing to 1 bph. 1/6/2019 1/6/2019 0.50 INTRMI CEMENT RURD P Lay down landing joint. Rig down CRT. 13,131.0 0.0 21:30 22:00 Clean and clear dg floor. 1/6/2019 1/7/2019 2.00 INTRMI CEMENT WWSP P Set and energize packoff. Sim-ops/Cut 0.0 0.0 22:00 00:00 and slip drilling line. 1/7/2019 1/7/2019 2.00 INTRMI CEMENT WWSP T Continue to set packoff. Could not 0.0 0.0 00:00 02:00 energize or test "P' seals. Pull packoff to inspect. Sim-ops/Mobilize DEEP sub equipment to rig floor. Page 26147 ReportPrinted: 211312019 operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stag Depth startnate End Time Dur(m) Phase Op Code Activity CWe Time P -T -X Operation (ftKB) End Depth(KKB) 1/7/2019 1/7/2019 4.00 INTRMI CEMENT WWSP T "P" seals damaged. Change out seals. 0.0 0.0 02:00 06:00 Confirm that packoff was at correct depth. Reset packoff as per Cameron rep. 1/7/2019 1/712019 3.00 INTRMI CEMENT WWSP T Attempt to energize and test packoff. 0.0 0.0 06:00 09:00 Unable to test. Pull packoff and inspect. "P" seals damaged. Sim- ops/Prep for ram change and DEEP sub install. 1/7/2019 1/7/2019 4.00 INTRMI CEMENT WWSP T Clean packoff and dress with dummy 0.0 0.0 09:00 13:00 seals. Paint interior of packoff and RIH and land out. Confirm packoff landed. Pull packoff and inspect. Observe that ODS of inside of packoff show scuff marks. Redress with new seals. Sim- ops/Mobilixe BHA to rig floor. 1/712019 117/2019 3.25 INTRMI CEMENT WWSP T Attempt to energize and test packoff. 0.0 0.0 13:00 16:15 Unable to test. Pull packoff and inspect. "P" seals damaged. Sim- ops/Work on MP 2's 1/712019 11712019 3.50 INTRMI CEMENT NUND T Monitor well and confirm static. Nipple 0.0 0.0 16:15 19:45 down BOPE and spacer spool. Set back on mezzanine. Nipple down tubing spool. 1/7/2019 1/812019 4.25 INTRMI CEMENT WAIT T Inspect hanger neck. Hanger neck 0.0 0.0 19:45 00:00 deformed and damaged on ODS. Consult with Drilling engineer and superintendent. Mobilize fishing hand and spear from Deadhorse. Prep emergency slip equipment and WACHS cutter. Sim-ops/Clean rig floor drain lines, work on MP 2's, inspect Poor equipment and TD. 1/612019 1/8/2019 0.50 INTRMI CEMENT BHAH T Mobilize Baker spear to rig floor. 0.0 0.0 00:00 00:30 1/8/2019 1/8/2019 1.501NTRM1 CEMENT BHAH T Make up spear with 8.681 grapple.RIH 0.0 0.0 00:30 02:00 and engage 9 5/8" rasing. Verify with 20K overpull. 118/2019 1/8/2019 1.00 INTRMI CEMENT CUTP T Pick up and pull to 350K to gain 0.0 0.0 02:00 03:00 clearance to set emergency slips. Pull total of 2'. Set emergency slips. 1/8/2019 1/8/2019 0.50 INTRMI CEMENT BHAH T Release and lay down spear aF per 0.0 0.0 03:00 03:30 1 1 Baker rep. 1/8/2019 1/8/2019 1.00 INTRMI CEMENT CUTP T Set up WACHS cutter. Cut 9 5/8" pup 0.0 0.0 03:30 04:30 joint 4" below hanger. 1/8/2019 1/8/2019 5.00 INTRMI CEMENT WWSP T Set packoff as per Cameron rep. 0.0 0.0 04:30 09:30 Visually inspect. Pull packoff and change wire mesh rings on "P" seals. Reset packoff and confirm good 1/8/2019 1/8/2019 1.25 INTRMI CEMENT NUND T Nipple up tubing spool. 0.0 0.0 09:30 10:45 1/8/2019 1/8/2019 1.25 INTRMI CEMENT WWSP T RILDS. Energize packoff with plastic O.0 0.0 10:45 12:00 packing. Test packoff to 3800 psi/10 mins. Witnessed by CPAI company man. 1/8/2019 1/8/2019 3.50 INTRMI CEMENT NUND T Nipple up BOPE. 0.0 0.0 12:00 15:30 i Page 26/47 Report Printed: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sun Depth Stan Time End Time Dur lhr) Phase Op Code Activity Cotle Tome P-T-X Operation (ttKB) Ed DepN(RKB) 1/8/2019 1/8/2019 6.75 INTRMI CEMENT FRZP P Rig up LRS to pump down OA. Test 0.0 0.0 15:30 22:15 lines to 3000 psi.Pump 10 bola diesel to establish injection rate and pressure. 1 bpm=400 psi. Pump 194 bbls of 70° heated water at 2 bpm. Initial pressure=400 psi. Final pressure=500 psi. Pump 190 bbls of 80" heated diesel at 2 bpm. Initial pressure=500 psi. Final pressure=420 psi. Sim-ops/Change upper pipe rams to 4 1/2" x 7" VBR's and install DEEP sub. 1/8/2019 1/8/2019 1.00 INTRMI CEMENT RURD P Complete DEEP sub installation on 0.0 0.0 22:15 23:15 TD. 1/8/2019 1/9/2019 0.75 INTRMI CEMENT RURD P Change out saver sub on TD. 0.0 0.0 23:15 00:00 1/9/2019 1/9/2019 4.00 INTRMI CEMENT BOPE P Test upper 4 1/2" x 7" VBR's and 0.0 0.0 00:00 04:00 annular preventer with 5 7/8" and 7" test joints to 250/3500 psi for 5 mins eaach. 1/9/2019 1/9/2019 2.00 INTRMI CEMENT RURD P Clean and Gear rig floor. Install mouse 0.0 0.0 04:00 06:00 1 1hole. Set 12 7/16" ID wear ring. 1/9/2019 1/9/2019 0.50 INTRMI CEMENT SVRG P Inspect and service lop drive. 0.0 0.0 06:00 06:30 1/9/2019 1/9/2019 3.50 INTRMI CEMENT BHAH P PJSM-Make up Intermediate 2 BHA as 0.0 338.0 06:30 10:00 per SLB DD. Confirm non-ported floats installed. 1/9/2019 1/9/2019 2.25 INTRMI CEMENT PULD P Pick up 39 joints 5 7/8" drill pipe. RIH 338.0 1,562.0 10:00 12:15 with 2 stands 1/9/2019 1/9/2019 0.25 INTRMI CEMENT TRIP P RIH with 2 stand of DP from derrick 1,562.0 1,749.0 12:15 1230 from 1562' MD to 1749' MD. 1/9/2019 1/9/2019 1.00 INTRMI CEMENT DHEO P Fill pipe. Shallow hole test MWD. 200 1,749.0 1,749.0 12:30 13:30 gpm=177 psi, 250 gpm=254 psi, 13% FO. Remain out of reamer activation range of 313-513 gpm. Bring pump up to 533 gpm, 1120 psi, 24% FO, turbine RPM=6200. Good pulse test. Blow down TD. 1/9/2019 1/9/2019 4.50 INTRMI CEMENT TRIP P RIH from 1749' MD to 8094' MD. Fill 1,749.0 8,094.0 13:30 18:00 pipe every 25 stds. PU=205K 50=110K. 1/9/2019 1/9/2019 5.00 INTRMI CEMENT TRIP P RIH from 8094' MD to 12944' MD. Fill 8,094.0 12,944.0 18:00 23:00 pipe ebery 25 stds. PU=270K SO=130K. 1/9/2019 1/10/2019 1.00 INTRMI CEMENT CIRC P Circulate and condition mud for casing 12,944.0 12,944.0 23:00 00:00 test. Bottoms up weight=10.2 ppg. 430 gpm, 1352 psi, F0=17%. PU=274 SO=145. Total of 5857 strokes pumped. 1/10/2019 1/10/2019 2.00 INTRMI CEMENT PRTS P Rig up and test 9 5/8" casing to 3500 12,944.0 12,944.0 00:00 02:00 psi for 30 mins. Rig down test equipment and blow down lines. 1/10/2019 1/10/2019 1.00 INTRMI CEMENT DHEO P RIH and tag float collar at 13042.92' 12,944.0 13,043.0 02:00 03:00 MD. Establish parameters. Cycle pumps and confirm Rhino Reamer closed. 470 gpm, 1543 psi. 22% FO, 40 rpm, 28-30K tq. 1/10/2019 1/10/2019 1.75 INTRMI CEMENT DRLG P Drill float collar from 13043' MD to 13,043.0 13,046.0 03:00 04:45 13046' MD. 470 gpm, 1560 psi,22% FO, 40 rpm, 25-26K tq, 18-25K WOB. Page 27/47 Report Printed: 2I13I2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Deem Stan Time I EM Time our (hr) Phase Op Doae A Vdy Code Time P -T -X Operation (aKB) End Depth (ftKB) 1/10/2019 1/10/2019 2.00 INTRMI CEMENT DRLG P Drill cement from 13046' MD to 13128' 13,046.0 13,140.0 04:45 06:45 MD. 470 gpm, 1535 psi,50 rpm, 34K tq, 20% FO, IOK WOB. Drill float shoe from 13128' MD to 13131' MD. 470 gpm, 1611 psi, 80 rpm, 35K tq, 20% FO, 51K WOB. Clean out rathole from 13131' MD to 13140' MD. 1/10/2019 1/10/2019 1.50 INTRMI CEMENT DDRL P Drilling new hole from 13140' MD to 13,140.0 13,160.0 06:45 08:15 13160' MD, 5780' TVD. 304 gpm, 823 psi, 13% FO, 8K WOB, 30 rpm 33K tq, 11.94 ECD. ADT=.56 Bit hrs=.56 Jar hrs=117.64 1/10/2019 1/10/2019 1.50 INTRMI CEMENT CIRC P Circulate and condition mud for LOT. 13,160.0 13,128.0 08:15 09:45 503 gpm, 1660 psi, 20% FO, 60 rpm, 34K tq, PU=290K SO=136K Rot=181 K. POOH to 13128' MD. SPR'S @ 13141 'MD 5776'TVD MW= 10.2 PPG MP #1) 30 SPM 360 -PSI 40 SPM 440 - PSI MP #2) 30 SPM 360 -PSI 40 SPM 440 - PSI 1/10/2019 1/10/2019 1.00 INTRMI CEMENT LOT P Blow down top drive. Rig up and 13,128.0 13,128.0 09:45 10:45 perform LOT to 15 ppg EMW with 1440 psi. Bled back 3.2 We 1/10/2019 1/10/2019 3.50 INTRM2 DRILL DISP P Displace well to new 10.5 ppg LSND 13,128.0 13,127.0 10:45 14:15 mud. 412 gpm, 1315 psi, 15% FO, Wash down to 13160' MD while spacer and mud exits bit and them pull up into casing to 13127' MD. PU=290K 5O=136K Rot=180K. Rotate at 30 rpm, 35K tq. SPR'S @ 13127'MD 5772'TVD MW= 10.5 PPG MP #1) 30 SPM 400 -PSI 40 SPM 500 - PSI MP #2) 30 SPM 400 -PSI 40 SPM 500 - PSI 1/10/2019 1/10/2019 0.25 INTRM2 DRILL OWFF P Lay down one joint DP. Blow down 13,127.0 13,096.0 14:15 14:30 TD.Monftor well. Static. 1/10/2019 1/10/2019 1.75 INTRM2 DRILL MPDA P Remove trip nipple. Install RCD 13,096.0 13,160.0 14:30 16:15 bearing. Install drip nipple. Establish circulation and break in bearing. 30 rpm, 25K tq for 3 mins and then 50 rpm tq with 466 gpm, 1667 psi, 24% FO. Wash down from 13142' Md to 13160' MD. SPR'S @ 13142'MD 5775'TVD MW= 10.5 PPG MP #1) 30 SPM 460 -PSI 40 SPM 540 - PSI MP #2) 30 SPM 440 -PSI 40 SPM 540 - PSI Page 28/47 Report Printed: 2113/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Starinme PSE Time Dur(hn Phase Op Code Activity CWe Time P-T-X Operation (EK8) End Depth(flKa) 1/10/2019 1/10/2019 3.00 INTRM2 DRILL DDRL P Drill 81/2" hole from 13160' MD to 13,160.0 13,287.0 16:15 19:15 13287' MD, 5812' TVD @ 547 gpm, 1899 psi, 33% FO, 100 rpm, 28K TO, 15K WOB, ECUS = 13.24, Off Btm = 1878 psi, PIU =230K, S/O =123K, ROT =170K, 24K TQ,Max gas=55 units ADT=1.28, BIT HRS=1.84, JAR HRS=118.92. 1/10/2019 1/10/2019 0.50 INTRM2 DRILL OTHR P Pick up to 13262' bit depth, 13137' 13,287.0 13,287.0 19:15 19:45 reamer blades depth.. Cycle pumps and open Rhino Reamer. Pump at 557 gpm, 2132 psi, 2851 TRPM. Slow rate to 255 gpm, 884 psi, Hold for 3 mins. Increase rate to 557 gpm, 1826 psi, 2304 TRPM. Confirm reamer open by setting down on ledge at 13145'( bit depth=13271') with 10K. 1/10/2019 1/11/2019 4.25 INTRM2 DRILL DDRL P Drill 81/2"x97/8" hole from 13287' 13,287.0 13,503.0 19:45 00:00 MD to 13503' MD, 5880' TVD @ 545 gpm, 1988 psi, 27% FO, 140 rpm, 31 K TO, 19K WOB, ECUS = 13.38, Off Btm = 1922 psi, P/U =230K, S/O =123K, ROT =169K, 28K TQ,Max gas=139 units ADT=3.41, BIT HRS=5.85, JAR HRS=122.93. 1/11/2019 1/11/2019 6.75 INTRM2 DRILL DDRL P Drill 8 1/2" x 9 7/8" hole from 13503' 13,503.0 13,837.0 00:00 06:45 MD to 13837' MD, 5967' TVD @ 545 gpm, 2004 psi, 28% FO, 140 rpm, 29K TQ, 20K WOB, ECUS = 13.40, Off Btm = 1959 psi, P/U =235K, S/O =120K, ROT =169K, 28K TQ,Max gas=148 units ADT=5.22, BIT HRS=11.07, JAR HRS=128.15. SPR'S @ 13807'MD 5956'TVD MW= 10.5 PPG MP #1) 30 SPM 555-PSI 40 SPM 640- PSI MP #2) 30 SPM 555-PSI 40 SPM 640- PSI 1/11/2019 1/11/2019 0.75 INTRM2 DRILL CIRC P CBU. Rotate and reciprocate from 13,837.0 13,837.0 06:45 07:30 13837' MD to 13803' MD. 546 gpm, 80 rpm, 19K tq, 29% FO, ECD=12.73. Total strokes pumped=6560 1/11/2019 1/11/2019 1.00 INTRM2 DRILL DDRL P Drill 81/2"x97/8" hole from 13837' 13,837.0 13,897.0 07:30 08:30 MD to 13897' MD, 5979' TVD @ 545 gpm, 2004 psi, 28% FO, 140 rpm, 28K TO, 20K WOB, ECD'S = 13.22, Off Btm = 1942 psi, P/U =238K, S/O =120K, ROT =171 K, 28K TQ,Max gas=50 units ADT=.82, BIT HRS=11.89, JAR HRS=128.97. 1/11/2019 1/11/2019 2.00 INTRM2 DRILL BKRM P BROOH from 13897' MD to 13711' 13,897.0 13,711.0 08:30 1030 MD. 454 gpm, 1854 psi, 80 rpm, 23K tq, PU=238K SO=120K Rot=171 K. Page 29147 Report Printed: 211312019 Operations Summary (with Timelog Depths) A1771 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (ho Phase Op Code Activity Code Time P -T-% Operation (fi End Depth (ftKB) 1/11/2019 1/11/2019 0.50 INTRM2 DRILL REAM P Wash and ream from 13711' MD to 13,711.0 13.897.0 10:30 11:00 13897' MD. 545 gpm, 1990 psi, 80 rpm, 23K tq. PU=238K SO=120K Rot=171 K. 1/11/2019 1/11/2019 1.00 INTRM2 DRILL DDRL P Drill 81/2"x97/8" hole from 13897' 13,897.0 13,981.0 11:00 12:00 MD to 13981' MD, 6005' TVD @ 545 gpm, 2010 psi, 29% FO, 140 rpm, 31 K TO, 18K WOB, ECUS = 13.34, Off Btm = 1942 psi, P/U =238K, S/O =120K, ROT =171K, 28K TQ,Max gas=99 units ADT=1.07, BIT HRS=12.96, JAR HRS=130.04, 1/11/2019 1111/2019 6.00 INTRM2 DRILL DDRL P Drill 81/2"x97/8" hole from 13981' 13,981.0 14,256.0 1200 18:00 MD to 14256' MD, 6030' TVD @ 545 gpm, 1965 psi, 29% FO, 140 rpm, 30K TO, 18K WOB, ECUS = 13.18, Off Btm = 1945 psi, P/U =244K, S/O =115K, ROT =171 K, 31K TQ,Max gas=27 units ADT=5.00, BIT HRS=17.96, JAR HRS=135.04. 1/11/2019 1/11/2019 4.00 INTRM2 DRILL DDRL P Drill 8 1/2"x97/8" hole from 14256' 14,256.0 14,449.0 18:00 22:00 MD to 14449' MD, 6045' TVD @ 545 gpm, 1975 psi, 29% FO, 120 rpm, 36K TO, 18K WOB, ECUS = 13.21, Off Btm = 1945 psi, P/U =247K, S/O =120K, ROT =170K, 31K TQ,Max gas=242 units ADT=3.6, BIT HRS=21.56, JAR HRS=138.64, 1/11/2019 1/12/2019 2.00 INTRM2 CASING CIRC P CBU x2. Rotate and reciprocate from 14,449.0 14,449.0 22:00 00:00 14449' MD to 14371' MD. 548 gpm, 80 rpm, 24K tq,30% FO, ECD=12.93. Total strokes pumped=12900. 1/12/2019 1/12/2019 1.00 INTRM2 CASING CIRC P Obtain final survey, SPR's and T&D. 14,449.0 14,449.0 00:00 01:00 Blow down top drive. SPR'S @ 14449'MD 6045'TVD MW= 10.5 PPG MP #1) 30 SPM 630 -PSI 40 SPM 630 - PSI MP #2) 30 SPM 550 -PSI 40 SPM 640 - PSI 1/12/2019 1/12/2019 0.50 INTRM2 CASING OWFF P Perform draw down test as per 14,449.0 14,449.0 01:00 01:30 procedure. Starting pressure=490 psi. Bleed for 20 sec's. Shut in for 5 mins and build to 173 psi. Bleed for 20 sec's. Shut in for 5 mins and build to 75 psi. Bleed for 20 sec's. Shut in for 5 mins and build to 45 psi. Bleed for 20 sec's/. Shut in for 5 mins and build to 26 psi. Bleed for 20 sec's. Shut in for 5 mins and build to 20 psi. Bleed for 20 sec's. Shut in for 5 mins and build to 17 psi. Bled back total of 1.02 bbls. Results indicate a pore pressure of 10.6 ppg EMW. 1/12/2019 1/12/2019 1.00 INTRM2 CASING CIRC P CBU. Rotate and reciprcate from 14,449.0 14,449.0 01:30 02:30 14449' MD to 14371' MD. 548 gpm, 1990 psi, 80 rpm, 24K tq, 30% FO. ECD=12.93 Max gas=109 units. Pump total of 6997 stks. Page 30/47 Report Printed: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sunt Depth Slant Time End Time Dur (hr) Phase op Code Activity Code Time P-T-X Operation (fKB) End Depth(flKB) 1/12/2019 1/12/2019 2.75 INTRM2 CASING CIRC P Circulate and weight up to 10.9 ppg 14,449.0 14,371.0 02:30 05:15 using 16 ppg spike fluid. Initial rate 548 gpm, 1990 psi, 30% FO, 80 rpm, 24K tq. Rotate and reciprocate from 14449' MD to 14371' MD. 1112/2019 1/12/2019 0.75 INTRM2 CASING CIRC P Obtain T&D and SPR's with new mud 14,371.0 14,371.0 05:15 06:00 weight. Close Rihino Reamer.548 gpm, 1990 psi, 2304 TRPM with reamer open. 548 gpm, 2265 psi, 2890 TRPM with reamer closed. SPR'S @ 14449'MD 6045'TVD MW= 10.9 PPG MP #1) 30 SPM 510-PSI 40 SPM 627- PSI MP #2) 30 SPM 520-PSI 40 SPM 627- PSI 1/12/2019 1/12/2019 2.00 INTRM2 CASING OWFF P Monitor well. Slight flow diminishing to 14,371.0 14,371.0 06:00 08:00 static. 1/12/2019 1/12/2019 4.00 INTRM2 CASING SMPD P Strip OOH with MPD from 14371' MD 14,371.0 13,309.0 08:00 12:00 to 13309' MD as per stripping schedule. PU=310K 5O=135K. 1/12/2019 1112/2019 1.00 INTRM2 CASING SMPD P Strip OOH with MPD from 13309' MD 13,309.0 13,044.0 12:00 13:00 to 13044' MD as per stripping schedule. PU=298K 5O=135K. 1/12/2019 1/12/2019 1.00 INTRM2 CASING CIRC P CBU. 450 gpm, 1760 psi, 60 rpm, 17K 13,044.0 13,044.0 13:00 14:00 1 1 1tq. PU=298K 5O=135K 1/12/2019 1/1212019 0.50 INTRM2 CASING OWFF P Monitor well. Static. Drop 3" OD rabbit. 13,044.0 13,044.0 14:00 14:30 111212019 1/1212019 5.25 INTRM2 CASING SMPD P Strip OOH with MPD from 13044' MD 13,044.0 8,859.0 14:30 19:45 to 8859' MD as per stripping schedule. PU=212K SO=127K. 1112/2019 1/12/2019 0.50 INTRM2 CASING OWFF P Flow check well. Close chokes and 8,859.0 8,859.0 19:45 20:15 observe 7 psi build in 10 mins. Bleed off pressure and open valve on RCD. Observe slight flow at 1.6 bph diminishing to .4 bph in 15 mins. 1/12/2019 1/13/2019 3.75 INTRM2 CASING SMPD P Strip OOH with MPD from 8859' MD to 8,859.0 4,951.0 20:15 00:00 4951' MD as per stripping schedule. PU=150K 5O=120K. 1/1312019 1/13/2019 3.00 INTRM2 CASING SMPD P Strip OOH with MPD from 4951' MD to 4,951.0 1,374.0 00:00 03:00 1374' MD as per stripping schedule. PU=95K SO=81K. 1/13/2019 1/13/2019 0.75 INTRM2 CASING OWFF P Monitor well. Slight flow at 1.25 bph 1,374.0 1,374.0 03:00 03:45 diminishing to static. 1/13/2019 1/13/2019 1.00 INTRM2 CASING MPDA P Remove RCD bearing. Set trip nipple. 1,374.0 1,374.0 03:45 04:45 1/13/2019 1/13/2019 2.25 INTRM2 CASING PULD P POOH laying down 33 jls 5 7/8" 1,374.0 338.0 04:45 07:00 DP.from 1374' MD to 338' MD. 1/13/2019 1/13/2019 0.25 INTRM2 CASING OWFF P Monitor well. Static. 338.0 338.0 07:00 07:15 1/13/2019 1/13/2019 4.00 INTRM2 CASING SHAH P Lay down BHA as per SLB DD. 338.0 0.0 07:15 11:15 Calc disp=163.6 Act disp=177.2 for trip. 1/13/2019 1/13/2019 0.75 INTRM2 CASING BHAH P Clean and clear dg floor. 0.0 0.0 11:15 12:00 1/13/2019 1/13/2019 2.00 INTRM2 CASING RURD P Make up X-O and pup joint on Baker 0.0 0.0 12:00 14:00 Dual Plug Dropping Head. Rig up GBR casing running equipment. 1/13/2019 1/13/2019 0.50 INTRM2 CASING SFTY P PJSrM on picking up and running 7" 0.0 0.0 14:00 14:30 1 I line Page 31147 ReportPrinted: 211312019 e Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth sled Time End Time our inn Phase or, Code Activay Code Time P -T -X operation (itKB) End Depth (10(B) 1/13/2019 1/13/2019 5.25 INTRM2 CASING PUTB P Make up shoe track. Thread lock first 0.0 1,405.0 14:30 19:45 5 connections. Pump 62 bbls through Floats at 3.8 bpm, 111 psi, Pick up and RIH with 7", 26#, L-80 Hyd 563 doped casing to 1405' MD. Fill every joint and top off every 10. Torque connections to 9,400 it/lbs and dope with Jet Lube Seal Guard. PU=78K SO=86K. 1/13/2019 1/13/2019 0.75 INTRM2 CASING RURD P Lay down CRT. Pick up power tongs. 1,405.0 1,405.0 19:45 20:30 Make up liner hanger as per Baker rep. 1/13/2019 1/13/2019 1.00 INTRM2 CASING CIRC P Circulate one liner volume. Stage 1,405.0 1,405.0 20:30 21:30 pump up from 3 bpm, 148 psi, 6% FO, 4 bpm, 180 psi, 8% FO, 5 bpm, 216 psi, 9% FO, 6 bpm, 251 psi, 10% FO, 7 bpm, 290 psi, 11% FO, 89 bpm, 334 psi, 13% FO. Rotate at 20 rpm. PU=78K SO=86K Rot=81K 1/13/2019 1/14/2019 2.50 INTRM2 CASING RUNL P RIH with liner on DP from 1405' MD to 1,405.0 3,848.0 21:30 00:00 3848' MD following surge schedule. Fill on each stand and top off every 10 stands. 1/14/2019 1/14/2019 6.00 INTRM2 CASING RUNL P RIH with liner on DP from 3848' MD to 3,848.0 10,157.0 00:00 06:00 10157' MD following surge schedule. Fill on each stand and top off every 10 stands. 1/14/2019 1/14/2019 4.75 INTRM2 CASING RUNL P RIH with liner on DP from 10157' MD 10,157.0 13,078.0 06:00 10:45 to 13078' MD following surge schedule. Fill on each stand and top off every 10 stands. 1/14/2019 1/14/2019 1.25 INTRM2 CASING CIRC P CBU. 336 gpm, 930 psi, 13% FO.20 13,078.0 13,078.0 10:45 12:00 rpm, 14.5K tq. PU=257K SO=113K. Pump total of 5100 stks. SPR'S @ 13086'MO, MW= 10.9+ PPG MP #1) 30 SPM 480 -PSI 40 SPM 560 - PSI MP #2) 30 SPM 500 -PSI 40 SPM 540 - PSI 1/14/2019 1/14/2019 3.00 INTRM2 CASING RUNL P RIH with liner on DP from 13078' MD 13,078.0 14,398.0 12:00 15:00 to 14398' MD following surge schedule. Fill on each stand and top off every 10 stands. PU=257K SO=113K 1/14/2019 1/14/2019 0.50 INTRM2 CASING WASH P Wash down from 14398' MD to 14449' 14,398.0 14,449.0 15:00 15:30 MD. 2 bpm, 515 psi, 6% FO. PU=313K SO=116K 1/14/2019 1/14/2019 0.50 INTRM2 CASING HOSO P POOH from 14449' MD to 14398' MD. 14,449.0 14,398.0 15:30 16:00 2 bpm, 500 psi, 4% FO. Lay down top single of stand #138. Blow down TD and isolate standpipe. 1/14/2019 1/14/2019 0.75 INTRM2 CEMENT RURD P Pick up Baker dual plug dropping 14,398.0 14,449.0 16:00 16:45 head and dg up cement hose 1/14/2019 1/14/2019 0.50 INTRM2 CEMENT WASH P Wash down from 14398' MD to 14449' 14,449.0 14,449.0 16:45 17:15 MD. 2 bpm, 515 psi, 6% FO. PU=313K SO=116K Page 32147 Report Printed: 211 312 01 9 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time EM Time our (hr) Phase Op Code Adivity Code Time P -T -X Operation (fiKB) EM Depth (flKB) 1/14/2019 1/14/2019 3.25 INTRM2 CEMENT CIRC P Circulate and condition for cement job. 14,449.0 14,446.0 17:15 20:30 Reciprocate from 14446' MD to 14428' MD. Stage up rate from 2 bpm, 513 psi, 3% FO to 7 bpm, 870 psi, 12% FO. 9814 total strokes pumped. 1/14/2019 1/14/2019 3.00 INTRM2 CEMENT CMNT P Pump 7.9 bbls water. Test lines to 14,446.0 13,004.0 20:30 23:30 4000 psi. Mix and pump 46 bbls 13 ppg Mud Push II at 5 bpm, 600 psi, 13% FO. Drop bottom dart. Mix and pump 86.5 bbls of 15.8 ppg cement at 4.7 bpm, 300 psi, 9% FO. Drop top dart. Pump 10 bbls water. Displace with rig pumps 10.9 ppg LSND mud at 7 bpm, 600 psi, Reciprocate in 12' strokes.Boltom dart latched bottom liner wiper plug at 2790 strokes pumped and sheared at 1950 psi. Top dart latched lop liner wiper plug at 2919 strokes pumped and sheared at 2770 psi. Cease reciprocating and set liner on depth at 2483 strokes pumped. Reduce rate to 3 bpm at 3346 stks 793 psi, 6% FO. Bump plugs at 3425 stks. Pressure up to 2546 psi and hold for 5 mins to set liner hanger. Bleed off and check floats. CIP at 22:40 hrs. Set 50K down on liner hanger to confinn set. Increase pressure to 4000 psi to release running tool. Could not confrm release. Pressure up to 4200 psi and release running tool. Pick up and clear rotating dogs. Set down with 50K. Pick up and set down 2 more rotating 15 rpm. TOL at 12957.11' MD and liner shoe at 14447' MD. 1/14/2019 1/15/2019 0.50 INTRM2 CEMENT CIRC P Pick up running tool to 12962' MD. 13,004.0 12,962.0 23:30 00:00 Circulate down DP 50 bbls, 316 gpm, 909,13% FO. Pick up to 12956' MD. Reverse circulate out residual cement. 420 gpm, 1904 psi. 1/15/2019 1/15/2019 0.50 INTRM2 CEMENT CIRC P Cont. Rev. circ. out residual cement. 12,962.0 12,952.0 00:00 00:30 @ 420 gpm 1904 psi. 60% F/O 4375 total strks pumped (3bbl. of cement recovered) 1/15/2019 1/15/2019 1.50 INTRM2 CEMENT TRIP P POOH F/12,952' -T/ 12,765', Monitor 12,952.0 12,765.0 00:30 02:00 1 1 1 returns (pit #5) 1/15/2019 1/15/2019 0.75 INTRM2 CEMENT PRTS P Rig up and test csg packer tip 1000 12,765.0 12,765.0 02:00 02:45 psi. holds for 10 (charted) 1/15/2019 1/15/2019 1.75 INTRM2 CEMENT TRIP P POOH F/12,765' -T/11,069', monitor 12,765.0 11,069.0 02:45 04:30 returns (pit #5) 1/15/2019 1/15/2019 5.50 INTRM2 CEMENT CIRC T Phase3. Circ. @ 3bpm 352 psi. 6% 11,069.0 11,069.0 04:30 10:00 F/O @ 11,069' (SIMOPS: NPRA safety training meeting) 1/15/2019 1/15/2019 2.50 INTRM2 CEMENT CIRC T Phase3. Circ. @ 3bpm 400 psi. 6% 11,069.0 11,069.0 10:00 12:30 F/0 @ 11,069 1/15/2019 1/15/2019 9.75 INTRM2 CEMENT CIRC T Phase3. Circ. @ 3bpm 400 psi. 6% 11,069.0 11,069.0 12:30 22:15 Flo @ 11,069 (SIMOPS: Parts Inventory list) 1/15/2019 1/16/2019 1.75 INTRM2 CEMENT TRIP P Weather conditions down graded to 11,069.0 8,974.6- 22:15 00:00 Phase 2. Slop circ. , blow down top drive, POOH F/11,069'- T/8,974'. 1/16/2019 1/16/2019 5.50 INTRM2 CEMENT TRIP P Conmtinue POOH with Baker running 8,974.0 472.0 00:00 05:30 tool, F/8,974'- T/472' Page 33147 Report Printed: 2113/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depen Start Time End Time Dur (m Phew Op Carle Activity Code Time P -T -X Operation (WB) End Depen (WB) 1/16/2019 1/16/2019 0.50 INTRM2 CEMENT PULD P UD 5 stands of 5 718 drill pipe 472.0 0.0 05:30 06:00 1/16/2019 1/16/2019 0.50 INTRM2 CEMENT BHAH P Inspect Baker running tool. Dog sub 0.0 0.0 06:00 06:30 indicated that the packer was properly set. UD running tool 1/16/2019 1/16/2019 1.00 INTRM2 CEMENT RURD P Pick up baker cement head, remove 0.0 0.0 06:30 07:30 all xo subs. UD 1/1612019 1/16/2019 1.50 INTRM2 CEMENT WWWH P Pull wear 12.5" bushing. Make up 0.0 0.0 07:30 09:00 NC50 BOPE stack washer, wash bop stack, recip. from 35'to 19', 12bpm=60psi, UD 3-jts 5-7/8dp, B/D top drive, drain bop stack. 1/16/2019 1/1612019 1.50 INTRM2 CEMENT BOPE P Close blinds, remove 4.5 x 7 upper 0.0 0.0 09:00 10:30 pipe rams, install 3.54 vbr's, (SIMOPS: rig up testing equip) 1/16/2019 1/16/2019 5.00 INTRM2 WHDBOP BOPE P Perform bi-weekly BOPE test. All tests 0.0 0.0 10:30 15:30 at 250/3500 psi. Test with 5 718" and 3 1/2" test joints. Test annular preventer with all both sizes. Test upper & lower pipe rams with 3 W'& 5 7/8"' test joint. Test choke valves #1 to #14, upper and lower top drive IBOP's, test 4" and 5 7/8" dart and TUN valves, test rig floor, mezzanine, HCR and manual kill valves, test HCR and manual choke valves, blind rams 25013500. hydraulic and manual chokes to 1500 psi and demonstrate bleed oft. Perform accumulator test. Starting pressure=3000 psi, after function=1850 psi, 200 psi attained=7 sec's, full recovery=62 sec. 6 nitrogen bottles at 2408 psi. Test gas alarms, PVT and flow show. Test witnessed by AOGCC Rep Matt Herrera (SIMOPS: preform derrick inspection) 1/1612019 1/16/2019 0.50 INTRM2 WHDBOP RURD P Rig down/Blow down all testing 0.0 0.0 15:30 16:00 equipment. 1/16/2019 1/16/2019 1.00 INTRM2 WHDBOP RURD P Drain BOPE, install wear bushing @ 0.0 0.0 16:00 17:00 35.19, run M2 lockdowns, wear bushing= 12.50"I.D., 13.50"O.D., 14.00"L 1/16/2019 1/16/2019 1.00 INTRM2 CEMENT RURD P Clean and clear rig floor, B/D Choke & 0.0 0.0 17:00 18:00 Kill line & Top drive, pick up 4" handling equipment 1/16/2019 1/16/2019 4.00 INTRM2 CEMENT BHAH P PJSM-Make up Production BHA as 0.0 319.0 18:00 22:00 1 per SLB DD. 1/16/2019 1/17/2019 2.00 INTRM2 CEMENT PULD P RIH with 4" XT39 DP out of the pipe 319.0 506.0 22:00 00:00 shed from 319' to 506' 1/17/2019 1/17/2019 2.00 INTRM2 CEMENT PULD P RIH 506' U 2216', P/U 4" XT 39 DP 506.0 2,216.0 00:00 02:00 from shed. monitor returns via pit #1. lop fill pipe via floor fill line. top off every 5 stds. Page 34147 Report Printed: 211312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur h ( r) Phan O code P Activity rode 'dt'1 Time P -T- X Operation Start Depth vt(ftKB)De End Depth (ftl(9) 1/17/2019 1/17/2019 2.00 INTRM2 CEMENT DHEQ T Attempted to perform a shallow hole 2,216.0 2,216.0 02:00 04:00 test with SIB. DD. but could not get a strong signal. Rig crew rigged up on the drill pipe in the hole with a head pin, witched bypassed the SLB. sensor on the stand pipe. Rig crew rigged down the head pin & rigged up on the Top Drive. Lined up to pump but couldn't get the pumps to prime. After troubleshooting the problem, it seems like aired up mud could have been the problem. Shallow Hole Test as with SLB. rep. @ 2216", 230 gpm, 1212 psi, 11% F/O, P/U-81 k, S/0-81 k. 1/17/2019 1/17/2019 2.00 INTRM2 CEMENT PULD P RIH F/2216'- T/ 3639' with 4"XT39 2,216.0 3,639.0 04:00 06:00 DP from shed. monitor returns via pit #1. top fill pipe via floor fill line. top off every 5 stds. PIU -94k, S/O-86k. 1/17/2019 1/17/2019 4.00 INTRM2 CEMENT PULD P RIH F/3639'- T/ 6963' with 4" XT39 3,639.0 6,963.0 06:00 10:00 DP from shed. monitor returns via pit #1, top fill pipe via floor fill line. top off every 5 stds. PUW=-136k, DOW= 86k. (210 total its of 4" picked up) 1/17/2019 1/17/2019 0.50 INTRM2 CEMENT TRIP P Make up 1 stand 5"dp, RIH, F/ 6963'— 6,963.0 7,064.0 10:00 10:30 T/7064' POW= 137k, SOW= 86k. 1/1712019 1/17/2019 4.50 INTRM2 CEMENT TRIP P RIH W/ 5-7/8 drillpipe from the derrick, 7,064.0 12,957.0 10:30 15:00 F/ 7064' — T/12957', monitor returns via pit #1, PUW= 281 k, SOW= 112k, fill pipe @ 9340', 10735', 12901', No WOB increase going through the 7"liner top @12957' 1/17/2019 1/17/2019 1.50 INTRM2 CEMENT TRIP P Continue RIH F/ 12901'—T/ 14126' 12,957.0 14,126.0 15:00 16:30 PUW= 304k, SOW=93k, 1/17/2019 1/17/2019 1.00 INTRM2 CEMENT COCF P Wash down F/14126' -T/ 4219' 14,126.0 14,219.0 16:30 17:30 Tagged cement stringer @ 14193' with 7k WOB, established circ, 250gpm=2080psi, 11%f/o, 40bbls to fill pipe, 1/17/2019 1/17/2019 3.50 INTRM2 CEMENT CIRC P Circ B/U prior to casing test, 14,219.0 14,219.0 17:30 21:00 reciprocate pipe F/ 14126'T/14219', 2509pm=1510psi, 11%f/o, PUW 300k,SOW=101 k, (No cement came Pack @ B/U) 1/17/2019 1/17/2019 1.50 INTRM2 CEMENT PRTS T Rigged up and attempt to test csg. 14,219.0 14,219.0 21:00 22:30 pumped 125 stks, 2200 psi, 9 bbls bleed back. Notice that the mud was still aired up in the hole. Rigged down/Blow down test equipment. 1/17/2019 1/18/2019 1.50 INTRM2 CASING CIRC T Continue. Circ. Adding defoamer and 14,219.0 14,219.0 22:30 00:00 screen clean to mud to reciprocating pipe F/ 14126'T/14219', 250gpm=1510psi, 11 % F/O, 9800 total stks pumped. POW=320k, SOW=101k, Page 35147 ReportPrinted: 2/13/2019 - Operations Summary (with Timelog Depths) r-.. ._, 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Dur(m) Phase Op Code Activity Code Time PX Operation (ftKB) End Depth(ftKB) 1/18/2019 1/18/2019 2.00 INTRM2 CEMENT PRTS P R/U Test casing 3500 psi. hold for 14,219.0 14,219.0 00:00 02:00 30min. pump 104 strk 10.5bb1bled back 10.5. rig down/blow down test equipment. 1/18/2019 1/18/2019 1.50 INTRM2 CEMENT WASH P Wash down F/ 14,219'-T/14,311' 210 14,219.0 14,311.0 02:00 03:30 gpm, 1600 psi. 10% F/O, 8K WOB, 28k TO. off bottom 1560 psi. 24k TQ, 1/18/2019 1/18/2019 7.25 INTRM2 CEMENT RGRP T Kelly hose failure, PJSM, Remove olld 14,311.0 14,311.0 03:30 1045 kelly hose, Stage new hose in pipe shed to warm up. PJSM, Breing new Kelly hose to the floor. Install new kelly hose to standpipe gooseneck & Top drive. Test hose to 3500 psi. hold for 10min. (no visual leaks) 1/18/2019 1/18/2019 5.00 INTRM2 CEMENT DRLG P Continue washing down F14,311'— 14,311.0 14,449.0 10:45 15:45 T/14,449'@ 203 gpm, 1567 psi. 10% F/O 60 RPM 27k TO. 6K WOB, PUW=308 SOW= 97K, ROT= 164, MW 10.8 ppg. Drlg. Float equipment @ 14,360' MD, Shoe@ 14,446' T/11,449' 1/18/2019 1/18/2019 1.00 INTRM2 CEMENT DDRL P Drill 20' of rat hole F/14,449'—T/ 14,449.0 14,469.0 15:45 1645 14,469'221 gpm, 1930 psi. 11 %F/0, 80rpm, 26k TQ. 11K WOB, PUW= 308k, SOW= 101k, ROT= 166k MW 10.8ppg. ECD= 12.49ppg, 1/18/2019 1/18/2019 3.75 INTRM2 CEMENT CIRC P Clrc.and condition mud poir to FIT 14,469.0 14,469.0 16:45 2030 Test $ 14,468'210 gpm 1740 psi. 60 rpm TO. 26k PUW= 309k, SOW= 101k pumped total 14000 stks. 10.8 in and out 1/18/2019 1/18/2019 2.50 INTRM2 CEMENT FIT T Pull back into the shoe. Attempt to 14,469.0 14,449.0 20:30 23:00 perform a F.I.T. (no go) strokes pumped did not equal proper pressure achieved. Checked surface equipment. Determine mud was aired up for a proper FIT 1/18/2019 1/19/2019 1.00 INTRM2 CEMENT CIRC T Circ. mud even and add defoamer to 14,449.0 14,449.0 23:00 00:00 help break out the air in the mud. Bit depth of 14,468' with 210 gpm 1740 psi. 60 rpm TO. 26k PUW= 309k, SOW= 101k 1/19/2019 1/19/2019 3.00 INTRM2 CEMENT CIRC T Circ. mud even and add defoamer to 14,449.0 14,468.0 00:00 03:00 help break out the air in the mud. 14,468'210 gpm 1740 psi. 60 rpm TO. 26k PUW= 309k, SOW= 101 k 10.8ppg MW in & out 1/19/2019 1/19/2019 1.00 INTRM2 CEMENT FIT P Pull back into the shoe @ 14,449'. 14,468.0 14,449.0 03:00 04:00 Rigged up and preformed F.I.T. Pressured up to 1130 psi. pumping @ 7sp. in 10min. pressure bled down 30psi. (14.3 EMW was achieved) rig down/blow down all 1/19/2019 1/19/2019 1.00 INTRM2 CEMENT MPDA P Drain stack, pull trip riser. install mpd 14,449.0 14,449.0 04:00 05:00 bearing and drill riser. line up and establish circ. and set MPD chokes. 1/19/2019 1/19/2019 1.00 INTRM2 CEMENT MPDA P RIH F/14,449'- T/ 14,468' Establish 14,449.0 14,449.0 05:00 06:00 Circ. warm bearing 7rpm and inspect MPD equipment. 22kTQ. P/U 309k S/O 96k 210 gpm 1545 psi. 12% F/O 1/19/2019 1/19/2019 2.25 INTRM2 CEMENT MPDA T Pull back into the shoe. Trouble shoot 14,468.0 14,449.0 06:00 0815 MPD bearing lube pump. Circ. @ 14,449'- 210 gpm 1498 psi10% FIO. 8556 total strokes pumped. Page 36/47 ReportPrinted: 211312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur ( Phase Do Cotle Aph,ty Cotle Time P-T-x Operation Start Depth (ftKB) End Depth(ftKB) 1/19/2019 1/19/2019 4.7.7 5 INTRM2 CEMENT CIRC P SPR @14,449' TVD 6045' MW 10.5 14,449.0 14,449.0 08:15 1300 12:30hrs. #1 30 spri (MPD back pressure 130psi.) 40 spri 1601 (MPD back pressure 91 1/19/2019 1/19/2019 0.50 INTRM2 CEMENT TRIP P RIH T/14,469'. Attempt to down link, 14,449.0 14,469.0 13:00 13:30 pumping @ 203 gpm, 1505 psi. 9% F/O, P/U 245k S/O 114k 40 rpm 15k TO to 34k TO. 1/19/2019 1/19/2019 2.75 INTRM2 CEMENT RGRP T Pull into the casing @ 14,470, blow 14,469.0 14,470.0 13:30 1615 down top drive. Trouble shoot Top Drive encoder, and IBOP actuator pressure switch. 1/19/2019 1/19/2019 1.75 PROD1 DRILL DDRL P Trip in the hole F/14,470'- T/14,469' 14,403.0 14,557.0 16:15 1800 Drill 6 1/8-hole section F/14,469'- T/14,557'254 gpm, 2090psi. 11% F/0, 70 rpm 24k TO 10k WOB, ECD= 11.71, off BTM = 2112 psi. P/U225k S/O 100k, ROT= 170k 22k TO Max gas=0 ADT=1.27 Bit hrs. 2.28 Jar Mrs. 4.78 1/19/2019 1/20/2019 6.00 PROD1 DRILL DDRL P Drill 6 1/8-hole section F/14.557"- 14,557.0 14,796.0 18:00 00:00 T/14,796' 254 gpm, 2258psi. 11% F/O, 80 rpm 26k TQ 10k WOB, ECD= 11.82, off BTM = 2190 psi. P/U225k 8/0 100k, ROT= 163k 22k TQ Max gas=22 units ADT=5.6 Bit hrs. 6.87 Jar hrs. 10.38 1/20/2019 1/20/2019 6.00 PROD1 DRILL DDRL P Drill 61/8 Hole F/14,796'-T/14,973' 14,796.0 14,973.0 00:00 0600 TVD 6050' @ 259 gpm 2217psi. 11 % F/0, 100rpm 26k TQ. 5k WOB, ECD=11.81, off bottom: 2201 p/u 282k, s/o195k, rot. 175k 22k tq. Max gas=22 units Adt=3.39 Bit hrs.=9.83 Jar hrs=12.34 SPR: 14,914' 6046' TVD, MW10.4 @0430 #1) 20spri 30spm= 825 #2) 20spri 30spm= 825 1/20/2019 1/20/2019 6.00 PROD1 DRILL DDRL P Drill 1/8 Hole F/14,973'-T/15,457' 14,973.0 15,457.0 06:00 1200 TVD 6054' @ 259 gpm 2254psi. 11% F/O, 120rpm 28k tq. 8k WOB, ECD=12.02, off bottom: 2231 p/u 330k, s/o101 k, rot. 173k 22k tq. Max gas= 552 units Adt=4.02 Bit hrs.=13.86 Jar hrs=16.36 1/20/2019 1/20/2019 6.00 PROD1 DRILL DDRL P Drill 6 1/8 Hole F/15,457'-T15,915' 15,457.0 15,915.0 12:00 1800 TVD 1250 250 gpm 2210psi. 12% F/0, 110rpm 29k to. 81k WOB, ECD=12.11, off bottom: 2125psi. p/u 331 k, s/o 90k, rot. 173k 28k tq. Max gas= 226 units Adt=4.37 Bit hrs.=18.23 Jar hrs=20.73 #2) 30spm= 1040 40spm= 12801k MPD 132psi. back pressure Page 37147 ReportPrinted: 2113/2019 r IL Operations Summary (with Timelog Depths) 2M-41 IRW Rig: DOYON 142 Jab: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time e P -T -X Operation Start Depth (ftKB) End Depth(IKS) 1/20/2019 1/21/2019 6.00 PROD1 DRILL DDRL P Drill 61/8 Hole F/15,915' -T/16.288' 15,915.0 16,288.0 18:00 0000 TVD 6071'@ 250 gpm 2290psi. 12 F/O, 100rpm 30k tq. 8k WOB, ECD=12.1, off bottom: 2125psi. p/u 335k, s/o 75k, rot. 171 k 28k tq. Max gas= 171 units Adt=4.36 Bit hrs.=22.59. Jar hrs=25.09 SPR: 16,007' 6065' TVD, MW 10.4 @19:30 #1) 20spm= 669 30spm= 780k #2) 20spm=669 30spm= 780k 1/21/2019 1/21/2019 6.00 PROD1 DRILL DDRL P Drill 1/8 Hole F/16,288' -T/16,476' 16,288.0 16.476.0 00:00 06:00 TVD 6065'@ 250 gpm 2165psi. 12% F/0, 60rpm 30k tq. 8k WOB, ECD=11.49, off bottom: 2100psi. p/u 345k, s/o 75k, rot. 171k 28k tq. Max gas= 10 units Adt=4.35 Bit hrs.=26.84 Jar hrs=29.44 1/21/2019 1/21/2019 6.00 PROD1 DRILL DDRL P Drill 1/8 Hole F/1676' -T/16,853' 16,476.0 16,853.0 06:00 12:00 TVD 6078'@ 255 gpm 2280psi. 11°/ F/O, 130rpm 32k tq. 4k WOB, ECD=12.06, off bottom: 2257psi. p/u 326k, s/o 67k, rot. 167k 30k tq. Max gas= 251 units Adt=4.84 Bit hrs.=31.68. Jar hrs=34.18 SPR: 16,851' 6077' TVD, MW 10.4+ @12:30 #1) 20spm= 800 30spm= 1000k #2) 20spm= 740 30spm= 940k 1/21/2019 1/21/2019 3.75 PROD1 DRILL DDRL P Drill 1/8 Hole F/16,853' -T/17.046' 16,853.0 17,046.0 12:00 1545 TVD 6080'@ 255 gpm 2370psi. 11 F/0, 130rpm 32k tq. 10k WOB, ECD=12.16, off bottom: 2338psi. p/u 326k, s/o 67k, rot. 167k 30k tq. Max -1 gas= 131 units 1/21/2019 1/21/2019 00 PROD? DRILL FIT P Pick up to 17,010'MD 6080 TVD 17,046.0 17,046.0 15:45 1645 10rpm. 26k tq. circ. open hole 550 stks. Preform Dynamic FIT. with MPD, with pumps running @ 248gpm SPP=2196, MPD BP= 101psi. ECD 12.04. while maintaining 248 gpm. Increased BP by slowly closing the choke position, until formation started to break@ 539psi= 13.3ppg. (ECD) 1/21/2019 1/21/2019 1.25 PROD1 DRILL DDRL P Drill 61/8 Hole F/17.046'-TT/17,140' 17,046.0 17,140.0 16:45 1800 TVD 6088'@ 255 gpm 2280psi. 11 F/0, 130rpm 32k tq. 8k WOB, ECD=11.93, off bottom: 2257psi. p/u 336k, s/o 87k, rot. 171k 30k tq. Max gas= 148 units Adt=3.57 Bit hrs.=35.25. Jar hrs=37.75 1/21/2019 1/22/2019 6.00 PROD1 DRILL DDRL P Drill 61/8 Hole F/17,140'-7/17,422' 17,140.0 17,422.0 18:00 0000 TVD 6025'@ 257 gpm 23650psi. 11 F/0, 130rpm 32k tq. 8k WOB, ECD=12.19, off bottom: 2300psi. p/u 330k, s/o 85k, rot. 170k 30k to. Max gas= 148 units Adt=3.59 Bit his =38.84. Jar hrs=41.34 1/22/2019 1/22/2019 6.00 PROD1 DRILL DDRL P Drill 6 1/8 Hole F/17,422' -T/17,625' 17,422.0 17,625.0 00.00 0600 TVD 6017'@ 267 gpm 2430psi. 11 F/0, 70rpm 26k lq. 8k -12K WOB, ECD=12.10, off bottom: 2400psi. p/u 300k, s/o 110k, rot. 174k 30k tq. Max gas= 163 units Adt=4.68 Bit hrs.=43.52 Jar hrs=46.02 Page 38/47 ReportPrinted: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time 1/22/2019 Ertl Time 1/22/2019 Dur(hn 6.00 Phase PROD? Op Code DRILL Activity Code Tme P -T -X Operation Start Depth (WB) End Depth(XK8) 06:00 1200 DDRL P unit 6 1/8 Hole F/17,625'– T/17,670' 17,625.0 17,670.0 TVD 6021'@ 267 gpm 2429psi. 11 F/O, 60rpm 24k to. 1 Ok WOB, ECD=12.45, off bottom: 2429psi_ p/u 300k, s/o 110k, rot. 174k 30k tq. Max gas= 202 units Adt=5.83 Bit hrs.=49.35. Jar hrs=51.85. SPR: 17,794' 6027' TVD, MW 10.51`PG. @11:30 #1) 20spm= 745 30spm= 1020k #2) 20spm= 685 30spm= 940k 1/22/2019 1/22/2019 6.00 PROD1 DRILL DDRL P Drill6 1/8 HOIe F/17,679–T/17,865 17,670.0 17,865.0 12:00 1800 TVD 6029'@ 267 gpm 2636psi. 12 F/O, 125rpm 32k tq. 1 O WOB, ECD=12.77, off bottom: 2601psi. p/u 315k, s/o 108k, rot. 174k 30k tq. Max gas= 163 units Adt=4.38 Bit hrs.=53.73. Jar hrs=56.23. 1/22/2019 1/23/2019 6.00 PROD1 DRILL DDRL P Drill 6 1/8 Hole _F/17865 –T/18111 —T7 8-65-0 18,111.0 18:00 00:00 ND 6029'@ 261 gpm 2712psi. 12 F/O, 125rpm 32k tq. 1 O WOB, ECD=12.9, off bottom: 2650psi. p/u 285k, s/o 96k, rot. 165k 30k tq. Max gas= 23 units Adt=4.91 Bit hrs.=58.64. Jar hrs=61.14. 1/23/2019 1/23/2019 —6 00 PROD1 DRILL DDRL P Tri 116 1/8 Hole F/18, 111'0–T/18,360' 18,111.0 18,360.0 00:00 06:00 TVD 6025'@ 261 gpm 2712psi. 12% F/0, t00rpm 32k tq. 8-12k WOB, ECD=12.94, off bottom: 2650psi. p/u 275k, s/o 90k, rot. 170k 30k tq. Max gas= 23 units Adt=4.14 Bit hrs.=62.78. Jar hrs=65.28. 1/23/2019 06:00 1/23/2019 6.00 PRODi DRILL DDRL P Dri1161/8 Hole F/18,360-7/18,585 18,360.0 18,585.0 1200 TVD 6031'@ 261 gpm 2730psi. 12% F/O, 11 Orpm 30k tq. 8-12k WOB, ECD=12.95, off bottom: 2685psi. p/u 258k, s/o 97k, rot. 171k 23k tq. Max gas= 156 units Adt=5.37 Bit ms =68.15 Jar hrs=70.65. SPR: 18,551' 6027' TVD, MW 10.5PPG. @11:30 #1) 20spm= 850 30spm= 1085 #2) 20spm= 845 30spm= 1040 1/23/2019 12:00 1/23/2019 6.o0 PRODi DRILL DDRL P Drilt 6 1/8 Hole F/18,585'–T/18759' 18,585.0 18,759.0 1800 TVD 6033'@ 260 gpm 2768psi. 11% F/O, 11 Orpm 2 8 k tq. 8K WOB, ECD=12.82, off bottom: 2757psi. p/u 255k, s/o 101k, rot. 167k 28k tq. Max gas= 218 units Adt5.00 Bit hrs.=73.15 Jar hrs=75.65 Begin increasing mud weight to 10.7ppg 1/23/2019 1/23/2019 4.50 PROD1 DRILL DDRL P Drill 6 1/8 Hole F/18,759'–T/18,926' 18,759.0 18,926.0 18:00 2230 TVD 3034'@ 260 gpm 2790psi. 11% F/O, 1OOrpm 28k tq. 8K WOB, ECD=12.9 off bottom: 2757psi. p/u 255k, s/o 101 k, rot. 167k 28k tq. Max gas= 218 units Act. 5.14 Bit hrs.=78.29 Jar hrs=80.79. TD @ 18,926 ft MD on Jan 23 2019 at 10:30 PM Page 39147 Report Printed: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EM rime Dur (hr) Phase Op Code Activity Code Time P -T -X Operadw start Depth (W13) End Depth (ftKB) 1/23/2019 1/24/2019 1.50 PROD1 CASING CIRC P Circ. & weight up mud to 10.7ppg. 18,926.0 18,926.0 22:30 00:00 @1801220gpm 2050/1983psi. 80rpm 24.5ktq. p/u 258 slot 05k rot. 172. ECD 13.0/13.2 Circ. rate was reduced due to ECD being at 13.2. 1/24/2019 1/24/2019 6.00 PROD1 CASING CIRC P Continue increasing mud weight to 18,926.0 18 926.0 00:00 06:00 10.7. pump rate dictated byECD. Rotate 80 rpm, 29k tq. 160 gpm, 1733 psi to 200 gpm 2100 psi. reciprocate pipe 18926'to 18,840'. 255k up, 101k down, 166k rot. receive 10.7 ppg mud in and out at 05:00, 25,000 total stks pumped. Continue to circulate 30 min and confirm mud weight out 10.7ppg. 13.17 eod, 209 gpm, 2400 psi, 20 rpm on up stroke. 1/24/2019 1/24/2019 1.00 PROD1 CASING CIRC P TAKE SPRS AND FINAL SURVEY ON 18,926.0 18,926.0 06:00 07:00 BOTTOM. SPR'S @ 18926' MD, 6034' TVD MW - 10.7 PPG, HRS- 06:35 MP#1) 20 SPM- 1230 PSI, 30 SPM - 1540 PSI MP #2) 20 SPM- 1235 PSI, 30 SPM - 1510 PSI BLOW DOWN TOP DRIVE 1/24/2019 1/24/2019 4.50 PROD1 CASING SMPD P STOH F/ 18924'—T/17005', P/U 305k, 18,926.0 17,005.0 07:00 11:30 S/O 100k, 40k overpull @ 17570'md, MPD holding 425 psi backpressure. 1/24/2019 1/24/2019 6.25 PROD1 CASING REAM T F/ 17046'MD TO 169521MD, 50K 17,005.0 16,952.0 11:30 1745 OVERPULL @ 17002', Attempt to work area without pump (No Go) Made up Top Drive and broke circ. easing pump rate up to 246GPM= 1645PSI, 9% F/O, PUW 220, SOW 78K, @ 16,982= 7.38" DIE @16,888'= 5.97° DL. Wash/Ream F/ 17046'—T/16952'MD until hole cleaned up 1/24/2019 1/24/2019 0.25 PROD1 CASING SMPD P Strip out of the hole. Holding 450psi. 16,952.0 16,854.0 17:45 18:00 on the backside F/16952' - T/16854', P/U 265K. 1/24/2019 1/24/2019 1.75 PROD1 CASING REAM T Wash Ream F/ 16854'—T/16760', 30k 16,854.0 16,760.0 18:00 19:45 overpull @ 16827', send downlink to put PowerDrive to neutral, 219gpm= 2210psi, 12%f/o, 20rpm=21 k, rot 169k, (ECD 12.76) 1/24/2019 1/25/2019 4.25 PRODt CASING SMPD P Strip out of the F/16,760 -T/16,490' 16,760.0 16,490.0 19:45 00:00 p/u 280k, pulled up to20km spots. Worked pipe back down throuh tight spots, Engauge #1 pump 250gpm 2600 psi. 60 rpm 18k tq. ECD 12.8. worked through issues. min back trough tight spots wiithout pumps (no problems) continue stripping out of the hole. Page 40147 ReportPrinted: 2/13/2019 Operations Summary (with Timelog Depths) 2M-41 16 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time EM Time our (hr) Phase Op Code AUvity Code Time P-T-% Opetabon SW Dept (WB) End Dept (ftKB) 1/25/2019 1/25/2019 4.50 PROD1 CASING SMPD P Strip out of the hole with MPD 16,490.0 14,407.0 00:00 04:30 F/16,490 - T/14,407' P/U 255k S/O 115k 490 psi of back pressure while pulling. 180 psi. while in the slips. Pull 30k over F/14,970 - 14,769' after pulling through, slacked stand back through tight area to ensure we would run 4.5 liner through 1/25/2019 1/25/2019 4.00 PROD1 CASING CIRC P Circ. at the 7" shoe 2x B/U, 250 gpm. 14,407.0 14,407.0 04:30 08:30 2340 psi 40 rpm 13k tq. ECD reciprocate pipe F/14,314'-T/14,407' Total strk = 13,000 1/25/2019 1/25/2019 1.00 PROD1 CASING SI-PC P Slip & Cutoff 118' of drilling line 14,407.0 14,407.0 08:30 09:30 1/25/2019 1/25/2019 0.50 PRODt CASING SVRG P Service Top Drive and Drawworks 14,407.0 14,407.0 09:30 10:00 1/25/2019 1/25/2019 3.00 PRODt CASING WAIT T Waft on brine truck. Clean and 14,407.0 14,407.0 10:00 13:00 1 1 maintain rig 1/25/2019 1/25/2019 1.50 PROD1 CASING CIRC P Pump70 bbl. spacer. continue to 14,407.0 14,407.0 13:00 14:30 pumping 2681 strk. @ 240 gpm 2140 psi, Rotating 40 rpm. 18k tq. 1/25/2019 1/252019 1.25 PROD1 CASING SMPD P Strip out of the hole F/14,407 - 14,407.0 13,843.0 14:30 15:45 T/13,843 P/U WT+238k S/O 115k. Maintaining 365 psi. on the back side while POOH 200psi. while in the slips 1/25/2019 1/25/2019 3.00 PROD1 CASING CIRC P Displace well over from 10.7ppg. to 13,843.0 13,843.0 15:45 18:45 11.2Brine @ 250gpm, 1970psi. 8-10 Z%F/O circ. till 11.2ppg is in & out. (180bbl. interface) Final Circ. psi. 2007 10%F/O 12031 strk. until 11.2 came back. SPR: @13,845'MD,6036'TVD MW- 11.2PPG, HRS- 18:30 MP #1) 20 SPM- 200PS1, 30 SPM- 45OPSI. MP #2) 20 SPM- 190PSI, 30 SPM- 45OPSI 1/25/2019 1/25/2019 0.50 PROD1 CASING OWFF P Monitor well intial vis cup reading 21 13,843.0 13,843.0 18:45 19:15 sec= 1.02bph observe reduction in flow to 333sec = .64bph 1/25/2019 1/25/2019 1.50 PROD1 CASING SMPD P Strip out from 13,843' to 12,443 13,843.0 12,443.0 19:15 20:45 racking back 5 7/8 in the derrick. p/u 230k s/o 121k. maintain 210psi. on the backside while POOH. 100 psi. while in the slips. 1/25/2019 1/25/2019 0.25 PROD1 CASING OWFF P Observed discrepancy in the hole fill 12,443.0 12,443.0 20:45 21:00 @ 12,443' monitor well with MPD. shut in chokes trapped 52 psi. on the back side. observed psi. build to 62 psi. over 5 min. and maintained 62psi. for 10 min. 1/25/2019 1/26/2019 3.00 PROD1 CASING SMPD P Strip out F/12,443'-T/9,228' racking 12,443.0 9,228.0 21:00 00:00 back 5 7/8 in the derrick P/U 170k S/O 100k Maintain 210 psi. on the backside while POOH. 100 psi. while in the slips. Page 41147 Report Printed: 2/1312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (M) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (flKB) 1/26/2019 1/26/2019 2.00 PROD1 CASING SMPD P Strip out of the hole F/9,228' -- 9,228.0 7,252.0 00:00 02:00 T/7,252' rack back 5 7/8 DP in the derrick. P/U 125, S/O 95k. Maintain 210 psi. on the back side while POOH, 100 psi. wgile in the slips. 1/2612019 1/26/2019 0.50 PROD1 CASING OWFF P Bleed down annulus and monitor 7,252.0 7,252.0 02:00 02:30 return flow. Observed reduction in flow 2.4bph to .64 1/26/2019 1/26/2019 2.00 PROD1 CASING RURD P Pull two stands of 5 718 drill pipe and 7,252.0 6,868.0 02:30 04:30 rack back in the derrick break down stand of 5" DP and lay down. Pull drill nipple and MPD bearing. Change handling equipment to 4" dip and install tripping nipple. 1/26/2019 1/26/2019 1.50 PROD? CASING TRIP P Continue POOH on trip tank, F/6,868' 6,868.0 4,970.0 04:30 06:00 - T/4,970' racking back 21 stands of 4" dip in the derrick. P/U 105k S/O 83k 1/26/2019 1/26/2019 5.50 PROD1 CASING PULD P UD 4" DP F14,970'- T/360'. Monitor 4,970.0 360.0 06:00 11:30 well on the trip tank. obtain 2" rabbit Ion top of the 4" HWDP. 1/26/2019 1/26/2019 0.25 PROD1 CASING BHAH P Monitor well to confirm the well is 360.0 360.0 11:30 11:45 static. Hold PJSM on UD BHA 1/26/2019 1/26/2019 2.25 PROD1 CASING BHAH P UD BHA as Per. SLB. 316' -to 360.0 0.0 11:45 14:00 surface. Clear floor and remove radioactive sources as per SLB. once source is secure in shielding container continue UD BHA 1/26/2019 1/2612019 1.50 PROCI CASING BHAH P 0.0 0.0 14:00 15:30 Clean and clear floor of all BHA tools, clean out rotary table down load mwd in pipe shed. 1/2612019 1126/2019 1.25 COMPZN CASING RURD P P/U GBR handling equipment & 0.0 0.0 15:30 16:45 Power tongs. Fill new hard line and hose with Hydraulic oil and function test power tongs (Good Test) stage 128 centralizer to the rig floor . 1126/2019 1/26/2019 1.00 COMPZN CASING PUTB P Load Perf joints and place in the 0.0 O.0 16:45 17:45 correct running oder. 1/26/2019 1/26/2019 3.25 COMPZN CASING PUTS P PIU 4-1/2" Eccentric float shoe. and 0.0 1,273.0 17:45 21:00 run in the hole per tally with 4 % liner T/1,273' 1/26/2019 1/26/2019 2.00 COMPZN CASING PUTB T Remove 26 jnts of 4.5" Hydril 503 1,273.0 1,273.0 21:00 23:00 range 2 liner, replace with 20 jnts of 4.5 Hydril 563 range 3liner. The arsenal -4.5" centraliizers would not fit due the upset of the box & pin ends on the Hydril 503. Reconfigure strategy on running the arsenal4.5" centralizers - to run on perforated joints only and 26xjts of Hydril 563 blank jts. 112612019 112712019 1.00 COMPZN CASING PUTBP Continue running in the hole w/ 4.5" 1,273.0 1,693.0 23:00 00:00 12.6# lower oompleation F/1,271 - T/1,693' as per tally. p/u 69k s/o 54k. 1/27/2019 1/27/2019 4.50 COMPZN CASING PUTB P RUN IN HOLE WITH 4 1/2" 12.6# 1,693.0 4,558.0 00:00 04:30 LOWER COMPLETION FROM 1693' TO 4558' AS PER TALLY. 1 OOK ON, 102K UP. To 503 CONNECTIONS TO 4.6K, 563 TO 3.8K. INSTALL CENTRALIZERS AS PER CO REP. TOTAL OF 118 JTS RAN. Page 42147 Report Printed: 2/13/2019 . Operations Summary (with Timelog Depths) $ 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Time EM Time Our (hr)Phase Op Code Activity Cane Time P -T -X Operation Stan Depth (AKS) End Depth (1tKB) 1/27/2019 1/27/2019 2.00 COMPZN CASING OTHR P PICK UP TOOLS FORM HANGER 4,558.0 4,602.0 04:30 06:30 ASSEMBLY. MAKE UP HANGER ASSEMBLY AND LOGGING TOOLS, FILL LINER TIEBACK WITH XAN PLEX D AS PER BAKER. AND RUN IN HOLE TO 4602'. P/U WT = 82K, SIO WT = 82K. 1/27/2019 1/27/2019 0.25 COMPZN CASING RUNL P M/U XOAND RUN IN 1 STAND OF 4" 4,602.0 4,690.0 06:30 06:45 DP F/ 4602' T/ 4690' P/U WT = 83K, S/O WT= 83K. 1/27/2019 1/27/2019 0.75 COMPZN CASING CIRC P ESTABLISH CIRCULATION AT 2 4,690.0 4,690.0 06:45 07:30 BPM, 80 PSI, 3% FIG, 3 BPM, 205 PSI, 3% FIG. 10 RPM, 1K TQ, 20 RPM, 1.5K TQ. P/U WT = 83K, S/O WT = 83K. B/D TOP DRIVE 1/27/2019 1/27/2019 2.25 COMPZN CASING RUNL P RIH W/ 20 STANDS OF 4" DP F/4,690 4,690.0 6,688.0 07:30 09:45 -T/6,594'. CHANGE OUT HANDLING EQUIPMENT, M/U X/O FROM XT -39 TO 4 1/2 IF AND P/U 3x JTS OF 5" DP, AND RUBICON SWIVEL AS PER RUBICON REPS. VERIFY SWIVEL MOVING FREELY. 6594'- 6,688' P/U WT = 105K, SIO WT = 88K. CHANGE HANDLIING EQUIPMENTAND CHANGE OUT ST -100 DIES FOR 5 7/8" DP. 1/27/2019 1/27/2019 0.75 COMPZN CASING RUNL P RUN IN HOLE WITH 41/2" LOWER 6,688.0 7,768.0 09:45 10:30 COMPLETION ON TAPERED STRING OF 5 7/6" DP FROM 6,688' TO 7,768'. RABBIT EACH STAND OUT OF THE DERRICK WITH 3" DRIFT. MAINTAIN RUNNING SPEED AS PER RUNNING SCHEDULE- 90' MIN. MONITOR DISPLACEMENT VIA PIT#5. M/U TOP DRIVE AND ESABLISH ROTATING PERAMETERS. 20 RPM, 1 K TQ, RT DN WT = 102K, RT UP WT = 126K, 40 RPM, 1.5K TQ, RT DN WT = 102K, RT UP WT = 127K. P/U WT = 126K, SIO = 100K. 1/27/2019 1127/2019 1.50 COMPZN CASING RUNL P RUN IN HOLE WITH 4 1/2" LOWER 7,768.0 8,980.0 10:30 12:00 COMPLETION ON TAPERED STRING OF 5 7/8" DP FROM 7768' TO 8980'. RABBIT EACH STAND OUT OF THE DERRICK WITH 3" DRIFT. MAINTAIN RUNNING SPEED AS PER RUNNING SCHEDULE- 90' MIN. MONITOR DISPLACEMENT VIA PIT #5. P/U WT = 146K S/O WT = 112. FILL PIPE EVERY 20 STANDS TO CONFIRM PIPE IS FULL. 2 BPM, 112 PSI, 3% FIG. 1/27/2019 1/27/2019 1.00 COMPZN CASING RUNL P RUN IN HOLE WITH 4 1/2" LOWER 8,980.0 10,494.0 12:00 13:00 COMPLETION TAPERED STRING ON 5 7/8" DP FROM 8980' TO 10490'. RABBIT EACH STAND OUT OF THE DERRICK WITH 3" DRIFT. MAINTAIN RUNNING SPEED AS PER RUNNING SCHEDULE- 90' MIN. MONITOR DISPLACEMENT VIA PIT #5. SIC 114K Page 43/47 Report Printed: 2/1312019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tune End Time ox (hn Phase Op Code Adivdy Code 7me P -T -X Operabon (MB) End Depth (ftKB) 1/27/2019 1/27/2019 0.50 COMPZN CASING CIRC P FILL PIPE AND ESTABLISH 10,494.0 10,494.0 13:00 13:30 ROTATING PARAMETERS AT 10490'. 2 BPM, 117 PSI, F/O 4%. 20 RPM, 2.51K TQ, RT WT= 126, RT UP WT= 169, RT DN WT= 126, AT 40 RPM, 2.5K TQ, RT UP WT = 167K, RT DN WT = 128K. P/U WT = 178K, S/O WT = 118K 1/27/2019 1/27/2019 3.25 COMPZN CASING RUNL P RUN IN HOLE WITH 41/2" LOWER 10,494.0 14,252.0 13:30 16:45 COMPLETION TAPERED STRING ON 5 7/8" DP FROM 1049' TO 14252'. RABBIT EACH STAND OUT OF THE DERRICK WITH 3" DRIFT. MAINTAIN RUNNING SPEED AS PER RUNNING SCHEDULE- 907MIN TO 12000' THEN REDUCE TO 33'/MIN. MONITOR DISPLACEMENT VIA PIT #5, USE FILL UP HOSE TO FILL ON THE FLY. P/U WT = 240K, SIO WT = 116K. 1/27/2019 1/27/2019 0.50 COMPZN CASING OWFF P AT 14252' OBTAIN PERAMETERS 14,252.0 14,252.0 16:45 17:15 PRIOR TO EXITING THE SHOE. 2 BPM, 140 PSI, 3% F/O, 3 BPM, 305 PSI, 4% F/O, 4 BPM, 560 PSI, 6% F/O. P/U WT = 240K, SIO WT= 118K. 10 RPM, 6K TQ, RT WT= 149K, 20 RPM, 6K TQ, RT UP WT= 205K, RT DN WT= 145K, 40 RPM, 8K TQ, RT UP WT= 199K, RT DN WT= 150K. 1/27/2019 1/27/2019 5.75 COMPZN CASING RUNL P RUN IN HOLE WITH 41/2" LOWER 14,252.0 18,926.0 17:15 23:00 COMPLETION ON TAPERED STRING OF 5 7/8" DP FROM 14252' TO 18926'. RABBIT EACH STAND OUT OF THE DERRICK WITH 3" DRIFT. MAINTAIN RUNNING SPEED AS PER RUNNING SCHEDULE. MONITOR DISPLACEMENT VIA PIT #5, USE FILL UP HOSE TO FILL ON THE FLY. 330K UP, 88K DN. ROTATE 20 RPM AND SLACK OFF -160K DNWT. 40 RPM- 171 K. ROTATE 20 AND PICK UP- 225K, 40 RPM 222.16 -18K TQ. 1/27/2019 1/28/2019 1.00 COMPZN CASING PACK P SET PACKER ON DEPTH. SHOE JT 18,926.0 18,918.0 23:00 00:00 DEPTH 18,918. PACKER SETTING DEPTH- 14,325'. 1/28/2019 1/28/2019 0.50 COMPZN CASING HOSO P Set packer on depth. Shoe 18,918' 18,918.0 18,918.0 00:00 00:30 TOL 14,325, 1/28/2019 1/28/2019 1.25 COMPZN CASING CIRC P Drop dart and pump on seal, @ 5bpm 18,918.0 18,918.0 00:30 01:45 864psi. reduce rate to 2bpm 139psi, engage rotary 2rpm, 16k tq. 2910 1/28/2019 1/28/2019 0.50 COMPZN CASING PACK T Drop Baker ball and engage pump #1 18,918.0 18,918.0 01:45 02:15 to pump ball down @ 5bpm 1000 psi. 22 bbl. pump away. Pump pressure increased to 1500 psi. pump #1 was shut down. Discussed with team what would cause the increase in pressure so early. Possible that part of the burst disk from the Rubicon Swivel got pumped on top of the hanger ball seat. Page 44147 Report Printed: 2/13/2019 . Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depen Start Time End 'n. Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (flKB) 1/28/2019 1/28/2019 1.75 COMPZN CASING PACK P Reengage pumps @ 4bpm 1042psi. 18,918.0 14,325.0 02:15 04:00 after 45strk we got returns, continue pumping @ 4bpm, after 1000 strks away the pressure decreased (possible washing the obstruction out of the way) reduced rate to 3bpm @ 1500 strks away. @ 2756 strks the ball seated press up to 2300 psi. slack of and set down 40k. increased pump pressure to 3500 psi., bled pressure off and released from hanger. Pick up and confirmed release. Slacked off and set down 40k 4' higher. Pick up and rotated 15 rpms and set down 30k, picked up to break over point 275k. TOL 14,325. 1/28/2019 1/28/2019 0.50 COMPZN CASING PRTS P Closed annular preventer and tested 14,325.0 14,325.0 04:00 04:30 4.5" packer to 3300 psi. held for 10 min. 112812019 1128/2019 0.50 COMPZN WELLPR TRIP P Pull running tool above the top of the 14,325.0 14,195.0 04:30 05:00 liner to 14,195' 1/28/2019 1/28/2019 1.75 COMPZN WELLPR CRIH P Mix corrosion inhibitor In pits, pump 14,195.0 14,195.0 05:00 06:45 corrosion inhibitor @ 61bpm 5008 strks 1/28/2019 1/28/2019 0.25 COMPZN WELLPR OWFF P Blow down Top Drive & monitor well 14,195.0 14,195.0 06:45 07:00 112812019 1/2812019 4.00 COMPZN WELLPR DLOG P Begin logging out of the hole F/14,195' 14,195.0 12,650.0 07:00 11:00 - T/12,265' plu 270 (lay down 5 7/8 DP in the mouse hole that was in the derrick) 128/2019 1/28/2019 1.50 COMPZN WELLPR PULD P POOH Laing down 5718 DP F/12,650 12,650.0 11,118.0 11:00 12:30 - 11,118' monitor well on the trip tank 1/282019 1/28/2019 0.50 COMPZN WELLPR OWFF P Observed improper hole fill. Monitor 11,118.0 11,118.0 12:30 13:00 well. Static. Rotate tripping nipple for better hole file. 128/2019 1/28/2019 10.00 COMPZN WELLPR PULD P POOH from 11,118' -to 2,123' LID 5 11,118.0 2,123.0 13:00 23:00 1 1 17/8 drill pipe in the pipe shed. 1/28/2019 1/29/2019 1.00 COMPZN WELLPR PULD P POOH laydown 1 stand of 5" DP & 2,123.0 1,800.0 23:00 00:00 rubicon swivel. Continue POOH laying down 4" drill pipe F2,123 - T/1,800' 1129/2019 1/2912019 1.50 COMPZN WELLPR PULD P POOH F 1800' T/running tool laying 1,800.0 0.0 00:00 01:30 DWN DP T/ shed. Monitor well via TT. 1292019 1/29/2019 2.00 COMPZN WELLPR SHAH P LID BHA, break down SCMT logging 0.0 0.0 01:30 03:30 tool, and linner running tool, clean and Gear rig 8r. of running tools. 129/2019 1/29/2019 1.50 COMPZN WELLPR PULD P UD remaining stands from derrick. pull 0.0 0.0 03:30 05:00 wear bushing and jet stack. clear rig fir, of remaing drilling tools and equip. 1/29/2019 1/29/2019 1.00 COMPZN RPCOMP RURD P Stage cannon clamps, I wire spool, 0.0 0.0 05:00 06:00 GBRR csg. tools on rig floor, I wire sheave. 1/29/2019 1/29/2019 1.00 COMPZN RPCOMP RURD P Rig up to run 3.5 upper completion. 0.0 0.0 06:00 0700 R/U I wire spool, secure I wire sheave, verify cannon clamp count (460 ea. full), ( 12 ea. 1/2 clamps) p/u hanger and pups. Verify pipe count in pipe house. 1129/2019 1/29/2019 1.75 COMPZN RPCOMP PUTS P RIH with 3.5 9.3# L-80 EUE 8rd upper 0.0 260.0 07:00 08:45 completion per running order T/ 260'. Install DHG in carrier. P/U 50K, SIO 50K, torq pipe @ 3030 ft/lbs. 1/29/2019 1/29/2019 0.25 COMPZN RPCOMP PRTS P Test DHG connections to 8000 psi F/ 260.0 260.0 08:45 09:00 1 10 min. Page 46147 Report Printed: 2113/2019 Operations Summary (with Timelog Depths) 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth De Start Time End Time Dur (nr) Phase Op code Activity Code Time P -T -X Operation (rt End DepM (flKB) 1/29/2019 1/29/2019 3.00 COMPZN RPCOMP PUTB P Conflnue RIH with 3.5 9.3# L-80 EUE 260.0 2,044.0 09:00 12:00 8rd upper completion per running order F/ 260'to 2044'. p/u 60k, s/o 67k, installing cannon clamps on every joint. 1/29/2019 1/29/2019 6.00 COMPZN RPCOMP PUTB P Continue RIH with 3.5 9.3# L-80 EUE 2,044.0 6,726.0 12:00 18:00 8rd upper completion per running order F/ 2044' MD to 6726' MD. p/u 82k, s/o 75k, installing cannon clamps Ion every joint. 1/29/2019 1/30/2019 6.00 COMPZN RPCOMP PUTB P Continue RIH with 3.5 9.3# L-80 EUE 6,726.0 10,622.0 18:00 00:00 8rd upper completion per running order F16726' MD to 10622' MD. p/u 108k, s/o 77k, installing cannon clamps on every joint. 1/30/2019 1/30/2019 6.00 COMPZN RPCOMP PUTB P Continue RIH with 3.5 9.3# L-80 EUE 10,622.0 14,353.0 00:00 06:00 8rd upper completion per running order F/ 10622' MO to 14351' MD. p/u 128k, s/o 76k, installing cannon clamps on every joint. Tag shear pins and set down 15K to shear. No-go out at 14353 with 10K wl. 1/30/2019 1/30/2019 1.75 COMPZN RPCOMP HOSO P Lay down joints #454 through #452. 14,353.0 14,264.0 06:00 07:45 Make up space out pup's (2.30'& 2.43'). 1/30/2019 1/30/2019 1.75 COMPZN RPCOMP THGR P Make up 4 1/2" 12.6# L-80 Hyd 563 14,264.0 14,350.0 07:45 09:30 joint and X -O. Make up hanger and landing joint. Terminate TEC wire and test connections to 5000 psi/5 mins. Land hanger. RILDS and torque to spec. (400 ft/lbs). Test hanger seals to 5000 psi/15 min's. Witnessed by CPAI Co Man. PU=124K SO=81 K, Total full cannon clamps run=454 Half clamps=8. WLEG set at 14349.96' MD 1/30/2019 1/30/2019 2.50 COMPZN RPCOMP PRTS P Rig up and pump down tubing to 3800 14,350.0 14,350.0 09:30 12:00 psi. to set packer. Hold for 30 min's. Bleed tubing to 2000 psi. Pressure up and test IAto 3300 psi/30 min's.Dump pressure from tubing and shear SOV. Pump 3 bbls down IA taking returns up tubing. 1.5 bpm, 200 psi. Blow down lines. Monitor well for 10 min's. Static. 1/30/2019 1/30/2019 0.50 COMPZN RPCOMP RURD P Rig down testing equipment and lay 14,350.0 0.0 12:00 12:30 1 1 down landing joint. 1/30/2019 1/30/2019 0.75 COMPZN WHDBOP MPSP P Set HPBPV and test to 2500 psi110 0.0 0.0 12:30 13:15 min's in direction of flow. 1130/2019 1/3012019 0.50 COMPZN WHDBOP OTHR P Clean and clear dg floor. 0.0 0.0 13:15 13:45 1/30/2019 1/30/2019 1.00 COMPZN WHDBOP MPDA P Lay down mouse hole. Rig down RCD 0.0 0.0 13:45 14:45 wing valve, RCD and Katch Kan. 1/30/2019 1/30/2019 1.75 COMPZN WHDBOP NUND P Nipple down BOPE and spacer 0.0 0.0 14:45 16:30 spools. 1130/2019 1/3012019 2.50 COMPZN WHDBOP NUND P Clean wellhead and tubing 0.0 0.0 16:30 19:00 hanger.Nipple up adapter flange.Terminate TEC wire. Final DHG readings= 3523 psi BHP and 151 ° F BHT. Test hanger void to 5000 psi/15 mins. 1/30/2019 1/30/2019 2.00 COMPZN WHDBOP NUND P Orient and nipple up tree. Orientation 0.0 0.0 19:00 21:00 1 1 I verified by POP lead. 1/30/2019 1/30/2019 0.50 COMPZN WHDBOP PRTS P Test tree to 250 psi/5 min's low and 0.0 0.0- 2 21:30 1 I I 5000 psi/15 min's high. 1 Page 46147 Report Printed: 2/1312019 Operations Summary (with Timelog Depths) r � an - 2M-41 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Corte Time P -T -X Operation (ftKB) End Depth(ftKB) 1/30/2019 1/30/2019 0.50 COMPZN WHDBOP CRIH P Rig up circ lines to pump freeze 0.0 0.0 2130 22:00 protect. 1/30/2019 1/31/2019 2.00 COMPZN WHDBOP FRZP P Test lines to 2500 psi. Pump 160 bbls 0.0 0.0 2200 00:00 diesel freeze protect down IA taking returns up tubing at 1.5 bpm. Initial circulating pressure=300 psi. Final circulating pressure=1000 psi. Line up and u -tube diesel. Rig down circ lines. Rig up lubricator and set BPV. Secure tree and cellar. Tubing=200 psi IA=200 psi OA=500 psi Release rig at 23.59 hrs 1/30/19 Page 47147 Report Printed: 2/13/2019 NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-41 2M-41 ConocoPhillips Definitive Survey Report 29 January, 2019 Final Definitive Survey Verified and Signed -off All targets andror well position objectives have been achieved. p] Yes 1- No I have checked to the best of my ability that the following data is correct. O Surface Coordinates 1.1 Declination 8 Convergence GRS Survey Corrections [:_ Survey Tod Codes SLB DE- Brandon Te rr� rl l e Digitally signed by Brandon Temple h' Date: 2019.01.291355:44-09'00' Client Representative: Madeline Woodard==�'-'-` Date- l.xxlx. mxix ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConvereion Local Coordinate Reference: Well 2M41 Project: Kupamk River Unit TVD Reference: 2M41 actual @ 140.54usft (Doyon 142) Site: Kuparuk 2M Pad MD Reference: 2M41 actual @ 140.54usft (Doyon 142) Well: 2M41 North Reference: True Wellbore: 2M41 Survey Calculation Method: Minimum Curvature Design: 2M-41 Database: OAKEDMP1 'roject Kupamk River Unit, North Slope Alaska, United States Asp System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level iso Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Asp Zone: Alaska Zone 04 Using geodetic scale factor WON 2M41 Well Position +N/S +E/ -W Position Uncertainty 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: 5,948,985.35 usft Latitude: 488,281.25 usft Longitude: 0.00 usft Ground Level: Wellbors 2M41 Magnetles Model Name Sample Date Declination Dip Angle (usft) (usft) Survey (Wellbore) Tool Name BGGM2018 12/20/2018 Survey Date 16.68 8080 Design 2M41 Gyrodata gyro single shots 12/16/2018 8:5: Audit Notes: 2,991.76 2M41 Srvy 2-SLB_MWD+GMAG (2M4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Version: 1.0 Phase: ACTUAL Tie On Depth: 40.04 Vertical Section: Depth From (ND) +N/S +FJ -W Direction MWD+IFR-AK-CAZ-SC (usft) (usft) (usft) (°I 13,078.24 2M41 Srvy 5-SLB_MWD+GMAG (2M4 40.04 0.00 0.00 286.49 70" 16' 18.580 N 150' 5'41.203 W 100.50 usft Field Strength (nT) 57,419 Survey Program Date 1/29/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 111.17 1,479.08 2M41 Srvy 1 - SDI _GYD-GC-SS (2M41 GYD-GCSS Gyrodata gyro single shots 12/16/2018 8:5: 1,562.30 2,991.76 2M41 Srvy 2-SLB_MWD+GMAG (2M4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/18/2018 8AE 3,091.75 3,091.752M41 Srvy 3- SLB _INC-Only-Filler(2M- MWD -INC -ONLY MWD-INC_ONLY_FILLER 12/25/201810:1' 3,172.43 8,915.092M41 Srvy4-SLB_W MD+GMAG(2M4 MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 12/25/2018101' 9,012.64 13,078.24 2M41 Srvy 5-SLB_MWD+GMAG (2M4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/30/2018 10:1 13,185.17 14,377.612M41 Srvy 6-SLB_MWD+GMAG(2M4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/10/201910:17 14,438.63 14,438.632M41 Srvy 7- SLB _INC-Only-Filler(2M- MWD -INC -ONLY MWD-INC_ONLY_FILLER 1/17/201910:11: 14,532.81 18,865.412M41 Srvy 8-SLB_MWD+GMAG(2M4 MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 1/17/20191017 Survey - Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E1 -W Northing Easting DLS Section (cell) (°) (°) (usft) (usft) (Wit) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 40.04 0.00 0.00 40.64 -100.50 0.00 0.00 5,948,985.35 488,281.25 0.00 0.00 UNDEFINED 111.17 0.20 208.62 111.17 -29.37 -0.11 -0.06 5,948,985.24 488,281.19 0.28 0.03 GYD-GCSS(1) 139.50 0.49 133.73 139.50 -1.04 -0.24 0.00 5,948,985.11 488,281.25 1.69 -0.07 GYD-GCSS(1) 167.77 0.32 176.63 167.77 27.23 -0.40 0.10 5,948,984.95 488,281.35 1.19 -0.21 GYD-GCSS (1) 201.39 0.62 186.17 201.39 60.85 -0.67 0.08 5,948,984.68 486,281.33 0.92 -0.27 GYD-GCSS (1) 230.37 0.83 156.08 230.37 89.83 -1.02 0.15 5,948,984.33 488,281.40 1.48 -0.43 GYD-GCSS(1) 259.56 0.72 178.42 259.55 119.01 -1.40 0.24 5,94$983.95 488,281.49 1.09 -0.63 GYD-GCSS(1) 291.91 1.52 159.70 291.90 151.36 -2.00 0.40 5,948983.35 488,281.64 2.69 4.95 GYD-GCSS(1) 129/2019 2:44:57PM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M41 Project: Kuparuk River Unit TVD Reference: 2M41 actual @ 140.54usft (Doyon 142) Site: Kuperuk 2M Pad MD Reference: 21041 actual @ 140.54usft (Doyon 142) Well: 2M41 North Reference: True Wellbore: 2M-41 Survey Calculation Method: Minimum Curvature Design: 2M41 Database: OAKEDMPI Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Essting DLS Section Wall) (1) (') (usft) 1 -ft) (usft) (Mfq (f) (ft) (°1100') (ft) Survey Tool Nam 322.76 1.03 150.65 322.74 182.20 -2.63 0.67 5,948,982.72 488,281.92 1.71 -1.39 GYD-GC-SS(1) 350.74 0.72 167.40 350.72 210.18 5.02 0.84 5,948,982.33 488,282.08 1.43 -1.66 GYD-GC-SS(1) 384.61 1.25 156.68 384.58 244.04 5.57 1.03 5.945981.78 488,282.27 1.65 -2.W GYD-GCSS(1) 415.49 1.34 160.78 415.45 274.91 4.22 1.28 5,948,981.13 488,282.52 0.42 -2.42 GYD-GC-SS(1) 444.71 1.57 164.10 444.66 304.12 4.92 1.50 5,948,980.42 488,282.74 0.84 -2.84 GYD-GCSS(1) 478.62 0.85 167.37 478.57 338.03 5.62 1.68 5,948,979.73 488,282.93 2.13 5.21 GYD-GCSS(1) 510.14 0.72 345.49 510.08 369.54 5.65 1.69 5,948,979.70 488,282.93 4.98 522 GYD-GCSS(1) 536.70 1.66 329.60 536.64 396.10 5.16 1.45 5,948,980.19 488,282.69 3.72 -2.85 GYD-GCSS (1) 580.88 171 355.95 580.80 440.26 5.95 1.08 5,948,981.40 488,282.32 1.74 -2.16 GYD-GCSS(1) 676.34 2.53 351.09 676.19 535.65 -0.45 0.65 5,948,984.90 488,281.90 0.88 -0.75 GYD-GC-SS(1) 770.12 3.40 7.75 769.85 629.31 4,35 0.71 5,948,989.70 488,281.96 1.30 0.56 GYD-GC-SS(1) 864.58 5.95 6.47 863.99 723.45 11.99 1.64 5,948,997.34 488,282.90 2.70 1.84 GYD-GC-SS(1) 957.92 5.19 10.28 955.89 816.35 20.96 2.93 5,949,006.30 488,284.22 0.91 3.14 GYD-GCSS(1) 1,050.55 6.33 4.29 1,049.05 908.51 30.17 4.06 5,949,015.51 488,285.36 1.39 4.67 GYD-GCSS(1) 1,146.00 6.59 4.42 1,143.89 1,003.35 40.88 4.88 5,949,026.22 488,286.19 0.27 6.93 GYD-GCSS(1) 1,239.69 10.83 359.17 1,236.48 1,095.94 55.05 5.17 5,949,040.38 488,286.50 4.60 10.67 GYD-GCSS(1) 1,334.02 13.79 356.90 1,328.63 1,188.09 75.14 4.43 5,949,060.47 488,285.80 3.18 17.08 GYD-GCSS(1) 1,427.60 17.05 356.28 1,418.83 1,278.29 99.97 2.94 5,949,085.31 488,284.34 3.49 25.57 GYD-GC-SS(1) 1,479.08 17.95 359.02 1,467.93 1,327.39 115.44 2.31 5,949,100.77 488,283.74 2.37 30.56 GYD-GC-SS(1) 1,562.30 21.29 357.27 1,546.31 1,405.77 143.36 1.37 5,949,128.69 488,282.85 4.07 39.38 MWD+IFR-AK-CAZ-SC (2) 1.657.10 24.69 357.86 1,633.57 1,493.03 180.34 -0.19 5,949,165.68 488,281.34 3.59 51.38 MWDAFR-AK-CAZ-SC (2) 1,750.20 26.67 358.79 1,717.47 1,576.93 220.67 -1.35 5,949,206.00 488,280.24 2.17 63.95 MWD+IFR-AK-CAZSC (2) 1,844.18 28.71 359.04 1,800.68 1,660.14 264.33 -2.18 5,949,249.66 488,279.48 2.17 77.13 MND+IFRAK-CAZSC (2) 1,938.97 31.69 358.04 1,882.59 1,742.05 311.99 5.41 5,949,297.31 488,278.32 3.19 91.85 MWD+IFR-AK-CAZSC(2) 2,033.32 35.35 357.69 1,961.24 1,820.70 364.04 5.36 5,949,349.37 488,276.46 3.88 108.50 MWD+1FRAK-CAZSC(2) 2,127.38 37.48 357.01 2,036.93 1,896.39 419.82 -7.95 5,949,405.14 488,273.95 2.30 126.81 MWD+IFR-AK-CAZ-SC(2) 2,220.71 39.44 357.59 2,110.01 1,969.47 477.80 -10.68 5,949,463.12 488,271.32 2.14 145.89 MM+IFR-AK-CAZ-SC (2) 2,315.55 41.34 35248 2,182.24 2,041.70 539.19 -13.32 5,949,524.51 488,268.77 2.00 165.86 MWD+IFR-AK-CAZSC (2) 2,409.45 42.40 355.23 2,252.16 2,111.62 601.77 -16.77 5,949,587.08 488,265.42 1.44 186.93 MND+IFR-AK-CAZSC(2) 2,503.53 43.18 355.15 2,321.20 2,180.66 665.49 -21.57 5,949,650.81 488,260.71 1.14 209.63 MWD+IFRAK-CAZSC(2) 2,597.98 45.94 352.38 2,388.50 2,247.96 731.35 -28.61 5949,716.67 488,253.58 3.57 235.26 MWD+IFRAK-CAZSC(2) 2,692.13 50.51 348.69 2,451.22 2,310.68 800.55 40.43 5,949,785.89 488,242.07 5.66 266.05 MWD+IFRAK-CAZSC(2) 2,786.78 53.14 348.71 2,509.71 2,369.17 873.51 55.01 5,949,858.05 488,227.61 2.78 300.74 MWD+IFR-AK-CAZ-SC (2) 2,880.32 55.75 350.46 2,554.10 2,423.55 948.35 58.74 5,949,933.71 488,213.99 3.18 335.16 MND+IFR-AK-CAZ-SC (2) 2,975.10 57.51 350.58 2,616.24 2,475.70 1,026.42 51.78 5,950,011.79 488,201.08 1.86 369.83 MWD+IFR-AK-CAZ-SC (2) 2,991.76 58.15 350.83 2,625.11 2,484.57 1,040.34 54.06 5,950,025.71 488,198.82 4.05 375.96 MN40+IFRAK-CAZSC(2) 3,091.75 57.79 349.79 2,678.14 2,537.60 1,123.90 58.32 5,950,109.28 488,184.69 0.95 413.36 MND -INC 0NLY(3) 3,172.43 58.28 348.94 2,720.85 2,580.31 1,191.16 -110.95 5,950,176.57 488,172.16 1.08 444.57 MWD+IFRAK-CAZSC(4) 3,266.59 58.54 344.00 2,770.20 2,629.65 1,269.11 -129.72 5,950,254.53 488,153.52 4.48 484.69 MWD+IFRAK-CAZ-SC(4) 3,362.16 58.83 338.97 2,819.89 2,679.35 1,346.49 -155.64 5,950,331.94 488,127.73 4.51 531.51 MWO+IFR-AK-CAZ-SC (4) 1292019 2:44:57PM Page 3 COMPASS 5000.14 Build 85D Survey ConocoPhillips I Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well 2641 Project: Kuparuk River Unit TVD Reference: 2641 actual @ 140.54usft (Doyon 142) Site: Kuparuk 2M Pad MD Reference: 2M41 actual ® 140.54usft (Doyon 142) Well: 2M41 North Reference: True Wellbore: 2M41 Survey Calculation Method: Minimum Curvature Design: 2M41 Database: OAKEDMPI Survey 1/29!2019 2:44:57PM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Asi TVD TVDSS +WS +E/ -W Northing Emoting DLS Section (wf4 (1) (1) (usft) (wft) (usft) (wilt) P9 (ft) (.1001 (ft) Survey Tool Name 3,455.25 59.22 333.75 2,867.83 2,727.29 1,419.56 -187.63 5,950,405.06 488,095.85 4.83 582.94 MWD+IFR-AK-CAZSC (4) 3,549.47 60.15 328.85 2,915.41 2,774.87 1,490.87 -226.69 5,950,476.42 488,056.91 4.60 640.63 MWD+IFR-AK-CAZSC(4) 3,642.43 60.50 323.81 2,961.45 2,820.91 1,558.05 -271.45 5,950,543.66 488,012.26 4.73 702.63 MWD+IFR-AK-CA2-SC(4) 3,736.88 60.40 319.06 3,008.05 2,867.51 1,62227 322.65 5,950,607.96 487,%1.16 4.38 769.95 MWD+IFR-AK-CAZ-SC(4) 3,830.33 WAB 315.27 3,054.38 2,913.84 1,681.77 377.81 5,950,667.54 487,906.09 3.53 839.74 MWD+IFR-AK-CAZ-SC(4) 3,924.39 60.35 312.13 3,101.04 2,%0.50 1,738.19 436.85 5,950,724.04 487,847.15 2.90 912.37 MWD+IFRAK-CAZ-SC (4) 4,018.52 61.74 308.64 3,146.62 3,006.8 1,791.53 499.58 5,9W,777.47 487,784.51 3.56 987.66 MWD+IFR-AK-CAZSC (4) 4,112.24 62.91 306.26 3,190.15 3,049.61 1,841.98 565.47 5,950,828.03 487,718.70 2.57 1,065.16 MWD+1FR-AK-CAZSC(4) 4,205.76 63.96 304.10 3,231.98 3,091.44 1,890.17 533.84 5,950,876.31 487,650.42 2.35 1,144.40 MWD+IFR-AK-CAZ-SC(4) 4,300.17 65.33 301.34 3,272.41 3,131.87 1,936.26 -705.61 5,950,922.52 487,578.73 3.01 1,226.30 M4VD+IFR-AK-CAZ-SC(4) 4,394.91 66.76 297.91 3,310.89 3,170.35 1,979.04 -706.86 5,950,965.41 487,503.55 3.64 1,310.60 MWD+IFR-AK-CAZ-SC(4) 4,488.42 68.28 292.65 3,346.66 3,206.12 2,015.90 558.% 5,951,002.38 487,425.51 5.45 1,395.% MW3+IFR-AK-CAZSC (4) 4,583.57 69.91 287.49 3,380.64 3,240.10 2,046.37 -942.42 5,951,032.98 487,342.11 5.35 1,484.63 MWD+IFR-AK-CAZSC(4) 4,678.97 71.03 293.81 3,412.54 3,272.0 2,070.61 -1,028.98 5,951,057.35 487,255.59 3.82 1,574.51 MWD+1FR-AK-CAZSC(4) 4,772.54 72.23 281.69 3,412.03 3,301.49 2,090.20 -1,115.59 5,951,077.08 487,169.03 2.50 1.663.12 MWD+IFR-AK-CAZ-SC(4) 4,866.64 73.58 281.93 3,469.66 3,329.12 2,108.59 -1,203.53 5,951,095.60 487,081.12 1.46 1,752.66 MWD+IFR-AK-CAZ-SC(4) 4,959.57 73.67 281.61 3,495.89 3,355.35 2,126.80 -1,290.91 5,951,113.94 486,993.78 0.34 1.641.61 MWD+IFR-AK-CAZSC(4) 5,053.74 74.26 281.57 3,521.90 3,381.36 2,144.98 -1,379.57 5,951,132.26 486,905.16 0.63 1,931.79 MWD+IFR-AK-CAZSC(4) 5,147.71 74.24 281.5 3,547.41 3,406.87 2,162.72 -1,468.26 5,951,150.13 486,816.51 0.53 2,021.1% MWD+1FR-AK-CAZSC(4) 5,242.89 74.43 280.92 3,573.11 3,432.57 2,180.18 -1,558.22 5,951,167.74 4%,726.58 0.24 2,113.08 MWD+IFR-AK-CAZ-SC(4) 5,337.10 74.27 280,90 3,598.52 3,457.98 2,197.35 -1,647.30 5,951,185.04 486,637.54 0.17 2,203.37 MWD+IFR-AK-CAZ-SC(4) 5,432.34 74.40 280.82 3,624.24 3,483.70 2,214.63 -1,737.36 5,951,202.46 486,547.51 0.16 2,294.63 MWD+IFR-AK-CAZSC (4) 5,525.78 74.12 280.19 3,649.58 3,509.04 2,231.02 -1,825.79 5,951,218.99 486,459.12 0.71 2,384.07 MWD+IFR-AK-CAZSC 14) 5,619.51 73.94 2W.09 3,675.37 3,534.83 2,246.89 -1,914.49 5,951,234.99 486,370.45 0.22 2,473.63 MWD+1FR-AK-CAZSC(4) 5,713.91 73.% 279.68 3,701.47 3,5W,93 2,262.46 -2,003.87 5,951,2W.70 486,281.11 0.42 2,563.75 MWD+IFR-AK-CAZ-SC(4) 5,807.29 73.70 279.68 3,727.48 3,586.99 2,277.54 -2,092.28 5,951,265.92 4%,192.73 0.28 2,652.80 MWD+IFR-AK-CAZ-SC(4) 5,901.62 73.74 279.89 3,753.92 3,613.38 2,292.93 -2,181.51 5,951,281.45 486,103.53 0.22 2,742.73 MWDAFR-AK-CAZSC(4) 5,997.12 73.84 279.52 3,780.58 3,690.04 2,308.39 -2,271.90 5,951,297.9 486,013.18 0.39 2,833.79 MWD+IFR-AK-CAZSC (4) 6,092.04 73.83 279.48 3,807.01 3,61%.47 2,323.44 -2,361.81 5,951,31223 485,923.29 0.04 2,924.28 MWD+IFR-AK-CAZSC 14) 6,186.12 73.89 279.89 3,833.16 3,692.62 2,338.69 -2,450.90 5,951,327.57 485,834.24 0.42 3,014.01 MWD+IFR-AK-CAZ-SC(4) 6,279.70 73.80 280.58 3,859.20 3,718.% 2,354.61 -2,539.35 5,951,343.68 485,745.82 0.71 3,103.36 MWD+IFR-AK-CAZ-SC(4) 6,373.04 73.70 280.37 3,885.32 3,744.78 2,370.90 -2,627.47 5,951,360.11 485,657.74 0.24 3,192.48 MWD+IFR-AK-CAZSC (4) 6,466.61 73.77 280.46 3,911.52 3,770.98 2,387.14 -2,715.81 5,951,376.48 485,569.43 0.12 3,281.80 MWD+IFR-AK-CAZSC (4) 6,560.48 73.83 280.99 3,937.71 3,797.17 2,403.92 -2,804.38 5,951,393.39 485,480.89 0.55 3,371.48 MWD+IFR-AK-CAZSC(4) 6,654.92 73.77 281.33 3,964.06 3,823.52 2,421.47 -2,893.36 5,951,411.08 46,391.96 0.35 3,461.78 MWD+1FR-AK-CAZ-SC(4) 6,749.06 73.84 281.40 3,990.32 3,849.78 2,439.29 -2,981.99 5,951,429.03 485,303.36 0.10 3,551.82 MWD+IFR-AK-CAZ-SC(4) 6,843.17 73.77 281.6 4,016.56 3,876.02 2,457.26 3,070.56 5,951,447.15 485,214.83 0.17 3,641.85 MWD+IFR-AK-CAZSC (4) 6,937.39 73.64 281.75 4,043.0 3,902.46 2,475.53 3,159.13 5,951,465.55 485,126.29 0.25 3,731.% MWD+IFR-AK-CAZSC (4) 7,030.76 73.64 281.92 4,069.30 3,928.76 2,493.90 3,246.81 5,951,484.5 485,038.65 0.17 3,821.26 MWD+IFR-AK-CAZSC(4) 7,126.38 73.77 281.90 4,096.13 3,955.59 2,512.84 3,336.62 5,951,503.13 484,948.88 0.14 3,912.74 MWD+IFR-AK-CAZ-SC(4) 1/29!2019 2:44:57PM Page 4 COMPASS 5000.14 Build 85D Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Co-ordinate Reference: Well 2M41 Project. Kupamk River Unit TVD Reference: 2M41 actual @ 140.54usf1(Doyon 142) Site: Kupamk 2M Pad MD Reference: 2M-41 actual @ 140.54usft (Doyon 142) Wall: 2M41 North Reference: True Wellbore: 2M41 Survey Calculation Method: Minimum Curvature Design: 2M41 Database: OAKEDMPI Survey 1292019 2:44:57PM Page 5 COMPASS 5000.14 Build 85D Map hap Vertical MD Inc AN TVD TVDSS +NIS +EI -W Northing Setting OLS Section (usfg (°) n (usm Wait) Neff) (uaft) (it) (fg (/1007 (4) Survey Tool Name 7,219.11 73.74 282.28 4,122.07 3,9131.53 2453149 -3,423.67 5,951 521.91 484,861.87 0.39 4,001.51 MWD+11FR-AK-CAZ-SC (4) 7,313.75 73.89 282.03 4,148.45 4,007.91 2,550.63 3,512.52 5,951,541.19 484,773.05 0.30 4,092.14 MWD+IFR-AK-CAZSC (4) 7,408.34 73.93 281.99 4,174.67 4,034.13 2,569.54 3,601.42 5,951,560.23 484,684.20 0.06 4,182.74 MWD+IFR-AK-CAZSC 14) 7,503.98 73.45 281.36 4,201.53 4,060.99 2,588.11 3,691.31 5,951,578.95 484,594.34 0.81 4,274.21 MWD+1FR-AK-CAZ-SC(4) 7,597.01 73.92 281.44 4,227.66 4,087.12 2,605.76 3,778.83 5,951,596.73 484,506.86 0.51 4,363.14 MWD+IFR-AK-CAZSC (4) 7,690.65 73.92 280.93 4,253.60 4,113.6 2,623.21 3,867.10 5,951,614.32 484,418.63 0.52 4,452.73 MWD+IFR-AK-CAZSC (4) 7,789.45 73.85 280.59 4,279.63 4,139.09 2,640.09 3,955.63 5,951,631.28 489,330.13 0.36 4,542.39 MWD+IFR-AK-CAZSC (4) 7,877.74 74.01 280.67 4,305.46 4,164.92 2,656.57 4,043.73 5,951,647.95 484,242.6 0.19 4,631.57 MWD+IFR-AK-CAZSC(4) 7,972.19 73.85 279.98 4,331.60 4,191.6 2,672.84 4,133.02 5,951,664.36 484,152.81 0.72 4,721.80 MWD+IFR-AK-CAZ-SC(4) 8,066.77 73.79 279.57 4,357.96 4,217.42 2,688.26 4,222.54 5,951,679.92 484,W3.33 0.42 4,812.01 MWD+IFR-AK-CAZ-SC(4) 8,160.33 73.98 279.48 4,383.92 4,243.38 2,703.14 4.311.18 5,951,694.93 483,974.71 0.22 4,901.23 MWD+IFR-AK-CAZSC (4) 8,255.73 74.02 278.84 4,410.22 4,269.68 2,717.73 4,401.72 5,951,709.66 483,884.21 0.65 4,992.18 MWD+IFR-AK-CAZSC (4) 8,349.30 73.67 278.68 4,436.26 4,295.72 2,731.42 4,490.54 5,951,723.49 483,795.41 0.41 5,081.24 MWD+IFR-AK-CAZSC(4) 8,443.54 73.78 278.47 4,462.67 4,322.13 2,744.91 4,580.00 5,951,737.11 483,705.99 0.24 5,170.84 MWD+IFR-AK-CAZ-SC(4) 8,537.44 73.43 278.89 4,489.17 4,348.63 2,758.51 4,669.04 5,951,750.85 483.616.97 0.57 5,260.09 MWD+IFR-AK-CAZ-SC (4) 8,631.75 73.78 279.16 4,515.79 4,375.25 2,772.70 4,758.40 5,951,765.18 483,527.65 0.46 5,349.79 MWD+IFR-AK-CAZSC (4) 8,725.81 73.92 279.71 4,541.95 4,401.41 2,707.51 4,847.53 5,951,780.12 483,438.55 0.58 5,439.46 1AWD+IFR-AK-CAZSC(4) 8,820.32 73.85 279.51 4,568.19 4,427.65 2,802.67 4937.05 5,951,795.42 483.349.07 0.22 5,529.60 MWD+IFR-AK-CAZ-SC(4) 8,915.09 73.92 279.50 4,594.49 4,453.95 2,817.70 5,026.84 5,951,810.59 483,259.30 0.07 5,619.97 MWD+IFR-AK-CAZ-SC(4) 9,012.64 73.52 279.90 4,621.84 4,481.30 2,833.48 5,119.14 5,951,826.51 483,167.04 0.57 5,712.95 MWD+IFR-AK-CAZ-SC (5) 9,107.14 73.47 280.05 4,648.68 4,508.14 2,849.17 5,208.38 5,951,842.34 483,077.83 0.16 5,802.97 MWD+IFR-AK-CAZ-SC (5) 9,200.89 73.50 281.19 4,675.34 4,534.80 2,865.74 5,296.72 5,951,859.04 48209.53 1.17 5,892.38 MWD+IFR-AK-CAZSC(5) 9,295.01 73.43 281.64 4,702.12 4,561.58 2,883.59 5,385.16 5,951,877.04 482,901.12 0.46 5,982.25 MWD+IFR-AK-CAZSC(5) 9,388.79 73.78 281.51 4,728.59 4,588.05 2,901.65 5,473.30 5,951,895.22 482,813.02 0.40 6,071.89 MWD+IFR-AK-CAZ-SC (5) 9,483.10 73.57 261.25 4,755.10 4,614.56 2,919.50 5,562.03 5,951,913.22 482,724.33 0.35 6,162.03 MWD+IFR-AK-CAZSC (5) 9,576.86 73.93 281.37 4,781.34 4,640.80 2,937.16 5,650.29 5,951,931.01 482,636.10 0.40 6,251.68 WV+1FR-AK-CAZSC(5) 9,671.54 74.03 281.19 4,807.47 4,666.93 2,954.96 5,739.54 5,951,948.95 482,546.89 0.21 6,342.31 MWD+IFR-AK-CAZSC(5) 9,765.38 74.25 280.48 4,833.11 4,692.57 2,971.93 -5,828.20 5,951,966.09 482,458.27 0.76 6,432.13 MWD+IFR-AK-CAZ-SC (5) 9,860.45 74.22 280.09 4,858.94 4,718.40 2,988.24 -5,918.23 5,951,982.50 482,368.28 0.43 6,523.09 MWD+IFR-AK-CAZ-SC (5) 9,954.01 74.26 279.88 4,884.35 4,743.81 3,003.83 5,005.91 5,951,998.23 482,279.63 0.19 6,612.55 MWD+1FR-AK-GAZSC(5) 10,048.15 73.79 280.00 4,910.26 4,769.72 3,019.45 5,0%.09 5,952,013.99 482,190.51 051 6,702.46 MWD+IFR-AK-CAZSC(5) 10,142.55 73.87 280.26 4,936.55 4,796.01 3,035.40 5,185.31 5,952,030.07 482,101.30 0.28 6,792.57 MWD+IFR-AK-CAZSC(5) 10,236.58 73.67 279.86 4,%2.83 4,822.29 3,051.17 5,274.20 5,952,045.98 482,012.43 0.46 6,882.28 MWD+IFR-AK-CAZ-$C(5) 10,331.48 73.89 280.00 4,989.34 4,848.80 3,W6.88 5,363.96 5,952,061.83 481,922.71 0.27 6,972.81 MWD+IFR-AK-CAZ-SC(5) 10,425.58 73.93 280.26 5,015.42 4,874.88 3,082.78 5,452.96 5,952,077.87 481,833.74 0.27 7,062.66 MWD+IFR-AKLAZSC(5) 10,519.24 73.71 280.38 5,041.52 4,900.98 3,098.90 5,541.46 5,952,094.12 481745.28 0.27 7,152.W MWD+IFR-AK-CAZSC(5) 10,613.20 73.77 280.53 5,W7.83 4,927.29 3,115.27 5,630.16 5,952,110.62 481,656.61 0.17 7,241.79 MWD+IFR-AK-CAZ-SC(5) 10,707.82 73.71 280.73 5,094.32 4,953.78 3,132.02 5,719.44 5,952,127.52 481,567.37 0.21 7,332.15 MWD+IFR-AK-CAZ-SC(5) 10,801.66 73.56 280.64 5,120.76 4,980.22 3,148.72 5,80291 5,952,144.35 481,478.93 0.18 7,421.73 MWD+IFR-AK-CAZSC(5) 10,895.86 73.58 281.02 5,147.41 5,006.87 3.165.69 5,8%.86 5.952,161.46 481,390.22 0.39 7,511.64 MWD+IFR.AK-CAZSC(5) 1292019 2:44:57PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M41 Project: Kuparuk River Unit TVD Reference: 2M-41 actual @ 140.54usft (Doyon 142) Site: Kuparuk 2M Pad MD Reference: 2M-41 actual ® 140.54usft (Doyon 142) Well: 2M41 North Reference: True Wellbore: 21J141 Survey Calculation Method: Minimum Curvature Design: 2M41 Database: OAKEDMP1 Survey 129/2019 2:44:57PM Page 6 COMPASS 500014 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E1 -W Northing Esetlng DLS Section (usft) (') (') (usfl) (usft) (uslt) (usm (ft) (ft) CI1001 (ft) Survey Toa] Name 10,990.19 73.78 281.06 5,173.91 5,033.37 3,183.03 5,985.51 5,952,178.93 481,301.40 0.22 7,601.76 MWD+1FR-AK-CAZ-SC(5) 11,085.26 73.52 281.26 5,200.68 5,060.14 3,200.68 -7,075.01 5,952,196.73 481,211.94 0.34 7,692.59 MWD+IFR-AK-CAZSC(5) 11,179.50 73.65 281.27 5,227.31 5,086.77 3,218.34 -7,163.67 5,952,214.32 481,123.32 0.14 7,782.61 MWD+IFR-AK-CAZSC(5) 11,273.72 74.05 281.43 5,253.51 5,112.97 3,236.16 -7,252.40 5,952,232.47 481,034.62 0.45 7,872.75 MWD+IFR-AK-CAZSC(5) 11,368.24 73.95 281.29 5,279.57 5,139.03 3,254.05 -7,341.48 5,952,250.50 480,945.58 0.18 7,963.24 MWD+IFR-AK-CAZSC(5) 11,462.15 74.02 281.07 5,305.48 5,164.94 3,271.55 -7,430.03 3,952,268.14 480,857.06 0.24 8,053.12 MWD+IFR-AK-CAZSC(5) 11,556.47 73.89 280.92 5,331.55 5,191.01 3,288.84 -7,519.01 5,952,285.57 480,768.12 0.21 8,143.35 MWD+IFR-AK-CAZ-SC(5) 11,650.70 73.80 280.79 5,357.76 5,217.22 3,305.89 -7,607.90 5,952,302.75 480,679.26 0.16 8,233.42 MWD+IFR-AK-CAZ-SC (5) 11,744.49 73.80 280.45 5,383.93 5,243.39 3,322.49 -7,696.43 5,952,319.48 480,590.77 0.35 8,323.01 MWD+IFR-AK-CAZSC(5) 11,839.34 73.74 280.36 5,410.44 5,269.90 3,338.93 -7,786.00 5,952,336.07 480,501.24 0.11 8,413.57 MWD+IFR-AK-CAZSC(5) 11,933.17 73.86 279.62 5,436.62 5,296.08 3,354.56 -7,874.74 5,952,351.84 480,412.53 0.77 8,503.09 MWD+IFR-AK-CAZSC(5) 12,027.37 73.77 279.48 5,462.88 5,322.34 3,369.57 -7,963.95 5,952,366.98 480,323.35 0.17 8,592.90 MWD+IFR-AK-CAZSC(5) 12,121.60 73.74 279.40 5,489.24 5,348.70 3,384.41 5,053.19 5,952,381.96 480,234.14 0.09 8,682.68 MWDAFR-AK-CAZSC(5) 12,216.29 73.74 279.30 5,315.75 5,375.21 3,399.18 -8,142.89 5,952,396.86 480,144.48 0.10 8,772.88 MWD+IFR-AK-CAZSC(5) 12,310.89 73.74 279.44 5,542.24 5,401.70 3,413.97 5,232.49 3,952,411.79 480,054.91 0.14 8,862.99 MWD+IFR-AK-CAZ-SC (5) 12,404.90 73.67 280.04 5,568.61 5,428.07 3,429.23 5,321.42 5,952,427.19 479,966.01 0.62 8,952.50 MWD+IFR-AK-CAZ-SC (5) 12,499.46 73.78 280.40 5,595.12 5,454.58 3,445.34 5,410.75 5,952,443.43 479,876.71 0.38 9,042.83 MWD+IFR-AK-W-SC (5) 12,592.94 73.67 280.58 5,621.31 5,480.77 3,461.67 5,498.99 5,952,459.91 479,788.51 0.22 9,132.07 MWD+IFR-AK-CAZ-SC(5) 12,687.07 73.80 280.70 5,647.68 5,507.14 3,478.36 5,587.80 5,952,476.73 479,699.74 0.18 9,221.96 MWD+IFR-AK-CAZSC(5) 12,781.21 73.77 280.35 5,673.96 5,533.42 3,494.87 5,676.67 5,952,493.38 479,610.90 0.36 9,311.86 MWD+IFR-AK-CAZSC(6) 12,875.84 73.70 280.43 5,700.47 5,559.93 3,511.25 5,766.02 5,952,509.90 479,521.58 0.11 9,402.19 MWD+IFR-AK-CAZSC(5) 12,969.64 73.80 280.38 5,726.72 5586.18 3,527.52 5,854.60 5,9S2,S26.30 479,433.04 0.12 9,491.74 MWD+IFR-AK-CAZ-SC (5) 13,064.20 73.69 280.29 5,753.19 5,612.65 3,543.80 5,943.90 5,952,542.72 479,343.77 0.15 9,531.99 MWD+IFR-AK-CAZ-SC (5) 13,078.24 73.83 280.26 5,757.11 5,616.57 3,546.21 5,957.17 5,952,545.15 479,330.51 1.02 9,595.39 MWD+IFR-AK-CAZ-SC(5) 13,165.17 73.94 280.20 5,781.24 5,640.70 3,561.04 -9,039.35 5,952,560.10 479,248.35 0.14 9,678.41 MWD+IFR-AK-CAZSC(6) 13,260.23 73.68 280.57 5,807.75 5,667.21 3,577.50 -9,129.15 5,952,576.70 479,158.60 0.46 9,769.18 M0,D+1FR-AK-CAZSC(6) 13,354.61 73.67 281.12 5,834.27 5,693.73 3,594.54 5,218.10 5,952,593.88 479,069.67 0.56 9,859.31 MWD+IFR-AK-CAZSC(6) 13,448.75 74.08 281.57 5,860.42 5,719.88 3,612.33 -9,3W.77 5,952,611.80 478,981.04 0.63 9,949.39 MWD+IFR-AK-CAZSC(6) 13,543.72 74.04 281.36 5,886.50 5,745.% 3,630.48 8,396.27 5,952,630.09 478,891.58 0.22 10,040.35 MWD+IFR-AK-CAZSC(6) 13,637.35 74.07 281.47 5,912.22 5,771.68 3,648.30 -9,484.52 5,952,648.05 478,803.37 0.12 10,130.03 MWD+IFR-AK-CAZSC(6) 13,731.41 73.94 281.34 5,938.14 5,797.60 3,666.18 -9,573.15 5,952,665.% 478,714.78 0.19 10,220.09 MWD+IFR-AK-CAZ-SC (6) 13,824.23 74.34 281.01 5,%3.51 5,822.97 3,683.48 8,660.74 5,952,683.50 478,627.22 0.55 10,308.99 MNDAFR-AK-CAZSC (6) 13,919.09 76.35 280.57 5,987.51 5,846.97 3,700.66 -9,750.89 5,952,700.82 478,537.11 2.17 10,400.30 MND+IFR-AKCAZ-SC (6) 14,013.60 79.25 278.98 6,007.48 5,866.94 3,716.33 8,891.91 5,952,716.63 478,446.12 3.48 10,492.03 MMAFR-AKCAZSC (6) 14,106.13 83.00 278.25 6,021.75 5,881.21 3,730.02 8,932.29 5,952,730.46 478,355.77 4.13 10,582.57 MWD+IFR-AK-CAZSC(6) 14,201.85 86.21 277.44 6,030.73 5,890.21 3,743.03 -10,026.68 5,952,743.61 478,261.41 3.46 10,676.77 MWD+IFR-AK-CAZSC(6) 14,2%.44 86.W 277.39 6,037.13 5,896.59 3,755.21 -10,120.26 5,952,755.93 478,167.86 0.17 10,769.97 MWD+IFR-AK-CAZSC (6) 14,377.61 86.69 277.26 6,042.26 5,901.72 3,765.53 -10,200.61 5,952,766.39 478,087.53 0.79 10,849.94 MND+IFR-AK-CAZ-SC (6) 14,438.63 88.71 277.34 6,044.71 5,904.17 3,773.28 -10,261.08 5,952,774.23 478,027.08 3.31 10,910.12 MND -INC ONLY (7) 14,532.81 90.31 277.45 6,045.51 5,909.97 3,785.40 -10,354.47 5,952,786.49 477,933.72 1.70 11,003.11 MWD+IFR-AK-CAZSC(8) 129/2019 2:44:57PM Page 6 COMPASS 500014 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2MA1 Project: Kuparuk River Unit TVD Reference: 2MA1 actual @ 140.54usft (Doyon 142) Site: Kuparuk 2M Pad MD Reference: 2M-41 actual Qa 140.54usft (Doyon 142) Well: 2MA1 North Reference: True Wellbore: 2M41 Survey Calculation Method: Minimum Curvature Design: 2M41 Database: OAKEDMP7 Survey 1/29/2019 2:44:57PM Page 7 COMPASS 5000.14 BU#d 85D Map Map Vertical MD Inc AZI TVD TVDSS +N1S +E/4N Northing Easting DLS Section (usR) (9 (') (usR) (usft) (usR) (usR) (ft) (it) (°11001 (n) Survey Tool Name 14,625.80 90.51 276.32 6,044.85 5,904.31 3,796.55 -10,446]9 5,952,797.78 477,841.43 1.23 11 09479 MWD+IFR-AK-CAZSC (8) 14,719.81 WAS 275.98 6,044.06 5,903.52 3,806.62 -10,540.25 5,952,808.00 477,747.99 0.37 11,187.27 MWD+IFR-AK-CAZSC(8) 14,817.34 89.36 277.78 6,044.22 5,903.68 3,818.30 -10,637.08 5,952,819.83 477,651.19 2.16 11,283.43 MW0+IFRAK-CAZSC(8) 14,909.46 86.41 282.89 6,047.62 5,907.08 3,834.81 -10,727.62 5,952,836.47 477,560.66 6.40 11,374.93 MWD+IFR-AK-CAZSC(8) 15,004.59 89.16 281.77 6,051.30 5,910.76 3,855.10 -10,820.46 5,952,856.91 477,467.89 3.12 11,469.71 MWD+IFRAK-CAZSC (8) 15,097.86 88.87 282.66 6,052.90 5,912.35 3,874.83 -10,911.60 5,952,876.78 477,376.79 1.00 11,56270 MWD+1FRAK-CAZSC (8) 15,191.45 89.01 283.58 6,054.63 5,914.09 3,896.07 -11,002.73 5,952,898.16 477,285.70 0.99 11,656.11 MWD+1FRAK-CAZSC (8) 15,286.07 89.14 283.86 6,056.16 5,915.62 3,918.51 -11,094.64 5,952,920.74 477,19383 0.33 11,750.61 MWD+IFR-AK-CAZSC(8) 15,381.79 89.24 281.87 6,057.51 5,916.97 3,939.82 -11,187.94 5,952,942.19 477,100.57 2.08 11,846.12 MWD+IFRAK-CAZ-SC (8) 15,475.83 90.43 278.13 6,057.79 5,917.25 3,956.15 -11,280.54 5,952,958.66 477,008.01 4.17 11,939.54 MWD+IFR-AK-CAZSC (8) 15,570.12 88.68 272.91 6,058.52 5,917.98 3,965.21 -11,374.35 5,962,967.87 476,914.22 5.84 12,032.07 MWD+IFR-AK-CAZSC (8) 15,663.03 89.14 272.63 6060.29 5,919.75 3,96970 -11,467.13 5,952,972.51 476,821.46 0.58 12,122.31 MWD+IFR-AK-CAZSC(8) 15,757.82 89.62 273.90 6,061.31 5,920.77 3,975.10 -11,56176 5,952,978.05 476,726.85 1.43 12,214.58 MWD+IFRAK-CAZSC (8) 15,652.&5 88.90 272.37 6062.54 5,922.00 3,980.30 -11,656.64 5,952,983.39 476,631.99 1.78 12,307.03 MWD+IFR-AK-CAZ-SC (8) 15,947.10 89.11 273.25 6,064.18 5,923.64 3,984.92 -11,750.76 5,952,988.16 476,537.88 0.96 12,398.59 MWD+IFRAK-CAZSC (8) 16,040.07 88.90 275.70 6,055.79 5,925.25 3,992.17 -11,843.43 5,952,995.56 476,445.24 2.64 12,489.50 MWD+IFR-AK-CAZ-SC (8) 16,134.65 88.66 281.70 6,067.81 5,927.27 4,006.47 -11,936.85 5,953,010.00 476,351.84 6.35 12,583.14 MWD+IFRAK-CAZ-SC (8) 16,229.49 88.63 283.46 6,070.05 5,929.51 4,027.12 -12,029.39 5,953,030.79 476,259.35 1.86 12,677.73 MWD+IFR-AK-CAZ-SC(8) 16,322.63 89.31 288.85 6,071.72 5,931.18 4,053.02 -12,118.80 5,953,056.83 476,169.98 5.83 12,770.82 MWD+IFRAK-CAZ-SC (8) 16,416.88 89.38 290.51 6,072.80 5,932.26 4,084.75 -12,207.54 5,953,088.70 476,081.31 1.76 12,864.91 MWD+IFRAK-CAZ-SC (8) 16,511.22 89.55 286.42 6,073.68 5,933.14 4,114.63 -12,297.00 5,953,118.71 475,991.90 4.34 12,959.17 MWD+IFRAK-CAZ-SC(8) 16,606.35 89.28 286.64 6,074.65 5,934.11 4,141.69 -12,388.19 5,953,145.91 475,900.76 0.37 13,054.30 MWD+IFRAK-CAZ-SC (8) 16,69978 89.25 285.28 6,075.85 5,935.31 4,167.38 -12,478.01 5,953,171.74 475,810.99 1.46 13,147.71 MWD+IFR-AK-CAZ-SC(8) 16,794.99 89.04 284.59 6,077.27 5,936.73 4,191.91 -12,569.99 5,953,196.41 475,719.06 0.76 13,242.88 MWD+IFRAK-CAZ-SC(8) 16,888.76 89.46 279.01 6,078.50 5,937.96 4,211.08 -12,651.74 5,953,215.72 475,627.35 5.97 13,336.29 MWD+IFRAK-CAZ-SC(8) 16,982.47 92.95 273.04 6,076.53 5,935.99 4,220.91 -12,754.85 5,953,225.69 475,534.26 7.38 13,428.36 MWD+IFRAK-CAZ-SC(8) 17,076.79 %.01 271.14 6,069.16 5,928.62 4,224.34 -12,848.80 5,953,229.27 475,440.32 3.82 13,519.42 MWD+IFRAK-CAZ-SC(8) 17,171.16 98.70 271.47 6,057.08 5,91654 4,226.47 -12,942.37 5,953,231.55 475,346.77 2.87 13,609.74 MWD+IFRAK-CAZ-SC(8) 17,265.54 96.98 27160 6,044.21 5,903.67 4,229.80 -13,035.80 5,953,235.01 475,253.35 2.17 13,700.27 MWD+IFRAK-CAZ-SC(8) 17,359.47 95.98 272.64 6,033.61 5,893.07 4,234.06 -13,129.03 5,953,239.43 475,160.14 107 13,790.88 MWD+IFRAK-CAZ-SC(8) 17,453.82 94.43 273.02 6,025.05 5,884.51 4,238.70 -13,222.87 5,953,244.21 475,066.31 1.69 13,882.17 MWD+IFRAK-CAZSC(8) 17,548.37 91.78 272.35 6,019.93 5,879.39 4,243.12 -13,317.17 5,953,248.78 474,972.03 2.89 13,973.85 MWD+IFRAK-CAZ-SC(8) 17,642.69 87.77 275.09 6,020.30 5,879.76 4,249.24 -13,411.26 5,953,255.04 474,877.96 5.15 14,065.81 MWD+IFR-AK-CAZ-SC(8) 17,736.78 87.75 274.76 6,023.98 5,883.44 4,257.31 -13,604.94 5,953,263.26 474,784.31 0.35 14,157.91 MWD+IFRAK-CAZSC(8) 17,831.84 89.67 272.65 6,026:12 5,885.58 4,263.45 -13,599.76 5,953,269.54 474,689.60 3.00 14,250.58 MWDAFR-AK-CAZSC(8) 17,925.90 89.59 272.87 6,026.72 5,886.18 4,267.98 -13,693.71 5,953,274.22 474,595.57 0.25 14,341.95 MWD+IFR-AK-CAZSC(8) 18,019.42 89.06 273.87 6,027.83 5,887.29 4,273.48 -13,787.06 5,953,279.86 474,502.24 1.21 14,433.02 MWD+IFR-AK-CAZ-SC(8) 18,113.93 89.93 274.53 6,028.66 5,888.12 4,280.40 -13,881.31 5,953,286.93 474,408.00 1.16 14,525.36 MWD+IFRAK-CAZSC(8) 18,207.48 90.75 275.38 6,028.10 5,887.56 4,288.48 -13,974.51 5,953,295.15 474,314.83 1.26 14,617.01 MWD+1FRAK-CAZSC(8) 18,30206 89.93 275.29 6,027.54 507.00 4,297.27 -14068.68 5,953,304.09 474,220.68 0.87 14,709.80 MWD+IFRAK-CAZSC(8) 1/29/2019 2:44:57PM Page 7 COMPASS 5000.14 BU#d 85D Company: Project: Site: Well: Wellbore: Design: Survey NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M41 2M-41 2M41 MD Inc AN TVD TVDSS (usft) V) (1) (usft) (usft) 18,396.35 89.62 279.06 6,027.91 5,887.37 18,490.59 88.61 276.05 6,029.37 5,888.83 18,585.35 89.49 272.25 6,030.94 5,890.40 18,679.20 90.15 273.34 6,031.23 5,890.69 18,773.60 88.99 273.30 6,031.98 5,891.44 18,865.41 88.05 274.67 6,034.40 5,893.86 18,926.00 88.05 274.67 6,035.46 5,895.92 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M41 2M41 actual @ 140.54usft (Doyon 142) 2M41 actual C 140.54usft (Doyon 142) True Minimum Curvature OAKEDMPI 1729/2019 2:44: 57PM Page 8 COMPASS 5000 14 Build 85D Map Map vertical +W -S +E/ -W Northing Easting DLS Section (usft) (calm (ft) (IU (°N00') (it) Survey Tool Name 4,309.05 -14,162.21 5,953,316.01 474,127.18 4.01 14,802.83 MWD+IFR-AK-CAZ-SC(8) 4,321.43 -14,255.61 5,953,328.54 474,033.81 3.37 14,895.90 MM+IFR-AK-CAZ-SC (8) 4,328.29 -14,350.09 5,953,335.54 473,939.35 4.12 14,988.44 MWD+IFR-AK-CAZSC (8) 4,332.87 -14,443.83 5,953,340.27 473,845.63 1.36 15,079.62 MWD+IFR-AK-CAZ-SC(8) 4,338.33 -14,538.06 5,953,345.88 473,751.41 1.28 15,171.53 MVVD+IFR-AK-CAZSC(8) 4,344.71 -14,629.62 5,953,352.40 473,659.88 1.78 15,261.13 MWD+IFR-AK-CAZSC(8) 4,349.64 -14,689.97 5,953,357.42 473,599.54 0.00 15,320.40 PROJECTED to TD 1729/2019 2:44: 57PM Page 8 COMPASS 5000 14 Build 85D - Cement Detail Report 2M-41 String: Surface Casing Cement Job: DRILLING ORIGINAL, 12/131201816:30 Cement Details Description Surface Casing Cement Cementing Start Date 12/21/2018 17:23 Cementing End Date 12/21/2018 19:05 Wellbore Name 2M-41 Comment Line up & SLB pump 5 bbls water. Pressure test lines to 3500 psi, good. Pump 40.2 bbls of CW100 @ 4.1 bpm, 228 psi, FO 11 %, PU 271 K, SO 150K. Pump 80 bbls of 10.5 ppg MP II @ 6 bpm, 148 psi, FO 18-19%. Drop bottom plug & start batching lead. Pump 569 bbls of 11.0 ppg lead cement at 4-6 bpm, 172-349 psi, FO 13%. PU 245K, SO 96K. Batch and pump 76.7 bbls of 12 ppg tail cement @ 6 bpm, 204-360 psi, FO 10%/12% CW100/MP II at surface with 41 bbls of Tail away. Land on hanger with 76.7 bbls. Tail away. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 9.5 ppg spud mud @ 8 bpm, 298- 660 psi, FO 18%.11 ppg lead cement at surface at 196 bbls of displacement away. Reduced rate to 5bpm. Bump plug with 4352 strokes (438 bbls), Pressure up to 950 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 21:08 hrs 12/21/2018. 241 bbl 11 ppg cement to surface. Lost 153.7 bbls total during job. Cement Stages Stage # 1 Description Surface Casing Cement Objective Top Depth (ftKB) Cement to Surface 39.4 Bottom Depth (ftKB) 3,096.0 Full Realm?V No Cement... 204'1.0 Top Plug? Yes Bum Plug? Yes Q Pump Init (bbl/m... 8 O Pump Final (bbll... 2 O Pump Avg (bbl/... 6 P Pump Final (psi) 950.0 P Plug Bump (psi) 450.0 Recip? Yes Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) 2,997.0 Tag Method bit Depth Plug Drilled Out To (ftKB) 3,088.3 Drill Out Diameter (in) 12 114 Comment bumped plug at calc. strokes, reciprocated 7.5' until pumped lead. 241 bbl. cement back to surface. 153.7bbl. losses. floats held, successful cement job. Cement Fluids & Additives Fluid Fluid Type CW100 Fluid Description 1 Estimated Top (ftKB) 0.0 Est Slim (ftKB) 0.0 1 Amount (sacks) Clan 1 40.0 Volume Pumped (bbl) Yield (R'/sack) Mix H2O Ratio (gat/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type MudPush II Fluid Description Estimated Top (ftKB) 0.0 Est Sum IRKS) 0.0 Amount (sacks) ClassVolume 80.0 Pumped (bbl) Yield (R°/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr t (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Lead Fluid Description 1 Estimated Top take) 0.0 Est Bim (ftKB) 2,596.0 Amount (sacks) 569 class Volume 1 G 569.0 Pumped (bbl) Yield (ft'/sack) 1.91 Mix H2O Ratio (gal/sa... 6.87 Free Water (%) Density (lb/gal) 17.00 Plastic Viscosity (CP) 16.25 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Fluid Description Estimated Top (ftKB)Est 2,596.0 Btm (ftKB) Amount 3,096.0 (sacks) 77 1 Class Volume G 76.6 Pumped (bbl) Yield tft /sack) 1.65 Mix H2O Ratio (Sallee... 5.73 Free Water (%) Density (Iblgal) Plastic 12.00 Viscosity (cP) 13.75 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 2114/2019 Cement Detail Report 2M-41 String: Intermediate 1 Casing Cement Job: DRILLING ORIGINAL, 12/13/2018 16:30 Cement Details Description Intermediate 1 Casing Cement Cementing Start Date 116/20191 Cementing End Date 1/6/2019 18:30 Wellbore Name 2M-41 Comment Pump 5.5 bbis water. Test lines to 3500 psi. Mix and pump 66.9 bbls 13 ppg Mud Push II at 5 bpm, 300 psi, 13% FO. Drop bottom plug. Mix and pump 150.2 bbis of 15.8 ppg cement at 5 bpm, 250 psi, 10-15% FO. Drop top plug. Pump 10 bible water. Displace with rig pumps 10.2 ppg -SND mud at 6 bpm, 245 psi, Reciprocate in 15' strokes. Land hanger at 3000 stks pumped. reduce rate to 5 bpm at 8280 stks and to 3 bpm at 9235 stks, 688 psi, 6% FO. Bump plugs at 9421 siks. Pressure up to 1425 psi and hold for 5 mins. CIP at 18:25 hrs. Cement Stages Stage # <Stage Number?> Description Intermediate 1 Casing Cement Objective Top Depth (ftKB) 10,449.0 Bottom Depth (ftKB) 13,140.0 Full Realm? Yes Vol Cement... Top Plug? Yes Bum Plug? Yes Q Pump Inst (bbl/m..Q 6 Pump Final (bbl/... 3 Q Pump Avg (bbll... 6 P Pump Final (psi) 688.0 P Plug Bump (psi) 1,425.0 Recip? Yes Stroke (ft) 15.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Mud Push II Fluitl Description Estimated Top (ftKB) 9,251.0 Est Bun (ftKB) 10,449.0 1 Amount (sacks) Class 1 Volume Pumped (bbl) 66.9 Yield (felsack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) 13.00 Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Intermediate Cement Fluid Descrlption Estimated Top (ftKB) 10,449.0 Est Elm (ftKB) 13,140.0 Amount (sacks) 727 Class G Volume Pumped (bbl) 150.2 Yield (ft'/sack) 1.16 Mix H2O Ratio (gal/sa... 5.0 Free Water (%) 1 Density (Ib/gal) 15.80 Plastic Viscosity (cP) 195.0 Thickening Time (hr) 5.51 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/14/2019 a - Cement Detail Report 2M-41 String: Intermediate 2 Casing Cement Job: DRILLING ORIGINAL, 12/13/201816:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 2 Casing Cement 1/14/2019 20:30 1/14/2019 23:30 2M-41 Comment Pump 7.9 bbis water. Test lines to 4000 psi. Mix and pump 46 bbis 13 ppg Mud Push II at 5 bpm, 600 psi, 13% FO. Drop bottom dart. Mix and pump 86.5 bbis of 15.8 ppg cement at 4.7 bpm, 300 psi, 9% FO. Drop top dart. Pump 10 We water. Displace with dg pumps 10.9 ppg LSND mud at 7 bpm, 600 psi, Reciprocate in 12' strokes.Bottom dart latched bottom liner wiper plug at 2790 strokes pumped and sheared at 1950 psi. Top dart latched top liner wiper plug at 2919 strokes pumped and sheared at 2770 psi. Cease reciprocating and set liner on depth at 2483 strokes pumped. Reduce rale to 3 bpm at 3346 stks 793 psi, 6% FO. Bump plugs at 3425 stks. Pressure up to 2546 psi and hold for 5 mins to set liner hanger. Bleed oft and check floats. CIP at 22:40 his. Set 50K down on liner hanger to confirm set. Increase pressure to 4000 psi to release running tool. Could not confirm release. Pressure up to 4200 psi and release running tool. Pick up and Gear rotating dogs. Set down with 50K. Pick up and set down 2 more rotating 15 rpm. TOL at 12959.11' MD and liner shoe at 14449' MD. Cement Stages Stage tt <Stage Number?> Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermetliate 2 Casing 12,957.1 14,449.0 Yes 3.0 Yes Yes Cement Init (bbi/m... Q Pump Final (bbil... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Rectp? Stroke (R) Rotated? Pipe RPM (rpm) QPump 7 3 7 793.0 2,500.0 Yes 12.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 14.2 Drill Bit 14,449.0 6 1/8 Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bum (ftKB) 1 Amount (sacks) Class Volume Pumped (bbl) Mud Push II 0.0 0.0 1 46.0 Yield (feleack) Mix H2O Ratio (gal/sa... Free Water (%) Density (ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 13.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid DescripUon Top (ftKB) Est Stan (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement JEstimated 12,957.0 14,449.0 419 G 86.5 Yield (Wlsack) Mix H2O Ratio (gallsa... Free Water (%) Density fib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.05 15.80 11 64.4 5.63 Additives Additive Type Concentration Cone Unit label Page 1I1 Report Printed: 211 412 01 9 p7 -D ai8 -/.- 1 Loepp, Victoria T (DOA) From: Sylte, Hanna<Hanna.Sylte@conocophillips.com> Sent: Friday, January 25, 2019 3:08 PM To: Loepp, Victoria T (DOA) Subject: 2M-41 (PTD #218-151) Completion Attachments: 2M-41 Schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, For the 21M-41 (PTD#218-151) producer completion, we are making a small change from the completion design submitted in the PTD. Instead of stabbing seals into the liner top, we will be running a 3-1/2" x 7" production packer at -14,140' MD, updated schematic attached. Please let me know if you have any questions or concerns with this change, we will be running in hole with the upper completion late Sunday or early Monday morning. Thank you, Hanna Sylte Completions Engineer ATO 1556 Office: (907) 265-6342 Mobile: (713) 449-2197 2M-41 Pr. _ )sed Wellbore Schematic' Producer — Non -Frac ConocoPhillips THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Graham Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99501-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 2M-41 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-151 Surface Location: 5165' FNL, 4839' FEL, SEC. 27, TI IN, R8E, UM Bottomhole Location: 686' FNL, 4299' FEL, SEC. 30, TI IN, R8E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French {l Chair DATED this ( day of December, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED NOV 0 7 2018 1a. Type of Work: 1b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Spa or: Drill ❑D . Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑✓ Service - Winj ❑ Single Zone ❑ Coalbed Gas Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil El Development - Gas E3 Service - Supply 1:1 Multiple Zone E] 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 2M-41 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 19,530' ND: 6,019' Kuparuk River Field Kuparuk Oil Pool ' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 5165' FNL & 4839' FEL, Sec 27, T11 N, R8E, UM • ADL025586 & ADL025585 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 141 8'FNL & 4325' FEL, Sec 29, T11 N, R8E, UM 931894000 &931893000 12/7/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 686' FNL & 4299' FEL, Sec 30, T11 N, R8E, UM 2560 & 2491 675' to ADL390691 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 144.5 15. Distance to Nearest Well Open Surface: x-488281.63 • y- 5948985.91 • Zone -4 GL / BF Elevation above MSL (ft): 105.5 to Same Pool: 1189' t0 2M-36 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 99.77 degrees Downhole: 3,798 psi Surface: 3,190 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD ND MD ND (including stage data) 42" 20 94# H-40 Welded 80' Surf Surf 120' 120' Installed 16" 13-3/8" 68# L-80 Hyd 563 3016' Surf Surf 3016' 2640' 1649sx 11 ppg lead, 232sx 12ppg tail 12-1/4" 9-5/8" 47# L-80 Hyd 563 11,272' Surf Surf 13172' 5790' 706 sx 15.8 ppg Class G 8-1/2" x 9-7/ 7" 26# L-80 Hyd 563 1317' 13000' 5742' 14317' • 6047' 1359 sx 15.8 ppg Class G 6-1/8" 4-1/2" 12.6# L-80 Hyd 563 5380' 14167' 6036' 19530' • 6019' N/A: Un -cemented Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Hydraulic Fracture planned? Yes ❑ No Q 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch e✓ Drilling Program Time v. Depth Plot Seabed Report B Drilling Fluid Program e Shallow Hazard Analysis 20 AAC 25.050 requirements 8✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Madeline Woodard Authorized Name: G. Alvord Contact Email: madeline.e.woodard co .com Authorized Title: Alaska Drilling Manager Contact Phone: 907-265-6086 Authorized Signature: G, _ Date: It( 'i (2,C(6 Commission Use Only Permit to Drill ��rcc� // lC%�! API Number: 44Ja �y�-� �" Permit Approval See cover letter for other Number: , 50-%c3 -�([i' Date: requirements. Conditions of approval : If box is checked, well may not be used to Other: explore for, test, or produce coalbed methane, as hydrates, or gas contained in shales: Samples Yes ( QOP req'd: ❑ NOF Mud log req'd: Yes❑ No[ �h 1-7 v`Qr it V/ r7 �l� fo 2 Hz�S, measures: Yes [✓�❑ NoDirectional Inclination svy req'd: Yes [✓]�No Spacing exception req'd: Yes ❑ Nov -only svy req'd: Yes E] NoR / tsf Post initial injection MIT req'd: Yes[] N.F APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10401 Revised 5/2017 This permit is valid f 2Mo th fro the date of approval per 20 AAC 25.005(g) Attachments in Duplicate ? 5� C{` � / , 1�8 I J I NAL ,//�/�e, /,.9''/$ Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-6086 Email: madeline.e.woodard(o)conocophillips.com November 6, 2018 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Producer, 2M-41 Dear Commissioner: Application for Permit to Drill, Well 2M-41 Saved: 7 -Nov -18 low r Conoco_ hfllips ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grassroots onshore producer, a single lateral horizontal well in the Kuparuk C sand. The expected spud date for this well is December 7, 2018. It is planned to use rig Doyon 142. A 16" surface hole will be drilled on diverter & 13-3/8" surface casing will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 -day cycle in accordance with COP and AOGCC policy. The first intermediate hole section will be a 12-1/4" hole with 9-5/8" casing run to total depth & cemented in place. The second intermediate section will be drilled with a 8-1/2" bit and underreamed to 9-7/8" with a 7" liner run to total depth and cemented in place. The 6-1/8" production lateral will be geo-steered in the Kuparuk C sand and lined with 4-1/2" pre -perforated liner. The upper completion will be run with 3-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Madeline Woodard at 265-6086 (madeline.e.woodard (n conocophillips.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 2M-41 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 2M-41 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be acconpamed by each ofthefollowikg therms, except for an item already on file craft the commission and identified in the application: (2) a plat ideniPiing the propen)v and tire property's corners and showing (A)ihe coordinates of the proposed location of the well at the .svrtace, at the top geeach objective formation. and at total depth, referenced to governmental section lines. (B) file coordinates of the Inoposed location of the it at the surface, referenced to the state plane coordinate spsteni for'this stale as maintained by the National Geodetic Survev in lire National Oceanic and Ahnospheric Admintsttntion: (C') the proposed depth oj'the well of the top of each objeclive fornmlion and at total depth: Location at Surface 5165.47' FNL, 4838.64' FEL, Sec 27, TI IN, R008E, UM NGS Coordinates Northings: 5948985.91' Eastings: 488281.63' i RKB Elevation 144.5' AMSL . Pad Elevation 105.5' AMSL Location at Surface Casing 4101.91' FNL, 4935.85' FEL, Sec 27, TI IN, R008E, UM NGS Coordinates Northings: 5950049.5' Eastings: 488183.9' Measured Depth, RKB: 3016' Total Vertical Depth, RKB: 2640' Total Vertical Depth, SS: 2495' Location at Intermediate 1 Casing 1593.41' FNL, 3329.43' FEL, Sec 29, T1 IN, ROME, UM NGS Coordinates Northings: 5952577.15' Eastings: 479230.01 Measured Depth, RKB: 13,172' Total Vertical Depth, RKB: 5790' Total Vertical Depth, SS: 1 5645' Location at Intermediate 2 Liner 1404.6' FNL, 4424.19' FEL, Sec 29, Tl 1N, ROME, UM NGS Coordinates Northings: 5952769.04' Eastings: 478135.27' Measured De Ih, RKB: 14317' Total Vertical Depth, RKB: 6047' Total Vertical Depth, SS: 5902' Location at Total Depth 686.22' FNL, 4299.66' FEL, Sec 30, TI IN, ROI OE, UM NGS Coordinates Northings: 5953504.12' Eastings: 472979.97' i Measured De th, RKB: 19530' Total Vertical De th, RKB: 6019' Total Vertical Depth, SS: 1 5874' and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) /j'a well is to be intentionally deviated, the application, for a Permit to Drill (Form 10-401) ,cast (1) include a plat, drawn to a suitable scale. shoving the path of the proposed wellbore, including all adjacent wellbores within 200 feel of any portion t f the phaposed well: Please see Attachment: Directional Plan And (2) jor all wells it irhin 200 feet of the proposed wellbore (A) list the names of the operators oj'those wells. to the extent that those names are known or discoverable it, public records, and stow /but each named operator has been finnished a copy oj'the application by certified ,rail; or (B) state that the applicant is the onhaffected miner. The Applicant is the only affected owner. Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-6086 Email: madeline.e.woodard(),conocoohill ios.com November 6, 2018 Alaska Oil and Gas Conservation Commission 333 West 7s' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Producer, 2M-41 Dear Commissioner: Application for Permit to Drill, Well 2M-41 Saved: 7 -Nov -18 Conor Phillips ,RECE1V.._ NOV 16 2018 AOGCC ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grassroots onshore producer, a single lateral horizontal well in the Kuparuk C sand. The expected spud date for this well is December 7, 2018. It is planned to use rig Doyon 142. -- A 16" surface hole will be drilled on diverter & 13-3/8" surface casing will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 -day cycle in accordance with COP and AOGCC policy. The first intermediate hole section will be a 12-1/4" hole with 9-5/8" casing run to total depth & cemented in place. The second intermediate section will be drilled with a 8-1/2" bit and underreamed to 9-7/8" with a 7" liner run to total depth and cemented in place. The 6-1/8" production lateral will be geo-steered in the Kuparuk C sand and lined with 4-1/2" pre -perforated liner. The upper completion will be run with 3-1/2" tubing. Please flnd attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Madeline Woodard at 265-6086 (madeline.e.woodard (a),conocophillins.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 2M-41 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 2M-41 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the follortng items. except for an item already on file with the commission and identified in the application: (2j a plat identifying the property and the property's owners and shomving (A)the coordinates of the proposed location of the well at the surface, at the top of each objective je, motion, and at total depth, referenced to gm'ernmenlal seclum 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 Surrey 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 5165.47' FNL 4838.64' FEL, Sec 27, TI1N, R008E, UM NGS Coordinates Northings: 5948985.91' Eastings: 488281.63' RKB Elevation 144.5' AMSL Pad Elevation 105.5'AMSL Location at Surface Casinz 4935.85' FEL Sec 27, Tl IN, ROOSE,IJN1 NGS Coordinates Northings: 5950049.5' Eastings: 488183.9' Measured Depth, RKB: 1 3016' Total Vertical Depth, RKB: 1 2640' Total Vertical Depth, SS: 1 2495' Location at Intermediate 1 Casio 1593.41' FNL, 3329.43' FEL, Sec 29, TI IN, ROO8E, UM NGS Coordinates Northings: 5952577.15' Eastings: 479230.01 Measured De th,RKB: 13,172' Total Vertical Depth, RKB: 1 5790' Total Vertical Depth, SS: 1 5645' Location at Intermediate 2 Liner 1404.6' FNL, 4424.19' FEL, Sec 29, T11N, R008E, UM NGS Coordinates Northings: 5952769.04' Eastings: 478135.27' Measured Depth. RKB: 14317' Total Vertical Depth, RKB: 6047' Total Vertical Depth SS: 1 5902' Location at Total Depth 686.22' FNL 4299.66' FEL, Sec 30, TI IN, ROIOE UM NGS Coordinates Northings: 5953504.12' Eastings: 472979.97' I Measured Depth, kKB7 19530' Total Vertical Depth, RKB: 1 6019' Total Vertical Depth, SS. 1 5874' 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 (Flo, in 10-401) ours( (1) include a plat, drawn to a suitable scale, shoring the path of the proposed wellbore, including all adjacent wellbores it idan 200 feet ofanyportion of the proposed well; Please see Attachment: Directional Plan And (2) for all it widnin 300 feet of the proposed wellbore (A) list the names of the operato,s of those wells, to the extent that those names are known or discoverable in public records, and show that each named operamr has been finnished 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 applicalion Jar a Permit to Drill must be accompanied by each of the following items, except for an item alreadv on file ,t ah the commission and identified in the application: (3) a diagram and description of the blonwut prevention equipment (BOPS) as required Fr '0 ! Ir -'i.035, 20 ' I ii7n .v Jn JAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142 & within this PTD application. Due to lower formation pressure in the overburden, a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations of the Intermediate 1 section, graphic attached. 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 hacards, including (A) the maximum dmenhole pressure that may be encountered. criteria used to determine it and maximum potential surface pressure based on a methane gradient: 3�`� The maximum potential surface pressure (MPSP hile drilling 2M-41 is calculated using an estimated maximum reservoir pressure of psi (estimate from reservoir simulator based on offset well injection/pressure data), a gas gradient of 0.10 psi/ft, and the estimate depth of the Kuparuk C sand at 6,087' TVD: �y C Sand Estimated. BHP = 3,798 psi 7 C Sand estimated depth = 6,087' TVD U Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) 0 Hydrostatic of full gas column = 608 psi (6,087' TVD * 0.10 psi/ft) G t�' MPSP = BHP — gas column = 3,190 psi (3,798 psi — 608 psi) (B) data on potential gas -ones; The wellbore 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 propensityfor differential sticking: See attached 2M41 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit 10 Drill must be accompanied by each of the following items, except for an item alreadv on file it ith the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests. as required under 20 AAC 25.03009; A procedure is on file with the commission for performing FIT/LOT'S. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application far a Permit to Drill unua be accompanied by each of the following items, excepttams an ite/ication. with the commission and identified in the application.: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.036. or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142 & within this PTDn. Due to lower formation pressure in the overburden, a fixed stack ram placement will be ulfill all barrier requirements during well construction operations of the Intermediate I secic attached. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) ,In application fora Permtno Drill must be accompanied by each of the following itlineill, item already on file with the commission and identified in the application: (4) information on drilling hazards. including (A) die maximum downhole pressure that may be encountered. criteria used to delximtmr potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while #illing 2M-41 is calculated using an estimated maximum reservoir pressure of 3190 psi (estimate fro reservoir simulator based on offset well injection/pressure data), a gas gradient of 0.10 psi/ft, d the estimated depth of the West Sak A2 sand at 4032' TVD: C Sand Estimated. BHP C Sand estimated depth Gas Gradient Hydrostatic of full gas column MPSP = BHP— gas column , (B) data on potential gas zones; The wellbore is not expected to And (C) data coneenring potential propensity for di ferential sticking; 3, 8 psi _ ,08T TVD 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) = 608 psi (6,087' TVD * 0.10 psi/ft) = 3,190 psi (3,798 psi — 608 psi) any shallow gas zones. as abnormally geo-pressured strata. lost circulation zones, and -ones that have a See attached 2M-41 Drilling Vazards Summary An application far' a Permit to Dr! must be accompanied by each of die following items, except for cm ilem already on file with the commission and identified in the application: (5) a description of the proced e for conducing formation inlegrit), tests, as required under20 AAC 25.03009; A procedure is on file ith the commission for performing FIT/LOT's. l� Ct � R� �J� Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An applic'alimr for a Permit to Drill roust be accompmded by each of the following items, except for an item already on file n'ith die commission and identified in the application: (6) a complete proposed casing and cemenfing program as required by 20 AAC 25.030, and a description of any slowed liner, p e-perforaied liner. or screen to be installed Casing and Cement Program Casing and Cementing Program Hole Casing Weight Grade Coupling Length MD Top TVD Bottom MD Bottomde TVD Cement Details 42" 20" 94# H-40 Welded 80 Surface Surface 119' 119' Installed 16" 13-3/8" 68# L-80 Hyd 563 3,016' Surface Surface 3,016' 2,640 1649 sx I L0 ppg Lead, 232 sx 12.0 ppg Tail 12.25" 9-5/8" 47#/40# L-80 Hyd 563 13,172' Surface Surface 13,172' 5,790' 706 sx 15.8 ppg Class G 8-1/2 x 9-7/8" T' 26# L-80 Hyd 563 1,317' 13,000' 5,742' 14,317' 6,647' 359 sx 15.8 ppg Class G 6-1/8" 4-12" j 12.69 L-80 Hyd 563 5,363' 14,167' 61036' 1 19,530' 61019' N/A: Un -cemented liner 13-3/8" Surface casing run to 3,008' MD / 2,640' TVD Cement surface casing back to surface. Pump a 500'of tail slurry with 12.0 ppg DeepCRETE and a lead slurry with 11.0 ppg LiteCRETE. Assume 200% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. 9-5/8" Intermediate I casine run to 13,172' MD / 5,790' TVD Single stage slurry is designed to be placed from TD to 11,379' MD/5,285' TVD; 40% excess annular volume. 9-5/8" Intrm 1 Cement Calculations 13-3/8" Surface Cement Calculations Cement yield = 1.16ft^3/sk Design: 500' of Tail Cmt @ 50% excess in OH & Lead Cmt to surface @ 200% excess in OH Tail Cement yield = 1.65 1 ftA3/sk I Lead Cement yield = 1.91 ft^3/sk bbls 11.0 ppg LiteCRETE Lead Slurry (13172'- 11379') x 0.0558 bbl/ft x 1.4 (40% excess) 140.0 CONDUCTOR = 119'x 0.1862 bbl/ft x 1.0 (0% excess) 22.2 bbls Btm of Lead to COND = (2516'- 119') x 0.0749 bbl/ft x 3 (200% excess) 538.7 bbls Total Lead Cement = 560.8 bbls or 3148.7 ftA3 or 1 1649 sks 12.0 ppg DeepCRETE Tail Slurry Shoetrack = 500'x 0.1497 bbl/ft x 1.0 (0% excess) 12.0 bbls Shoe to Top of Tail = (3016'- 2516') x 0.0749 bbl/ft x 1.5 (50% excess) 56.2 bbls Total Tail Cement = 68.2 bbls or 382.7 ftA3 I or 1232 sks Displacement = (3016'- 80') x 0.1497 bbl/ft = 439.6 bbls 9-5/8" Intermediate I casine run to 13,172' MD / 5,790' TVD Single stage slurry is designed to be placed from TD to 11,379' MD/5,285' TVD; 40% excess annular volume. 9-5/8" Intrm 1 Cement Calculations Design: UniSLURRY Class G 15.8 ppg Cement @ 40% excess in OH Cement yield = 1.16ft^3/sk 7 Planned TOC = 11379' MD Shoe Track 80'x 0.0732 bbl/ft x 1.0 (0% excess) 5.9 1 bbls Shoe to Top of Cement = (13172'- 11379') x 0.0558 bbl/ft x 1.4 (40% excess) 140.0 bbls Total Cement Volume = 145.9 bbls or 819.1 ftA3 I or 1 706 sks Displacement = (13172'- 80') x 0.0732 bbl/ft = 958.4 1 bbls 7" Intermediate 11 Liner run to 14,317' MD / 6,048' TVD Single stage slurry is designed to be placed from TD to the 7" liner top at 13,000' NM with 30% excess annular volume. Diverter System Information Reauirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except fman item already on file ivilh the commission and identified in the application: (7) a diagram and description of the diverter system as required by 10 AAC 15.035, 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 masl be accompanied by each of the folloving items, except for an item already on file 1Uh the commission and identified in the application: (8) a drilling Mid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,• Mud Program Summary 7" Intrm 2 Cement Calculations Intermediate 1 12-1/4" Hole 9-5/8" Casing Intermediate 2 8-1/2" x 9-7/8" Hole 7" Liner Design: UniSLURRY Class G 15.8 ppg Cement to 7" Liner Top Mud System Spud (WBM) Cement yield = 1.16 ftA3/sk I Planned TOC = 13000' MD Shoe Track = 80'x 0.0383 bbl/ft x 1.0 (0% excess) 3.1 bbls 8-1/2" OH x 7" Annulus = 110'x 0.0226 bbl/ft x 1.3 (30% excess) 3.2 bbls 9-7/8" OH x 7" Annulus = 1035'x 0.0471 bbl/ft x 1.3 (30% excess) 63.4 bbls 9-5/8" Csg x 7" Annulus = 172'x 0.0256 bbl/ft x 1.0 (0% excess) 4.4 bbls Total Cement Volume = 74.1 bbls or 1 416.1 ftA3 I or 1 359 sks 10-12 11-15 Displacement = (14237'- 13000') x 0.0383 bbl/ft+ 13000'x 0.0235 bbl/ft = 352.8 bbls Diverter System Information Reauirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except fman item already on file ivilh the commission and identified in the application: (7) a diagram and description of the diverter system as required by 10 AAC 15.035, 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 masl be accompanied by each of the folloving items, except for an item already on file 1Uh the commission and identified in the application: (8) a drilling Mid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,• Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Surface 16" Hole 13-3/8" Casing Intermediate 1 12-1/4" Hole 9-5/8" Casing Intermediate 2 8-1/2" x 9-7/8" Hole 7" Liner Production 6-1/8" Hole 4-1/2" Liner Mud System Spud (WBM) LSND WBM LSND (WBM) Flo -Pro NT (WBM Density 8.8-9.5 9.5-10.5 10.5-12.2 10.5-12.2 PV 30-50 10-20 10-20 10-20 YP 30-80 16-24 17-28 16-24 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A NIA N/A Initial Gel 30-50 10-12 11-15 5-8 10 minute Gel 30-50 10-18 12-22 5-12 API Filtrate NC < 6 < 6 < 6 HTHP Fluid Loss at 120 F N/A <10 <10 <10 H 9.0-10.0 9.0-10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applicalion fma Permit to Drill must he accompanied by each of the follmving Items, except for an item already on file with the commission and !dent fed in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. L Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 16" hole to casing point as per directional plan with 5-7/8" DP. Survey & log with MWD, GWD, GR. 3. Run and cement 13-3/8", 68#, L80, Hydril 563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. Evacuate top 2 feet of cement from annulus for sealant job (post rig). 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi high and 250 psi low. Notify ✓ AOGCC 24 hrs before test. 5. PU 12-1/4" PDC bit and directional drilling assembly, with MWD, Gamma Ray, & Resistivity. RIH to 100' above float collar with 5-7/8" DP. Test surface casing to 3,000 psi for 30 minutes. 6. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 12.5 ppg EMW, record results. 7. Directionally drill to 12-1/4" intermediate 1 hole to TD at +/- 13,172' MD/5,790' TVD in the HRZ. S. BROOH to surface shoe, circulate well clean then POOH on elevators. 9. Lay down intermediate 1 BHA. 10. Run 9-5/8", 47#/409 L80, Hydril 563 casing from surface to TD. 11. Pump cement job as per Schlumberger proposal. Displace cement with mud and check floats upon bumping plug. Top cement to be placed @+/- 11,379' MD/5,285' TVD. 12. Install 9-5/8" packoff & test to 5000 psi. 13. PU 8-1/2" bit, and drilling assembly with underreamer, MWD, Gamma Ray, Resistivity, and Neutron Density. 14. RIH on 5-7/8" DP to top of float equipment. Test casing to 3,500 psi for 30 minutes. 15. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 12.0 ppg EMW recording results. 16. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel to freeze protect. 17. Directionally drill 8-1/2" x 9-7/8" hole to TD in the Kuparuk C sand at +/- 14,317' MD/6,047' TVD. 18. Circulate 1 BU and flow check. POOH on elevators to 9-5/8" shoe. CBU to clean casing & POOH on elevators. 19. Lay down intermediate 2 BHA. 20. Rig up & Run 7", 26#, L-80, Hydril 563 liner and liner top packer. Change out handling gear and RIH with 7" Liner on 5-7/8" DP to bottom. 21. Pump cement job as per Schlumberger proposal. Displace cement with mud. Top of cement to be at the liner hanger +/- 13,000' MD/5,742' TVD. 22. Release liner running tool and set packer. PU and pressure test packer to 1,000 psi for 10 minutes. 23. PU 6-1/8" bit and drilling assembly with MWD, Gamma Ray, Resistivity, Neutron Density, & PeriScope. RIH and clean out cement to float equipment. Test the liner to 3,500 psi for 30 min, record results. 24. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 13.0 ppg EMW, recording results. 25. Directionally drill the 6-1/8" production section, geo-steering in the Kuparuk C sand to TD of+/- 19,530' MD/6,019' TVD. 26. Circulate lx BU at TD and flow check. 27. BROOH to the 7" shoe. CBU and POOH on elevators. 28. Lay down the 6-1/8" production BHA. 29. PU and run 4-1/2", 12.6# pre -perforated liner with liner hanger & packer. 30. Set liner hanger & packer. 31. Pressure test liner top packer to 3,000 psi, chart results. 32. Flow check well. 33. POOH with liner running tools and lay down. SRO FUE 34. Run 3-1/2" 9.34, L -80,44y&9363 upper completion and land tubing. 35. Nipple down BOPE and nipple up tree. Test tree and freeze protect well. Install BPV. 36. 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 fman item already on file mith the commission and identified in the application: (14) a general description of homy the operator' plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authonfairon under 20 AAC 25.080 for an annular disposal operation in the well.: Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class 11 disposal well at the 113 Facility. If needed, excess cuttings generated will be hauled to Milne Point or 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 BOP Ram Placement for Intermediate I Section Attachment 2 Well Schematic Attachment 3 Diverter Layout Diaeram Attachment 4 Directional Plan Attachment 5 Drilline Hazards Summary Intrm Z BOP 'This is for the Intrm #1 section only, the subsequent sections will have a configuration with VBRs in the upper cavity. — Ann Fixed Blind VBR Intrm 2 & Production Operations 2M-41wp05 Proposed Wellbore Schematic Producer — Non -Frac ConocoPhillips Spud mud 8.6-9.5 PPG 2,983' TVD Ali 14,679 -TVD LSND WBM 10.5-KWF PPG Sand Too: 6.040' TVD Conductor: 20" driven to +/-119' Updated: 11/26/18 by M. Woodard 16" Surface Hole Surface Casing: Below West Salk 13-3/8" 68# L-90 Hydril 563 3,016' MD / 2,640' TVD, 60 ° deg INC 74"Tangent Tubing 3-Y," 9.3# L-80 8RD EUE TOC: 11,379' MD/5,285' TVD HRD-E ZXP Packer 7" x 95/8" Flex -Lock liner hanger HRD-E ZXP Packer 7" x 4-h" Baker Fl, 00 12-1/4" Intermediate I Hole 8-1/2" x 9-7/8" Intermediate II Hole 4-1/2" 12.6# L-80 HYD563 +/-19,530' MD/6,019' TVD 1►9lmll 2M-41wp05 Proposed Wellbore Schematic Producer — Non -Frac ConocoPhillips l AM I eLDZ -q—N 31YO I JOIN 13AIV :A8 NMVNO DNIMV60 inmvl WZSO :31111 sdgliydo:)ouo:) IOIN 13AIV :A8 NMV80 NVId 101d 3115 TING WE 31Is ,llaa 13:06, October OB 2018 � _ 2M-41 wp05 s PPrmMac°^ plan Summa T 13-3/8 x 16 9-5/8 x 12-1/4 Measured Depth 7^ x 39 + 105.5 @ 144.50usft (Doyon 0 2500 5000 -7500 10000 12500 15000 13-3/8 x 16 9.518x 12-1/4 Horizontal Departure 7" x 8-1/2 by 9-7/E 41/2 x ( 21 Equivalent Magnetic Distance 0 2000 4000 nep1h Frmn Depth To Sum"Man sane 1300.00 2M41wp05 fosen: 2M-41) 1300.00 2300.00 21 41wp05(Plan : 210-41) 1300.00 3015.00 2M41wp05(Plan: 20-41) 3015.00 4515.00 2M41wp05(Plan : 3M411 3015.00 13170.00 2M41wix15(Plan: 21041) 13170 43 .03115.043 'Gd-41wpU51Plan: 2M -4p 13170.0014315.50 2sh41wp45(Ptvi 210-41) 14315.001se15A3 2M41vry05(Plan: 210.41) 14315.0019530.36 210-41wp05(Plan: W-41) 6000 8000 10000 Tool GVD-GC-SS MWD M NIFR-AK-CAZ-SG MWD MWD+IFWAK-CA2-SC MWO MWD+IFR AK-CAZ-SC MWD NNNDAFR-AK-cAZ-SC so MO Inc Ali ND +N/S +E/ -W 1 39.00 0.00 0.00 39.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 3 400.00 1.00 130.00 399.99 41.56 0.67 4 500.00 1.00 130.00 499.98 -1.68 2.01 5 600.00 0.00 0.00 599.97 -2.24 2.67 6 800.00 3.00 0.00 799.88 2.99 2.67 7 1307.89 15.70 0.00 1300.00 85.32 2.67 8 1411.76 15.70 0.00 1400.00 113.43 2.67 9 3016.64 59.64 351.94 2640.00 1063.56 -99.46 10 3036.64 59.64 351.94 2650.11 1080.64 -101.87 11 47%.58 73.64 280.57 3431.05 2102.93 -1157.70 1213796.69 73.64 280.57 5966.30 3686]5 -964696 1314217.22 86.00 278.00 6040.50 3753.21 -10054.55 1414317.22 86.00 278.00 6047.48 3767.10 -10153.34 151433222 86.00 278.00 6048.87 3769.87 -10173.09 1614575.90 90.77 277.99 6055.59 3803.05 -10409.30 1715282.33 90.77 271.99 604605 3901.26 41108.80 1815333.95 90.00 278.02 604570 3908.45-11159.91 1915464.34 88.04 278.03 6047.93 3926.65-11289.01 2016612.60 88.04 278.03 6087.12 4086.91 -12425.36 2116786.50 95.00 278.02 6082.50 4111.16 -12597.38 2216905.69 99.77 278.01 6067.19 4127.6,1 -12714.40 2317022.22 99.77 278.01 6047.42 4143.64 42828.12 2417116.41 96.00 278.02 6034.50 415664-12920.49 2517240.82 91.02 278.02 6026.88 4173.96-13043.41 2618246.69 91.02 278.02 6008.91 4314.23 -14039.29 2718314.95 90.00 278.03 6008.30 4323.75 -14106.88 2818350.69 89.46 278.04 6008.47 432875-14142.27 2919530.36 89.46 278.04 6019.50 4493.84.15310.27 120uu 14uuu North/V: East l X: Pad Elevation: 105.50 180 39 300 300 4% 490 - fi70 670 860 860 1040 1040 12',30 230 1410 oto - tw9 1000 3350 23 0 3100 3100 3850 39.'30 - ,soo 4000 5350 5350 6100 6100 - WO am M 7690 9393 saw 10560 10580 12070 10070 - 13560 13500 - 15060 15060 165W 16550 16040 I W40 - 19533 s-vexiz--tial Magnetic Model & Date: BGGM2018 31 -Dec -18 x 8-/2 -7 Magnetic North is 16.67° East of True North (Magnetic Declination) 4re Magnetic Dip & Field Strength: 80.80° 57417nT Dleg Trace VSecl larger 0.00 0.00 0.00 0.00 0.00 0.00 repared by B. Temple 1.00 130.00 -0.60 0.00 0.00 -2.40 1.00 180.00 -3.20 1.50 0.00 -1.72 2.50 0.00 21.46 0.00 0.00 29.38 2.75 -10.00 394.97 0.00 0.00 02.10 3.75 -95.54 1703.10 0.00 0.0010294.69 3.00 -11.8110704.60 21,141 Tot Heel M0818 JM 0.00 0.00 10803.20 0.00 0.0010823.03 2.00 -0.1011059.02 0.00 0.0011757.87 1.50 177.9311808.94 2M41 T0204818 JM 1.50 179.7811937.93 0.00 0.0013073.41 4.00 -0.0613245.31 21041 T03 020818 JM 4.00 -0.121M62.23 0.00 0.0013475.85 4.00 179.8513568.15 2M41 TN MM18 JM 4.00 -179.9713690.97 0.00 0.0014686.04 1.50 179.2814753.58 2M41 T05020818 JM 1.50 178.4114788.94 0.00 0.0015956.16 21041 T06 Toe 02081!1 JM igh all wells pass AC, it is emended to TCRW both off set at the surface. 2111-19 and 2M-20 rt out in the out Annotation KOP: Start 11100 DLS, 130' TF, for 100' Hdtl for 100 Start 1 °/100' DLS, 180 -TF. for 100' Start 1.5°/100' DLS, 0 -TF, for 200 Start 2.51100' DLS, 0°TF, for 537.89 Hold for 103.87' Start 2.751100' DLS,-10°TF, for 1604.88' Hold for 20' soon 3.751100' DLS, -95.54°TF, for 1759.94' Hold for 9000.1' Siad 3T 00' DLS, -11.81 'TF, for 420.53' Hdtl for 109' A4ust TF to 04, for 20' Stan 2°/100' DLS, -0.1 °TF, for Mass' Hold for 706.43' Start 1.51100' DLS,1T MM' TF, for 51.62' Adiust TF to 178.78°, for 130.39' Hold tar 1148.26 Start 411 Ott DIS, -0.06°TF, for 173.9' Adjest TF to -0.12-,, for 119.19' Hdtl for 116.53' Start 41f 00' DLS, 179.85- TF. for 94.19 Adjust TF to -179.97°, for 124.41' Hold for 1005.87 Sian 1.51100 DIS,179.28° T5 for 68.26' Actual TF to 178.41 °, for 35.74' Hold for 1179.67' TD: 19530.36' MD, 6019.5' TVD ensured it's and collision avoidance 1 also acknowledge that Lilhology Calumo Base Perm 111.1 W SaK D enns Base WS sma.s Camp SS C-50 C-37 /Iceberg C-35 I-'---..-....___..._____.._'. he, 1, by V. Osara ccepted by J. Ryan Approved by: M. Woodard repared by B. Temple OB 2010 2M-41 wpO5 39.00 To 19530.36 I Spider Easting (2500 usft/in) 0 -7 2M-41 wp05 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4-1/2 x 6-1/8 6000 7 x 8-1/2 by 9-7/8 9-5/8 x 12-1/4 O M ; O DLOj.' O Oco O O O O O O', (O O 4000 1 ell N o 0 + 2M-41 T06 Toe 020818 J o— 0 0 0 0 0 0 r 2M-41 T05 0208T,8 J 2M-41 T03 02081$ J O 0 0 13-3/8 x 16 0 z2M-41 T04 020818 J 2M-41 T02 020818 J `D C oo ]2000 2M-41 T01 Heel 020818 J °o ; 0 C0 2 00 0 00 -2000— -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 West( -)/East(+) 2M-41 wp05 -2000 T-3 K-15 Base Perm 0 oa" N/ SaK D 1000 Base WS Camp SS n 2000- W 000 W g0�� o'" C-50 O ,`off bo 0 a o0 o C-37 / Iceberg ion Vi > 13-3/8 x 16 `O o o C-35 THRZ 4000 ro o o BHRZ / TKLB o o ,-'Top Kuparuk T- o_' _ ___________________________________________________________ Ln W ----------------- , O ® 6000 --- ---------- -- == =-=- = ---------------- = _ _11 LCQD "- ---_ oc° 9-5/8 x 12-1/4 0 0 0 7" x 8-1/2 by 9-7/8" 4-1/2 x 6-1/8 0 2000 4000 6000 8000 10000 12000 14000 16000 Vertical Section at 286.360 Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-41 (19-20) 50103xxxxx00 Plan: 2M-41 Plan: 2M-41wp05 Standard Proposal Report 08 October, 2018 ConocoPhillips Database: OAKEDMP7 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Stte: Kupawk 2M Pad Well: Plan: 2M-41 (19-20) Wellbore: Plan: 2M-41 Design: 2M-41wp05 ConocoPhillips Standard Proposal Report Local Coordinate Reference: Well Plan: 21041 (19-20) TVD Reference: Plan: 39 + 105.5 @ 144.50usft (Doyon 142) MD Reference: Plan: 39 + 105.5 @ 144.50usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kupawk 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 Kupawk 2M Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: Grid Convergence: Well Plan: 2M-41 (19-20) Well Position +NIS 0.73 usft Northing: Latitude: +E/ -W 422.21 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: Wellbore Plan: 2M-41 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (°1 K) BGGM2018 12/31/2018 16.67 80.80 57,417 Design 2M41wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) -NIS +E/ -W Direction (usft) (usft) (usft) (1) 39.00 0.00 0.00 286.36 1018/2018 1:01:34PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMPI ConocoPhillips (Alaska) Inc. -Kup2 Kupawk River Unit Kupamk 2M Pad Plan: 2M-41 (19-20) Plan: 2M-41 2M41wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Plan Survey Tool Program Date 912512018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,300.00 2M-41wp05(Plan: 2M41) GYD-GC-SS Gyrodata gyro single shots 2 1,300.00 2,300.00 2M41wp05(Plan: 21041) MWD MWD - Standard 3 1,300.00 3,015.00 2M-41wp05(Plan: 2M41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 3,015.00 4,515.00 2M41wp05(Plan: 2M41) MWD MWD - Standard 5 3,015.00 13,170.00 2M-41wp05(Plan: 2M-41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6 13,170.00 14,315.00 2M41wp05 (Plan: 2M41) MWD MWD - Standard 7 13,170.00 14,315.00 2M41 wp05(Plan: 21041) MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 8 14,315.00 15,815.00 2M-41wp05(Plan: 2M41) MVvU MWD - Standard 9 14,315.00 19,530.36 2M41wp05(Plan: 2M41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ConocoPhillips Standard Proposal Report Well Plan: 2M-41 (19-20) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) True Minimum Curvature 10MO18 1:01:34PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMP7 Company: ConocoPhillips (Alaska) Inc.-Kup2 Project Kupamk River Unit Site: Kuparuk 2M Pad Well: Plan: 21041 (19-20) Wellbore: Plan: 2M41 Design: 2M41wp05 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 2M-41 (1420) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NIS +E/ -W Rate Rate Rate TFO (usft) (1) V) (usft) (usft) lush) (°1100usft) (°1100usft) (°H00usft) (') Target 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 1.00 130.00 399.99 -0.56 0.67 1.00 1.00 0.00 130.00 500.00 1.00 130.00 499.98 -1.68 2.01 0.00 0.00 0.00 0.00 600.00 0.00 0.00 599.97 -2.24 2.67 1.00 -1.00 0.00 180.00 800.00 3.00 0.00 799.88 2.99 2.67 1.50 1.50 0.00 0.00 1,307.89 15.70 0.00 1,300.00 85.32 2.67 2.50 2.50 0.00 0.00 1,411.76 15.70 0.00 1,400.00 113.43 2.67 0.00 0.00 0.00 0.00 3,016.64 59.64 351.94 2,640.00 1,063.56 -99.46 2.75 2.74 -0.50 -10.00 3,036.64 59.64 351.94 2,650.11 1,080.64 -101.87 0.00 0.00 0.00 0.00 4,796.58 73.64 280.57 3,431.05 2,102.93 -1,157.70 3.75 0.80 -4.06 -95.54 13,796.69 73.64 280.57 5,966.30 3,686.75 -9,646.86 0.00 0.00 0.00 0.00 14,217.22 86.00 278.00 6,040.50 3,753.21 -10,054.55 3.00 2.94 -0.61 -11.81 2M-41 T01 Heel 0208 14,317.22 86.00 278.00 6,047.48 3,767.10 -10,153.34 0.00 0.00 0.00 0.00 14,337.22 86.00 278.00 6,048.87 3,769.87 -10,173.09 0.00 0.00 0.00 0.00 14,575.90 90.77 277.99 6,055.59 3,803.05 -10,409.30 2.00 2.00 0.00 -0.10 15,282.33 90.77 277.99 6,046.05 3,901.26 -11,108.80 0.00 0.00 0.00 0.00 15,333.95 90.00 278.02 6,045.70 3,908.45 -11,159.91 1.50 -1.50 0.05 177.932M-41 T02020818 Jh 15,464.34 88.04 278.03 6,047.93 3,926.65 -11,289.01 1.50 -1.50 0.01 179.78 16,612.60 88.04 278.03 6,087.12 4,086.91 -12,425.36 0.00 0.00 0.00 0.00 16,786.50 95.00 278.02 6,082.50 4,111.16 -12,597.38 4.00 4.00 0.00 -0.06 2M-41 T03 020818 Jh 16,905.69 99.77 278.01 6,067.19 4,127.64 -12,714.40 4.00 4.00 -0.01 -0.12 17,022.22 99.77 278.01 6,047.42 4,143.64 -12,828.12 0.00 0.00 0.00 0.00 17,116.41 96.00 278.02 6,034.50 4,156.64 -12,920.49 4.00 -4.00 0.01 179.85 2M-41 T04 020818 JA 17,240.82 91.02 278.02 6,026.88 4,173.96 -13,043.41 4.00 -4.00 0.00 -179.97 18,246.69 91.02 278.02 6,008.91 4,314.23 -14,039.29 0.00 0.00 0.00 0.00 18,314.95 90.00 278.03 6,008.30 4,323.75 -14,106.88 1.50 -1.50 0.02 179.28 2M-41 T05 020818 Jh 18,350.69 89.46 278.04 6,008.47 4,328.75 -14,142.27 1.50 -1.50 0.04 178.41 19,530.36 89.46 278.04 6,019.50 4,493.84 -15,310.27 0.00 0.00 0.00 0.00 2M-41 T06 Toe 02081 10/8/2018 1:01: 34PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPt Local Co-ordinate Reference: Well Plan: 21041 (19-20) Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Project: Kupamk River Unit MD Reference: Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 210-41 (19-20) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-41 Design: 2M-41wp05 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +E/.W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°HOOustt) (°1100usft) (°1100usft) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 1.00 130.00 399.99 -0.56 0.67 -0.80 1.00 1.00 0.00 500.00 1.00 130.00 499.98 -1.68 2.01 -2.40 0.00 0.00 0.00 600.00 0.00 0.00 599.97 -2.24 2.67 -3.20 1.00 -1.00 0.00 700.00 1.50 0.00 699.96 -0.93 2.67 -2.83 1.50 1.50 0.00 800.00 3.00 0.00 799.88 2.99 2.67 -1.72 1.50 1.50 0.00 900.00 5.50 0.00 899.60 10.40 2.67 0.36 2.50 2.50 0.00 1,000.00 8.00 0.00 998.90 22.15 2.67 3.67 2.50 2.50 0.00 1,100.00 10.50 0.00 1,097.59 38.23 2.67 8.20 2.50 2.50 0.00 1,200.00 13.00 0.00 1,195.49 58.59 2.67 13.94 2.50 2.50 0.00 1,300.00 15.50 0.00 1,292.40 83.20 2.67 20.87 2.50 2.50 0.00 1,307.89 15.70 0.00 1,300.00 85.32 2.67 21.46 2.50 2.50 0.00 1,400.00 15.70 0.00 1,388.68 110.25 2.67 28.48 0.00 0.00 0.00 1,411.76 15.70 0.00 1,400.00 113.43 2.67 29.38 0.00 0.00 0.00 1,500.00 18.09 358.64 1,484.42 139.06 2.35 36.91 2.75 2.71 -1.54 1,600.00 20.81 357.47 1,578.71 172.34 1.20 47.39 2.75 2.72 -1.17 1,700.00 23.54 356.56 1,671.30 210.04 -0.78 59.90 2.75 2.73 -0.91 1,800.00 26.28 355.83 1,761.99 252.05 -3.59 74.43 2.75 2.73 -0.73 1,900.00 29.01 355.23 1,850.57 298.30 -7.21 90.94 2.75 2.74 -0.60 2,000.00 31.75 354.72 1,936.83 348.68 -11.65 109.38 2.75 2.74 -0.51 2,100.00 34.49 354.29 2,020.57 403.06 -16.89 129.72 2.75 2.74 -0.43 2,200.00 37.23 353.91 2,101.61 461.32 -22.91 151.91 2.75 2.74 -0.38 2,300.00 39.97 353.58 2,179.75 523.34 -29.71 175.90 2.75 2.74 -0.33 2,400.00 42.72 353.29 2,254.82 588.95 -37.27 201.63 2.75 2.74 -0.30 2,500.00 45.46 353.02 2,326.64 658.02 -45.57 229.04 2.75 2.74 -0.27 2,600.00 48.20 352.78 2,395.05 730.39 -54.59 258.08 2.75 2.74 -0.24 2,700.00 50.95 352.55 2,459.89 805.89 -64.31 288.67 2.75 2.74 -0.22 2,800.00 53.69 352.35 2,521.01 884.34 -74.71 320.75 2.75 2.75 -0.21 2,900.00 56.44 352.15 2,578.27 965.56 -85.77 354.23 2.75 2.75 -0.19 3,000.00 59.18 351.97 2,631.53 1,049.37 -97.45 389.05 2.75 2.75 -0.18 3,016.64 59.64 351.94 2,640.00 1,063.56 -99.46 394.97 2.75 2.75 -0.17 3,036.64 59.64 351.94 2,650.11 1,080.64 -101.87 402.10 0.00 0.00 0.00 3,100.00 59.44 349.20 2,682.23 1,134.51 -110.82 425.85 3.75 -0.32 4.33 3,200.00 59.24 344.84 2,733.24 1,218.31 -130.13 467.98 3.75 -0.20 4.35 3,300.00 59.19 340.48 2,784.44 1,300.29 -155.72 515.62 3.75 -0.05 4.36 3,400.00 59.28 336.12 2,835.61 1,380.09 -187.48 568.58 3.75 0.09 4.36 3,500.00 59.52 331.77 2,886.53 1,457.39 -225.29 626.62 3.75 0.24 4.35 3,600.00 59.90 327.45 2,936.98 1,531.84 -268.96 689.50 3.75 0.38 4.32 3,700.00 60.43 323.17 2,986.75 1,603.14 -318.32 756.94 3.75 0.52 4.28 3,800.00 61.08 318.94 3,035.62 1,670.96 -373.16 826.66 3.75 0.66 4.23 3,900.00 61.87 314.76 3,083.39 1,735.04 -433.24 904.36 3.75 0.79 -4.17 4,000.00 62.78 310.66 3,129.85 1,795.08 -498.31 983.70 3.75 0.91 4.11 4,100.00 63.81 306.62 3,174.79 1,850.83 -568.08 1,066.34 3.75 1.03 -4.04 4,200.00 64.96 302.66 3,218.04 1,902.05 -642.25 1,151.94 3.75 1.14 -3.96 4,300.00 66.20 298.77 3,259.40 1,948.53 -720.52 1,240.13 3.75 1.24 -3.89 4,400.00 67.54 294.96 3,298.69 1,990.07 -802.54 1,330.53 3.75 1.34 -3.81 4,500.00 68.97 291.23 3,335.76 2,026.48 -887.96 1,422.75 3.75 1.43 -3.73 4,600.00 70.47 287.57 3,370.43 2,057.61 -976.42 1,516.40 3.75 1.51 -3.66 4,700.00 72.05 283.98 3,402.56 2,083.33 -1,067.54 1,611.07 3.75 1.58 -3.59 4,796.58 73.64 280.57 3,431.05 2,102.93 -1,157.70 1,703.10 3.75 1.64 -3.53 4.800.00 73.64 280.57 3,432.02 2,103.53 -1,160.93 1,706.36 _ 0.00 0.00 0.00 10/8/2018 1:01:34PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Coordinate Reference: Well Plan: 2M-41 (19-20) Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 39+ 105.5 @ 144.50usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 39+ 105.5 @ 144.50usft (Doyon 142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 2M-41 (19-20) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-41 Design: 2M-41wp05 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +EI -W Section Rate Rate Rate (usft) (1) (1) (usl (usft) (usft) (usft) (°HOOus@) (11100usft) (1/100usft) 4,900.00 73.64 280.57 3,460.18 2,121.13 -1,255.25 1,801.82 0.00 0.00 0.00 5,000.00 73.64 280.57 3,488.35 2,138.73 -1,349.57 1,897.29 0.00 0.00 0.00 5,100.00 73.64 280.57 3,516.52 2,156.33 -1,443.89 1,992.75 0.00 0.00 0.00 5,200.00 73.64 280.57 3,544.69 2,173.92 -1,538.22 2,088.21 0.00 0.00 0.00 5,300.00 73.64 260.57 3,572.86 2,191.52 -1,632.54 2,183.67 0.00 0.00 0.00 5,400.00 73.64 280.57 3,601.03 2,209.12 -1,726.86 2,279.13 0.00 0.00 0.00 5,500.00 73.64 280.57 3,629.20 2,226.72 -1,821.19 2,374.59 0.00 0.00 0.00 5,600.00 73.64 280.57 3,657.37 2,244.31 -1,915.51 2,470.05 0.00 0.00 0.00 5,700.00 73.64 280.57 3,685.54 2,261.91 -2,009.83 2,565.51 0.00 0.00 0.00 5,800.00 73.64 280.57 3,713.71 2,279.51 -2,104.15 2,660.97 0.00 0.00 0.00 5,900.00 73.64 280.57 3,741.88 2,297.11 -2,198.48 2,756.43 0.00 0.00 0.00 6,000.00 73.64 280.57 3,770.05 2,314.71 -2,292.80 2,851.90 0.00 0.00 0.00 6,100.00 73.64 280.57 3,798.21 2,332.30 -2,387.12 2,947.36 0.00 0.00 0.00 6,200.00 73.64 280.57 3,826.38 2,349.90 -2,481.45 3,042.82 0.00 0.00 0.00 6,300.00 73.64 280.57 3,854.55 2,367.50 -2,575.77 3,138.28 0.00 0.00 0.00 6,400.00 73.64 280.57 3,882.72 2,385.10 -2,670.09 3,233.74 0.00 0.00 0.00 6,500.00 73.64 280.57 3,910.89 2,402.69 -2,764.42 3,329.20 0.00 0.00 0.00 6,600.00 73.64 280.57 3,939.06 2,420.29 -2,858.74 3,424.66 0.00 0.00 0.00 6,700.00 73.64 280.57 3,967.23 2,437.89 -2,953.06 3,520.12 0.00 0.00 0.00 6,800.00 73.64 280.57 3,995.40 2,455.49 -3,047.38 3,615.58 0.00 0.00 0.00 6,900.00 73.64 280.57 4,023.57 2,473.09 -3,141.71 3,711.05 0.00 0.00 0.00 7,000.00 73.64 280.57 4,051.74 2,490.68 -3,236.03 3,806.51 0.00 0.00 0.00 7,100.00 73.64 280.57 4,079.91 2,508.28 -3,330.35 3,901.97 0.00 0.00 0.00 7,200.00 73.64 280.57 4,108.07 2,525.88 -3,424.68 3,997.43 0.00 0.00 0.00 7,300.00 73.64 280.57 4,136.24 2,543.48 -3,519.00 4,092.89 0.00 0.00 0.00 7,400.00 73.64 280.57 4,164.41 2,561.07 -3,613.32 4,188.35 0.00 0.00 0.00 7,500.00 73.64 280.57 4,192.58 2,578.67 -3,707.64 4,283.81 0.00 0.00 0.00 7,600.00 73.64 280.57 4,220.75 2,596.27 -3,801.97 4,379.27 0.00 0.00 0.00 7,700.00 73.64 280.57 4,248.92 2,613.87 -3,896.29 4,474.73 0.00 0.00 0.00 7,800.00 73.64 280.57 4,277.09 2,631.47 -3,990.61 4,570.19 0.00 0.00 0.00 7,900.00 73.64 280.57 4,305.26 2,649.06 -4,084.94 4,665.66 0.00 0.00 0.00 8,000.00 73.64 280.57 4,333.43 2,666.66 -4,179.26 4,761.12 0.00 0.00 0.00 8,100.00 73.64 280.57 4,361.60 2,684.26 -4,273.58 4,856.58 0.00 0.00 0.00 8,200.00 73.64 280.57 4,389.77 2,701.86 -4,367.91 4,952.04 0.00 0.00 0.00 8,300.00 73.64 280.57 4,417.94 2,719.45 -4,462.23 5,047.50 0.00 0.00 0.00 8,400.00 73.64 280.57 4,446.10 2,737.05 -4,556.55 5,142.96 0.00 0.00 0.00 8,500.00 73.64 280.57 4,474.27 2,754.65 -4,650.87 5,238.42 0.00 0.00 0.00 8,600.00 73.64 280.57 4,502.44 2,772.25 -4,745.20 5,333.88 0.00 0.00 0.00 8,700.00 73.64 280.57 4,530.61 2,789.85 -4,839.52 5,429.34 0.00 0.00 0.00 8,800.00 73.64 280.57 4,558.78 2,807.44 -4,933.84 5,524.81 0.00 0.00 0.00 8,900.00 73.64 280.57 4,586.95 2,625.04 -5,028.17 5,620.27 0.00 0.00 0.00 9,000.00 73.64 280.57 4,615.12 2,842.64 -5,122.49 5,715.73 0.00 0.00 0.00 9,100.00 73.64 280.57 4,643.29 2,860.24 -5,216.81 5,811.19 0.00 0.00 0.00 9,200.00 73.64 280.57 4,671.46 2,877.83 -5,311.13 5,906.65 0.00 0.00 0.00 9,300.00 73.64 280.57 4,699.63 2,895.43 -5,405.46 6,002.11 0.00 0.00 0.00 9,400.00 73.64 280.57 4,727.80 2,913.03 -5,499.78 6,097.57 0.00 0.00 0.00 9,500.00 73.64 280.57 4,755.96 2,930.63 -5,594.10 6,193.03 0.00 0.00 0.00 9,600.00 73.64 280.57 4,784.13 2,948.23 -5,688.43 6,288.49 0.00 0.00 0.00 9,700.00 73.64 280.57 4,812.30 2,965.82 -5,782.75 6,383.95 0.00 0.00 0.00 9,800.00 73.64 280.57 4,840.47 2,983.42 -5,877.07 6,479.42 0.00 0.00 0.00 9,900.00 73.64 280.57 4,868.64 3,001.02 -5,971.40 6,574.88 0.00 0.00 0.00 10,000.00 73.64 280.57 4,896.81 3,018.62 -6,065.72 6,670.34 0.00 0.00 0.00 10,100.00 73.64 280.57 4,924.98 3,036.21 -6,160.04 6,765.80 0.00 0.00 0.00 10.200.00 73.64 280.57 4.953.15 3.053.81 -6.254.36 6.861.26 0.00 0.00 0.00 10/8/2018 1:01:34PM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 2M-41 (19-20) Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Project: Kupamk River Unit MD Reference: Plan: 39+ 105.5 @ 144.50usft (Doyon 142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 210-41 (19-20) Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-41 Design: 2M-41wp05 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +NI -S +E/ -W Section Rate Rate Rate (usft) (^) (1) (usft) (usft) (usft) (usft) ("/t00usft) (°/100usft) (`1100usft) 10,300.00 73.64 280.57 4,981.32 3,071.41 -6,348.69 6,956.72 0.00 0.00 0.00 10,400.00 73.64 280.57 5,009.49 3,089.01 -6,443.01 7,052.18 0.00 0.00 0.00 10,500.00 73.64 280.57 5,037.66 3,106.61 -6,537.33 7,147.64 0.00 0.00 0.00 10,600.00 73.64 280.57 5,065.82 3,124.20 -6,631.66 7,243.10 0.00 0.00 0.00 10,700.00 73.64 280.57 5,093.99 3,141.80 -6,725.98 7,338.57 0.00 0.00 0.00 10,800.00 73.64 280.57 5,122.16 3,159.40 -6,820.30 7,434.03 0.00 0.00 0.00 10,900.00 73.64 280.57 5,150.33 3,177.00 -6,914.63 7,529.49 0.00 0.00 0.00 11,000.00 73.64 280.57 5,178.50 3,194.59 -7,008.95 7,624.95 0.00 0.00 0.00 11,100.00 73.64 280.57 5,206.67 3,212.19 -7,103.27 7,720.41 0.00 0.00 0.00 11,200.00 73.64 280.57 5,234.84 3,229.79 -7,197.59 7,815.87 0.00 0.00 0.00 11,300.00 73.64 280.57 5,263.01 3,247.39 -7,291.92 7,911.33 0.00 0.00 0.00 11,400.00 73.64 280.57 5,291.18 3,264.99 -7,386.24 8,006.79 0.00 0.00 0.00 11,500.00 73.64 280.57 5,319.35 3,282.58 -7,480.56 8,102.25 0.00 0.00 0.00 11,600.00 73.64 280.57 5,347.52 3,300.18 -7,574.89 8,197.71 0.00 0.00 0.00 11,700.00 73.64 280.57 5,375.69 3,317.78 -7,669.21 8,293.18 0.00 0.00 0.00 11,800.00 73.64 280.57 5,403.85 3,335.38 -7,763.53 8,388.64 0.00 0.00 0.00 11,900.00 73.64 280.57 5,432.02 3,352.97 -7,857.85 8,484.10 0.00 0.00 0.00 12,000.00 73.64 280.57 5,460.19 3,370.57 -7,952.18 8,579.56 0.00 0.00 0.00 12,100.00 73.64 280.57 5,488.36 3,388.17 -8,046.50 8,675.02 0.00 0.00 0.00 12,200.00 73.64 280.57 5,516.53 3,405.77 -8,140.82 8,770.48 0.00 0.00 0.00 12,300.00 73.64 280.57 5,544.70 3,423.37 -8,235.15 8,865.94 0.00 0.00 0.00 12,400.00 73.64 280.57 5,572.87 3,440.96 -8,329.47 8,961.40 0.00 0.00 0.00 12,500.00 73.64 280.57 5,601.04 3,458.56 -8,423.79 9,056.86 0.00 0.00 0.00 12,600.00 73.64 280.57 5,629.21 3,476.16 -8,518.12 9,152.33 0.00 0.00 0.00 12,700.00 73.64 280.57 5,657.38 3,493.76 -8,612.44 9,247.79 0.00 0.00 0.00 12,800.00 73.64 280.57 5,685.55 3,511.36 -8,706.76 9,343.25 0.00 0.00 0.00 12,900.00 73.64 280.57 5,713.71 3,528.95 -8,801.08 9,438.71 0.00 0.00 0.00 13,000.00 73.64 280.57 5,741.88 3,546.55 -8,895.41 9,534.17 0.00 0.00 0.00 13,100.00 73.64 280.57 5,770.05 3,564.15 -8,989.73 9,629.63 0.00 0.00 0.00 13,200.00 73.64 280.57 5,798.22 3,581.75 -9,084.05 9,725.09 0.00 0.00 0.00 13,300.00 73.64 280.57 5,826.39 3,599.34 -9,178.38 9,820.55 0.00 0.00 0.00 13,400.00 73.64 280.57 5,854.56 3,616.94 -9,272.70 9,916.01 0.00 0.00 0.00 13,500.00 73.64 280.57 5,882.73 3,634.54 -9,367.02 10,011.47 0.00 0.00 0.00 13,600.00 73.64 280.57 5,910.90 3,652.14 -9,461.34 10,106.94 0.00 0.00 0.00 13,700.00 73.64 280.57 5,939.07 3,669.74 -9,555.67 10,202.40 0.00 0.00 0.00 13,796.69 73.64 280.57 5,966.30 3,686.75 -9,646.86 10,294.69 0.00 0.00 0.00 13,800.00 73.74 280.55 5,967.23 3,687.33 -9,649.99 10,297.86 3.00 2.94 -0.64 13,900.00 76.67 279.92 5,992.77 3,704.50 -9,745.13 10,393.98 3.00 2.94 -0.63 14,000.00 79.61 279.30 6,013.31 3,720.83 -9,841.61 10,491.16 3.00 2.94 -0.62 14,100.00 82.55 278.70 6,028.81 3,736.28 -9,939.18 10,589.12 3.00 2.94 -0.60 14,200.00 85.49 278.10 6,039.22 3,750.81 -10,037.55 10,687.61 3.00 2.94 -0.60 14,217.22 86.00 278.00 6,040.50 3,753.21 -10,054.55 10,704.60 3.00 2.94 -0.59 14,300.00 86.00 278.00 6,046.27 3,764.71 -10,136.33 10,786.30 0.00 0.00 0.00 14,317.22 86.00 278.00 6,047.48 3,767.10 -10,153.34 10,803.29 0.00 0.00 0.00 14,337.22 86.00 278.00 6,048.87 3,769.87 -10,173.09 10,823.03 0.00 0.00 0.00 14,400.00 87.26 278.00 6,052.56 3,778.59 -10,235.16 10,885.04 2.00 2.00 0.00 14,500.00 89.26 277.99 6,055.61 3,792.50 -10,334.14 10,983.93 2.00 2.00 0.00 14,575.90 90.77 277.99 6,055.59 3,803.05 -10,409.30 11,059.02 2.00 2.00 0.00 14,600.00 90.77 277.99 6,055.26 3,806.40 -10,433.16 11,082.86 0.00 0.00 0.00 14,700.00 90.77 277.99 6,053.91 3,820.30 -10,532.18 11,181.79 0.00 0.00 0.00 14,800.00 90.77 277.99 6,052.56 3,834.21 -10,631.20 11,280.71 0.00 0.00 0.00 14,900.00 90.77 277.99 6,051.21 3,848.11 -10,730.22 11,379.64 0.00 0.00 0.00 15,000.00 90.77 277.99 6,049.86 3,862.01 -10,829.24 11,478.57 0.00 0.00 0.00 1082018 1:0134PM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 15,200.00 15,282.33 15,300.00 15,333.95 15,400.00 15,464.34 15,500.00 15,600.00 15,700.00 15,800.00 15,900.00 16,000.00 16,100.00 16,200.00 16,300.00 16,400.00 16,500.00 16,600.00 16,612.60 16,700.00 16,786.50 16,800.00 16,900.00 16,905.69 17,000.00 17,022.22 17,100.00 17,116.41 17,200.00 17,240.82 17,300.00 17,400.00 17,500.00 17,600.00 17,700.00 17,800.00 17,900.00 18,000.00 18,100.00 18,200.00 18,246.69 18,300.00 18,314.95 18,350.69 18,400.00 18,500.00 18,600.00 18,700.00 18,800.00 18,900.00 19,000.00 19,100.00 19,200.00 OAKEDMPI ConocoPhillips (Alaska) Inc. -Kup2 Kupawk River Unit Kupawk 2M Pad Plan: 2M-41 (1320) Plan: 2M-41 2M41wp05 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: 2M-41 (19-20) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Time Minimum Curvature Vertical Dogleg Vertical Tum Section Rate Inclination Azimuth Depth +N/ -S +E/ -W (°/100usft) (°) (°) (usft) (usft) (usft) 0.00 90.77 277.99 6,047.16 3,889.82 -11,027.28 0.05 90.77 277.99 6,046.05 3,901.26 -11,108.80 1.50 90.51 278.00 6,045.85 3,903.72 -11,126.30 0.01 90.00 278.02 6,045.70 3,908.45 -11,159.91 0.00 89.01 278.02 6,046.27 3,917.67 -11,225.32 0.00 88.04 278.03 6,047.93 3,926.65 -11,289.01 0.00 88.04 278.03 6,049.14 3,931.63 -11,324.30 0.00 88.04 278.03 6,052.56 3,945.58 -11,423.26 0.00 88.04 278.03 6,055.97 3,959.54 -11,522.22 0.00 88.04 278.03 6,059.38 3,973.50 -11,621.18 0.00 88.04 278.03 6,062.79 3,987.45 -11,720.15 0.00 88.04 278.03 6,066.21 4,001.41 -11,819.11 88.04 278.03 6,069.62 4,015.37 -11,918.07 4.00 88.04 278.03 6,073.03 4,029.32 -12,017.03 13,356.67 88.04 278.03 6,076.45 4,043.28 -12,115.99 4.00 88.04 278.03 6,079.86 4,057.24 -12,214.96 13,475.85 88.04 278.03 6,083.27 4,071.19 -12,313.92 -4.00 88.04 278.03 6,086.69 4,085.15 -12,412.88 13,650.60 88.04 278.03 6,087.12 4,086.91 -12,425.36 -4.00 91.54 278.02 6,087.43 4,099.11 -12,511.88 13,848.44 95.00 278.02 6,082.50 4,111.16 -12,597.38 0.00 95.54 278.02 6,081.26 4,113.03 -12,610.69 14,145.22 99.54 278.01 6,068.14 4,126.85 -12,708.84 0.00 99.77 278.01 6,067.19 4,127.64 -12,714.40 14,442.00 99.77 278.01 6,051.19 4,140.59 -12,806.43 0.00 99.77 278.01 6,047.42 4,143.64 -12,828.12 14,686.04 96.66 278.02 6,036.31 4,154.37 -12,904.34 -1.50 96.00 278.02 6,034.50 4,156.64 -12,920.49 14,788.94 92.66 278.02 6,028.19 4,168.27 -13,003.01 0.00 91.02 278.02 6,026.88 4,173.96 -13,043.41 15,035.62 91.02 278.02 6,025.82 4,182.21 -13,102.00 0.00 91.02 278.02 6,024.04 4,196.16 -13,201.01 15,332.45 91.02 278.02 6,022.25 4,210.10 -13,300.02 0.00 91.02 278.02 6,020.46 4,224.05 -13,399.02 15,629.29 91.02 278.02 6,018.68 4,237.99 -13,498.03 91.02 278.02 6,016.89 4,251.94 -13,597.04 91.02 278.02 6,015.10 4,265.88 -13,696.04 91.02 278.02 6,013.32 4,279.83 -13,795.05 91.02 278.02 6,011.53 4,293.77 -13,894.06 91.02 278.02 6,009.74 4,307.72 -13,993.07 91.02 278.02 6,008.91 4,314.23 -14,039.29 90.22 278.03 6,008.33 4,321.67 -14,092.08 90.00 278.03 6,008.30 4,323.75 -14,106.88 89.46 278.04 6,008.47 4,328.75 -14,142.27 89.46 278.04 6,008.93 4,335.65 -14,191.09 89.46 276.04 6,009.86 4,349.65 -14,290.10 89.46 278.04 6,010.80 4,363.64 -14,389.11 89.46 278.04 6,011.73 4,377.63 -14,488.13 89.46 278.04 6,012.67 4,391.63 -14,587.14 89.46 278.04 6,013.60 4,405.62 -14,686.15 89.46 278.04 6,014.54 4,419.62 -14,785.16 89.46 278.04 6,015.48 4,433.61 -14,884.17 89.46 278.04 6,016.41 4,447.61 -14,983.18 ConocoPhillips Standard Proposal Report Well Plan: 2M-41 (19-20) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Time Minimum Curvature Vertical Dogleg Build Tum Section Rate Rate Rate (usft) ('1100usn) (°1100usft) (°/100usft) 11,676.42 0.00 0.00 0.00 11,757.87 0.00 0.00 0.00 11,775.35 1.50 -1.50 0.05 11,808.94 1.50 -1.50 0.05 11,874.29 1.50 -1.50 0.01 11,937.93 1.50 -1.50 0.01 11,973.19 0.00 0.00 0.00 12,072.08 0.00 0.00 0.00 12,170.97 0.00 0.00 0.00 12,269.85 0.00 0.00 0.00 12,368.74 0.00 0.00 0.00 12,467.63 0.00 0.00 0.00 12,566.51 0.00 0.00 0.00 12,665.40 0.00 0.00 0.00 12,764.29 0.00 0.00 0.00 12,863.18 0.00 0.00 0.00 12,962.06 0.00 0.00 0.00 13,060.95 0.00 0.00 0.00 13,073.41 0.00 0.00 0.00 13,159.87 4.00 4.00 0.00 13,245.31 4.00 4.00 0.00 13,258.61 4.00 4.00 -0.01 13,356.67 4.00 4.00 -0.01 13,362.23 4.00 4.00 -0.01 13,454.18 0.00 0.00 0.00 13,475.85 0.00 0.00 0.00 13,552.01 4.00 -4.00 0.01 13,568.15 4.00 -4.00 0.01 13,650.60 4.00 -4.00 0.00 13,690.97 4.00 -4.00 0.00 13,749.51 0.00 0.00 0.00 13,848.44 0.00 0.00 0.00 13,947.37 0.00 0.00 0.00 14,046.29 0.00 0.00 0.00 14,145.22 0.00 0.00 0.00 14,244.15 0.00 0.00 0.00 14,343.07 0.00 0.00 0.00 14,442.00 0.00 0.00 0.00 14,549.93 0.00 0.00 0.00 14,639.85 0.00 0.00 0.00 14,686.04 0.00 0.00 0.00 14,738.78 1.50 -1.50 0.02 14,753.58 1.50 -1.50 0.02 14,788.94 1.50 -1.50 0.04 14,837.73 0.00 0.00 0.00 14,936.67 0.00 0.00 0.00 15,035.62 0.00 0.00 0.00 15,134.56 0.00 0.00 0.00 15,233.51 0.00 0.00 0.00 15,332.45 0.00 0.00 0.00 15,431.40 0.00 0.00 0.00 15,530.34 0.00 0.00 0.00 15,629.29 0.00 0.00 0.00 10/8/2018 1:01:34PM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPi Local Co-ordinate Reference: Well Plan: 2M-01(19-20) Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Depth Plan: 39+ 105.5 @ 144.50usft (Doyon 142) Project: Angle Kuparuk River Unit TVD MD Reference: +E/ -W Northing Easting Plan: 39+ 105.5 @ 144.50usft (Doyon 142) Site: (°) Kuparuk 2M Pad (usft) North Reference: 2M41 TO5 020818 JM True Well: 6,008.30 Plan: 2M41 (19-20) -14,106.88 Survey Calculation Method! Minimum Curvature Wellbore: 7.000 Plan: 2M41 19,530.36 - Circle (radius 100.00) 4-1/2x6-1/8 4.500 Design: 2M41wp05 2M-41 TO6 Tae 020818. 0.00 0.00 6,019.50 Planned Survey -15,310.27 - plan hits target center Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +EI -W Section Rate Rate Rate -12,920.49 (usft) (°) (I (usft) (usft) (usft) (usft) (°1100usft) (1100usft) (°/100usft) - Circle (radius 100.00) 19,400.00 89.46 278.04 6,018.28 4,475.59 -15,181.21 15,827.18 0.00 0.00 0.00 0.00 19,500.00 8946 278.04 6,019.22 4,489.59 -15,280.22 15,926.12 0.00 0.00 0.00 19,530.36 8946 278.04 6,019.50 4,493.84 -15,310.27 15,956.16 0.00 0.00 0.00 Design Targets Measured Target Name Casing Hole Depth Depth -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2M41 TO5 020818 JM 0.00 0.00 6,008.30 4,323.75 -14,106.88 - plan hits target center 6,047.48 7" x 8-1/2 by 9-7/8" 7.000 9.875 19,530.36 - Circle (radius 100.00) 4-1/2x6-1/8 4.500 6.125 2M-41 TO6 Tae 020818. 0.00 0.00 6,019.50 4,493.84 -15,310.27 - plan hits target center - Circle (radius 100.00) 2M41 T04020818 JM 0.00 0.00 6,034.50 4,156.64 -12,920.49 - plan hits target center - Circle (radius 100.00) 2M-41 T01 Heel 020818 0.00 0.00 6,040.50 3,753.21 -10,054.55 - plan hits target center - Circle (radius 100.00) 2M41 T02020818 JM 0.00 0.00 6,045.70 3,908.45 -11,159.91 - plan hits target center - Circle (radius 100.00) 2M-41 T03 020818 JM 0.00 0.00 6,082.50 4,111.16 -12,597.38 - plan hits target center - Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (In) 3,016.64 2,640.00 13-3/8 x 16 13.375 16.000 13,172.59 5,790.50 9-5/8 x 12-1/4 9.625 12.250 14,317.22 6,047.48 7" x 8-1/2 by 9-7/8" 7.000 9.875 19,530.36 6,019.50 4-1/2x6-1/8 4.500 6.125 1002018 1:01.34PM Page 9 COMPASS 5000 14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMPI ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-41 (19-20) Plan: 21041 2M41wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: 2M-41 (19-20) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Plan: 39+ 105.5 @ 144.50usft (Doyon 142) True Minimum Curvature Formations Measured Vertical Local Coordinates Depth Measured Vertical +NIS +E/ -W Dip (usft) Depth Depth (usft) (usft) Dip Direction 300.00 (usft) (usft) Name Lithology V) ( ) 400.00 457.51 457.50 T-3 0.67 0.00 500.00 586.53 586.50 K-15 2.01 0.00 600.00 1,500.08 1,484.50 Base Perm 2.67 0.00 800.00 2,097.49 2,018.50 WSaKD 2.67 0.00 1,307.89 2,959.60 2,610.50 Base WS 2.67 0.00 1,411.76 3,693.42 2,983.50 Camp SS 2.67 0.00 3,016.64 7,464.21 4,182.50 C-50 -99.46 0.00 3,036.64 9,228.55 4,679.50 C-37 / Iceberg -101.87 0.00 4,796.58 11,752.59 5,390.50 C-35 -1,157.70 0.00 13,796.69 13,137.09 5,780.50 THRZ -9,646.86 0.00 14,217.22 13,651.84 5,925.50 BHRZ/TKLB -10,054.55 0.00 14,317.22 13,841.76 5,978.50 K-1 -10,153.34 0.00 14,337.22 14,217.22 6,040.50 Top Kuparuk -10,173.09 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +E/ -W (usft) Waft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1 ill OY DLS, 130° TF, for 100' 400.00 399.99 -0.56 0.67 Hold for 100' 500.00 499.98 -1.68 2.01 Start 1'/100' DLS, 180° TF, for 100' 600.00 599.97 -2.24 2.67 Start 1.5°/100' DLS, 0° TF, for 200' 800.00 799.88 2.99 2.67 Start 2.5-/100' DLS, 0° TF, for 507.89' 1,307.89 1,300.00 85.32 2.67 Hold for 103.87' 1,411.76 1,400.00 113.43 2.67 Start 2.75°/100' DLS, -10° TF, for 1604.88' 3,016.64 2,640.00 1,063.56 -99.46 Hold for 20' 3,036.64 2,650.11 1,080.64 -101.87 Start 3.75°/100' DLS, -95.54° TF, for 1759.94' 4,796.58 3,431.05 2,102.93 -1,157.70 Hold for 9000.1' 13,796.69 5,966.30 3,686.75 -9,646.86 Start 3'/100' DLS, -11.81° TF, for 420.53' 14,217.22 6,040.50 3,753.21 -10,054.55 Hold for 100' 14,317.22 6,047.48 3,767.10 -10,153.34 Adjust TF to 0*, for 20' 14,337.22 6,048.87 3,769.87 -10,173.09 Start 2°/100'DLS, -0.1°TF, for 238.69' 14,575.90 6,055.59 3,803.05 -10,409.30 Hold for 706.43' 15,262.33 6,046.05 3,901.26 -11,108.80 Start 1.5°/100' DLS, 177.93' TF, for 51.62' 15,333.95 6,045.70 3,908.45 -11,159.91 Adjust TF to 179.78*, for 130.39' 15,464.34 6,047.93 3,926.65 -11,289.01 Hold for 1148.26' 16,612.60 6,087.12 4,086.91 -12,425.36 Start 4°/100' DLS, -0.06° TF, for 173.9' 16,786.50 6,082.50 4,111.16 -12,597.38 Adjust TF to -0.12°, for 119.19' 16,905.69 6,067.19 4,127.64 -12,714.40 Hold for 116.53' 17,022.22 6,047.42 4,143.64 -12,828.12 Start 4°/100' DLS, 179.85" TF, for 94.19' 17,116.41 6,034.50 4,156.64 -12,920.49 Adjust TF to -179.97', for 124.41' 17,240.82 6,026.88 4,173.96 -13,043.41 Hold for 1005.87' 18,246.69 6,008.91 4,314.23 -14,039.29 Start 1.5°/100' DLS, 179.28° TF, for68.26' 18,314.95 6,008.30 4,323.75 -14,106.88 Adjust TF to 178.41°, for 35.74' 18,350.69 6,008.47 4,328.75 -14,142.27 Hold for 1179.67' 19,530.36 6,019.50 4,493.84 -15,310.27 TD: 19530.36' MD, 6019.5' TVD 10,82018 1:01:34PM Page 10 COMPASS 5000.14 Build 85D AC Summary ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-41 (19-20) Plan: 2M-41 50103xxxxx00 2M-41wp05 ConocoPhillips Clearance Summary Anticollision Report 08 October, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2111(19 -20) -Plan: 2M-41 - 2M-41wp05 Well Coordinates: Datum Height: Plan: 39+ 105.5 @ 144.50usft (Doyon 142) Scan Range: 0.00 to 19,530.36 usft. Measured Depth. Scan Radius is 2,149.14 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 86D Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: ConocoPhillips ConocoPhillips B97.83 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2M-41 (19-20) - 2M-41wp05 351.14 900.00 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Centre Distance Pass - Major Risk Reference Design: Kuparuk 2M Pad -Plan: 2M-41 (19-20) -Plan: 2M-41-2M-41wp05 6,122.76 402.42 Scan Range: 0.00 to 19,630.36 usft. Measured Depth. 258.72 5,400.00 Scan Radius is 2,149.14 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Clearance Factor Pass - Major Risk 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 2M Pad 2M -D5 -2M -05-2M-05 B97.83 372.68 897.83 351.14 900.00 17.305 Centre Distance Pass - Major Risk 2M -05 -2M -05-2M-05 6,122.76 402.42 6,122.76 258.72 5,400.00 2.800 Clearance Factor Pass - Major Risk 2M -D6 -2M -06 -2M -O6 39.10 362.21 39.10 360.88 40.60 271.315 Centre Distance Pass - Major Risk 2M -06 -2M -06 -2M -O6 597.78 366.19 597.78 352.26 600.00 26.305 Clearance Factor Pass - Major Risk 2M -10 -2M -10-2M-10 993.68 295.71 993.68 271.97 1,000.00 12.457 Centre Distance Pass - Major Risk 2M -10 -2M -10-2M-10 1,188.22 298.12 1,188.22 269.43 1,200.00 10.392 Clearance Factor Pass - Major Risk 2M-11 - 2M-11 - 2M-11 296.50 276.76 296.50 270.21 300.00 42.263 Centre Distance Pass - Major Risk 2M-11 - 2M-11 -2M-11 4,362.06 302.02 4,362.08 182.57 4,100.00 2.528 Clearance Factor Pass - Major Risk 2M -12 -2M -12-2M-12 39.00 252.20 39.00 250.86 41.50 189.074 Centre Distance Pass - Major Risk 2M -12 -2M -12-2M-12 1,093.28 - 259.92 1,093.28 233.54 1,100.00 9.854 Clearance Factor Pass - Major Risk 2M -13 -2M -13-2M-13 595.00 159.90 595.00 146.22 600.00 11.668 Centre Distance Pass - Major Risk 2M-13 - 2M-13 - 2M-13 794.28 161.67 794.28 142.98 800.00 8.649 Clearance Factor Pass - Major Risk 2M-14 - 2M-14 - 2M-14 39.00 137.21 39.00 135.87 40.40 102.865 Centre Distance Pass - Major Risk 2M -14 -2M -14-2M-14 596.98 141.85 596.98 127.67 600.00 10.147 Clearance Factor Pass - Major Risk 2M -15 -2M -15-2M-15 296.50 112.16 296.50 105.35 300.00 16.450 Centre Distance Pass -Major Risk 2M -15 -2M -15-2M-15 994.74 113.04 994.74 89.06 1,000.00 4.713 Clearance Factor Pass -Major Risk 2M -16 -2M -16-2M-16 902.97 84.50 902.97 63.12 9D0.00 3.953 Centre Distance Pass -Major Risk 2M -16 -2M -16-2M-16 1,001.65 85.66 1,001.65 61.78 1,000.00 3.586 Clearance Factor Pass -Major Risk 2M -17 -2M -17-2M-17 694.88 59.05 694.88 42.56 700.00 3.582 Clearance Factor Pass - Major Risk 2M -18 -2M -18-2M-18 296.50 37.21 296.50 30.66 300.00 5.676 Centre Distance Pass - Major Risk 2M -18 -2M -18-2M-18 895.74 40.32695.74 900.00 Lggg / Clearance Factor Pass - Major Risk 2M -19 -2M -19-2M-19 396.28 11.79 396.26 2.62 400.00 1.286)Clearance Factor Pass - Major Risk 2M -20 -2M -20-2M-20 39.10 12.41 39.10 40.60 9.292 Centre Distance Pass - Major Risk 2M-20 - 2M-20 - 2M-20 498.64 14.31 498.64 �2.70 500.00 1.233 learence Factor Pass - Major Risk 2M -21 -2M -21-2M-21 39.20 37.56 39.20 36.22 41.70 28.107 Centre Distance Pass - Major Risk 2M -21 -2M -21-2M-21 397.90 38.76 397.90 29.80 400.00 4.325 Clearance Factor Pass - Major Risk 2M -22 -2M -22-2M-22 499.33 62.02 499.33 5D.47 500.00 5.368 Centre Distance Pass - Major Risk 2M -22 -2M -22-2M-22 598.50 62.77 598.50 48.79 600.00 4.491 Clearance Factor Pass - Major Risk 08 October, 2018 - 13:00 Page 2 orb COMPASS ConocoPhillips Anticollision Report for Plan: 2M-41 (19-20) - 2M-41wpO5 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M-41 (19-20) - Plan: 21111-41-2M-41wp06 Scan Range: 0.00 to 19,630.36 usft. Measured Depth. Scan Radius is 2,149.14 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit 08 October, 2018 - 13:00 Page 3 of 6 COMPASS 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 2M -23 -2M -23-2M-23 405.66 86.66 405.66 80.24 400.00 13.502 Centre Distance Pass - Major Risk 2M -23 -2M -23-2M-23 505.56 87.41 505.56 79.52 500.00 11.074 Clearance Factor Pass - Major Risk 2M -24 -2M -24-2M-24 298.49 111.92 298.49 105.03 300.00 16.244 Centre Distance Pass - Major Risk 2M -24 -2M -24-2M-24 400.00 112.47 400.00 103.17 400.00 12.103 Clearance Factor Pass - Major Risk 2M -25 -2M -25-2M-25 39.60 137.61 39.60 136.26 35.10 102.617 Centre Distance Pass - Major Risk 2M -25 -2M -25-2M-25 304.58 138.98 304.58 133.76 300.00 26.628 Clearance Factor Pass - Major Risk 2M -26 -2M -26-2M-26 98.50 153.14 98.50 150.76 100.00 64.352 Centre Distance Pass - Major Risk 2M -26 -2M -26-2M-26 298.46 154.64 298.46 147.77 300.00 22.507 Clearance Factor Pass - Major Risk 2M-31 - 2M-31 - 2M-31 297.50 124.84 297.50 119.97 300.00 25.594 Centre Distance Pass - Major Risk 2M -31 -2M -31-2M-31 697.56 127.09 697.56 116.40 700.00 11.888 Clearance Factor Pass - Major Risk 2M -33 -2M -33-2M-33 39.80 74.78 39.80 73.44 42.30 55.668 Centre Distance Pass - Major Risk 2M -33 -2M -33-2M-33 297.50 75.31 297.50 70.39 300.00 15.292 Clearance Factor Pass - Major Risk 2M -34 -2M -34-2M-34 39.90 49.31 39.90 47.97 42.40 36.677 Centre Distance Pass - Major Risk 2M -34 -2M -34-2M-34 97.50 49.52 97.50 47.41 100.00 23.449 Clearance Factor Pass - Major Risk 2M -35 -2M -35-2M-35 497.16 22.26 497.16 14.15 500.00 2.743 Centre Distance Pass - Major Risk 2M -35 -2M -35-2M-35 696.96 24.00 696.96 12.70 700.00 2.125 Clearance Factor Pass - Major Risk 2M -36 -2M -36-2M-36 43.20 463.73 43.20 462.70 39.49 448.175 Centre Distance Pass - Major Risk 2M -36 -2M -36-2M-36 400.00 466.14 400.00 459.51 400.00 70.264 Clearance Factor Pass - Major Risk 2M -38 -2M -38-2M-38 43.20 82.79 43.20 81.24 29.57 53.400 Centre Distance Pass - Major Risk 2M -38 -2M -38-2M-38 414.63 86.56 414.63 79.24 400.00 11.824 Clearance Factor Pass - Major Risk 08 October, 2018 - 13:00 Page 3 of 6 COMPASS ConocoPhillips Anticollision Report for Plan: 2M-41 (19-20) - 2M-41wp05 Survey tool orouram From To Su,eylPlan Survey Tool (ustt) (us@) 39.00 1,300.00 2M41wp05 GYD-GC-SS 1,300.00 2,300.00 2M-41wp05 MWD 1,300.D0 3,015.00 2M41wp05 MWD+IFR-AK-CAZ-SC 3,015.00 4,515.00 2M-41wp05 MWD 3,015.00 13,170.00 2M-41wp05 MWD+IFR-AK-CAZ-SC 13,170.00 14,315.00 2M41wp05 MWD 13,170.00 14,315.00 2M-41wp05 MWD+IFR-AK-CAZ-SC 14,315.00 15,815.00 2M-41wp05 MWD 14,315.00 19,530.36 2M41wp05 MWD+IFR-AK-CAZ-SC 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. ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit 08 October, 2016 - 13:00 Page 4 of 6 COMPASS 13:13, October OB 2018 2M-41 wp05 Ladder View g{-285 *W) Q 1D � I I 90 N d U 0 N d N L E 95 m m U N Equivalent Magnetic Distance 0 0 2000 4000 6000 8000 10000 12000 14000 Measured Depth SURVEY PROGRAM CASING DETAILS pth From Depth To Survey/Plan Tool TWD MD Nam 39.00 1300.00 2M-41wp05 (Plan: 2M-41) GYD-GC-SS 2640.00 3016.64 13-3/8 x 16 1300.00 2300.00 2M-41wp05 (Plan: 2M-41) MWD 5790.50 13172.59 9-5/8 x 12-1/4 1300.00 3015.00 2M-41wp05 (Plan: 2M-41) MWD+IFR-AK-CAZ-SC 6047.48 14317.220" x 8-1/2 by 9-7/8" 3015.00 4515.00 2M-41wp05 (Plan: 2M-41) MWD 6019.50 19530.36 4-1/2 x 6-1/8 3015.0013170.00 2M-41wp05 (Plan: 2M-41) MWD+IFR-AK-CAZ-SC 13170.00 14315.00 2M-41wp05 (Plan: 2M-41) MWD 13170.0014315.00 2M-41wp05 (Plan: 2M-41) MWD+IFR-AK-CAZ-SC wp an: 2M-41) MVVL) 14315.0019530.36 N N 2M-41wp05 (Plan: 2M-41) MWD+IFR-AK-CAZ-SC m , I 0 ll n N q) �L. X30 ----------- U 0 m q) :cquivalw Magnetic Distance 0 0 550 1100 1650 2200 2750 Partial Measured Depth TC View 2M-41 wp05 39.00 To 19530.36 I Spider casting tzouu usrvin7 Errors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-41 (19-20) 50103xxxxx00 Plan: 2M-41 Plan: 2M-41 wp05 Error Ellipse Survey Report 08 October, 2018 Company: ConocoPhillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Site: Kupamk 2M Pad Well: Plan: 2M41 (19-20) Wellbore: Plan: 210-41 Design: 2M41wp05 Conocolohillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: output errors are at Database: Well Plan: 210-41 (19-20) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMPI Project Kupamk River Unit, North Slope Alaska, United States MWD Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor site Kuparuk 2M Pad Site Position: Northing: Latitude: From: Map Easting; Longitude: Position Uncertainty: 0.00 usft Slot Radius: Grid Convergence: Well Plan: 2M-41 (19-20) MWD MWD - Standard Well Position +NIS 0.00 usft Northing: Latitude: MWD+IFR-AK-CAZ-SC +E1 -W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: Wellbore Plan: 210-41 MWD MWD - Standard Magnetics Model Name Sample Date Declination Dip Angle Field Strength MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC (°I (°l (nT) MWD-IFR-AK-CAZ-SC BGGM2016 12/31/2018 MWD 16.67 80.80 57,417 MWD-IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC Design 2M-41wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) -NIS +EAW Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 286.36 Survey Tool Program Date 9/25/2018 From To (usft) (usft) Survey (Wellbore) 39.00 1,300.00 2M-41wp05 (Plan: 2M41) 1,300.00 2,300.00 2M-41wp05(Plan:2M-41) 1,300.00 3,015.00 2M41wp05(Plan: 2M41) 3,015.00 4,515.00 2M41wp05(Plan: 2M-41) 3,015.00 13,170.00 2M41wp05(Plan: 2M41) 13,170.00 14,315.00 2M41wp05(Plan: 2M41) 13,170.00 14,315.00 2M-41wp05(Plan: 2M41) 14,315.00 15,815.00 2M-41wp05(Plan: 21041) 14,315.00 19,530.36 2M-41wp05(Plan: 2M41) Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC MWD MWD -Standard MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC MWD MWD -Standard MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD -Standard MWD-IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 10/8/2018 1:04: 09PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupawk 2M Pad MD Reference: Well: Plan: 2M-41 (19-20) North Reference: Wellbore: Plan: 2M-41 Survey Calculation Method: Design: 2M41wp05 Output errors are at 2 1,300.00 Database: Plan Survey Tool Program Date 9/25/2018 Depth From Depth To (usft) lush) Survey (Wellbore) Tool Name Remarks 1 39.00 1,300.00 2M-41wp05 (Plan: 2M-41) GYD-GC-SS VeNra1 Nighside Gyrodata gyro single shots 2 1,300.00 2,300.00 2M-41wp05 (Plan: 2M-01) MWD Semi+ninor MWD - Standard 3 1,300.00 3,015.00 2M-41wp05 (Plan: 2M-01) MWD+IFR-AK-CAZ-SC Bias Eno, Blas MWD+IFR AK CAZ SCC 4 3,015.00 4,515.002M-41wp05(Plan: 2M-41) MWD Aalmurh TOD1 !usft) MWD - Standard 5 3,015.00 13,170.00 2M-4lwp05 (Plan: 2M-41) MWD+IFR-AK-CAZ-SC (usal (usft! hiss! MWD+IFR AK CAZ SCC 6 13,170.00 14,315.00 2M-41wp05 (Plan: 2M-01) MWD 39.00 000 MWD - Standard 7 13,170.00 14,315.002M-41wp05(Plan: 2M41) MWD+IFR-AK-CAZ-SC 0.00 0.00 0.00 MWD+IFR AK CAZ SCC 8 14,315.00 15,815.00 2M-41wp05 (Plan: 2M-41) MWD 100.00 0.00 0.00 MWD - Standard 9 14,315.00 19,530.362M-41wp05(Plan: 2M-41) MWD+IFR-AK-CAZ-SC 1.15 0.00 0.00 MWD+IFR AK CAZ SCC Well Plan: 2M-41 (19-20) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Plan: 39 + 105.5 @ 144.50ush (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMPI Position uncertainty and bias at survey station Measured Indinadon blmmh VeNra1 Nighside Utes! Venical Magnkude sem'w jar Semi+ninor Depol Depth Enor Bias Eno, Blas Error Bias Of Bae Emer Error Aalmurh TOD1 !usft) V) n !usft) luaft) (uen) (usal (usft! hiss! loan) (..ft) (ush) luau) (1) 39.00 000 0.00 3900 0.00 0.00 9.00 0.00 0.00 0.00 0.00 0.00 000 0.00 UNDEFINED 100.00 0.00 0.00 100.00 0.04 0.00 0.04 0.00 1.15 0.00 0.00 0.01 0.04 0.00 GYD-GCSS (1, 1) 200.00 0.00 0.00 200.00 0.19 one 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 GYD-GCSS (1, 1) 300.00 0.00 0.00 300.00 0.33 0.00 0,33 0.00 1.15 0.00 0.00 0.33 0.33 0.00 GYD-GGSS(1, 1) 400.00 1.00 130.00 Mass 0.43 0.00 0.43 0.00 1.15 0.01 0.01 0.43 0.43 45.00 GYD-GGSS(1, 1) 500.00 1.00 13000 499.98 0.50 0.00 0.50 0.00 1.15 0.02 0.02 0.50 0.50 45.00 GYD-G6W n. ti 600.00 0.00 0.00 599.97 0.61 0.00 0.61 0.00 1.15 0.03 0.03 0.61 0.61 45.00 GYD-GOSa(1, 1) 700.00 1.50 0100 699.96 0.74 0.00 0.74 0.00 1.16 0.04 004 0.74 0.74 4500 GYD-GCSS(1, 1) 800.00 3.00 0.00 799.88 0.88 0.00 9.88 000 1.16 0.06 0.08 0.88 0.88 00.42 GYD-GC S(1, 1) 900.00 5.50 0.00 899.60 1.01 -0.01 1.02 0.00 1.16 0.08 0.00 1.02 1,02 00.37 GYD-GGSS (1, 1) 1'00.00 8.00 0.00 99800 1.15 -0.01 1.16 0.00 1.16 0Ao 0.10 1.17 1.16 74]8 GY G6SS p, 1) 1,100.00 10.50 0.00 1,097.59 1.29 -0.01 1.32 0.00 1.16 0.12 0.12 1.32 1.31 23.57 GYDAGss(1, 1) 1,200.00 13.00 0.00 1,195.49 1.43 -0.02 1.48 0.00 1.16 0.15 0.15 1.48 1.47 6.26 GYD-GOSS(1, 1) 1,300.00 15.50 0.00 1.282.40 1.50 -0.03 1.58 -0.01 1.15 0.18 0.18 1.58 1.55 3.46 MM (1.2) 1,307.09 15.70 0.00 1900.00 1.50 -0.03 1.59 -0.01 1.15 0.10 0.18 1.59 1.56 3.35 MM (1, 2) 1,400.00 15.70 0.00 1,388.60 1.52 .0.03 1.68 -0.02 1.15 0.21 0.21 1.68 1.57 0.71 Mwo(1, 2) 1,411.76 15.70 0.00 1,400.00 1.52 -0.03 1.70 -0.02 1.15 0.21 0.21 1.70 1.58 0.57 MM (1. 2) 1,500.00 18.09 358.64 1,484.42 1.53 -004 1.88 403 1.15 0.24 0.24 1.06 1.61 179.85 MM n. 2) 10/82018 1:04:09PM Page 3 COMPASS 5000.14 Build 85D Company: ConocoPhillips (Alaska) Inc. -Kup2 Project Kupawk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M41 (19-20) Wellbore: Plan: 210-41 Design: 2M-41wp05 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-41 (19-20) Plan: 39+ 105.5 Q 144.50usft (Doyon 142) Plan: 39 + 105.5 Q 144.50usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMPI Measured M.H.Wion Avmuth Veracal Hlghsile lateroi Ver6n5 Magnitude Bemimalor semiminm Depth Depm Emnr Blas Emar Bias Emor Blas Wei. Emor Error AzimuN Tod (..n) (9 V) (usnl (.ft) (..ft) (urn) (usn) (usn) (..ft) (u.nl (vanl (use) 1'1 1,600.00 20.81 357.47 1,578.71 1.50 -0.05 2.19 -0.05 1.15 0.27 0.28 2.19 1.66 179.13 MWD(1. 2) 1)00.00 23.54 356.58 1.671.30 1.61 -0.08 2.61 -0.08 1.15 0.31 0.33 2.61 1.73 170.41 MWD (1, 2) 1,800.00 28.20 355.83 1,761.99 1.68 -0.08 3.13 -0.11 1.16 0.35 0.37 3.13 1.81 177.82 MM (1. 2) 11900.00 29.01 355.23 1,850.57 136 -0.09 334 -0.16 1.17 0.38 0.43 3.74 1.91 177.27 MM (1, 2) 2,000.00 31.75 35432 1193863 1.87 -0.11 4.43 -0.21 1.19 0.42 0.49 4.43 2.03 176.78 MM (1, 2) 2,100.00 34.49 35429 2,020.57 2.00 -0.13 5.20 -0.27 1.23 0.46 0.58 5.20 2.16 176.35 MM (1, 2) 2,200.00 37.23 353.91 2,101.61 2.14 -0.15 6.04 -0.35 1.29 0.50 0.64 864 2.29 175.96 MVJD(1. 2) 2.300.00 39.97 353.58 2,179.75 2.30 4.10 6.95 -OA3 1.37 0.54 0.73 6.95 2.44 175.61 MWD(1, 2) 2,400.00 42.72 353.29 2,254.02 1.88 -0.21 3.50 0.01 1.22 0.57 0.62 3.50 2.16 173.57 MVr9+IFR-AK4:AZSC(2,2) 2,500.00 45.46 353.02 2,326.64 1.95 -0.24 3.87 0.01 1.27 0.61 0.67 3.87 2.24 17334 MW IFR-AK-CAZ-SC(2,2) 2,600.00 48.20 352.78 2,395.05 2.03 -0.27 4.26 0.01 1.32 0.65 032 4.26 2.32 173.14 MWD+IFR-AK-CA-SC(2,2) 2,700.00 50.95 352.55 2.459.09 2.11 -0.31 4.68 0.01 1.39 0.68 0.77 4.68 2.40 172.96 MMAFR-AK-CA -SC (2. 2) 2,800.00 53.69 352.35 2,521.01 2.20 -0.34 5.12 0.02 1.47 0.71 0.82 5.12 2.48 172.81 MWD+IFR-AR-CA -SC (2. 2) 2,900.00 56.44 352.15 2,578.27 2.28 -0.38 5.58 0.02 1.58 034 0.88 5.50 2.55 172.67 MWD+1FR-AK-CAZSC(2, 2) 3,000.00 59.48 351.97 2,631.53 2.37 -0.41 6.06 0.02 1.88 0.77 0.91 668 2.62 172.56 MWD+IFR-AK-CA2-SC(2. 2) 3,016.64 59.64 351.94 2,64060 237 -0.42 6.15 0.00 1.61 0.78 0.92 6.15 2.70 172.50 MM (2, 3) 3,036.64 59.84 351.94 2,650.11 2.37 -0.42 6.26 -0.03 1.61 0.78 0.93 6.26 2.70 172.60 1A4YD(2,3) 3,100.00 59.44 349.20 2,682.23 2.39 -042 6.66 -0.13 1.63 0.00 0.97 6.87 2.71 172.56 RAM (2.3) 3200.00 $9.24 314.84 2,733.24 2.48 -0.40 7.39 4.29 130 0.83 1.08 7.0 232 171.95 MWD (2, 3) 3.300.00 50.19 340.48 2,784.44 2.62 4.39 6.24 .0.48 161 0,86 1.19 8.35 236 170.75 MWD (2, 3) 3,400.00 59.28 338.12 2,835.61 2.83 437 9.15 -0.69 1.95 0.88 136 9.37 2.01 169.11 MM (2, 3) 3,500.00 59.52 331.77 2,808.53 3.10 -0.34 10.11 .0.92 2.12 0.91 1.57 10.46 2.88 167.20 MWD (2, 3) 3.600.00 59.90 327.45 2.936.98 3.42 -0.31 11.10 -1.16 2.31 0.95 1.81 11.61 2.98 165AI WM (2,3) 3,700.00 60.43 323.17 2,986.75 3.77 -0.28 12.09 -1.42 2.52 0.98 2.08 12.79 3.09 162.91 1AWD(2,3) 3,000.00 61.08 318.94 3,035.62 4.16 -0.24 13.07 4.69 234 1.01 2.37 14.01 3.23 180.65 MM (2, 3) 3.900.00 61.87 314.76 3,083.39 4.58 -0.20 14.04 -1.97 2.97 1.04 2.69 15.25 3.38 158.35 MM C2.3) 4,000.00 62.78 310.65 3129.05 4.96 .0.16 15.00 -2.26 322 1.07 3.03 16.51 3.54 156.02 MWD (2.3) 4,100.00 63.81 306.62 3,174.79 5.36 -0.12 15.93 -2.55 3.48 1.09 140 17.79 3.72 153.69 MM (2. 3) 4,200.00 64.911 302.66 3,218.04 535 4.09 16.83 -2.86 335 1.12 3.77 19.07 3.90 151.35 MWD(2. 3) 4,300AD 66.20 298.77 3,259.40 6.11 -0.08 17.70 -3.16 4.03 1.15 4.17 20.36 4.09 149.03 MWD (2, 3) 4,400.00 67.54 294.96 3,298.69 6.45 -0.04 18.54 -3.47 4.31 1.17 4.57 21.64 4.29 148.72 MM (2, 3) 4.500.00 68.97 291.23 3,33536 635 -0.03 19.4 -3.77 4.61 1.20 4.99 22.92 4.49 144.43 KIM (2. 3) 4,600.0 70A7 287.57 3,370.43 3.90 -0.85 8.55 0.86 2.06 1.22 1.74 11.07 3.85 150.24 MWD+1FR-AK-GA SC(3,3) 4,700A0 72.05 283.98 3.402.55 3.94 -0.90 8.66 0.91 3.00 1.24 138 11.42 3.99 148.07 MWD+IFR-AK-CAZ C(3,3) 4,786.58 73.64 280.57 3,431.05 3.97 -0,95 836 0.97 3.13 1.26 1.03 11.76 4.13 145.98 MW0+1FR-AK-CA-5G(3,3) 4,000.00 73.64 280.57 3,432.02 3.97 -0.95 838 0.97 3.13 1.26 1.83 11.72 4.13 145.91 VM+IFR-AK-CAZ-SC(3, 3) 4,900.00 73.64 280.57 3,480.18 4.09 -0.95 9.30 097 3.28 1.28 1.07 12.12 4.27 143.80 MV IFR-AK-CAZ-SC(3, 3) 51000.00 73.64 280.57 3.400.35 4.22 -0.95 9.83 0.97 3.62 1.29 1.91 12.69 4.40 141.78 MMAFR-AK-CA -SC (3, 3) 5,100.00 7364 280.57 3,516.52 4.34 4.95 10.37 0.97 3.57 1.31 1.96 12.88 4.53 130,86 MWD+IFR-AK-CA -SC (3,3) 5,200.00 73.84 280.57 3,544.69 4.48 -0.95 10.92 0.97 3.72 1.33 201 13.20 4.65 138.03 MVWD+1FR-AK-CA -SC (3,3) 5,300.00 73.64 280.57 3,572.86 4.61 -0.95 11.46 0.97 3.87 135 2.05 13.70 4.77 136.30 MWD+IFR-AK-CA2 C(3,3) 5,400.00 73.64 280.57 3,601.03 435 -0.95 12.02 0.97 4.03 1.37 2.10 14.13 4.88 134.68 MWD+IFR-AK-CAZSC(3,3) 5,500.00 73.64 200.57 3,629.20 4.89 -0.95 12.57 0.97 4.18 1.38 2.15 1458 4.98 133.15 MDMA R -AK -CA -W(3,3) 5,600.00 73.64 280.57 3,657.37 5.03 -0.95 13.13 0.97 4.34 1.40 2.21 15.03 5.00 131.71 MMAFR-AK-CAZ-SC (3, 3) 5,700.00 73.64 280.57 3,685.54 5.17 -0.95 1369 0.97 4.49 1.42 2.26 15.50 5.18 130.37 MWD+IFR-AK-CAZSC (3,3) 5,800.00 73.64 280.57 3,713.71 5.32 -0.95 1426 0.97 4.85 1.44 2.32 15.97 5.26 129.11 MM -IFR -AK -CA -Sc (3.3) 5,900.00 7364 280.57 3,741.88 5.47 -0.95 14.82 0.97 4.81 1.46 2.37 16.46 5.35 127.93 MM+IFR-AK-CAZSC(3,3) 6.000.00 73.64 280.57 3,770.05 5.62 -0.95 1589 0.97 4.97 1.48 2.43 16.95 5.42 126.83 MWD+IFR-AK-0A2-SC(3,3) 11,100.00 73.64 280.57 3.798.21 537 -0.95 15.96 0.97 5.13 1.50 2.49 1745 5.50 125.79 MWDNFR-AK-CA-SC (3,3) 6,200.00 73.64 280.57 3,828.30 5.92 -0.95 16.53 0.97 5.29 1.52 2.55 17.96 5.57 124.63 MAVAFR-AK-CA .W (3,3) 6,300.00 73.64 280.57 3,854.55 6.07 -0.95 17.11 0.97 5.45 1.54 2.61 10.47 5.64 123.92 MM+1FR-AK-0ALSC(3,3) 8,400.00 73fi4 280.57 3.882.72 6.23 4.95 17.88 0.97 5.61 156 2.60 18.99 5.70 12107 MVMAFR-AK-CA -SC (3,3) 8,500.00 73.84 280.57 3,910.89 6.38 -0.95 18.26 0.97 537 1.58 234 19.51 536 122.27 MWD+1FR-AK-CA .8C (3,3) 6,600.00 73.64 280.57 3,939.06 6.54 -0.95 18.83 0.97 5.93 1.80 2.81 20.04 5.82 121.52 MWD+IFR-AK-CAZSC(3, 3) 10/82018 1:04:09PM Page 4 COMPASS 5000.14 Build 85D Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupafuk River Unit Site: Kupawk 2M Pad Well: Plan: 2M-41 (19-20) Wellbore: Plan: 2M-41 Design: 2M41wp05 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-41 (19-20) Plan: 39+ 105.5 CD2 144.50usR (Doyon 142) Plan: 39+ 105.5 @ 144,50usR (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMPI Measured Whiled.. Avmuth V¢NCAI Hi9hside Laterat Vertical Magnitude semimajor semiminor DepM Dean Erne Bias Enor Bias En. Blas of aiaz Emr E. Azimuth Tool (.n) 19 41 luso) lural luso) loan) (usa) lusnl loan) loan) loan) (oan) C) 6]00.00 73.64 280.57 3,967.23 6.70 -0.95 1941 0.97 809 1.63 287 20.57 5.88 120.81 MWD+IFR41<-CAZSC (3, 3) 6.800.00 73.64 280.57 3.99540 8.88 -0.95 19.99 0.97 6.25 1.65 2.94 21.11 5.91 120.15 MWD+IFR-AK-CA -SG (3, 3) 6,900.00 73.6,1 280.57 4,023.57 7.02 -095 20.57 0.97 6.42 1.67 3.01 21.65 5.98 119.52 MWD+IFR-AK-CA-SC(3. 3) 7,000.00 73.64 280.57 4,051.74 7.18 -elai 21.15 0.97 6.58 1,89 348 22.19 6.04 118.93 MMAFR-AKZC -SC (3. 3) 7,100.00 73.64 2869 4,079.91 T34 4.95 21.73 0.97 6.74 1.71 3.15 22.74 6.09 118.37 MVA+IFR-AK-CR-SC(3,3) 7,200,00 73.64 280.57 4,108.07 7.50 4.95 22.31 0.97 6.91 174 3.22 23.28 6.14 117.84 MWD -IFR -AK -CA -SC (3, 3) 7,300.00 73.64 280.57 4,136.24 7.66 -0.95 22.89 0.97 7.07 1.76 3.29 23,84 6.19 117.34 MWD+1FR-AK-GA -SC (3, 3) 7,400.00 73.64 280.57 4.164.41 7,83 -0.95 2347 0,97 T24 1.78 3.37 24.39 6.23 116.87 MWD+1FR-AK-CA-SC(3,3) 7.500.00 73.64 280.57 4,192.58 7.99 -0.95 24.06 0.97 7.40 1.80 3.44 24.94 6.20 116.41 MWDHFR-AK-CA-SC(3,3) 7,600.00 73.64 280.57 4,220.75 0.15 -0.95 24.64 0.97 7.57 1.83 3.52 25.50 6.32 115.99 MWDNFR-AK-CAZ G(3,3) 7.700,00 73.64 280.57 4,248.92 0.32 -0.95 25.22 0.97 7.73 1.85 3.60 26.06 6.37 115.58 MWD+IFR-AK-CAZ C(3,3) 00609 73.64 280.57 4,277.09 8.48 -0.95 25.81 0.97 7.90 187 3.67 26.62 6.41 115.19 MWD+IFR-MK- SC (3, 3) 7,900.00 73,6,1 280.9 4,305,26 8.65 -0.95 26.39 0.97 &M 1.90 3.75 27.18 6.45 114.82 MWDHFR-AK-C -SG (3, 3) 8,000.00 73.64 280.57 4,333.43 8.81 -0.95 26.98 087 8.23 1.92 3.03 27.74 6.49 114.47 MWDAFR-AK-CA 4iC(3.3) 8,100.00 73.64 280.57 4,351.60 a98 -0.95 27.56 0.97 8.39 1.95 3.91 28.31 6.54 114.13 MWD+IFR-AK-0A-SC (3.3) 8,200.00 73.8,1 280.57 4,38937 9.15 4.95 28.15 0.97 am 1.97 3.99 28.87 6,58 113.81 MWD+IFR-AK-C -SC (3,3) 8,300.00 73.64 280.57 4,417.94 9.31 4.95 28.73 0.97 872 2.00 4.08 29.44 6.62 11150 MWD+IFR-AK-C -SC (3.3) 8,400.00 73.64 280.57 4,446.10 948 .0.95 29.32 097 8.89 2.02 4.16 30.01 6.66 113.20 MWD+IFR-AK-CA-SC (3.3) 8,500.00 73.64 280.57 4,474.27 9.65 -0.95 29.90 0.97 905 2.05 425 30.58 6,70 112.92 MVA+IFR-AK-GA-SC(3,3) 8,600.00 73.64 280.57 4,502.44 9.82 -0.95 30,49 0,97 9,22 2.07 d 33 31.15 6.74 112.65 MND+IFR-AK-CAZSC (3,3) 8,700.00 73.84 28057 4,530.61 9,98 495 31,08 0.97 9.39 2.10 4.42 31.72 6.7 112.39 MM -IFR -AK -CA -SC (3;3) 8,000.00 73A4 280,57 4,558.78 10.15 -0.95 31.66 0.97 8.55 2.12 4.50 32.29 6,01 112.14 MAD+IFR-AK-CA-SC(3,3) 0,900.00 73.64 280.57 4,586.95 10.32 -0.95 32.25 0.97 972 215 4,59 32.86 6.85 111.90 MM+IFR-AK-GA-SG(3,3) 9,000.00 73,84 280.57 4,61612 10.49 -0.95 32.84 0.97 9.09 2.18 4.68 33.43 6.89 111.67 MWD+1FR-AK-CA-SC(3,3) 9,100.00 7364 280.57 4,643.29 lode -0.95 33.42 0.97 10.05 2.20 4.77 34.01 6.93 111.45 MWD+IFR-AK-CA -SG (3. 3) 9.200.00 73.641 280.57 4,671.46 10.83 4.95 34.01 0.97 10.22 2.23 4.86 34.58 6.97 111.23 MW IFR -AK -CA C(3,3) 9,300.00 73.64 2811.57 4,899,53 11.00 -0.95 34.60 0.97 10.39 226 4.95 35.16 7.00 111.03 MND+IFR-AK-C -SC (3,3) 9,400.00 73.64 2811.57 4,727,80 11.17 4.95 35.19 0.00 10.55 2.28 5.05 35.73 7.04 110.83 MWD+IFR-AK-CA -SC (3,3) 9.500.00 73.64 280.57 4]5596 11.34 41.95 3537 0.97 10.72 2.31 5.14 36.31 7.08 110.64 MWD+IFR-AK-C -SC (3.3) 9,600.00 7384 280.57 4,784.13 11.51 4.95 36.38 0.97 10.89 2.34 5.23 36.89 7.12 110.45 MWD+IFR-AK-C -SC (3,3) 9,700.00 73.64 280.57 4,812.30 11.68 -0.95 3695 0.97 11.05 2.38 5133 37.47 7.16 110.27 MWDMFR-AK-CA -SC (3.3) 9,800.00 73.64 280.57 4,840.47 11.85 .0.95 37.6,1 0.97 11.22 2.39 5.42 38.476 7.19 110.10 MWD+1FR-AK-CA2-SC (3,3) 9,900.00 73841 280.57 4,880.8,1 12.02 -0.95 38.13 0.97 11.39 2.42 5.52 38.62 7.23 109.93 MWD+IFR-AK-CA-SC (3,3) 10,000.00 73.64 280.57 4,896.01 12.19 -0.95 38,71 0.97 11.55 2.45 5.62 39.20 7.27 109.77 MWD+IFR-AK-CA-W(3,3) 10,100.00 73.84 280.57 4,924.98 12.36 -0.95 39.30 0,97 1132 2.60 5.72 39.78 7.31 109.61 MWD+IFR-AK-CAZSC(3,3) 10,200.00 73.64 280.57 6953.15 12.53 -0.95 39.89 0.97 11.89 2.51 5.62 40.36 7.34 109.46 MWD+1FR-AK-CA-SC (3,3) 10,300.00 73.64 280.57 4,981.32 12.70 -0.95 40.48 0.97 12.06 2.54 5.92 40.94 7.38 109.31 MM -IFR -AK -GA -SG (3,3) 10.100.00 73.64 280.57 5,009.49 12.87 -0.95 41.07 0.00 12.22 2.56 6.02 41.52 7.42 109.17 MWD+1FR-AK-CA-SC(13) 10,50000 73+64 280,57 5,037,66 13.04 -0.95 41.66 0.97 12.39 2.59 6.12 42.10 7.46 109.03 MM+IFR-AK-CAASC(3,3) 16600.00 73.64 200.57 5,05.82 13.22 -0.95 42.25 0.97 12.55 2.62 6.22 42.68 7.50 108.90 MVA+IFR-M(-CAZ SC (3,3) 10,700,00 73.64 200.57 5.09399 13.39 -0,95 42.8,1 0.00 12.72 285 6.32 43.27 7.53 100]7 MM+IFR-AK-CAZSC(3,3) 16000.00 73,84 280,57 5,122.16 13.56 -0.95 43.43 0.97 12.89 2.68 6.43 43.85 7.57 108.64 MM -IFR -AR -CA -SG (3,3) 10,900.00 73.64 200.57 5,150.33 13.73 -0.95 44.02 0.97 13.06 2.71 6.53 44.43 7.61 108.52 MVA+IFR-AK-CA 4iC(3,3) 11,000.00 73.64 200,57 51178.50 13.90 -0.95 44.61 0.97 13.23 2.74 6.64 45.01 7.65 106.40 MV0+1FR-AK-CASC(3,3) 11,100.00 73.64 280.57 5,206.67 14.07 -0.95 45.19 0.97 13.39 2.77 6.76 4580 7.68 108.20 MW0+1FR-AK-CASC(3,3) 11,200.00 73.64 280.9 5,234.64 14.25 -0.95 45.70 0.97 13.56 2.81 6.85 46.18 7.72 108.17 MWD+IFR-AK-CA 4iC(3,3) 11,300.00 73.6,1 280.9 5,263,01 14.42 -0.95 46.37 0.97 13.73 2.84 6.96 46.76 7.76 108,08 MWD+IFR-AK-CA-SC(3, 3) 11,400.00 73.64 280.57 5,291.10 14.59 4.95 46.96 0.97 13.90 2.87 7.07 47,34 7.80 107.95 MWDNFR-AK-CASG(3,3) 11,500.00 7164 280.57 5.319.35 14.76 -0.95 47.55 0.97 14.07 2.90 7.18 47.93 7.84 107.84 MMAFR-MA -SC (3.3) 11.00.00 73.89 280.57 5,30.52 14.94 -0.95 48.14 0.97 14.23 2.93 7.29 48.51 7.88 107.74 MWD+IFR-AK-C -SC (3, 3) 11,70000 73.64 280.57 5,375.69 15.11 -0.95 48.73 0.97 14.40 2.98 7.40 4ell) 7.92 107.64 MWD+IFR-AK-C -SC (3,3) 11,800.00 7364 280.57 5,403.85 15.28 -0.95 49.32 0.97 14.57 3.00 7.52 49.60 7.95 107.55 MWD+IFR-ML -SC (3.3) 11,900.00 73.64 280.57 5,432.02 15.45 -0.95 49.91 0.97 14.74 3.03 7.83 5027 7.99 107.45 MWD+IFR-AK-CA -SC (3,3) 12,000.00 73.84 280.57 5,460.19 15.63 -0.95 Sew 097 14.90 3.06 7.74 50.85 8.03 107,36 MWD+IFR-AKLA-SC (3,3) 10562018 1:04.09PM Page 5 COMPASS 5000.14 Build 85D Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupawk 2M Pad Well: Plan: 2M-41 (19-20) Wellbore: Plan: 2M-41 Design: 2M41wp05 Position uncertainty and blas at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-41 (19-20) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMPI Mosured Inclination Azimuth Vertical Highsiae W..1 Venloal Mlifl uile Semi+lmlor Sami+nlnor onset Depth Error Bias Error Bliss Error Blas of Blas Error Enor Aalmuth Tod luartl PI PI (usnl loon) lush) (usnt (uan) (ase) willo (um) loon) lush) fl 12.100.00 73.64 280.57 5,488.36 15.80 -0.95 51.09 0.97 15.07 3.09 7W 5100 607 107.27 MW IFR-AK-CAZ-SC(3, 3) 12,200.00 73.64 280.52 5,516.53 15.97 -0.95 51.68 0.97 15.24 3.13 7.92 52.02 8.11 107.18 MWD.IFR-AK-CAZSC(3,3) 12,300.00 23.64 200.52 5,511]0 18,15 -095 52.22 0.92 15.01 3.16 809 52.61 8.15 102.10 MM+1FR-AI(-CAZ-SC(3, 3) 12,100.00 23.64 280.52 5572.82 16.32 -0.95 52.86 0.02 15.58 3.19 8.21 53.19 8.19 102.01 Mw -IFR-AK-0AZ-SC (3, 3) 12,50000 73.64 280.52 5,601+04 16.49 -0.95 53.45 0.92 15.74 3.23 8.32 53.78 8.23 100.93 MW IFR-AK-CAZ-SC(3,3) 12,600.00 73.64 280.57 5,629.21 16.66 -0.95 54.04 e97 15.91 3.28 844 54.36 0.22 106.85 MM+1FR-AK-CAZSC(3, 3) 12,700.00 73.64 280.52 5,652.38 16.84 -0.95 54.63 0.97 16.08 3.29 8.56 54.95 8.31 106.22 MM+1FR-AK-CAZ-SC(3, 3) 12,8110.00 73.61 280.57 5,685.55 12.01 4.95 5522 0.92 16.25 3.33 8.68 55.53 8.35 108.20 MWD.IFR-AK-CAZ-SC(3, 3) 12,90000 23.64 280.52 5,713.71 17.18 -0.95 55.81 0.97 16.42 3.36 8.80 56.12 8.39 106.62 MW IFR-AK-CAZ-SC(3,3) 13,000.00 73.64 280.57 5.241.08 17.36 -0.95 56.40 0.97 16.58 3.40 8.92 56]1 8.43 106.55 MM+IFR-AK-CAZSC (1,3) 13,100.00 73.64 280.57 5,270.05 12.53 -0.95 52.00 0.97 16.25 3.43 9.05 57.29 8.42 106.48 MIND+IFR-AK-CP-SC (3,3) 13.2011.00 73.61 280.57 5,298.22 12.62 4.95 52.60 070 16.83 3.47 9.15 52.90 8.65 108.48 MM (3,4) 13,300,00 73.64 280.57 5,826.39 1]63 -0.95 58.25 0.18 16.83 3.50 9.25 sem 8.63 106,46 MM (3. 4) 13,400.00 73.64 280.52 5,854.56 17.64 -0.95 58.94 -0.35 16.85 3.54 9.38 59.24 8.81 106.43 MWD (3,4) 13,500.00 73.84 280.57 5,802.73 12.66 -0.95 Was -0.88 16.87 3.52 9.54 59.97 8.60 106.39 MWD(], 4) 13,600,00 73.64 280.57 5.910.90 17.68 -0.95 60.43 -1.41 16.89 3.61 9.73 60.23 659 106.35 MM (3.4) 13,200.00 23.81 280.52 5,939.07 12.22 -0.95 61,23 4.93 16.93 3.65 9.94 61.53 8.58 1(6.29 MWD(3,4) 13,296.69 73.64 280.52 5,986.30 17.22 -0.95 62.03 -844 16.97 3.68 10.12 6233 8.58 108.24 MWD(3.4) 13,80000 23.24 280.55 5,967.23 17.77 -0.97 62.06 -2.46 16.97 3.68 10.18 62.36 0.58 106.24 MWD(3,4) 13,900.00 76.82 229.92 5,992.77 12]4 -167 62.86 -2.89 17.02 372 less 63.22 8.59 106.17 MM (3,4) 14,000.00 79.61 279.30 6,043.31 17.69 -1.92 63.89 -3.34 17.07 374 1021 64.13 8.59 10509 MWD (3,4) 14,1(600 82.55 278.20 6,028.81 17.62 -2.48 64.55 -3.29 17.14 3.76 10.99 65.07 8.59 106.00 MIK) (3.4) 14,200.00 85.49 278.10 6.039.22 17.52 -2.99 65.44 425 1721 3.n 11.29 sees 8.80 105.89 MWD(3,4) 14217.22 MAI) 228.00 6,010.50 12.50 -3.08 65.60 -4.33 12.22 3.22 11.34 66.21 0.60 105.82 MAD (3.4) 14,300.00 86.00 228.00 6,046.22 12.57 -3.08 66.44 -4.80 12.29 3.77 11.59 62.04 8.61 105.22 MM (3.4) 14,312.22 88.00 278.00 6,042.48 12.21 .3.09 59.46 1.34 16.93 3.77 10.46 fi0w 8.22 106.34 MM (4, 5) 14,33722 86.00 278.00 6,048.87 17.21 -3.09 59.60 1.23 18.93 378 10.46 60.22 8.71 106.33 MM (4. 5) 14,000.00 8226 278.00 6.052.56 17.13 41.31 60.04 0.87 16.9"1 3.28 10.48 Was 8.69 106.29 MM (4. 5) 14,500.00 89.26 222.99 5055.61 12.00 -3.65 60.72 ow 16.95 3.28 10.53. 61.39 867 106.23 MM (4, 5) 14,575.90 90.n 227.99 6,055.59 16.90 -3.91 61.36 -0.13 16.% 3.78 Iew 61.97 8.65 106.17 MM (4, 5) 14.600.00 90.22 277.99 6,055.26 16.91 -3.91 61.54 427 16.92 3.28 10.60 62.16 865 106.15 MM (4, 5) 14.200.00 90.22 277.99 6,053.91 16.93 -391 62.35 4).84 Islas 3.28 10.70 62.97 8.63 106.06 MWD(4,5) 14,800.00 90.22 2n.99 5052.56 16.97 -3.91 63.20 -1.41 17.03 318 10.83 6300 0.63 105.97 MM (4.5) 14,900.00 90]2 222.99 8,051.21 12.01 -3.91 64.08 0.98 12.02 378 10.99 64.67 8.62 105.82 MM (4, 5) 15,000.00 90.7 277.99 6,049.88 17.06 5.91 84.99 -2.54 17.12 3.78 Mill 65.58 8.63 105.77 MM (4, 5) 15,100.00 90.22 277.99 6048.51 12.12 -3.91 65.93 -3.11 12.18 3.78 11.39 65.51 8.63 105.88 MM (4. 5) 15,200.00 90.77 277.99 6.017.16 17.19 -3.91 66.90 -3.66 17.24 3n 11.63 67.48 8.64 105.54 MWD(4,5) 15.282.33 90.27 2.99 6,046.05 12.25 -3.91 67.22 -4.15 17.30 377 11.84 6829 8.65 105.45 MWD (4, 5) 15130000 90.51 278.00 6,045.85 12.28 41.82 87.90 -4.25 17.32 3.77 11.89 68.47 8.66 105.43 MM (4, 5) 15.333.95 90.03 278.02 6,045]0 17.34 .377 68.25 4.45 17.34 3.77 11.98 68.81 8.66 105ae MWD (4, 5) 15,40000 89.01 27802 6,046.27 17.47 -3.59 68.93 4.83 17AO 372 12.17 69.48 8.68 105.31 MWD(4,5) 15,464.84 88.04 278.03 6,047.93 17.59 -3.41 69.60 5.19 17.45 378 12.37 20.15 8.69 105.24 MWD(4,5) 15,500.00 Item 228.03 6,049.14 17.62 -3.11 69.98 -5.40 17.49 378 12.48 20.52 670 105.20 MWD(4, 5) 15,600.00 88.00 278.03 6,052.55 17.72 -3.41 71.06 -5.92 17.53 370 12.81 71.59 8.72 105.08 MWD(4, 5) 15,200.00 we" 228.03 6.055.97 17.82 -3.41 22.16 -8.53 17.68 3.28 13.15 72.68 8.25 104.96 MWD (4, 5) 15,800.00 0804 228.03 6,059.38 17.93 -3.41 73.28 -2.10 12.79 3.29 13.52 73.80 8.27 104.83 MM (4. 5) 15,90000 8804 278.03 6.062.79 17.31 -3.41 63.16 1.38 17.17 379 11.62 6376 876 105.96 MWD+IFR-AK-CU-SC(5, 5) 16,000.00 88.04 228.03 8,088.21 12.30 -3.41 63.43 1.38 12.20 379 11.75 64.03 en 105.92 MW +IFR-AK-CAZ-SC(5,5) 161100.00 88.04 278.03 6,069.62 17.32 41.41 63.71 1.38 17.23 379 11.83 64.311 878 105.89 MWDAFR-AK-CAZ-SC(55) leMe0 Net 278.03 6.073.03 12.41 0.41 63.99 1.38 17.27 3.80 11.91 64.58 8.79 105.86 MWD+IFR-AK-CAZSC(5,5) 16,300.00 68.04 278.03 6,076.45 17.44 -3.41 64.28 1.38 17.30 3.80 12.00 "As 8.60 105.82 MWD+IFR-AK-CA-SG(5,5) 16,400.00 88.04 278.03 6,079.88 12.48 -3.41 61,58 1.38 17.34 3so 1800 65.15 0.81 105.79 MM.IFR-AK-CA -SC (5, 5) 16,500.00 Sees 228.03 8,083.27 17.52 -3.41 Use 1,38 12.38 3.81 12.16 65.4 8.82 105.25 MM+IFR-AK-CA -SC (5, 5) 18,600.00 88.04 228.03 6,086.60 12.56 5.41 65.15 1.38 17.42 3.81 12.25 65.23 8.84 105.71 MWDNFR-AK-CAZ-SC(5, 5) 10/8/2018 1:04:09PM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well Plan: 21VI-41 (19-20) Project: Kuparuk River Unit TVD Reference: Plan: 39+ 105.5 @ 144,50usft (Doyon 142) Site: Kuparuk 2M Pad MD Reference: Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Well: Plan: 2M-41 (19-20) North Reference: True Wellbore: Plan: 2M-41 Survey Calculation Method: Minimum Curvature Design: 2M-41wp05 Output errors are at 1.00 sigma Depth Database: OAKEDMPI Position uncertainty and bias at survey station Measured Wh..lion Aalmmh wm,sl HiIhsi& Labral vertical Magnitu8 Semimajor Seml+ninor Dept Depth Error Bias Error alas Error Blas o1Bus Error ERor Azimuth Tool (usft) (°i (°) (usin (usm (usft) (usa) (usn) (ush) (usft) (usft) (usfi) (.aft) (°I 16,612.50 88.04 27803 6,087.12 17.57 -3,41 65.19 1.38 17.43 3.81 1226 6577 8.84 105.71 MWD+1FR-AK-CP-SC(5, 5) 16.700.00 91.54 278.02 6,087.43 17.35 4.12 65.45 138 17.47 3.81 12.32 %.03 0.85 105.68 MM -IFR -AK -CA -W(5, 5) 18,785.50 95.00 278.02 6082.50 17.10 4.81 65.71 1.38 17.50 3.81 12.38 66.29 8.86 105.64 MM+IFR-AK4: -SC (5. 5) 16,800.00 95.54 278.02 6,081.26 17.06 4.92 65.75 1.38 17.51 3.81 12.38 %.33 8.86 105.64 MWDNFR-AK-CA-SC(5, 5) 16.900.00 99.54 278.01 6,068.14 16.73 -5.69 66.05 1.39 17.56 3.00 12.43 66.63 8.87 105.60 MWD+1FR-AK-CA-W(5, 5) 16,905.69 99.77 278.01 6087.19 16.71 -534 68.07 1.39 17.56 3.80 12.43 %.65 8.87 105.60 MWD+1FR-AK-CAZSC(5, 5) 17,000.00 99.77 27801 6,051.19 1636 -534 66.36 1.39 17.60 339 12.47 saw 8.88 105.57 MND+1FR-AK-CA-SC(5, 5) 17,02232 0.77 278.01 6047.42 16.77 -534 %.43 1.39 17.61 339 12.47 6700 8.89 10558 MWD+1FR-AI6CALSC (5, 5) 17,100.00 %.66 278.02 6,0311.31 17.10 -5.13 66.67 Lia 17.65 338 12.51 67.24 8.90 105.53 MM -IFR -AK -CA -SC (5. 5) 17,116.41 96.00 278.02 8,034.50 17.17 -5.00 8832 1.38 17.66 338 12.51 67.29 8.90 105.52 MWD+1FR-AK-CA-SC(5, 5) 17.20000 92.86 278.02 6,028.19 17.50 4.33 Base 1.38 17.70 3.78 12.% 67.55 8.91 105.49 MWD+IFR-AK-CALSC(5, 5) 17,240.82 91.02 278.02 6,026.88 17.65 5.99 67.11 138 17.72 338 12.59 67.67 8.92 105.47 MWD+IFR-AK-CA -SC (5, 5) 17,30000 91.02 278.02 6,025.82 17.68 -3.99 67.30 1.38 1736 338 12.63 67.86 8.93 105.45 MM -IFR -AK -CA -SC (5, 5) 17,400.W 91.02 218.02 6,024.04 17.74 -3.99 67.63 1.38 17.01 338 12.70 68.18 8.94 105.41 MWn4FR-AK-CA -SC (5, 5) 17,500.00 91.02 278.02 9022.25 17.79 -3.99 67.95 1.38 17.87 338 12.77 68.51 8.96 105.37 MWD+1FR-AK-CA -SC (5, 5) 17,600.00 91.02 278.02 6,020.48 17.85 5.99 68.28 1.38 17.92 3.77 12.64 68.83 8.98 105.33 MM+IFR-AWCAZSC(S. 5) 17,700.00 91.02 278.02 6,018.68 17.91 -399 68.62 1.38 17.90 In 12.91 69.16 8.99 105.29 MWD+IFR-AK-CA -SC (5, 5) 17,000.00 91.02 278.02 so16.89 17.97 -3.99 68.95 1.38 18.05 337 12.98 69.50 9.01 105.25 MWD+1FR-AK-CAZSC(5, 5) 17,900.00 91.02 278.02 6.015.10 18.03 -3.99 69.20 1.38 18.11 337 13.05 69.84 9.03 105.21 MM+IFR-AK-CA-SC(5, 6) 18,00000 91.02 278.02 6013.32 18.10 -3.99 69.64 1.38 10.17 3.T7 13.12 70.18 9.05 105.17 MWD+1FR-AK-CA-SC(5,5) 18,10000 91.02 278.02 6,011.53 18.17 -3.99 69.98 1.38 18.24 337 13.19 70.52 9.% 105.13 MM -IFR -AK -CA -SG (5, 5) 1$200.00 91.02 278.02 6.00934 18.23 -3.99 70.33 1.38 18.31 3.T7 13.26 70.86 9.08 105,09 MWD+1FR-AK-CA -SC (5, 5) 18,246.69 91.02 278.02 6,008.91 18.26 -3.99 70.50 1.30 10.34 3.77 13.30 71.03 9.09 105.07 MWD+IFR-AK-CA -SC (5, 5) 19300.00 9e22 278.03 6,008.33 18.36 -3.82 70.69 1.38 18.37 3T/ 13.34 71.21 9.10 105.05 MWD+1FR-AK-CAZSC(5, 5) 16.314.95 90.00 278.03 6,008.30 18.39 -3.77 70.74 1.38 18.39 337 13.35 71.26 9.10 10504 MWD+IFR-AR-CAZ C(5. 5) 18,3W.69 89.46 98.04 6,008.47 18.45 -3.65 70.87 1.30 18.41 3.77 13.37 71.39 9.11 105.03 MWD+1FR-AK-CA -SC (5, 5) 18.400.00 89.46 278.04 6,008.93 18.48 .3.65 71.04 1.38 18.44 337 13.41 71.56 9.12 105.01 MM+IFR-AKCA-SC(5. 5) 1950000 89.46 278.04 6,009.86 18.55 -3.65 71.40 1.38 18.52 3.A 13.49 71.91 9.14 104.96MWD+1FR-AK-CA-SC(5, 51 18.auaw 89.46 98.04 9010.80 18.83 5,65 71.76 1.30 18,59 337 13.57 72.27 9.16 104.92 MWD+IFR-AK-CA-SC(5,5) 18.700W 89.48 278.04 6,011.73 18.70 5.65 72.12 1.38 18.66 337 13.64 72.63 9.18 1NA5 MM -IFR -AK -CA -SC (5.5) 18,WO.W 8s,16 278.04 6,012.67 18.78 -3.85 72.49 1.38 18.74 In 43.72 73.00 9.20 104.84 MWD+IFR-AK-CA -SC (5. 5) 18.900.00 89.46 98.04 6,013.60 18.85 5.65 72.86 1.38 18.82 337 1380 73.36 9.22 104.W MWD+1FR-AK-CAZSC(5, 5) 1900.00 89.46 278.04 6,014.54 18.93 -3.66 73.23 1.38 18.W 3.77 13.88 7333 9.24 10436 MM+IFR-AK-CAZ C(5, 5) 19,1o0.W 89.46 278.04 6,015A8 19.01 -3.65 73.61 1.38 10.90 In 1396 74.10 9.28 104.71 MND+IFR-AK-CAZ C(5, 5) 19,200.W 89.46 278.04 6,016.41 19.09 -3.65 73.98 1.38 19.% 177 14.03 74.47 9.28 104.87 MWD+1FR-AK-CA-SC(5, 5) 19.W0.W 39.46 278.04 6,017.35 19.18 -3.65 74.36 1.38 19.14 337 14.11 74.85 9.30 104.63 MM -IFR -AK -CA -SC (5, 5) 19.00.00 89.46 278.04 9018.28 19.26 -3.65 74.75 1.38 19.23 In 14.19 75.23 9.32 1114.59 MWD+1FR-AK-0AZSC (5, 5) 19,500011 89.46 98.04 9019.22 19.35 -3.65 75.13 1.38 19.31 377 14.27 75.61 9.34 104.55 MWD+1FR-AK-CA-SC(5, 5) 18.53038 89.46 278.04 6,019.50 19.37 -3.65 75.25 1.38 19.34 337 14.29 75.72 9.35 104.64 MM+IFR-AK-CAZSC (5, 5) 101811018 1: 04: 09PM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M-41 (19-20) Wellbore: Plan: 2M-41 Design: 2M-41wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 210-41 (19-20) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) Plan: 39 + 105.5 @ 144.50usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP1 Design Targets Measured Vertical Dip Target Name Depth Dip Direction (usft) -hit/misstarget Dip Angle Dip Dir. TVD +N/S +E/ -W Northing Easting -Shape (°) (1) lush) (usft) (usft) Wait) (usft) Latitude Longitude 2M41 T05020818 JM 0.00 0.00 6,008.30 4,323.75 -14,106.88 0.00 - plan hits target center 2,097.49 2,018.50 W SaK D 0.00 - Circle (radius 100.00) 2,610.50 Base WS 0.00 3,693.42 2M-41 TO6 Toe 020818. 0.00 0.00 6,019.50 4,493.84 -15,310.27 4,182.50 - plan hits target center 0.00 9,228.55 4,679.50 C-37 / Iceberg - Circle (radius 100.00) 11,752.59 5,390.50 C-35 0.00 2M-41 T04020818 JM 0.00 0.00 6,034.50 4,156.64 -12,920.49 - plan hits target center 5,925.50 BHRZ/TKLB 0.00 13,841.76 - Circle (radius 100.00) K-1 0.00 14,217.22 6,040.50 2M41 T01 Heel 020818 0.00 0.00 6,040.50 3,753.21 -10,054.55 - plan hits target center - Circle (radius 100.00) 2M-41 T02020818 JM 0.00 0.00 6,045.70 3,908.45 -11,159.91 - plan hits target center -Circle (radius 100.00) 2M41 T03 020818 JM 0.00 0.00 6,082.50 4,111.16 -12,597.38 - plan hits target center - Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 3,016.64 2,640.00 13-3/8 x 16 13.375 16.000 13,17259 5,790.50 9-5/8x12-1/4 9.625 12.250 14,31T22 6,047.48 7' x 8-1/2 by 9-7/8" 7.000 9.875 19,530.36 6,019.50 4-1/2x6-1/8 4.500 6.125 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 0 19 457.51 457.50 T-3 0.00 586.53 586.50 K-15 0.00 1,500.08 1,484.50 Base Perm 0.00 2,097.49 2,018.50 W SaK D 0.00 2,959.60 2,610.50 Base WS 0.00 3,693.42 2,983.50 Camp SS 0.00 7,464.21 4,182.50 C-50 0.00 9,228.55 4,679.50 C-37 / Iceberg 0.00 11,752.59 5,390.50 C-35 0.00 13,137.09 5,780.50 THRZ 0.00 13,651.84 5,925.50 BHRZ/TKLB 0.00 13,841.76 5,978.50 K-1 0.00 14,217.22 6,040.50 Top Kuparuk 0.00 10/82018 1:04 09PM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M41 (19-20) Project: Kupamk River Unit TVD Reference: Plan: 39+ 105.5 @ 144.50usR (Doyon 142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+ 105.5 @ 144.50usft (Doyon 142) Well: Plan: 2M41 (19-20) North Reference: True Wellbore: Plan 2M41 Survey Calculation Method: Minimum Curvature Design: 2M-41wp05 Output errors are at 1.00 sigma 400.00 399.99 Database: OAKEDMP7 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1 °/100' DLS, 130° TF, for 100' 400.00 399.99 -0.56 0.67 Hold for 100' 500.00 499.98 -1.68 2.01 Start 1°/100' DLS, 180° TF, for 100' 600.00 599.97 -2.24 2.67 Start 1.50/100' DLS, 0° TF, for 200' 800.00 799.88 2.99 2.67 Start 2.5°/100' DLS, 0° TF, for 507.89' 1,307.89 1,300.00 85.32 2.67 Hold for 103.87' 1,411.76 1,400.00 113.43 2.67 Start 2.75°/100' DLS, -10° TF, for 1604.88' 3,016.64 2,640.00 1,063.56 -99.46 Hold for 20' 3,036.64 2,650.11 1,080.64 -101.87 Start 3.75'/100' DLS, -95.54° TF, for 1759.94' 4,796.58 3,431.05 2,102.93 -1,157.70 Hold for 9000.1' 13,796.69 5,966.30 3,686.75 -9,646.86 Start 3"/100' DLS, -11.81' TF, for 420.53' 14,217.22 6,040.50 3,753.21 -10,054.55 Hold for 100' 14,317.22 6,047.48 3,767.10 -10,153.34 Adjust TF to 0', for 20' 14,337.22 6,048.87 3,769.87 -10,173.09 Start 2°/100'DLS, -0.1"TF, for 238.69' 14,575.90 6,055.59 3,803.05 -10,409.30 Hold for 706.43' 15,282.33 6,046.05 3,901.26 -11,108.80 Start 1.5°/100'DLS, 177.93' TF, for 51.62' 15,333.95 6,045.70 3,908.45 -11,159.91 Adjust TF to 179.78°, for 130.39' 15,464.34 6,047.93 3,926.65 -11,289.01 Hold for 1148.26' 16,612.60 6,087.12 4,086.91 -12,425.36 Start 4-/100' DLS, -0.06° TF, for 173.9' 16,786.50 6,082.50 4,111.16 -12,597.38 Adjust TF to-0.12°,for 119.19' 16,905.69 6,067.19 4,127.64 -12,714.40 Hold for 116.53' 17,022.22 6,047.42 4,143.64 -12,828.12 Start 4.1100' DLS, 179.85* TF, for 94.19' 17,116.41 6,034.50 4,156.64 -12,920.49 Adjust TF to -179.97°, for 124.41' 17,240.82 6,026.86 4,173.96 -13,043.41 Hold for 1005.87' 18,246.69 6,008.91 4,314.23 -14,039.29 Start 1.5°/100' DLS, 179.28°TF, for 68.26' 18,314.95 6,008.30 4,323.75 -14,106.88 Adjust TF to 178.41', for 35.74' 18,350.69 6,008.47 4,328.75 -14,142.27 Hold for 1179.67' 19,530.36 6,019.50 4,493.84 -15,310.27 TO: 19530.36' MD, 6019.5' TVD Checked By: Approved By: Date: 101812018 1:04:09PM Page 9 COMPASS 5000.14 Build 85D Pool Report 7-22 It A LLMA F2M-711 0 C - .-.._...._. EM �3:�� OCiOVCf ��B WELLWRE TARGET DETAILS,MAP CC RDINATES. 2M-41 wp05 Name ND 56�a 2M<1 TW HW JM BOa0.50 Ci�de (Nffiw: 1320.00) Quarter Mile View 2", IM02MIBJM 6WC " GRds ,AWN :1320.001 2Ma1 703020810 JM 6002.50 CIMSIRedlus: 1326.061 2NA176{020618 JM 60.10.56 Ckde(RW..: 1326.00, 2l TW 020010 JM 6008.30 Cktls (RSElus: 1320.00) 21M1TO6T 62CB1B JM 6019.50 Code (Rad'u5: 132606) AC Wells Only 00.0 9000- ,S6000- 0 000 6000 y qp�O M 000� 3000---- 0 000 O a� s Z s y i 0 2�.2 N� p0 -3000 - ti X000 4i 0 3g�0� 1 -6000 °?�`� ,00 4200 4 -18000 -15000 -12000 -9000-60P30 -3000 0 3000 6000 WELLBORE TARGET DETAU (MAR CO RDINAMM 13:28, October 082016 2M-41wp05 Neme TVD simO 2M.41 TW1 Ned020JM 6040.50 Clyde lReduc: 1320.001 1M4tT@020BiB JMM 6045]0 C4Ge 1AeGu6: 1320.001 Quarter Mile View 2 4 T03020BIa JM 008250 CIde(ReWlus: 1320.00) 2N441704020818 JM 6034.50 Cde(ReOiuc: 1320.00) NT 705020018 JM 600830 Cilde(Rwius: 1320.00) 2M41 TN Toe 020018 JM 6D19.50 Gild. (Raduc: 1320,W) All Wells �ry 9000 � Y N 19, N 2,0 a� sY I zM-2 r -6000 __ .__ 42100 2M-19 ?4.p O �, ry 2M, g O Co --3000- If -3000 .f CIE N l O a p® -3000® a00�44) Op 9000 -6000 �0p0 dy1, 4200 _ A -18000 -15000 -12000 -9000 6 �z���P� 3000 35 0 3000 6000 U) 0 0 0 3000 -3000 -18000 -15000 -12000 -9000 WELLBORE TARGET DETAILS (MAP COORDINATES) Name WD snap W41 TD1 Heel 020818 JM 6040.50 Cede (RAJiva: 132D.00) 2M41 T02 020018 JM 8045.79 Cade ffl G.s: 1329.0) 2M41 T0302081 B JM 600260 Cirde(Re@us: 1320.00) 2M 1 704 02081 a JM 603450 Gid.(Redus: 1320.0) 2" 705020810 JM 6000.30 cide(Ra .;1320.0) 2"1 T06 T 020810 JM 6019.0 Cirde M.fts: 1320.00) All Wells - Encroachment Only c� soh mb T t%VA 1 - V o a N C �. / S900 `�SP�A ?y�B® �coop qq -6000 -3000 0 3000 6000 2M-41WP05 Surface Location Q CPAI Coordinate Converter From. ___ ____- To Datum: NpD83 Regionalaska Datum: NAD27 Region: alaska r Latitude/Longitude DecimalDegrees i f Latitude/Longitude jDacirnalDegrees r UTM Zone: I — r South T UTM Zone: True r South F State Plane Zone: I' J Units: us4t Slate Wane Zane: �� Units: uslt + r Legal Description (NAD27 on(yl C Legal Description (NAD27 only) Starting Coordinates: ---- K' 11628314.50 I Ending Coordinates:---- — X: 488281.625458335 i Y: 594873600 Y: 5948985.90825892 . i ......----..___...._.._.............._ Transorm � Quit Help 12M-41WP05 Surface Location I t� CPA? Coo -d inate Com.erter � I From Datum: NAD83 Region: alaska —� * Latdude/Longitude IDecimalDegmes —� f UTM Zone: F— f— South G Slate Plane Zone: 14 Units: us{[ Starting Coordinates: x: 1628314.50 j Y: 594873600 To Datum: NAD27 Region: alaska (' Lafitude)Longitude Decimal Degrees C UTM Zone: True f— South ( Stale Plane Zom F4 Units: us -Ft C Legal Description (NAD27 only] Legal Description Township: 011 Kil Range: 008 Meridian: IV Section:27 FNL 5165.4696 FEL + 4838.6403 Trensfoim 4ud Help 2M-41WP05 Surface Casing ®, CPAICoordinate From. - - -- Datum: NAD83 Region: alaska • Latitude/Longitude IDecimal Degrees • UTM Zone: r— r South C State Plane Zone: �q � Units: us -ft i Legal Description (NAD27 only) Starling Coordinates: To:---_ _ Datum: FNA—D-27--_--]Region alaska r Latitude/Longitude Decimal Degrees r UTM Zone: True 1- South C Stale Plane Zone: �� Units: us -ft r Legal Description )NAD27 o*) -- -- Ending X: 1628216.76 Y: 5949799.61 ......_..T ianslo!m .......... X: 488183.901936974 Y: 5950049.50099743 Quit Help J -J 12M-41WP05 Surface Casing I M CPA1Coordinate From. To: ---. --- _ 1 Datum: NAD83 Region:alaska - Datum NAD27 Region: alaska I Latitude/Longitude recimal Degrees C Latitude/Longitude IDecimalDegFees C' UTM Zone:1 r South r UTM Zone: True r South C State Plane Zone: [4----:,D Units: us� i C State Plane Zone: r4--:-:] Units:usit C Legal Description (NAD27 only) Starting Coordinates, -- -- �- Legal Description----------- - X: 11828216.76 Township: 011 I" J Range: P I` J Y: 15949799.61 Meridian: I" J Section:27 fNL 4101.9077 FEL - 4935.8530 Transform Quit_ _ Help 2M-41WP05 Production Horizon ®. CPA1 Coordinate From: Datum: NAD83 Region: alaska t Lalitude/-ongitude Dec -al Degrees r UTM Zone: F—r- South G State Plane Zone: f q Units: us -R C' Legal Description (NAD27 only) To: Datum: NAD27 Region alaska !" Latilude'Longitude IDecimalDegees, C' UTM Zone: True r South C• State Plane Zone: F--,:-] Uretr. us -ft - T Legal Description (NAD27 only) Starting Coordnates --- -- -- --� Ending Coordinates: X'. 1618267.00 Y: 5952505.00 X: 478234.029096995 Y: 5952755.03326385 ........ ....._.._.........._..._---.._......_., I i.....__.......Transfoon Quit Help 12M-41WP05 Production Horizon I M CPA! 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Coordinate Converser OIL- FTOM _.-... -_- _.... - To: Datum: INAD82 Regionalaska Datum: Npp27 Region: alaska f' LatRude/Longilude IDecimalDegfeas f Latitude/Longitude IDecimalDegrees * UTM Zone: r- r South C UTM Zone: True r South G State Plane Zone.!' -1 Units: us-I[ f" State Plane Zone j Units: fu-, Ft * I s-.aoiption (f sHD - G Legal Description (NAD27 only) Starting Coordinates: Legal Description X 1613013 Township: 011 P`.J Range: 0o8 FE-_-:] Y: 5953254 Meridian: JU Sectior[ 30 - - - ----------... ___ - FNL 686.22371 FEL 4299.6619 it Transform I Quit Help Tollerable Collision Risk Worksheet As -built Z_* I mu sa i i i 94 A AR R a A.'AeA=p uvatrxs R .vi+ DRILL SITE 2M Scope Overview • 2P.4-39(Inj)—Grassroots Water Injection' Well • Located 5' south of injection well 211-09 (LISI), requires well to be P&A' d • Twinned well, tie-in to f)a.:dineto injection wel1211-06 • Welito be pre -produced usingexisting production tie-ins • Well houses 2.1-09 and 2r+1-08to be replaced with narrow (12'-3") style :•cell houses • 21+40(Prod)— Grassroots Gas Lifted Production Well • Located5'n orth of production well 21-4-05 (LISI), requires ellto be P&A'd Rein to 211-05; 2rA-27 flaxline • Use manifold slot for 2l.1-05, convert to production service • Requires tripling of.ve021427 with tsvinnedwater and gas MAGI injection wells 2lA-OVO4 Well houses ZM-05 and 211-06 to be replaced with narrow (12'-3") style well houses • 211-41(Prod)— Grassroots Gas Lifted Production well • Located between wells 21419 an d 210-20. • Tie in to manifold slot for 2M. 35, convert to production sw.,ice • 21+35 flocaines require replacement dueto corrosion 21,1-35 slot subsidence will require repair before installing neer 2M-41 production line • hlew12'4' Nide-well house required • All wells limited to drill dglioyon 142 dueto:•:ell spacing tnrtocoPful6ps Haagen Dazs Necessary Plan Request (NPR) Appendix ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30' of horizontal inclination AND drilling within 30' of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges ■ Tier 1 (Standard): ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations 2M-41 Drilling Hazards Summary 16" Surface Section - 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Stuck Pipe Low Reduced pump rate and low mud temperatures. Additions Gas Hydrates Low of ScreenKleen. Abnormal Reservoir Pressure Moderate Offset well 2M-36 experienced severe mud loss and 2M - 38 had minor losses. Ensure enough lost circulation Lost Circulation Moderate material on location. Reduce drilling ROP and trip speed when necessary. Lost Circulation Moderate Reduce tripping speed, proper hole filling (use of trip Hole swabbing on trips Moderate sheets), pump out of hole if necessary. Monitor real time surveys closely, run gyro survey to Anti -Collision Low eliminate magnetic interference from nearby wells when needed. mud temperatures as low as possible, minimize Washouts / Hole Sloughing ModerateKeep circulating time when possible 12-1/4" INTRM 1 Section - 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Keep good hole cleaning practices, monitor ECD via Stuck Pipe Low PWD and torque/drag real time The Iceberg formation pressure is estimated to be Abnormal Reservoir Pressure Moderate 10.1ppg. Weight up mud to 10.3 ppg before drill into Iceberg formation. Monitor ECD to below expected formation fracture gradient. Prepare enough lost circulation material on Lost Circulation Moderate location. Reduce drilling ROP and trip speed when necessary. Perform OH FIT if necessary. tripping speed, proper hole filling (use of trip Hole swabbing on trips ModerateReduce sheets), pump out of hole if necessary. 2M-41 Drilling Hazards Summary.docx 1117/2018 10:46:14 AM 8-1/2"x9-7/8" INTRM2 Section -7" Liner Hazard Risk Level Mitigation Strate Keep good hole cleaning practices, monitor ECD and Stuck Pipe Low torque/drag real time. Maintain constant bottom hole Abnormal Reservoir Pressure Moderate ressure with MPD. The intermediate II section is penetrating into the reservoir of Kuparuk C, which is estimated to be up to 12.0 Abnormal Reservoir Pressure Moderate ppg. Utilize MPD for shale stability and pore pressure management. Shut in nearby injectors to prevent pore Lost Circulation Moderate ressure rise. Differential Sticking Low Monitor real time equivalent circulating density (ECD) to below expected formation fracture gradient. Prepare Lost Circulation Moderate enough lost circulation material on location. Reduce drillin ROP and trip seed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, proper hole filling (use of trip Hole swabbing on trips Moderate sheets , um out of hole if necessary 6-3/4" Production Section - 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy The reservoir pore pressure of Kuparuk C is estimated to be 9.0-12.0 ppg. Utilize MPD to manage and ensure Abnormal Reservoir Pressure Moderate wellbore overbalance. Shut in nearby injectors to prevent ore ressure rise. Keep good hole cleaning practices, use PWD tools Stuck Pipe Low monitoring, stabilized BHA Reduced pump rates, mud rheology, use LCM program, Lost Circulation Moderate control ECD below expected fracture gradient Differential Sticking Low Follow mud program, keep pipe moving when able Monitor T&D real time for early signs of issues, properly Getting Liner to bottom Moderate clean hole prior to pulling out of hole to run liner. Use proper tripping speed, monitor proper hole fill (use Hole swabbing on trips Moderate of trip sheets), pumping or backreaming out if necessar 2M-41 Drilling Hazards SuMMary.docx 1 V7/2018 10:46:14 AM Loepp, Victoria T (DOA) From: Woodard, Madeline E < Made] ine.E.Woodard@conocophilIips.com> Sent: Monday, November 26, 2018 3:00 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: 21V-41 Tubing (PTD 218-151) Attachments: 2M-41 Schematic_wp05_v2.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, I am hoping you meant wellbore schematic? I wasn't too sure on WBS, let me know if I misinterpreted. I also only see the change needing to be made in the procedure (step 34). Thanks, Madeline From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Monday, November 26, 2018 11:56 AM To: Woodard, Madeline E <Madeline.E.Woodard@conocophiIlips.com> Subject: [EXTERNAL]RE: 2M-41 Tubing (PTD 218-151) I can change it by hand; do send(email) a revised WBS. I see the change in the procedure and on the WBS. Let me know where else. Thanx, Victoria From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Sent: Monday, November 26, 2018 11:41 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Subject: 2M-41 Tubing (PTD 218-151) Victoria, There was a change in the upper completion plan and we will run 3-1/2" 8RD ELIE rather than the 3-1/2" hydril 563 as written in the application. Would you like me to change it on the 401 form and in the application and send back to you? I am unsure on steps forward for a change like this. Thanks, Madeline Woodard Drilling Engineer ConocoPhillips Alaska, Inc Office: 907-265-6086 Mobile: 907-764-8095 Loepp, Victoria T (DOA) From: Hayden, Philip <Philip.Hayden@conocophillips.com> Sent: Monday, November 26, 2018 2:43 PM To: Bearden, J Daniel; Loepp, Victoria T (DOA) Cc: Brunswick, Scott A, Woodard, Madeline E Subject: RE: [EXTERNAL]RE: KRU 2M-41(PTD 218-151) GMTU MT6-07(PTD 218-154) Anti - collision Analysis Follow Up Flag: Follow up Flag Status: Flagged Thanks Dan. Madeline Woodard has been in touch with me already concerning this and we are working on it. Regards Philip From: Bearden, J Daniel Sent: Monday, November 26, 2018 1:40 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com>; Hayden, Philip <Philip.Hayden@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2M-41(PTD 218-151) GMTU MT6-07(PTD 218-154) Anti -collision Analysis Hi Victoria, I've changed positions, but the folks CC'd will be able to help out with providing the technical basis for our AC analysis. Hope all is well, Daniel Bearden Planning Coordinator — Global Wells ConocoPhillips 281-293-1449 work 907-602-7068 cell From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Sent: Monday, November 26, 2018 2:40 PM To: Bearden, J Daniel <J Daniel. Bearden conocophillips.com> Subject: [EXTERNAL]RE: KRU 2M-41(PTD 218-151) GMTU MT6-07(PTD 218-154) Anti -collision Analysis Randy is out of the office. Should this be directed to you or someone else? Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Monday, November 26, 2018 11:18 AM To: Kanady, Randall B (Randall.B.Kanady@conocophillips.com) <Randall.B.Kanadv@conocophillips.com> Cc: Polasek, Tom G <Tom.G Polasek@conocophillips.com>; 'Woodard, Madeline E' <Madeline.E.Woodard(n@conocophiIIips.com> Subject: KRU 2M-41(PTD 218-151) GMTU MT6-07(PTD 218-154) Anti -collision Analysis Randy, Please provide a review of the technical basis, calculations, risk analysis for the anti -collision analysis and the CPAI criteria for pass/fail major risk. Also the TCR analysis. We are also interested in the close approach in the two subject wells while drilling the surface hole around 500'. Our staff is available on Wed(11/28) or Thurs(11/29) to review. 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(c)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 Loeoo@alaska aov From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Sent: Monday, November 26, 2018 10:00 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: RE: [EXTERNAL]KRU 2M-41(PTD 218-151) GMTU MT6-07(PTD 218-154) Anti -collision Victoria, It is based on clearance factor. Anything greater than 1.0 does not require a TCR. We did not do a TCR for 2M-41, it was put on the well plan as a suggestion by the well planner, but because the separation factor between 2M-19 and 2M-20 are greater than 1.0 it is not needed. Madeline From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Monday, November 26, 2018 9:29 AM To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Cc: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]KRU 2M-41(PTD 218-151) GMTU MT6-07(PTD 218-154) Anti -collision Madeline, Tom, What is the criteria in the anti -collision analysis for a pass -major risk? That is, is it based on clearance factor? For the drilling of KRU 2M-41, a TCRW was performed. Please provide analysis and results. The concern is the close approach to offset wells while drilling the surface hole, MT6-07 may have a diverter waiver. There appears to be no intention of shutting in offset wells/setting deep plug while drilling the surface holes. 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 LoePD(rDalaska.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 Loeoo@alaska aov From: Woodard, Madeline E <Madeline E Woodard@conocophi Ili ps.com> Sent: Monday, November 26, 2018 7:17 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Cc: Polasek, Tom G <Tom G Polasek@conocophillips.com> Subject: RE: [EXTERNAL]KRU 2M-41(PTD 218-151) Anti -collision Victoria, "Our best practices and guidelines for major risk failures can be summarized as follows: In case of major risk failure the well path must be changed. If that is not possible then the well must be minor risked by the use of mitigating measures such as shutting in, setting a deep plug, using alternative surveying techniques, etc. If either of these is not possible then the well cannot be drilled." Thanks, Madeline From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Sent: Tuesday, November 20, 2018 2:44 PM To: Woodard, Madeline E <Madeline E Woodard@conocophillips.com> Subject: RE: [EXTERNAL]KRU 2M-41(PTD 218-151) Anti -collision Tom, Madeline, Please provide CPAI's best practices and guidelines for major risk failures on the anti -collision report submitted with the PTDs. I am sending this to both of you concerning your grassroots PTDs. Thanx, Victoria From: Woodard, Madeline E <Madeline E.Wooda rd CcDconocophillips.com> Sent: Monday, November 19, 2018 3:50 PM To: Loepp, Victoria T (DOA) <victoria loepp@alaska.eov> Subject: RE: [EXTERNAL]KRU 2M-41(PTD 218-151) Hi Victoria, Sorry about that. This has the correct TVD and target reservoir. Please let me know if you need anything else. Currently those wells pass our internal AC rules, but they were flagged with a note made to bring to my attention and a TCR is not required. Madeline From: Loepp, Victoria T (DOA) <victoria loepp@alaska.gov> Sent: Monday, November 19, 2018 3:10 PM To: Woodard, Madeline E <Madeline E Woodard Co)conocophillips.com> Subject: [EXTERNAL]KRU 2M-41(PTD 218-151) Madeline, Please check/correct the MPSP, maximum reservoir pressure and TVD depth information under 20 AAC 25.005(c)(4). Send me a corrected copy of the page. The anti -collision report indicates close approach to 2M-19 and 2M-20 while drilling. What is the status of each of these wells and will they be shut in at surface or a deep plug set? Tha nx, 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(Malaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, 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 Loeoo@alaska aoy Davies, Stephen F (DOA) From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Sent: Thursday, November 8, 2018 2:12 PM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]KRU 2M-41 (PTD 218-151) - Request Hi Steve, I think this should cover all the formations. The BHP for 2M-41 was based on a BHP taken on 2M-37 in July, this injector was shut in recently to hopefully bring down the pressure from what is predicted. Please let me know if you need anything else. Top T-3 Sand 442 313 200 8.7 K-15 Marker 571 442 260 8.7 Base Permafrost 1469 1340 670 8.7 Top W Sak (W Sak D) 2003 1874 910 8.7 Base W Sak 2595 2466 1180 8.7 Camp SS 2971 2839 1350 8.7 C-50 4170 4038 1890 8.7 C-37 /Top Iceberg 4667 4535 2460 10.1 C-35 5378 5246 2830 10.1 Top HRZ 5802 5670 2630 8.7 Base HRZ/Top Kalubik_ 5913 -� 5781 2680 8.7 K1 5966 5834 2700 Top Kuparuk C 6071 5939 2050-3320 2840-3790 From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Thursday, November 8, 2018 2:06 PM To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Subject: [EXTERNAL)KRU 2M-41 (PTD 218-151) - Request Madeline, F RM 6.5 -10.5 (2M-39/40) 9.0 -12.0 (2M-41) I'm reviewing CPAI's Permit to Drill application for the KRU 2M-41 well. The Drilling Hazards Information section references a C Sand Estimated BHP of 3798 psi at an estimated depth of 6087' TVD. Are these values from a nearby well or from a reservoir simulation? If from a well, which well? Regarding the planned mud program, could CPAI please provide most likely pore pressure values for the following horizons? Values in units of psi or ppg EMW will be fine. Horizon MD T-3 458 K-15 S87 Base Perm 1,500 W SaK D 2,097 Base WS 2,960 Camp SS 3,693 C-50 7,464 C-37 / Iceberg 9,229 C-35 11,753 THRZ 13,137 BHRZ/TKLB 13,652 K-1 13,842 Top Kuparuk 14,217 Thank you, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or Steve daviesr&alaska.aov. TRANSMITTAL LETTER CHECKLIST WELL NAME: ��K LL Z PTD: Z/O'/s;- / Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: te2 POOL: 4� to; Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(1), 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 lops to be run. In addition to the well logging program proposed by (Comnanv Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2181510 Company CONOCOPHILLIPS ALASKA, INC. Initial Classfrype DEV Well Name: KUPARUK RIV UNIT 2M-41 Program DEV Well bore seg ❑ / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconver' gasconforms to AS31,05.0300A.A),02.A-D)...................... NA _.....-----.... ---_--_...-_-.--- - - ------ _-----....---------------.. 1 Pemlit fee attach ed- - - - - - - - - - - - - - - - - - - - - - - - - - - - ----- - - - - - NA - - - - - - - - - - - - - - - - - - ........ - . _ 2 Lease number appropriate_ _ _ _ - - - - -- - - - - - - - - Yes _ .. _ Surface Location lies within Surface Location; Top Prod Int & TD He within ADL0025585._ _ - - - 3 Unique well, name and number _ _ _ _ _ _ - - - - Yes - - - - - - - - - - ---- - - - - - - -- - - - - - - - --- - - - - - --- - - - - - ---- - - - - - - - - - - - - - 4 Well Jocated in a. defined pool. _ _ - - - - - - - - - - - - - . _ - - - Yes _ Kuparuk River Oil Pool, governed by Conservation Order No. 432D - - - -- - - - - - - - - - - - - 5 Well located proper distance from drilling unit. boundary. _ _ _ _ _ _ _ Yes _ _ _ _ Conservation Order No. 432D has no interwell spacing_ restrictions, Wellbore. will be more than 50V _ _ _ .. _ _ 6 _ Well located proper distance. from other wells . . . . . . . . . . . . . ... . . . .. Yes _ . - . from an externa] property line where_ ownership or.larldownership.changes. As proposed well will... 7 Sufficient acreage available in. drilling unit.. _ _ _ _ ____ _ _ __ _ _ _ _ Yes _ _ _ conform to spacing. requirements. 8 If deviated, is_wellbore plat included - - - - - - - - - - - - - - - - - - - - - . _ Yes 9 Operator only affected party- - - - - - - - - - - - - - _ _ _ _ _ .. Yes 10 Operator has appropriate _bond in force . . . ....... ... _. _... ---- Yes 11 Permit can be issued without conservation order _ .. _ .. _ _ _ _ _ _ ... - YeS Appr Date 12 Permit can be issued without administrativeapproval_ _ _ _ .... - _ Yes SFD 11/8/2018 '13 Can permit be approved before 15 -day wait _ _ _ _ _ _ Yes 14 Well Jocated within area and strata authorized by Injection Order # (put lO# in. comment5).(For_ NA- - - - - - - - - - - - - 15 All wells _within 1/4.mile area of review identified (For service well only) . . .... . . . . . .. . . NA_ .. _ - - - - 16 Pre -produced injector; duratlon of pre -production less than 3 months. (For service well only) ...NA . . . . ... . . . . ........ . . 18 Conductor string provided - - - - - - - ----- - - - -- - - - - -- - - - - - - - - - - - _ Yes . - - - - - _ 80' conductor set- Engineering 19 Surface casing. protects all known USDWs . . . . ... . . . . . . ..... . . . . . .. . . . Yes .... _ _ _ Surface casing set to 3016'.MD 20 CMT_ vol, adequate. to circulate on conductor _& surf csg . . . . . ... . . . . .. . . . . ..... Yes _ _ _ _ . - - 1T9%_excess. . 21 CMT. vot adequate to tie-in long string to surf csg----- - --------..... -----No__-___ ...... -----....------......------..--.-.-- 22 CMTwillcover all known productive horizons _ _ - - - - - - - - -- - - - - - --- - - - No..... - - - Productive interval will be completed with -uncemented production liner 23 Casing designs adequate for C, T, B &_ permafrost. _ _ - - --- - - - - - - - - - - Yes - 24 Adequate tankage. or reserve pit _ _ _ _ - - - - - - - - - - - - - - - - . Yes ..... Rig has steel tanks; all waste -t0 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; Reviewed TOR in meeting 11/29/18 w/.OPAI _ _ ..... . 27 If diverter required, does it meet regulations _ _ - - - --- - ---- - - - - - - - - Yes _ _ ... Diverter size. and route_ meets regulations _ _ _ _ _ _ .. - - - _ _ . - _ _ - - - - - - - - - 28 Drilling fluid. program schematic& equip list adequate. _ _ _ _ _ _ _ _ _ _ . Yes _ _ _ _ Max formation pressure is 3798 psig(12.0 ppg EMW ); will drill w/ 8,8-12,2_ppg EMW - - . Appr Date VTL 11/19/2018 29 BOPEs, do they meet regulation _ _ _ - - - ... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - - - - ... _ _ _ _ _ ... _ _ _ _ _ _ _ ..... _ _ _ _ .. - _ _ _ - - - - - - 30 BOPS press rating appropriate; test to _(put psig in comments)_ . . . .. . . . . .. . . . Yes _ _ MPSP is 3190 psig; will lest BOPs_to 3500.psig 31 Choke manifold complies w/API_RP-53 (May 84) . . . . . ..... . . . . ... . . . . .. Yes 32 Work will occur without operation shutdown- - - ---- - - - - - - --- - - - - -- - - - - - - Yes 33 Js presence of H2$ gas. probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ _ _ _ _ _ _ ... - - Yes .... H2$ measures required. - - . 34 Mechanical condition of wells within AOR verified (For -service well only) ___ _ _ _ _ _ __ _ _ _ NA .... - - . - - - - - - - _ . - - - - - - - - _ - - - _ - - ......- 35 Permit can be issued w/e hydrogen sulfide measures . . . . ... . . . . . . . .... No_ .. - - Wells _on?M-Pad are 1-12S -bearing. H2S measures required, Geology 36 Data.presented on potential overpressure zones _ _ _ _ _ _ _ . Yea - - Planned mud weights appear adequate to control the. operator's forecast of most likely pore pressures, Appr Date 37 Seismic analysis of shallow gas. zones_ - - - - - -- - - ---- - - - - - - - - - - - NA.... SFD 11/8/2018 38 Seabed condition survey (if off -shore) . ... . . . .. . . . ... . . . . .. . . . ...... . . . NA . _ . _ ...... 39 Contact name/phone for weeklyprogressreports_ [exploratory only] _ _ _ - . NA- Geologic Engineering Public Date Commissioner: Date: Commissioner: Date Co er
