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Home My WebLink About219-097MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3R-106 KUPARUK RIV U WSAK 3R-106 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 3R-106 50-029-23641-00-00 219-097-0 W SPT 3662 2190970 1500 500 500 500 500 120 120 120 120 4YRTST P Adam Earl 8/10/2024 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 3R-106 Inspection Date: Tubing OA Packer Depth 1400 2110 2065 2065IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240812140041 BBL Pumped:0.6 BBL Returned:0.8 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 15:13:46 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-08-23_23046_KRU_3R-103_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23046 KRU 3R-106 50-029-23641-00 Injection Profile 23-Aug-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 219-097 T39527 9/9/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.09 12:50:43 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-13_21076_KRU_3R-106_CaliperSurvey_CaliperLogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21076 KRU 3R-106 50-029-23641-00 Caliper Survey w/ Caliper Log Data 13-May-11 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:219-097 T36619 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.17 15:43:22 -08'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim Regg CL DATE: Monday, August 17, 2020 SUBJECT: Mechanical Integrity Tests P.I. Supervisor1 \eex l Type Test L SPT Nest psi 1500 ConocoPhillips Alaska, Inc. 0.7 BBL Returned: 3R-106 FROM: Brian Bixby KUPARUK R1V U WSAK 3R-106 Petroleum Inspector Notes Src: Inspector Reviewed B P.I. Supry J� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 3R-106 API Well Number 50-029-23641-00-00 Inspector Name: Brian Bixby Permit Number: 219-097-0 Inspection Date: 8/13/2020 Insp Num: mitBDB200813155840 Rel Insp Num: Pretest Packer Depth Well 3R-106 Type Inj i w TVD 1 3662 " PTD 2190970 Type Test L SPT Nest psi 1500 BBL Pumped: 0.7 BBL Returned: 0.6 a1 4YRTST IPF -- P Notes Initial 15 Min 30 Min 45 Min 60 Min Tubing 690 690 690 —690 IA 1630 2490 - —1-244-0 - 2430 " OA 200 285 285 I 285 - Monday, August 17, 2020 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 1/312020 Permit to Drill 2190970 Well Name/No. KUPARUK RIV U WSAK 3R-106 Operator ConocoPhillips Alaska, Inc. API No. 50-029-23641-00-00 MD 14165 TVD 3837 Completion Date 9/10/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes REQUIRED INFORMATION Mud Log No I// Samples No "/ Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res/Sonic LWD Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 31300 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C 31300 Digital Data 31300 Digital Data 31300 Digital Data 31300 Digital Data 31300 Digital Data 31300 Digital Data 31300 Digital Data 31300 Digital Data 31300 Digital Data 31300 Digital Data 31300 Digital Data 31300 Digital Data (from Master Well Data/Logs) Log Log Run Interval CHI Scale Media No Start Stop CH Received Comments 40 2294 10/4/2019 Electronic Data Set, Filename: 3R- 106 VISION Service LWD001.1as 2161 5536 10/4/2019 Electronic Data Set, Filename: 3R- 106 VISION Service LWD002.las 5496 14164 10/4/2019 Electronic Data Set, Filename: 3R- 106 VISION Service LWD003.las 36 14158 10/4/2019 Electronic Data Set, Filename: 3R- 106 VISION Service RM.las 10/4/2019 Electronic File: 3R-106 VISION_Resistivity_LW D001_RM.dlis 10/4/2019 Electronic File: 3R-106 VISION_Resistivity_LW D002_RM_DLIS.dlis 10/4/2019 Electronic File: 3R-106 VISION—Resistivity _LW D001_RM_DLIS.dlis 10/4/2019 Electronic File: 3R-106 VI SION_Resistivity_RM_DLIS.dlis 10/4/2019 Electronic File: 3R-106 VISION_Resistivity_RM_DLIS_(1).dlis 10/4/2019 Electronic File: 3R- 106_VIS ION_Service_RM_2_MD.pdf 10/4/2019 Electronic File: 3R- 106—VISION Service_ RM_ 2_TVD.pdf 10/4/2019 Electronic File: 3R - 106_V ISION_Service_RM_5_MD.pdf 10/4/2019 Electronic File: 3R - 106_V ISION_Service_RM_5_TVD.pdf A00CC Page I of 3 Friday, January 3, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/3/2020 Permit to Drill 2190970 Well Name/No. KUPARUK RIV U WSAK 3R-106 Operator ConocoPhillips Alaska, Inc. MD 14165 TVD 3837 Completion Date 9/10/2019 ED C 31300 Digital Data ED C 31300 Digital Data ED C 31300 Digital Data ED C 31300 Digital Data ED C 31300 Digital Data ED C 31300 Digital Data ED C 31300 Digital Data ED C 31300 Digital Data ED C 31300 Digital Data ED C 31300 Digital Data Log 31300 Log Header Scans Well Cores/Samples Information Name INFORMATION RECEIVED Completion Report YD Production Test Information Y / Geologic Markers/Tops o COMPLIANCE HISTORY Interval Start Stop API No. 50-029-23641-00-00 Completion Status 1WINJ Current Status 1WINJ UIC Yes 10/4/2019 Electronic File: 3R-106 NAD27 EOW Compass /Y/® y Composite Logs, Image, Data Files I r Surveys [Canvas].txt 10/4/2019 Electronic File: 3R-106 NAD27 EOW Compass Surveys [Macro].txt 10/4/2019 Electronic File: 3R-106 NAD27 EOW Compass Surveys [Petrel].txt 10/4/2019 Electronic File: 3R-106 NAD27 EOW Compass Surveys [Survey].txt 10/4/2019 Electronic File: 3R-106 NAD27 EOW Compass Surveys.pdf 10/4/2019 Electronic File: 3R-106 NAD83 EOW Compass Surveys [Canvas].txt 10/4/2019 Electronic File: 3R-106 NAD83 EOW Compass Surveys [Macro).txt 10/4/2019 Electronic File: 3R-106 NAD83 EOW Compass Surveys [Petrel].txt 10/4/2019 Electronic File: 3R-106 NAD83 EOW Compass Surveys [Survey]Axt 10/4/2019 Electronic File: 3R-106 NAD83 EOW Compass Surveys.pdf 0 0 2190970 KUPARUK RIV U WSAK 3R-106 LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data ® Mud Logs, Image Files, Digital Data Mechanical Integrity Test Information Y / NA /Y/® y Composite Logs, Image, Data Files I r Daily Operations Summary P) Cuttings Samples Y /\9 Core Chips Y / A Core Photographs Y I Laboratory Analyses Y N A06( ( Page 2 of 3 Friday, January 3, 2020 DATA SUBMITTAL COMPLIANCE REPORT 113/2020 Permit to Drill 2190970 Well Name/No. KUPARUK RIV U WSAK 3R-106 Operator ConocoPhillips Alaska, Inc. MD 14165 TVD 3837 Completion Date 9/10/2019 Completion Status 1WINJ Current Status 1WINJ Completion Date: 9/10/2019 Release Date: 7/19/2019 Description Date Comments Comments: Compliance Reviewed B�,tr l� API No. 50-029-23641-00-00 UIC Yes Date: AOGCC Page 3 of 3 Friday, January 3, 2020 i' MA 32- (O!a Regg, James B (CED) PM Z4g0q-r0 From: CPF3 Prod Engrs <n1223@conocophillips.com> I Sent: Thursday, October 17, 2019 6:01 PM lr '� ( I OI y! jr To: Regg, James B (CED) ` Cc: Well Integrity Compliance Specialist WNS & CPF3; NSK Prod Engr Specialist; NSK Optimization Engr; NSK West Sak Prod Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; Valentine, Doug K; Kozak, Devin; Jolley, Liz C; Martin, Kenneth Lloyd; Ellis, Kaelin Subject: FW: Defeated LPP/SSV on well 3R-106 Mr. Regg, The low-pressure pilot on injection well 3R-106 (PTD# 219-097) has been returned to normal operation, as of Friday, September 27', 2019, in accordance with "Administrative Approval No. CO 4068.001". Best regards, Lynn Aleshire / Kaelin Ellis / Kenneth Lloyd Martin CPF3 Production Engineer ConocoPhillips Alaska Ph: 907-659-7871 From: CPF3 Prod Engrs Sent: Friday, September 20, 2019 5:55 PM To: jim.regg@alaska.gov Cc: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com>; CPF3 Maint Supv <n2069@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Valentine, Doug K <Doug.K.Valentine@conocophillips.com>; Jolley, Liz C <Liz.C.Jolley@conocophillips.com>; CPF3 Ops & DOT Pipelines Supt <n1175@conocophillips.com>; CPF3 Ops Supv (n2070@conocophillips.com) <n2070@conocophillips.com> Subject: Defeated LPP/SSV on well 313-106 Mr. Regg, The low-pressure pilot (LPP) on injection well 3R-106 (PTD# 219-097) was defeated Friday evening 9/20/2019. 311-106 is a grassroots injection well that was brought online 9/20/2019. 311-106 is currently at a wellhead injection pressure of 283 psi and an injection rate of 1060 bbls of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased to above 250 psi and the LPP/SSV function is returned to normal operation, in accordance with "Administrative Approval No. CO 4068.001" Kaelin Ellis/ Kenneth Lloyd Martin CPF3 Production Engineer MEMORANDUM State of Alaska Insp Num: mitBDB191002104054 Alaska Oil and Gas Conservation Commission Rel Insp Num: DATE: Monday, October 7, 2019 TO: Jim Regg p� I IDI j P.I. Supervisor 11{ SUBJECT: Mechanical Integrity Tests l G ConocoPhillips Alaska, Inc. T 3R-106 yype lnj W' TVD 3662 Tubing 375 375 3R-106 FROM: Bryan Bixby KUPARUK RIV U WSAK 3R-106 Petroleum Inspector sPT See: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 3R-106 API Well Number 50-029-23641-00-00 Inspector Name: Brian Bixby Permit Number: 219-097-0 Inspection Date: 1011/2019 ' Insp Num: mitBDB191002104054 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min T 3R-106 yype lnj W' TVD 3662 Tubing 375 375 375 375 r '2190970 - Type Test sPT Test psi 1500 IA 1280 2000 1960 • 1950 mped: 0.5 . BBL Returned: 0 5 OA 160 220 220 220 " Interval INITAL P/F P Notes: Monday, October 7, 2019 Page I of I 210-01 31;�Q0 Schlumberger Transmittal #: 020CT19-SP01 Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska, Inc. Dispatched To: AOGCC: Natural Resource Tech Well Name: 3R-106 Date Dispatched: 2 -Oct -19 Service Order #: 19AKA0103 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date LWD Recorded Mode Prints N/A Contents on CD 5 -Sep -19 VISION Service 2" MD x 5 MD x TVD 5"TVD RECIElvED x OCT 4 2019 AO CC Digital Data N/A Contents on CD LAS/DLIS Data x Surveys N/A Contents on CD Directional Survey Nad27 x Directional Survey Nad83 x CD 1 CD Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom. Osterkamp(a)conocophilIips.com Alaska PTS PrintCenter(aDslb.com Attn: Tom Osterkamp Attn: Stephanie Pacillo lRo Received By: ML� /1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ta. Well Status: oil EJ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ❑ WINJEl WAGE] WDSPL❑ No. of Completions: Service 2] Stratigraphic Test El 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Abend.: 9/1012019 219-097 < 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 8/20/2019 60.029-23641-00.00 r 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 1697' FNL, 2937' FEL, Sec 9, T13N, R9E, UM 914/2019 KRU 3R-106 r Top of Productive Interval: 9. Ref Elevations: KB:49.29 17. Field / Pool(s): 4645' FNL, 1049' FEL, Sec 4, T13N, R9E, UM GL: 9.80 BF: Kuparuk River FieldlWest Sak Oil Pool Total Depth: 10. Plug Back Depth MD/ VD: 18. Property Designation: 657' FNL, 3233' FEL, Sec 11, T13N, R9E, UM < N/A ADL 355023 - 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD(rVD: 19. DNR Approval Number: Surface: x- 520649 y- 6031666 Zone- 4 1416513837 ' 931933000 TPI: x- 522524 y- 6034002 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 530906 y- 6032741 Zone- 4 N/A 1742/1703 r 5. Directional or Inclination Survey: Yes 121 (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MDITVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary COMPLETION GR/Res/Sonic LWD for Top of Cement D TE l0 2otq VERIFIED �IJ 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MHOLE SIZE CEMENTING RECORD D SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 20 94 H-40 Surface 119 Surface 119 42 Existing cement to surface 10 314 45.5 L-80 Surface 2290 Surface 2166 131/21199sx 11.0ppg Class G 199sx , 2.Oppq Class G 75/8 29.7 L-80 Surface 5528 Surface 3690 97/8 535sx 15.8ppg Class G 4 112 12.6 L-80 5366 14165 3670 3837 63/4 N/A 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) If Yes, list each interval open (MDr VD of Top and Bottom; Perforation Size and Number; Date Perfd): 41/2 5407 N/A ICD's @: (Run date 9/6/2019) 5628-5664 MD and 3696-3698 TVD 10381-10406 MD and 3743-3744 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6123-6149 MD and 3703-3703 TVD 11214-11240 MD and 3769-3744 TVD 6597-6622 MD and 3718-3719 TVD 11766.11792 MD and 3781-3782 TVD 7468-7493 MD and 3643-3641 TVD 12436-12462 MD and 3768-3770 TVD 7827-7852 MD and 3637-3639 TVD 13028-13054 MD and 3778-3779 TVD Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8502-8527 MD and 3676-3677 TVD 13580-13606 MD and 3822-3824 TVD 9061-9087 MD and 3704-3705 TVD 13932-13957 MD and 3832-3833 TVD 9701-9726 MD and 37053705 TVD 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A INJECTION ONLY -- NOT PRE -PRODUCED Date of Test: Hours Tested: lProduction for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casino Press: I Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API(cord: Press. 24 -Hour Rate Form 10-407 Revised 5/2017 ji]Z, ID/,Z311 q CONTINUED PNPAGE 2 Submit ORIGINAL onn gets fdt-so/r9 ,� l %/t RBDMSLgv OCT 0 7 2019 l� 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 2 If Yes, list formations and intervals cored (MD1 VD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, it 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 1742 1703 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 5418 3678 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Salk D K-15 1926 1867 ' Ugnu C 3335 2813 Ugnu B 4049 3181 Ugnu A 4261 3283 West Sak D 5418 3678 TO 14165 3837 ' Formation at total depth: West Salk D r 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, paleontolooical report oroduction or well test results, 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Madeline Woodard Authorized Title: Alaska Drilling Manage Contact Email: madeline.e.woodardtWcop.com Authorized DD Contact Phone: 265-6086 Q+` ( i 2_( Zf ( 9 Signature: Date: ° INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-107 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 forth 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 8 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 0 �'jj FN II4 MU/119 TVD " <55" LAO,Hve56l J1 �}I23�' wawew/nelne x..er r..<, lua/Y"xY-x•. r SOW pel e9. . .. l.Bl l" DB nipple E,105'MO/pA1ry TVD Ou Lla r I,CAMCO411"v V" .DV 3 Sle'MO/3.533TVD 3R-106 ICU Injector Final Schematic M1DIE.166'TVD q1 N 9 Oue Lill MmWel CAMC00.1R-x I' W 90V D 0.753'MD/1.J89'TVD 3 75' DB vpple w/Dwl nepM a xl9 tAl /I513'TVO U.,J-In', Ii 6Y L. Y-Y"x blM" 63/4'OH I<.I45'FN/1.836'TVD� xyE 563 4xclWhk Pwkee -(Wnwr Sxg d) k MPLwa Top, Wu&Line Hmger SEO'M1W /1b66'MI g y _ .... . . .. .. .. K ]-SR-, 39.79, LSO, HyE561, C l v 5338'eD1 /1,66Y'TVD SI.B SGeinS Slenc WTTSNi gSl elCD Y -K.. yDy Sna< I 14,165' efflIIAWTVD KUP PROD WELLNAME 311-106 WELLBORE 3R-106 ComicoPhillip5 Alaska. Inc. s.-uss"p]oreass49:T7Laet Tag .l.miawlaOaml AinWalbn Depm(mel EM. vaslppre Lest MW By ............................ xaro.,;xT...._._. .... Last Tag: ULM 3R-106 ccedijw Last Rev Reason cv,aaa; aao+xip Igxtin VYn;$19.0 MVMM-ammy:2ata1 ueMtl: 4,M9xomin) Larsmr, papal Sar ameey. 5sar.e mm,n,.mma: M ss.ne 0 lme eige epe iiiiiiie Ir 9.ffi0 L AmwlNgn EM DM WeIICore Last a. By Rev Reason'. SBHP, SET DV, PDI.LDFCV, BET INJ VLV 91122019 3R-106 con0itw Casing Strings cal pe, Penn 00 (in) I1 hn) Top(XNaI semepm (me) seroep+n lrvDl_. wuLen p... lease IDpT rmld Corded., 20 18.65 d00 1200 120.0 215.50 causing DeKraker OD (in) 10(m) .1(.9) is. Depth uffi laef DpN DVI wIMn 0 -Grade 1r) Th. Sura10314 995 39.9 2,290.1 2,2,166S 4550 L-80 Hytl563 ce C»IngDaw"Nam OO fel I011n) Ripper-) ant DapmlrIXB) atl Depth pap, jappoen(....Grads TnPThmed antermedia.e ]58 688 .6 5.5289 3,6900 29.]0 L80 H563 Caainp .-I've. ON [in) IOtin) Tap(M(B) Ism Legh jake, am Depen ITVD1...wtlLen(1-jurew Production Liner 4112 396 5,3662 141650 1260 L-80 TOP Thread HYD 563 Liner Details Top 05,38 TOp (TVgI(IOUD6733 Tap lWA Ihm Des COm RIM) lD pnl 5, .1 3,fi]33 .10 Nipple - RS RS Nipple 7.63" L-80 5-10 179 Hytl 563 (Baker) 4890 5, 9.0 3,6738 8021 Hanger FIek4LkcK 5Wx TL -80. Flex Lock Hanger HYO 563 48W pin by pin (Baker) 5 ' JWN 3,6754 80.59 BBE (Seal Baker 8047 Sealbove Extension a 4750 Bore 563 box x pin Expansion) 5, S 3,696.2 8643 71D- 4-112" WFT shiftable ICD (0) Open 91152019 3.920 5,]03.1 3,]010 8631 Sliding Sleeve 4-12" SLB shiftable passive #15 3.890 5,]65. 3,]050 06.35 Swell Packer Baker Hughes 6125" wellpacker(P) Hyd563 3.960 6,0301 3,706.8 9341 Swell Packer Baker Hughes SAW Swellpacker(0) Hyd563 3.960 6,123.8 3,702.8 9149 ICD 4-12"WFT suitable ICD (N)(0) Open San 512019 3.920 6,198. 3,701.5 90.55 S -ding Sleeve 4-V2"SLB shiftable sleeve#14 3.89D 6,25 8 3,7013 8984 Swell Packer Baker Hughes 6.125"Swellpacker IN) Hyd563 3.960 ----6577-1 3,]1].8 8729 TCD 4 -W - MT suitable (CD (M) (0) Open 91152019 3.920 6, ] 9 3,720.0 89.36 Sliding Sieeve 410SLB shiffiablesleeve#13 3890 6,7397 3,719.9 9079 Swell Packer Baker Hughes 6.125- Sirellpacker(M) Hyd563 3960 7,411. 3,6494 9633 Swell Packer Baker Hughes 0.125' SWellpacker(L) Hyd563 3.96D 7,4 3 3,6431 NOD ICD 442" WFT shiftable ICD (L) (0) Open &157019 392D 7,666.1 3,6307 9048 Slidin9Sleeve 4-10SL5 drillable sleeve#12 3.890 7.688.0 3,6307 8941 Swell Packer Baker Hughes 6.125" Swellpacker(K) Hyd563 3960 7.927.2 3,6374 8637 ICD IWFT shihable ICDc(K)(0) Open91152019 3920 8, 3,649.6 8662 Sliding Sleeve 412' Ste suffoadle Sleeve #11 3,890 ,1 .e 3,656 9 85.18 Ewell Packer baker Hughes 8.125' Swellpacker (J) Hytl563 3 960 -3.6764 88.13 ICD 4-10VVI`T Shiftable ICED (J) (0) Open W0019 3,920 =,5 3,6834 87.23 Sliding Sleeve 4-112'SLB ab' able sleeve#10 3,890 761.6 3,6886 86.73 Ewell Packer Baker Hughes 0.25' SweBpacker(1) Hyd563 3,960 1.5 3,]04.0 88.08 ICD 412' WFT shuatse ICD (1)(0) Open 911512019 3920 57 3.7076 90.55 Sliding Slesen. 412"SLB suitable sieeve#9 5,450 0.6 3,7053 9190 Swell Packer Baker Hughes SAW Swellpacker(H) Hyd563 3.960 701.5 3,]04.9 88,73 ICO 4-llr WFT shiflabha ICD (H) (0) Open 9/15/2019 3920 ,897.7 3,7139 8524 Sliding Sleeve 4112" SLB shiBable sleeve #8 3890 ,0020 3,7243 8345 SwellPmker Baker Hughes 8.125°Swellpacker (G)Hytl563 3.860 0,381.2 3,743.5 88.14 ICO 412" WFT shiftable lCID (G)(0) Open 911 W019 3.920 10,694.] 3,7597 86 54 Sliding Sleeve 412" SLB shiftable shares #7 3SW 0798.3 37637 8889 Swell Packer Baker Hughes 6.125" Swellpader(F) Hyd563 3.960 1,214.8 3,769.0 8U25 ICD 4-12" WFT shapable ICD (F)(0) Open &152019 3920 11,289.2 3,7696 90.01 Sliding Sleeve 4-1 " SLB shihable sleeve #6 3.890 11,391.6 3,7690 89.97 Swell Packer Baker Hughes 6,125'Swellpeker(E) Hyd563 3.90 11)66.6 3,]81.4 88.02 ICD 4-1&' WFT shiftable ICD (E) (0) Open 91152019 3.9 D 12,1212 3.]]2.0 93.71 Sliding Sleeve 44a SLB suitable sleeve #5 3.890 12,182.8 3,7674 94.06 Swell Packer Baker Hughes 6,125- Swellpacker(D) Hyd563 3.980 12,436.5 3,768,2 85.67 ICD 4-12WFT shiftable ICD (D) (0) Open WIW019 3.920 125911 3,777.5 87.84 Sliding Sleeve 4-12" SLB SIIiBabte sleeve#4 3.890 12.692.6 3,]]95 89.98 Swell Packer Baker Hughes 6.125" Swellpacker(C) Hyd563 3.9fi0 13,028.0 3.778.4 88.47 ICD 4-112' WFT shiftable ICO (C) (0) Open 91152019 3.920 13,383.0 3,8042 85.89 Sliding Sleeve 4-112' SLB suftablc sleeve 43 3.890 13,405,0 3,8058 85.85 Swell Packer Baker Hughes 6.125" Swellpacker(B) Hyd563 3,960 13.5 7 3,822.0 85.03 ICO 4112" WFT 0,ftaW ICD (B) (0) Open &152019 3.920 1 14.5 3,830.1 88.]5 Sliding Sleeve 4112'SLB shi ble sleave k2 3890 13,8364 3,830.5 8 81 Swell Packer Baker Hughes 6.125" Swellpacker(A) Hyd53 3.960 13,932.1 3,832.3 8891 ICD 4112' WFT shiftable ICD(A)(0) Open Is 19 3920 14006 9 3834.1 8.39 Sliding Sleeve 4112" SLB shapable sleeve #1 3. 14,0687 3,835.5 8897 Fac Sleeve Wel rel solation serve, -11 uu1-114-11131",one DD00 psi shear Tubing Strings Tumne lav -pt -o Sulo. Ma. 4112"UPpm 4112 Completion ID pn) 396 TOP -.1 3d.] set Oapm (cfe. 5,406.8 Depen (rvGl (... 3,676> 11' q I111'W1 12.60 Gude L-80 H P1t3 Mmn Hytl563 Completion Details Top (gKBI TaplrvDl Top me' BKB) f) Item Des Com xominal mlinl 34.] 347 0.00 Hanger VETCOIGLk 1 -1 "x 112' mmm9hangml4, ,k Box Up) 3.958 KUP PROD WELLNAME 311-106 WELLBORE 3R-106 ConocoPhillipsQ E::] Aleska.Inc . ax-,re.,mvm,a6aaunM Completion Details Ve,RalecNwaEe laawl Top OVol Top and Top(MB) (fl B6 fl IRm Ne Co. x^ml^al to lm) __.'................ xmsFaeT""""' 2,1411 2,049.8 1 34.59 INipplo - OB Nipple, 4.5".1113" OR, HyC 563 B xP SN#3654-7 3.813 4,8198 3.513.9 69.03Nipple-OB Nipple,4lZ Oamco, DB, 37S Prale SN# 6198-2 3750 5,366.1 3,559] 19.33 1 U.Wr Lwalpr, Baker GBH -22 3860 5,367.8 3,570.0 19.40 Seal Assembly Seal Assembly, aker GBH-2?It 015waIlYw1-place6360 387 Corem:m.u,mo NO 9a Iry.monvM.: vu5 Other In Role (Wireline retrievable plugs, valves, pumps, fish, etc.) "Q10) Top lflKBj ToflNBI Top Incl 1') pes I Run BOR 10 (in) 2,145.0 2,0492 34.58 Injection Valve e13.812 OBL 11 INJECTION VALV L= 911812019 1.500 sm.ee. aeasaw+� SERIAL # HSS -120 0625" ORIFICE ld w-4vnmyl 2W64 Mandrel Inserts $, M.MnI: a,75R.9 aV on roplrvo) N i0p(N(B) (flNB) MaXe MoMI OD(in) aery valve l.Rn parts. Trsoaon type Type 0^) IWI) evn pert Co. 2,81fi0 2534.0 Camw KBMG 1 GAS LIFT OMY BK 0.000 0.0 91912019 Wumr:S , 4.752,91 3,469A I GBMc KBMG I 1 IGAS LIFT JDMY IBK I 000 0.0 &1212019 Swl PavrW:5W 8 InM 1M:39.65.5�.0 sia lme MGM Pro]uc4cn Wer, A3�2 1X,,650 Uperations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth Start Time End Time Our (hr) Phase Op Code Actively Code Time P -T -X Opere w (ftKB) End Depn (HKB) 8/19/2019 8/19/2019 2.00 MIRU MOVE MOB P Moved Motor complex, Pump 14:00 16:00 complex, Pipe shed complex, Rock washer, Pit complex, Skid Floor. Pull sub off 3R-112. 8/19/2019 8/19/2019 1.00 MIRU MOVE MOB P Lay cellar composite/stomper/sub 16:00 17:00 mats. Stage tubing spool adapter flange, production tree behind sub. 8/19/2019 8/1912019 1.50 MIRU MOVE MOB T Attempt to spot sub over well. 17:00 18:30 Thermosyphon in the way. Mobilize crane and cut thermosyphon off at ground level. 8/19/2019 8/19/2019 2.50 MIRU MOVE MOB P Spot sub over 3R-106. Lower 18:30 21:00 stompers. Skid rig floor. 8/19/2019 8/20/2019 3.00 MIRU MOVE MOB P Spot pit, pump and motor module's. 21:00 00:00 Plugging in interconnect. 8/20/2019 8/20/2019 1.75 MIRU MOVE MOB P Spot pipe shed and rock washer 0.0 0.0 00:00 01:45 1 1 1 modules 8/20/2019 8/20/2019 4.25 MIRU MOVE MOB P Continue with rig acceptance 0.0 0.0 01:45 06:00 checklist. Plug in interconnect. Repair shaker #1. Swap to cal power @ 03:30. Test gas alarms - Good test. Test rig evacuation alarm - Good test. Rig accepted @ 06:00 8/2012019 8/20/2019 3.00 MIRU MOVE RURD P N/U surface riser. Install mouse hole. 0.0 0.0 06:00 09:00 Service top drive and ST100. Load pipe shed with one row of 10 3/4" casing. Load pipe shed with 66 joints 5" drill pipe. Function all E -stop's 8/20/2019 8/20/2019 5.00 MIRU MOVE PULD P Build 22 stands of 5" drill pipe, 2 0.0 0.0 09:00 14:00 stands of HWDP, jar stand and 1 stand of drill collars. Rack back in derrick. 8/2012019 8/20/2019 2.00 MIRU MOVE BHAH P PJSM with SLB and rig crew. Stage 0.0 0.0 14:00 16:00 BHA equipment on rig floor. M/U bit, stabilizer, motor and HWDP. Rig on hi -line @ 15:00 Hrs 8/2012019 8/20/2019 0.50 MIRU MOVE PRTS P Fill conductor. Check for leaks - No 0.0 0.0 16:00 16:30 leaks. Pressure test mud lines T/ 3500 PSI - Good test. 8/2012019 8/20/2019 1.00 MIRU MOVE DRLG P Clean out conductor. Drill out 20" 0.0 130.0 16:30 17:30 conductor with 13'A bit F/ surface' T/ 130' MD @ 405 GPM. 268 PSI. 17% F10 20 RPM 1.61K Tq. 5.51K WOB 8/2012019 8/20/2019 0.50 MIRU MOVE PMPO P Pump OOH F/ 130'T/ 37'@ 500 130.0 37.0 17:30 18:00 GPM, 380 PSI, 19% F/O 8/2012019 8/20/2019 1.75 MIRU MOVE BHAH P UD clean out BHA. M/U BHA #1. 37.0 121.0 18:00 19:45 8/20/2019 8/21/2019 4.25 SURFAC DRILL DDRL P Directionally Drill 13 1/2" surface hole 121.0 313.0 19:45 00:00 F/ 130' T/ 313' @ 400 GPM, 461 PSI, 44% F/O, 40 RPM, 21K Tq, 10K WOB, P/U=64K, S/0=69K, ROT=66K. Off bottom 438 PSI, 1 K Tq 8/2112019 8/21/2019 6.00 SURFAC DRILL DDRL P Directionally Drill 13 112" surface hole 313.0 691.0 00:00 06:00 F/ 313' T/ 691' MD, 691' TVD @ 500 GPM, 751 PSI, 51% F/O, 40 RPM, 31K Tq, 41K WOB, P/U=77K, S/0=86K, ROT=82K. Off bottom 708 PSI, 1 K Tq. Max gas= 18 Page 1/18 ReportPrinted: 9120/2019 operations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start DepM Sten Terse End Time our (hr) Phase Op Code AMity Code Time P -T -X Operation (MB) End Depth(UB) 8/21/2019 8/21/2019 6.00 SURFAC DRILL DDRL P Directionally Drill 13 1/2" surface hole 691.0 1,125.0 06:00 12:00 F/ 691' T/ 1125' MD, 1123' TVD @ 500 GPM, 900 PSI, 49% F/0, 40 RPM, 4.5K Tq, 25K WOB, PIU=86K, S/0=92K, ROT=87K. Off bottom 735 PSI, 1K Tq. Max gas= 91 8/21/2019 8/21/2019 6.00 SURFAC DRILL DDRL P Directionally Drill 13 1/2" surface hole 1,125.0 1,600.0 12:00 18:00 F/ 1125'T/ 1600' MD, 1572' TVD @ 500 GPM, 950 PSI, 51 % F/0, 40 RPM, 4.5K Tq, 30K WOB, P/U=86K, S/0=92K, ROT=87K. Off bottom 840 PSI, 1KTq. Maxgas176 8/21/2019 8/22/2019 6.00 SURFAC DRILL DDRL P Directionally Drill 13 1/2" surface hole 1,600.0 2,204.0 18:00 00:00 F/ 1600'T/ 2204' MD, 2029' TVD @ 500 GPM, 1095 PSI, 49% F10, 40 RPM, 8K Tq, 25K WOB, P/U=112K, S/0=102K, ROT=106K. Off bottom 960 PSI, 31K Tq. Max gas100 8/222019 8/22/2019 1.25 SURFAC DRILL DDRL P Directionally Drill 13 1/2" surface hole 2,204.0 2,295.0 00:00 01:15 F/ 2204'T/ 2295' MD, 2169.84' TVD @ 500 GPM, 1175 PSI, 49% F/0, 40 RPM, 8K Tq, 30K WOB, P/U=114K, S/0=102K, ROT=106K. Off bottom 960 PSI, 41K Tq. Max gas100 8/22/2019 8/22/2019 0.50 SURFAC CASING CIRC P Circ BU @ 650 GPM, 1453 PSI, 60 2,295.0 2,207.0 01:15 01:45 RPM, 5K Tq, PIU=101 K. BROOH T/ 2207' while circulating. Observe well for flow - No flow 822/2019 8/22/2019 1.75 SURFAC CASING BKRM P BROOH F/ 2207' T/ 1923' @ 650 2,207.0 1,923.0 01:45 03:30 GPM, 1383 PSI, 60 RPM, 3K Tq, P/U=97K 8/222019 8122/2019 1.50 SURFAC CASING BKRM P BROOH pumping BU per stand pulled 1,923.0 1,734.0 03:30 05:00 F/ 1923' T/ 1734' @ 550 GPM, 988 PSI, 60 RPM, 3K Tq, P/U=97K 8/222019 8/22/2019 4.00 SURFAC CASING TRIP P POOH F/ 1734' T/ 223', P/U=79K, 1,734.0 223.0 05:00 09:00 S/0=80K 8122/2019 822/2019 2.00 SURFAC CASING BHAH P UD BHA F/ 223' T/ surface. Rack 223.0 0.0 09:00 11:00 back 1 stand of drill collars. UD reaming BHA. 8/22/2019 8/22/2019 0.75 SURFAC CASING CLEN P Clean and clear rig floor. 0.0 0.0 11:00 11:45 8/22/2019 8/22/2019 0.25 SURFAC CASING SFTY P PJSM with rig crew and GBR rep on 0.0 0.0 11:45 12:00 R/U and running 10 3/4" rasing with Volant CRT 8/2212019 8/22/2019 0.50 SURFAC CASING RURD P R/U Volant CRT 0.0 0.0 12:00 12:30 8/2212019 8/22/2019 8.00 SURFAC CASING PUTS P RIH with 10 %"45.5#, L-80, HYD 563 0.0 1,500.0 12:30 20:30 casing T/ 1500' MD (JT. #38) S/0= 91 K, Monitor displacement. Baker lock first 3 connection. Install Bowspring centralizers one each connection. Fill on the fly, Top off every 5Its. M/U Tq= 16200 fl/lbs. 8/22/2019 8/22/2019 0.75 SURFAC CASING CIRC P Establish circulation, stage pumps up 1,500.0 1,500.0 20:30 21:15 T/ 315 GPM, 165 PSI, 38% F/0, 510=91K. 2457 strokes pumped 8/2212019 8/22/2019 1.25 SURFAC CASING PUTB P Cont. RIH with 10 %"45.5#, L-80, 1,500.0 1,808.0 21:15 22:30 HYD 563 casing F/ 1500' T/ 1808' MD (JT. #44) S/0= 95K, Monitor displacement. Fill on the fly, Top off every 5Its. M/U Tq= 16200 ft/lbs. 8/22/2019 8/23/2019 1.50 SURFAC CASING CIRC P Establish circulation, stage pumps up 1,808.0 1,808.0 22:30 00:00 T/ 336 GPM, 127 PSI, 38% F/0, S/0=103K. 4450 strokes pumped Page 2118 Report Printed: 912 012 01 9 Uperations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depm Start Tlme End Time our(hr) Phase Op Code Acbvfty Code Time P -T -X Operation (itKB) End Depm(fiKe) 8/23/2019 8123/2019 2.50 SURFAC CASING PUTS T Volanl CRT would not release from 1,808.0 1,808.0 00:00 02:30 casing joint. Manually release tool. Troubleshoot problem. RID CRT. R/U single stack tongs. Worked pipe 3X's during trouble time. P/U=122K, S/0=102K 8/2312019 8/23/2019 2.50 SURFAC CASING PUTB P Cont. RIH with 10 %"45.5#, L-80, 1,808.0 2,246.0 02:30 05:00 HYD 563 casing F/ 1808' T/ 2246' MD (JT. #57) S/0= 111 K, Monitor displacement. Fill on the fly, Top off every 5 its. M/U Tq= 16200 8/lbs. 8/23/2019 812312019 1.00 SURFAC CASING PUTB P M/U mandrel hanger and landing joint. 2,246.0 2,290.0 05:00 06:00 RIH and land hanger @ 2290' MD 8/23/2019 8/2312019 2.75 SURFAC CEMENT CIRC P Circ & Recip. Stage pumps up T/ 7.5 2,290.0 2,290.0 06:00 08:45 BPM, 255 PSI, 35% F/0, P/U=137K, S/0=118K. Recip pipe F/ 2290' T/ 2270' 812312019 8/2312019 0.50 SURFAC CEMENT SFTY P PJSM with SLB cement, GE wellhead 2,290.0 2,290.0 08:45 09:15 and rig crew. 6/23/2019 8/2312019 3.75 SURFAC CEMENT CMNT P Line up & SLB pump 5,1 bbls CW 2,290.0 2,290.0 09:15 13:00 100r. Pressure test lines to 3500 psi - good test. Pump 34.9 bbls of CW 100 @ 4.1 bpm, 142 psi, F10 26%. Batch up and pump 80.1 bbls of 10.5 ppg MP II @ 6 bpm, 190 psi, Drop bottom plug & start batching lead. Pump 404.2 bbls of 11.0 ppg Deeperete lead cement at 6 bpm, 309 psi, F/O 27%. Land bottom plug at 217 bbls pumped. Land hanger at 370 bbls lead pumped Balch and pump 58.4 bbls of 12 ppg tail cement @ 5.5 bpm, 270 psi, F/0 43%. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 9.5 ppg spud mud @ 8 bpm, 553 psi, F/0 38%. @ 192.5 bbl. reduced rate to 3 bpm 370 psi. Bump plug with 2009 strokes,fnal circ. psi. 380 Pressure up to 950 psi & hold for 5 minutes. Bleed off pressure, Check floats good. CIP 12:37 hrs 08/23/19. 222 Bbls cement to surface. 8/23/2019 8/23/2019 1.25 SURFAC CEMENT CMNT P Monitor cement column in stack. fat 0.0 0.0 13:00 14:15 15 Min level fell 5'= 1.38 Bbls / 5.5 BPH, 2nd 15 Min level fell 1.1' = .3 Bbls / 1.2 BPH. 3rd 15 Min level did not fall. 8/23/2019 812312019 1.75 SURFAC CEMENT RURD P RID landing joint, GBR rasing 0.0 0.5- 14:15 16:00 equipment. Clean and Gear rig floor. Jet riser and flow line with black water, inspect and clean flow line in pits and clean cement from valves. 8/23/2019 8/2312019 2.00 SURFAC CEMENT NUND P N/D divertedess riser. and GE starting 0.0 0.0 16:00 18:00 head. Tagged firm cement 3.75' below concoctor..5' below 4" outlets. 8/23/2019 8/2312019 2.50 SURFAC WHDBOP NUND P N/U casing and tubing heads as per 0.0 18:00 20:30 Don MCYckers. ULDS @ 34.67'. LLDS @ 36.29' RKB. 8/23/2019 8123/2019 0.25 SURFAC WHDBOP PRTS P Test wellhead seals 712000 PSI for 10 20:30 20:45 Min - Good test 8/23/2019 8/2412019 3.25 SURFAC WHDBOP NUND P NIL adapter spools TI well head. NIL 20:45 00:00 BOP with 7 5/8 solid body rams in the top, 3 1/2 x 6" in the bottom. R/U choke and kill lines. R/U riser. Plug 4" outlets on concoctor. Page 3118 Report Printed: 912 012 01 9 Uperations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Star( Depth SWIrme End Time Dur (hr) phase Op Code Activity CWe Time P -T -X Operation (ftl(a) End De"(ftKB) 8/24/2019 8/24/2019 5.00 SURFAC WHDBOP NUND P N/U adapter spools T/ well head. N/U 00:00 05:00 BOP with 7 5/8 solid body rams in the top, 3 1/2 x 6" in the bottom. R/U choke and kill lines. R/U riser. Plug 4" outlets on concoctor. 8/24/2019 8/24/2019 0.50 SURFAC WHDBOP BOPE P Shell test BOP. 250/3500 PSI for 5 05:00 05:30 Min each - Good test 8/24/2019 8/24/2019 2.00 SURFAC WHDBOP WAIT P Notify AOGCC rep Jeff Jones of 05:30 07:30 passing shell test. Instructed to wait on rep to perform BOP test. 8/24/2019 8/24/2019 5.50 SURFAC WHDBOP BOPE P Perform Initial BOPE test. All tests at 07:30 13:00 250/3500 psi. Test with 7 5/8", 5" and 4" test joints. Test annular preventers with 7 5/8" & 4" test joint. Test upper pipe rams with 7 5/8 test joint. Test the Lower pipe rams with 4" & 5" Test joint. Test blind rams.Test choke valves #1 to #14, upper and lower top drive IBOP's, test & 5" dart and TIW valves, test rig floor, mezzanine, HCR and manual kill valves, test HCR and manual choke valves, hydraulic and manual chokes to 1500 psi and demonstrate bleed off. Perform accumulator test. Starting pressure=3000 psi, after function= 1725 psi, 200 psi attained=12 sec's, full recovery=78 sec. 6 nitrogen bottles at 2050 psi. Test gas alarms, PVT and flow show. Test was witnessed by AOGCC Rep. Jeff Jones. Zea overall Fail/Pass. 1 FaiVPass on accumulator: annular 4 -way valve was not actuating fully - which was adjusted back to 100%. 1 Fail/Pass on accumulator air pump gauge showing erratic pressure - air pump repaired reconnecting the piston to plunger with roll pin. 8/24/2019 8/24/2019 0.50 SURFAC WHDBOP RURD P RID testing equipment. B/D choke 13:00 13:30 manifold, choke and kill lines. 8/24/2019 8/24/2019 0.50 SURFAC WHDBOP RURD P Install wear bushing 12.35" ID. 13:30 14:00 8/24/2019 8/24/2019 0.50 SURFAC DRILLOUT SFTY P PJSM with SLB and rig crew on P/U 14:00 14:30 BHA 8/24/2019 8/24/2019 2.75 SURFAC DRILLOUT BHAH P P/U 9.875" Intermediate BHA T/ 404' 0.0 404.0 14:30 17:15 8/24/2019 8/24/2019 2.75 SURFAC DRILLOUT PULD P PUDP F/ 404'T/ 2185' MD. Tag TOC 404.0 2,185.0 17:15 20:00 @ 2185', set down 1 OK to confirm. P/U=108K, SI0=98K 8/24/2019 8/24/2019 1.25 SURFAC DRILLOUT CIRC P Circ and Cond mud @ 2170', 446 2,185.0 2,170.0 20:00 21:15 GPM, 646 PSI, 45% F/O. 9.3 PPG in and out. P/U=108K, S/0=98K 8/24/2019 8/24/2019 1.00 SURFAC DRILLOUT RUNL P R/U surface lines to test 10 3/4" 2,170.0 2,170.0 21:15 22:15 casing. Purge lines with mud. 8/24/2019 8/24/2019 0.75 SURFAC DRILLOUT PRTS P Test 10 3/4" casing T/ 3100 PSI for 30 2,170.0 2,170.0 22:15 23:00 Min - Good test. 8/24/2019 8/24/2019 0.50 SURFAC DRILLOUT RURD P RID surface testing lines and B/D kill 2,170.0 2,170.0 23:00 23:30 line. 8/24/2019 8/25/2019 0.50 SURFAC DRILLOUT DRLG P Tag up and drill cement F/ 2185'T/ 2,170.0 2,203.0 23:30 00:00 2203' MD @ 450 GPM, 660 PSI, 45% F/0, 40 RPM, 31K Tq, 5K WOB, P/U=108K, S/0=98K, ROT=101 K. Off bottom 600 PSI, 3K Tq Page 4118 ReportPrinted: 9/20/2019 Operations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sm Depth SW Tme End Time Dur (hr) Phase op Cme Activity Code Time P -T -X Openabon (flKB) End Depth (MB) 8/25/2019 8/25/2019 6.00 SURFAC DRILLOUT COCF P Drill cement, shoe track and 20' of 2,203.0 2,315.0 00:00 06:00 new hole F/ 2203'T/ 2315' MD, 2116' TVD @ 400-050 GPM, 525 PSI, 45% F/0, 40-80 RPM, 5-91K Tq, 3-12 WOB, P/U=110K, S/0=98K, ROT=103K. Off bottom 600 PSI, 3K Tq 8/2512019 8/2512019 2.00 SURFAC DRILLOUT CIRC P Condition mud while rotating & 2,315.0 2,225.0 06:00 08:00 reciprocating F/ 2315'T/ 2225' MD @ 557 GPM, 993 PSI, 46% F/0,35 RPM, 4K Tq, P/U=110K, S/0=98K, ROT=103K. Mag gas 34. Pull up through shoe with no rotation, observed over pull of 4K. Worked string though with rotation to clean up shoe. 8/25/2019 8/25/2019 0.50 SURFAC DRILLOUT SFTY P PJSM on FIT with rig crew. R/U 2,225.0 2,225.0 08:00 08:30 surface equipment for test. 8/25/2019 8/2512019 1.25 SURFAC DRILLOUT FIT P Performed FIT with test pump. 430 2,225.0 2,225.0 08:30 09:45 PSI achieved EMW= 13.0 PPG. S/I well observed pressure drop F/ 430 PSI T/ 325 PSI 8/25/2019 8/2512019 0.75 SURFAC DRILLOUT RURD P RID testing equipment. Replace SLB 2,225.0 2,225.0 09:45 10:30 stand pipe sensor. 8/25/2019 8/25/2019 1.50 INTRMI DRILL DDRL P RIH, Drill 9 7/8" Surface Hole F/2315'- 2,225.0 2,481.0 10:30 12:00 T12481' MD, 2300 TVD @ 566 GPM, 685 PSI, 48% F/O, 80 RPM, 4K Tq, l l K WOB, ECD's =9.8, P/U=110K, 8/0=100K, ROT=103K. Off bottom 680 PSI, 2K Tq. Displace 9.3 PPG spud mud with 9.2 PPG LSND. SPR'S @ 2386' MD, 2249' TVD MW - 9.2 PPG, HRS -11:20 MP #1) 30 SPM- 100 PSI, 40 SPM - 120 PSI MP #2) 30 SPM- 96 PSI, 40 SPM- 110 PSI 8125/2019 8/25/2019 6.00 INTRMI DRILL DDRL P Drill 97/8" Surface Hole F2481' -T/ 2,481.0 3,237.0 12:00 18:00 3237' MD, 2740' TVD @ 673 GPM, 993 PSI, 49% NO, 120 RPM, 5K Tq, 5K WOB, ECD's =9.92, P/U=117K, S/0=102K, ROT=104K. Off bottom 991 PSI, 4K Tq. Max gas 70 8/25/2019 8126/2019 6.00 INTRMI DRILL DDRL P Drill 97/8" Surface Hole F/3237'- T/ 3,237.0 3,984.0 18:00 00:00 3984' MD, 3150' TVD@ 673 GPM, 1090 PSI, 48% F/0, 120 RPM, 6K Tq, 4K WOB, ECD's =9.88, P/U=126K, S/0=112K, ROT=117K. Off bottom 1083 PSI, 4K Tq. Max gas 86 SPR'S @ 3900' MD, 3106' TVD MW - 9.2 PPG, HRS -23:15 MP #1) 30 SPM- 130 PSI, 40 SPM - 160 PSI MP #2) 30 SPM- 130 PSI, 40 SPM - 160 PSI Page 5118 Report Printed: 9/20/2019 Operations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Shin Depth Shed Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (fIKB) 8/26/2019 8/26/2019 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Surface Hole F/3984'- T/ 3,984.0 4,684.0 00:00 06:00 4684' MD, 3464' TVD@ 673 GPM, 1131 PSI, 49% F/0, 120 RPM, 7K Tq, 12K WOB, ECD's =9.88, P/U=134K, S/0=110K, ROT=124K. Off bottom 1130 PSI, 5K Tq. Max gas 104 8/26/2019 8/26/2019 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Surface Hole F/4684'- T1 4,684.0 5,320.0 06:00 12:00 5320' MD, 3661' TVD@ 673 GPM, 1300 PSI, 50% F/0, 100 RPM, 7K Tq, 14K WOB, ECD's =10.23, P/U=133K, S/0=114K, ROT=125K. Off bottom 1296 PSI, 5K Tq. Max gas 41 SPR'S @ 4749' MD, 3491' TVD MW - 9.2 PPG, HRS -06:30 MP #1) 30 SPM- 160 PSI, 40 SPM - 200 PSI MP #2) 30 SPM- 160 PSI, 40 SPM - 200 PSI 8/26/2019 8/26/2019 2.25 INTRMI DRILL DDRL P Drill 97/8"Surface Hole F/5320' -T/ 5,320.0 5,536.0 12:00 14:15 5536' MD, 3694' TVD@ 757 GPM, 1635 PSI, 50% F/O, 140 RPM, 7.5K Tq, 1 O WOB, ECD's =10.43, PIU=133K, S/0=114K, ROT=124K. Off bottom 1632 PSI, 4K Tq. Max gas 207 8/26/2019 8/26/2019 0.50 INTRMI CASING DDRL P Obtain final torque and drag 5,536.0 5536.5- 14:15 14:45 parameters, and final survey. UD 2 singles. P/U=133K, S/0=114K, ROT=124K. 4K Tq SPR'S @ 5533' MD, 3694' TVD MW - 9.2 PPG, HRS -14:30 MP #1) 30 SPM- 200 PSI, 40 SPM - 225 PSI MP #2) 30 SPM- 180 PSI, 40 SPM - 240 PSI 8/26/2019 8/26/2019 1.25 INTRMI CASING CIRC P Pump to vis sweep followed by 11.2 5,536.0 5,443.0 14:45 16:00 PPG hi vis sweep while Rot & Recip F/ 5536' T/5443' MD @ 758 GPM, 1643 PSI, 50% F/O, 120 RPM, 5K Tq, P/U=133K, S/0=114K, ROT=124 8/26/2019 8/26/2019 0.25 INTRMI CASING OWFF P Observe well for flow - No flow 5,443.0 5,443.0 16:00 16:15 8/26/2019 8/26/2019 1.75 INTRMI CASING BKRM P BROOK LOOP in mouse hole F/ 5,443.0 5,155.0 16:15 18:00 5443' T/ T/ 5155' MD @ 757 GPM, 1578 PSI, 50% F/0, 110 RPM, 4K Tq, Rotating P/U=II6K 8/26/2019 8/27/2019 6.00 INTRMI CASING BKRM P BROOK LDDP in mouse hole F/ 5,155.0 3,807.0 18:00 00:00 5155' T/ T/ 3807' MD @ 757 GPM, 1413 PSI, 50% F/O, 110 RPM, 4K Tq, Rotating P/U=108K Pump low/hi vis sweep while back reaming F/ 3902'T/ 3807'. 60% increase in cutting at shaker. 8/27/2019 8/27/2019 6.00 INTRMI CASING BKRM P BROOK LDDP in mouse hole F/ 3,807.0 2,290.0 00:00 06:00 3,807 - T/ 2,290' MD @ 757 GPM, 1201 PSI, 50% FIC, 110 RPM, 3K Tq, Rotating P/U=100, 2X Ream @ 2,860' MD -T/ 2,786 MD, @ 2,768 — 2,720', @ 2,611 — 2,595' due to 12k to 18k torque. Slow to 60 rpm while pull stabilizers through shoe@ 2,290' Page 6118 Report Printed: 912 012 01 9 Uperations Summary (with Timelog Depths) - 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time D,'h') Phase Op Code Activity Cade Time P -T -X Operation Stan Depth (ftKB) End Depth (aKB) 8/27/2019 8/27/2019 1.00 INTRMI CASING CIRC P Pump 42 bbl. 9,2 ppg Low -Vis sweep 2,290.0 2,290.0 06:00 07:00 followed by 40 bbl. 11.2 ppg. Hi - density sweep @ 757 gpm, 1191 psi. 50% F/O, 60 rpm. Circ until the shakers are clean. 60% increase in cutting at shaker when sweeps came back. 8/27/2019 8/27/2019 0.25 INTRMI CASING OWFF P Monitor well (Static) 2,290.0 2,290.0 07:00 07:15 8/27/2019 8/2712019 2.75 INTRMI CASING TRIP P POOH on Elevator, Laying down 5" 2,290.0 951.0 07:15 10:00 j Drillpipe F/2,290-T/951'MD 8/27/2019 8/27/2019 1.00 INTRMI CASING SFTY P Spill drill in the Pits, Rig evacuation 951.0 951.0 10:00 11:00 drill, Fire drill in motor room drill, Man down drill, All drills are recorded in wellview operational checks 8/27/2019 8/27/2019 1.00 INTRMI CASING RGRP T Troubleshoot hole fill pump system 951.0 951.0 11:00 12:00 8/27/2019 8127/2019 1.00 INTRMI CASING TRIP P POOH on Elevator, Laying down 5" 951.0 248.0 12:00 13:00 ddllpipe F/951'-T/248'M1D 8/27/2019 8/2712019 0.25 INTRMI CASING OWFF P Monitor well before laying down BHA 248.0 248.0 13:00 13:15 1 (Static) 8127/2019 8/27/2019 1.50 INTRMI CASING SHAH P Laydown 9 7/8 BHA 248.0 0.0 13:15 14:45 8/27/2019 8/27/2019 1.00 INTRMI CASING CLEN P Clean and clear rig floor, Pickup BOP 0.0 0.0 14:45 15:45 cleaning tool and flush out the BOP stack 8/27/2019 8/2712019 1.50 INTRMI CASING RURD P Pull wear ring, rig up 7 5/8" casing 0.0 0.0 15:45 17:15 equipment. 8/27/2019 8/27/2019 0.75 INTRMI CASING PUTB P Make up 7 5/8" shoe track, baker lock 0.0 211.0 17:15 18:00 each connection. Make TQ = 10,300 8/27/2019 8/27/2019 4.00 INTRMI CASING PUTB P RIH with 7.625" 29.7 ppf L-80, Hyd 211.0 2,280.0 18:00 22:00 563, F/211' - 2,280' MD, Fill on the fly. Top off evey 10 joints. 8127/2019 8/27/2019 1.00 INTRMI CASING CIRC P Circ. B/U @ the 10.75 shoe. stage 2,280.0 2,280.0 22:00 23:00 pumps up to 251 gpm, 173 psi. 28% F/O, Circ. BILI @363 gpm 179 psi. FIC, 38%. (No losses during circulation) 8/27/2019 812812019 1.00 INTRMI CASING PUTB P RIH with 7.625" 29.7 ppf L-80, Hyd 2,280.0 2,457.0 23:00 00:00 563, F/2,280'- 2,457' MD, Fill on the fly. Top off evey 10 joints. 8/28/2019 8/28/2019 1.25 INTRMI CASING PUTB P RIH with 7.625" 29.7 ppf L-80, Hyd 2,457.0 3,230.0 00:00 01:15 563, F/2,457'- T/ 3,230 MD, Fill on the fly. Top off every 10 joints. SIO 107k 8/28/2019 8/28/2019 1.00 INTRMI CASING CIRC P Circulate B/U while continue RIH with 3,230.0 3,312.0 01:15 02:15 7.625" 29.7 ppf L-80, Hyd 563, Due to improper hole fill @ 6bpm F/ 3,230'- T/ 3,312' 8/28/2019 8/28/2019 4.00 INTRMI CASING PUTB P RIH with 7.625" 29.7 ppf L-80, Hyd 3,312.0 4,252.0 02:15 0615 563, F/3,312' -T/ 4,252 MD, Fill on the fly. Top off every 10 joints. 101k S/O 8128/2019 8/28/2019 0.75 INTRMI CASING CIRC P Circulate B/U while continue RIH with 4,252.0 4,293.0 06:15 07:00 7.625" 29.7 ppf L-80, Hyd 563, Due to increasing drag F/ 4,252'-T/4,293' @ 6bpm. Regained 6/8k after circulation 8/28/2019 8/28/2019 1.25 INTRMI CASING PUTB P RIH with 7.625" 29.7 ppf L-80, Hyd 4,293.0 5,488.0 07:00 08:15 563, F/4,252" - T/ 5,488 MD, Fill on the fly. Top off every 10 joints. 110k SIO 8/28/2019 8/28/2019 0.25 INTRMI CASING HOSO P Make hanger to landing joint. 5,488.0 5,488.0 08:15 0830 Page 7/18 Report Printed: 9/2 012 01 9 Uperations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op code, Activity Dials Time P -T -X Operation (t0(B) End Depth (fiKB) 8/28/2019 8/28/2019 0.50 INTRMI CASING WASH P Wash down FI 5,488' MD T/5,528' @ 5,468.0 5,528.0 08:30 09:00 3bpm, 240 psi. 20% F/O, P/U = 163, SIO = 115k. Tag landing ring and reciprocate, rasing F/ 5,528'—T/ 5,498 8/28/2019 8/28/2019 0.25 INTRM1 CEMENT RURD P Rig up the cement hose, blow down 5,528.0 5,528.0 09:00 09:15 topdrive 8128/2019 8/28/2019 1.50 INTRMI CEMENT CIRC P Circulate and condition mud, easing 5,528.0 5,528.0 09:15 10:45 rate up to 8bpm 461 psi. 39% F/O (4806 total strokes pumped) 8/28/2019 8/28/2019 4.00 INTRMI CEMENT CMNT P Load 1st bottom plug. Pump 5 bbls 5,528.0 5,528-0- 10:45 14:45 Mud Push. Test lines to 4000 psi. Pump 45bbls of 13.5 ppg Mud Push II, 4 bpm, 260 psi. 20% Flow out. Load 2nd bottom plug. (Cmt Wet @ 11:40hrs) Batch up and pump 110.5 bbis 15.8 ppg Class G cement - pump rale 5.6 bpm, 260 psi, 38% Flow out. Load lop plug. Schlumberger pump 10.0 bbls water. Swap to rig and displace with 9.2 ppg. LSND. @ 7 bpm 148 psi. 17% F/O. Decreased rate to 6bpm @ 79.9 bbl. Pumped, 123 psi. 32% F/O decreased rate to 5 bpm @ 179.9 bbl. pumped 549 psi. 28% F/O decreased rate to 2bpm @ 229.9 bbl. pumped 800 psi. 12% F/O, Bumped plug @ 237.8 bbl. pumped (2362 stks.) 900 psi. pressured up to 1400 psi. hold for 5 min. Bled down pressure to check floats. Could not confirm floats were holding. Pressure up the casing to 1400 psi. held for 5 min, bled presser off floats held. Pumped 2 bbl. and bled off 2 bbl. CIP @ 14:47 8/28/2019 8/28/2019 0.50 INTRMI CEMENT PRTS P Pressure lest 7 5/8 casing to 3500 psi. 5,528.0 5,528.0 14:45 15:15 hold for 30 min. (Good Test) 8/28/2019 8/28/2019 0.50 INTRMI CEMENT RURD P Rig down cement equipment and 5,528.0 5,528.0 15:15 15:45 casing equipment, clean and clear dg floor. 8/28/2019 8/2812019 1.00 INTRMI CEMENT RURD P LID landing joint, blow down top drive, 5,528.0 5,528.0 15:45 16:45 pump out stack and 8/28/2019 8/28/2019 1.25 INTRMI CEMENT W WSP P Install pack off test to 5000 psi. hold 5,528.0 5,528.0 16:45 18:00 for 10 min. (Good Test) lay down hwdp and pack -off running tool. 8/28/2019 8/28/2019 1.25 INTRMI CEMENT CLEN P Clear rig floor, install wear ring ID= 5,528.0 5,528.0 18:00 19:15 9.0625" 8/28/2019 8/28/2019 1.25 INTRMI CEMENT BOPE P Test 4" floor valves TIW/Dart 250/3500 5,528.0 5,528.0 19:15 20:30 hold for 5 min. SIMOPS: Load 4" DP in the pipe shed 8/28/2019 8/28/2019 1.25 INTRMI CEMENT OTHR P @ 2045 hrs. fluid pack CIA with .6 bbl. 5,528.0 5,528.0 20:30 21:45 of H2o, Pump 1 bbl. in to the O/A (10 slks total) broke over @ 450 and bled to 200 psi. Charted. Continue pumping 1 bbl. per hr. into the O/A. SIMOPS; Continue changing over saver sub, and install hole fill line 8128/2019 8282019 0.75 INTRMI CEMENT RURD P Continue changing saver sub 5,528.0 5,528.0 21:45 22:30 8/28/2019 8/29/2019 1.50 INTRMI CEMENT SLPC P Slip and cut off drilling line 5,528.0 5,528.0 22:30 00:00 8/29/2019 8/29/2019 1.50 INTRMI CEMENT SLPC P Continue Cut & Slip off drilling line. 5,528.0 5,528.0 00:00 01:30 Page 8118 Report Printed: 9/20/2019 Uperations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stan cepm Sten Time End Tim. our (hr) Phase Op Code Activey Code Time P -T -X Operation (eKa) End Depth(flKa) 8/29/2019 8/29/2019 1.00 INTRMI CEMENT GLEN P Rig down slip & Cut equipment, Clean 5,528.0 0.0 01:30 02:30 drip pan, continue pumping 1 bbl. down the CIA per hour 8/29/2019 8/29/2019 1.50 INTRMI DRILLOUT SHAH P PJSM. Make up 6.75 BHA T/393' 0.0 393.0 02:30 04:00 8/2912019 8/29/2019 3.00 INTRMI DRILLOUT PULD P RIH with 4" DP from pipeshed F/ 393'- 393.0 2,290.0 04:00 07:00 T/ 2,290 8/29/2019 812912019 0.75 INTRMI DRILLOUT DHEQ P Shallow hole test SLB tools @ 250 2,290.0 2,290.0 07:00 07:45 gpm, 1126 psi. 31% F/O, P/U = 85k S/0= 61 k, Pump 1 bbl. down the O/A 8/29/2019 8/29/2019 4.50 INTRMI DRILLOUT QEVL P Make up full stands and RIH MADD 2,290.0 5,318.0 07:45 12:15 pass F/2,290 - 5,318' MD PIU = 119k S/O= 85k, Pump 1 bbl. down the O/A @ 09:15 812912019 8/2912019 0.50 INTRMI DRILLOUT WASH P Washed down F/5,318'- 5,329'@ 230 5,318.0 5,397.0 12:15 12:45 gpm, 1237 psi. Rot. 75 rpm F/ 5,329'- T/5,397 (Tagged Plugs) 8/29/2019 8/29/2019 2.25 INTRMI DRILLOUT COCF P Drill out plugs & float collar F/5,397'- 5,397.0 5,402.0 12:45 15:00 T/ 5,402' MD 236 gpm, 1338 psi. 32% FIO, 80 rpm 6K Tq. 2K WOB, PIU = 120k S/O = 86k ROT = 96k 8/29/2019 8/29/2019 1.25 INTRMI DRILLOUT DRLG P Drill cement F/ 5,402'—T/5,526' MD 5,402.0 5,526.0 15:00 16:15 236 gpm, 1338 psi. 32% F/0, 80 rpm 6K Tq. 2K WOB, P/U = 117k S/O = 82k ROT = 96k 8/29/2019 8/29/2019 1.00 INTRMI DRILLOUT DRLG P Drill Shoe and 20' new hole. F/ 5,526' 5,526.0 5,556.0 16:15 17:15 — T/5,556' MD 229 gpm, 1279 psi. 30% F/O, 100 rpm 6K Tq. 2K WOB, PIU = 117k S/O = 82k ROT = 96k 8/29/2019 8/29/2019 1.50 INTRMI DRILLOUT CIRC P Circ and condition mud for a F.I. T 5,556.0 5,513.0 17:15 18:45 Rotate & Reciprocate F/ 5,556' — T/5,513' MD 230 gpm 1261 psi. 50 rpm, 5K Tq. ECD = 10.20 (no over pull when pulling through the shoe) 8/29/2019 8/29/2019 0.25 INTRMI DRILLOUT TRIP P POOH T/5,513', Rack back stand in 5,513.0 5,513.0 18:45 19:00 the derrick, Rig up for a F.I.T. 8/29/2019 8/29/2019 1.00 INTRMI DRILLOUT FIT P Preform FIT pressured up to 710 psi. 5,513.0 5,513.0 19:00 20:00 with 9.3 ppg. mud = 13.0 EMW 8/29/2019 6129/2019 0.50 INTRMI DRILLOUT RURD P Rig down/Blow down test equipment. 5,513.0 5,513.0 20:00 20:30 8/29/2019 8129/2019 0.25 INTRMI DRILLOUT TRIP P RIH F/5,513' -T/5,556' 5,513.0 5,556.0 20:30 20:45 8129/2019 8/29/2019 1.75 PROD1 DRILLOUT CIRC P Displace well to 9.2 ppg. Flo -Pro NT 5,556.0 5,513.0 20:45 22:30 WMB @ 230 gpm, 1363 psi. 27% F/O 80 RPM, 5k Tq. Reciprocate F/ 5,556' —T/ 5,513' MD 8/29/2019 8/3012019 1.50 PROD1 DRILLOUT TRIP P Pull to the shoe and clean surface 5,513.0 5,513.0 22:30 00:00 lines, dg floor, shakers, troughs. 8/30/1019 8/30/2019 2.00 PROD1 DRILLOUT GLEN P Clean surface lines, dg floor, shakers, 5,513.0 5,513.0 00:00 02:00 1 1 troughs, and pits 8/30/2019 8/30/2019 0.50 PROD1 DRILLOU I TRIP P RIH F/ 5,513'- T/ 5,556' MD, Attempt 5,513.0 5,556.0 02:00 02:30 1 1 to engage NOVOS, would not engage Page 9118 Report Printed: 9/20/2019 Uperations Summary (with Timelog Vepths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start DepM Start Time End Time Dur(hr) Phase Op Cade Activity Code Time P -T -X Operation (ftKB) End Depth(ftKB) 8/30/2019 8/30/2019 3.50 PRODi DRILL DDRL P Drill 6'/. hole F/ 5,556'— T/ 5,828' MD, 5,556.0 5,828.0 0230 06:00 3,708 TVD @ 260 gpm, 1513 psi, 30% F/O, 80 rpm, 3K Tq. I WOB, ECD = 10. 16, Off Btm = 1512 psi. 2k Tq, P/U= 104k S/O= 92k ROT= 97k Max Gas= 256 units. SPR'S @ 5,553'MD, 3693' TVD, MW - 9.2 PPG, HRS- 02:14 MP #1) 20 SPM -320 PSI, 30 SPM- 460PSL MP #2) 20 SPM -300 PSI, 30 SPM- 450PSL 8/30/2019 8/30/2019 6.00 PROD1 DRILL DDRL P Drill 6'/. hole F/ 5,828'— T/ 6,275' MD, 5,828.0 6,275.0 0600 12:00 3,700 TVD @ 260 gpm, 1601 psi, 30% F/O, 120 rpm, 3K Tq. 2k WOB, ECD = 10.40, Off Btm = 1600 psi. 2k Tq. P/U= 104k S/O= 88k ROT= 97k Max Gas= 593 units SPR'S @ 5,895'MD, 3713' TVD, MW - 9.2 PPG, HRS- 06:52 MP #1) 20 SPM -330 PSI, 30 SPM -500 PSI. MP #2) 20 SPM -300 PSI, 30 SPM -460 PSI. 8/30/2019 8/30/2019 6.00 PRODII DRILL DDRL P Drill 6'/. hole F/ 6,275'— T/ 6,693' MD, 6,275.0 6,693.0 1200 1800 3720 TVD @ 260 gpm, 1638 psi, 33% F/O, 120 rpm, 3K Tq. 2k WOB, ECD = 10.39, Off Btm = 1637 psi. 1 k Tq. P/U= 105k S/O= 90k ROT= 98k Max Gas= 112 units 8/30/2019 8/31/2019 6.00 PROD1 DRILL DDRL P Drill 6'/. hole F/ 6,693'—T/ 7,112' MD, 6,693.0 7,112.0 18:00 00:00 3686 TVD @ 260 gpm, 1634 psi, 33% F/O, 120 rpm, 3K Tq, 2k WOB, ECD = 10.32, Off Btm = 1631 psi. 1 k Tel. P/U= 107k S/O= 90k ROT= 97k Max Gas= 124 units SPR'S @ 6,750'MD, 3724' TVD, MW - 9.3 PPG, HRS- 18:30 MP #1) 20 SPM -340 PSI, 30 SPM -520 PSI. MP #2) 20 SPM -340 PSI, 30 SPM -500 PSI, 8/31/2019 8/31/2019 6.00 PROD1 DRILL DDRL P Drill 6 % hole F/ 7,112'—T/ 7,434' MD, 7,112.0 7,434.0 00:00 06:00 3646 TVD @ 261 gpm, 1711 psi, 30% F/O, 120 rpm, 3K Tq. 3k WOB, ECD = 10.55, Off Btm = 1698 psi. 1 k Tq. P/U= 107k S/O= 87k ROT= 97k Max Gas= 87 units Page 10118 ReportPrinted: 9/20/2019 Uperations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Lop Steri Depm Start Tarre Eno Time Dur (hr) Phase Op Code Activity Code Time P -T -x Opessum (ftKB) EM Depm (XKB) 8/31/2019 8/31/2019 6.00 PROD1 DRILL DDRL P Drill 6 %, hole FI 7,434'—T17,828' MD, 7,434.0 7,828.0 06:00 12:00 3737 TVD @ 261 gpm, 1710 psi, 30% FIO, 120 rpm, 4K Tq. 2k WOB, ECD = 10.44, Off Btm = 1700 psi. 3k Tq. P/U= 110k S/C= 83k ROT= 97k Max Gas= 87 units. SPR'S @ 7,51 O'MD, 3636' TVD, MW - 9.2 PPG, HRS- 06:52 MP #1) 20 SPM -400 PSI, 30 SPM -560 PSI. MP #2) 20 SPM -350 PSI, 30 SPM -530 PSI. 8/31/2019 8/31/2019 6.00 PROD1 DRILL DDRL P Drill 6 %. hole F/ 7,828'—T/ 8368' MD, 7,828.0 8,368.0 12:00 18:00 3673 TVD @ 261 gpm, 1722 psi, 30% F/0, 120 rpm, 4K Tq. 2k WOB, ECD = 10.54, Off Btm = 1719 psi. 3k Tq. P/U= 112k S/O= 82k ROT= 97k Max Gas= 116 units 8/31/2019 9/1/2019 6.00 PRODI DRILL DDRL P Drill 6 % hole FI 8,368'—T/ 8,837' MD, 8,368.0 8,837.0 18:00 00:00 3693 TVD @ 261 gpm, 1738 psi, 30% NO, 120 rpm, 41K Tq. 2k WOB, ECD = 10.52, Off Btm = 1740 psi. 3k Tq. P/U= 114k S/O= 84k ROT= 97k Max Gas= 284 units 9/1/2019 9/1/2019 6.00 PROD1 DRILL DDRL P Drill 6 % hole F/ 8,837'— T/ 9,376' MD, 8,837.0 9,376.0 00:00 06:00 3703 TVD @ 260 gpm, 1782 psi, 30% F/O, 120 rpm, 41K Tq. 2k WOB, ECD = 10.58, Off Blm = 1774 psi. 3k Tq. PIU= 114k S/O= 81 k ROT= 97k Max Gas= 560 units 9/1/2019 9/1/2019 6.00 PROD1 DRILL DDRL P Drill 6 % hole F/ 9,376'—T/ 9,894' MD, 9,376.0 9,894.6- 06:00 12:00 3712 TVD @ 272 gpm, 2013 psi, 30% F/0, 120 rpm, 4K Tq. 1k WOB, ECD = 10.78, Off Btm = 1013 psi. 4k Tq. PIU= 114k S/O= 79k ROT= 97k Max Gas= 560 units. SPR'S @ 9,408'MO, 3705' TVD, MW - 9.2 PPG, HRS- 06:40 MP #1) 20 SPM -390 PSI, 30 SPM -570 PSI. MP #2) 20 SPM -400 PSI, 30 SPM -580 PSI. 9/1/2019 9/1/2019 6.00 PROD? DRILL DDRL P Drill 6%hole F/9,894'—T/10,450' 9,894.0 10,450.0 12:00 18:00 MD, 3745 TVD @ 268 gpm, 2021 psi, 31 % FIO, 120 rpm, 5K Tq. 2k WOB, ECD = 10.90, Off Btm = 2001 psi. 4k Tq. P/U= 117k S/0= 80k ROT= 97k Max Gas= 139units 9/112019 9/2/2019 6.00 PROD1 DRILL DDRL P Drill 63% hole F/ 10,450'—T/ 10,790' 10,450.0 10,790.0 18:00 0000 MD, 3765 TVD @ 274 gpm, 2126 psi, 31% F/O, 120 rpm, 6K Tq. 2k WOB, ECD = 10.93, Off Btm = 2118 psi. 4k Tq. P/U= 118k SIO= 76k ROT= 97k Max Gas= 222 units SPR'S @ 10,453'MD, 3765' TVD, MW - 9.2 PPG, HRS- 18:20 MP #1) 20 SPM -460 PSI, 30 SPM -660 PSI. MP #2) 20 SPM -440 PSI, 30 SPM -660 PSI. Page 11/18 ReportPrinted: 9/2012019 . Uperations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sen Depth sten Tare End Time our(hr) Phase Op code Activity Code Time P4A Operation (ftKB) EM Depth(f1KB) 9/2/2019 9/22019 6.00 PROD1 DRILL DDRL P Drill 63%hole F/10,790'—T/11,212' 10,790.0 11,212.0 00:00 06:00 MD, 3768 TVD @ 274 gpm, 2050 psi, 31% F/O, 120 rpm, 5K Tq. 4k WOB, ECD = 10.70, Off Btm = 2030 psi. 41< Tq. P/U= 118k S/0= 74k ROT= 97k Max Gas= 104 units 9/22019 9/2/2019 6.00 PROD1 DRILL DDRL P Drill %hole F/ 11,212'—T/ 11,586' 11,212.0 11,586.0 06:00 12:00 MD, 3767 TVD @ 272 gpm, 2107 psi, 31% F/0, 100 rpm, 6K Tq. 9k WOB, ECD = 10.80, Off Btm = 2102 psi. 4k Tq. P/U= 119k S/0= 74k ROT= 97k Max Gas= 45 units SPR'S @ 11,305'MD, 3770' TVD, MW - 9.2 PPG, HRS- 06:45 MP #1) 20 SPM -460 PSI, 30 SPM -680 PSI. MP #2) 20 SPM -450 PSI, 30 SPM -660 PSI. 9/2/2019 9/2/2019 6.00 PRODi DRILL DDRL P Drill 6 % hole F/ 11,586'—T/ 12,046' 11,586.0 12,046.0 1200 1800 MD, 3775 TVD @ 272 gpm, 2227 psi, 30% F/0, 120 rpm, 5K Tq. 2k WOB, ECD = 10.87, Off Btm = 2225 psi. 4k Tq. P/U= 130k S/0= 75k ROT=103k Max Gas= 147 units. (Pick up weight increased due to drilling with stand of HWDP out of the Derrick) 9/2/2019 9/32019 6.00 PROD1 DRILL DDRL P Drill 6 %hole F/ 12,046'—T/ 12,432' 12,046.0 12,432.0 18:00 0000 MD, 3765 TVD @ 273 gpm, 2308 psi, 31 % F/O, 120 rpm, 6K Tq. 2k WOB, ECD = 10.95, Off Btm = 2225 psi. 5k Tq. P/U= 130k S/0= 77k ROT=103k Max Gas= 102 units. SPR'S @ 12,132'MD, 3772' TVD, MW - 9.2 PPG, HRS- 18:35 MP#1) 20 SPM -500 PSI, 30 SPM -740 PSI. MP #2) 20 SPM -500 PSI, 30 SPM -780 PSI. 9/3/2019 9/3/2019 6.00 PROD1 DRILL DDRL P Drill %hole F/ 12,432'—T/ 12,730' 12,432.0 12,730.0 00:00 06:00 MD, 3778 TVD @ 273 gpm, 2541 psi, 30% F/O, 120 rpm, 6K Tq. 2k WOB, ECD = 10.95, Off Btm = 2447 psi. 5k Tq. P/U= 145k S/0= 79k ROT=114k Max Gas= 102 units 9/32019 9/32019 6.00 PROD1 DRILL DDRL P Drill %hole F/ 12,730'—T/ 13,198' 12,730.0 13,198.0 06:00 12:00 MD, 3786 TVD @ 280 gpm, 2626 psi, 30% F/0, 100 rpm, 6K Tq. 6k WOB, ECD = 11.16, Off Btm = 2620 psi. 5k Tq. P/U= 145k S/0= 79k ROT=114k Max Gas= 103 units. SPR'S @ 12,774'MD, 3781' TVD, MW - 9.2 PPG, HRS- 06:25 MID #1) 20 SPM -560 PSI, 30 SPM -830 PSI. MP #2) 20 SPM -570 PSI, 30 SPM -800 PSI. Page 12118 Report Printed: 9120/2019 Uperations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stmt Depm Stan Time End Twe Dur (hr) Phase Op Code Activity Cze Time P -T -X Operation (Pore) End Depen (RKB) 9/3/2019 9/3/2019 6.00 PROD1 DRILL DDRL P Drill 63/ hole F/ 13,198'—T/ 13,603' 13,198.0 13,603.0 12:00 18:00 MD, 3819 TVD @ 272 gpm, 2702 psi, 31 % F/O, 120 rpm, 6K Tq. 2k WOB, ECD = 11.52, Off Btm = 2698 psi. 5k Tq. P/U= 154k S/0= 78k ROT=116k Max Gas= 220 units. 9/3/2019 9/4/2019 6.00 PROD1 DRILL DDRL P Drill 6%hole F113,603'—T/13,972' 13,603.0 13,972.0 18:00 00:00 MD, 3833 TVD @ 273 gpm, 2606 psi, 31% F/O, 120 rpm, 7K Tq. 2k WOB, ECD = 11.21, Off Btm = 2606 psi. 5k Tq. P/U= 160k S/0= 80k ROT=117k Max Gas= 1088 units. SPR'S @ 13,693'MD, 3833' TVD, MW - 9.2 PPG, HRS -19:40 MP #1) 20 SPM -700 PSI, 30 SPM -900 PSI. MP #2) 20 SPM -740 PSI, 30 SPM -920 PSI. 9/4/2019 9/4/2019 225 PROD? DRILL DDRL P Drill %hole F/ 13,972'—T/ 14,165' 13,972.0 14,165.0 00:00 02:15 MD, 3835 TVD @ 261 gpm, 2606 psi, 31 % F/0, 120 rpm, 7K Tq. 2k WOB, ECD = 11.40, Off Btm = 2625 psi. 5k To. P/U= 160k S/0= 79k ROT=117k Max Gas= 449 units. SPR'S @ 14,165'MD, 3835' TVD, MW - 9.2 PPG, HRS -02:25 MP #1) 20 SPM -740 PSI, 30 SPM -940 PSI. MP #2) 20 SPM -700 PSI, 30 SPM -920 PSI. 9/4/2019 9/4/2019 1.50 PROD1 CASING CIRC P CBU @ 261 gpm, 2563 psi. 31% IF/O, 14,165.0 14,165.0 02:15 03:45 120 rpm, 6K Tq, ECD = 11.40, 4168 strks pumped 9/4/2019 9/4/2019 0.25 PROD1 CASING OWFF P Monitor well (Static) 14,165.0 14,165.0 03:45 04:00 9/4/2019 9/4/2019 8.00 PROD1 CASING BKRM P BROOH F/14,165 - 11,770' MO @ 265 14,165.0 11,770.0 04:00 12:00 gpm, 2204 psi. 31 F/O, 120 rpm, 41K Tq. ECD = 10.91 9/4/2019 91412019 6.00 PROW CASING BKRM P BROOH F/11,770'-9,636' MD @ 265 11,770.0 9,636.0 12:00 18:00 gpm, 1966 psi. 31 F/O, 120 rpm, 41K Tq. ECD = 10.72 9/4/2019 9/4/2019 5.00 PROD1 CASING BKRM P BROOH F/9,636'— 7474' MD @ 265 9,636.0 7,474.0 18:00 23:00 gpm, 2039 psi. 31 1`/0, 120 rpm, 41K Tq. ECD = 11.55 9/412019 9/5/2019 1.00 PROD1 CASING BKRM P Pump pressure increased 7474' MD, 7,474.0 7,621.0 23:00 00:00 RIH T/7621' and back reamed @ 100' ft/hr. 271 gpm 2024 psi. 120 rpm. 4k Tq. ECD 11.26 P/U 89k. CBU 2491 strokes pumped 9/5/2019 9/5/2019 0.75 PRODi CASING BKRM P Continue backreaming @ 100' it/hr. 7,621.0 7,475.0 00:00 00:45 271 gpm 2024 psi. 120 rpm. 4k Tq. ECD 11.26 P/U 89k. CBU 2491 strokes pumped. 40% increase in cutting at the shaker. 9/5/2019 9/5/2019PROD1 CASING BKRM P BROOH F/7,475'—T/6,130'MD@ 1 7,475.0 6,130.0 00:45 05:00 270 gpm, 1809 psi. 31% F/O, 120 rpm, 3K Tq. ESD 11. 10, P/U WT=92k. Page 13118 ReportPrinted: 9/20/2019 operations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur ft) Phase Op Code Activity Code Time P -T -X Operawn (M(B) EM Depth(RKB) 9/5/2019 9/5/2019 1.00 PRODI CASING BKRM P Pump pressure increased 6,130' MD, 6,290.0 6,130.0 05:00 06:00 RIH T/6,290' and back reamed @ 100' fl/hr. 271 gpm 1890 psi. 120 rpm. 4k Tq. ECD 11.26 PIU 89k. 30% increase in cutting at the shaker. 915/2019 91512019 4.00 PRODI CASING BKRM P BROOH F/6,130' -T/5,519'' MID @ 6,130.0 5,519.0 06:00 10:00 270 gpm, 1809 psi. 31 % F/O, 120 rpm, 3K Tq. ESD 11. 10, P/U WT =92k. 9/512019 9/512019 2.50 PROD1 CASING CIRC P Rotate & Reciprocate FI 5,519' MD- 5,519.0 5,519.0 10:00 12:30 T/ 5,420' MD @230, gpm. 1138 psi. 30% F/O, 40 rpm, 2K Tq. Pump 9.2 ppg. 36. BBL. Lo vis sweep followed by 9.5 ppg. bbl. Hi Ys sweep. Displaced @ the shoe with solids free 9.2 FloPro mud system. 9/5/2019 91512019 0.25 PRODI CASING OWFF P Monitor well (static), Blow down Top 5,519.0 5,519.0 12:30 12:45 Drive 9/5/2019 91512019 3.00 PRODI CASING TRIP P POOH on elevators LID singles F/ 5,519.0 2,995.0 12:45 15:45 5,519' MD - T/ 2,955' 9/5/2019 9/5/2019 1.75 PRODI CASING TRIP P Drop 2" Rabbit in the drill string, 2,995.0 393.0 15:45 17:30 continue POOH F/ 2,995' MD - T/ 393' 9/5/2019 9/5/2019 0.25 PROD1 CASING OWFF P Monitor Well (Static) 393.0 393.0 17:30 1745 9/512019 9/5/2019 1.50 PROD1 CASING BHAH P L/D 6.75 Production BHA 393.0 0.0 17:45 19:15 9/5/2019 9/5/2019 1.50 PRODI CASING CLEN P Clean and clear dg floor, simops dg up 0.0 0.0 19:15 20:45 and wash BOP stack, Blow down Top Drive. 9/5/2019 9/5/2019 1.00 COMPZN CASING RURD P Rig up to test BOPE 4" & 4.5 Test 0.0 0.0 20:45 21.45 Joint. 9/5/2019 9/6/2019 2.25 COMPZN CASING BOPE P Bi -weekly BOPE lest. All tests ai 0.0 0.0 21:45 0000 250/3500 psi. Test with 4.5" and 4" test joints. Test annular preventers with 4.5" & 4" test joint. Test upper pipe rams was not required to be tested. Test the Lower pipe rams with 4.5" & 4" Test joint. Test blind rams. Test choke valves #110 #14, upper and lower top drive IBOP's, test & 5" dart and TI W valves, test dg floor, mezzanine, HCR and manual kill valves, test HCR and manual choke valves, hydraulic and manual chokes to 1500 psi and demonstrate bleed off. Perform accumulator test. Starting pressure=3000 psi, after function= 1700 psi, 200 psi attained=8 sec's, full recovery --72 sec. 6 nitrogen bottles at 2008 psi. Test gas alarms, PVT and flow show. Test was witnessed by CAPI Lenward Toussanl. Page 14/18 Report Printed: 9/20/2019 . operations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Tme End Time our (hr) Phase op Code A Ay Code Time P -T -x Operation start Depm (aKB) End! Depth (MB) 9/6/2019 9/6/2019 3.25 COMPZN CASING BOPE P Bi -weekly BOPE test. All tests at 0.0 0.0 00:00 03:15 25013500 psi. Test with 4.5" and 4" test joints. Test annular preventers with 4.5" & 4" test joint. Test upper pipe rams was not required to be tested. Test the Lower pipe rams with 4.5" & 4" Test joint. Test blind rams. Test choke valves #1 to #14, upper and lower top drive IBOP's, test & 5" dart and TIW valves, test rig floor, mezzanine, HCR and manual kill valves, test HCR and manual choke valves, hydraulic and manual chokes to 1500 psi and demonstrate bleed off. Perform accumulator test. Starting pressure=3000 psi, after function= 1700 psi, 200 psi attained=8 sec's, full recovery --72 sec. 6 nitrogen bottles at 2008 psi. Test gas alarms, PVT and flow show. Test was witnessed by CAPI Lenward Toussant. 9/6/2019 9/6/2019 0.75 COMPZN CASING RURD P Rig down testing equipment, pull test 0.0 0.0 03:15 04:00 plug & Install wear bushing. 9/6/2019 9/6/2019 1.00 COMPZN CASING RURD P Rig up GBR Casing equipment and 0.0 0.0 04:00 05:00 handling tools 9/6/2019 9/6/2019 3.75 COMPZN CASING PUTB P Pick up/Make up 4.5", #12.6, L-80, 0.0 1,375.0 05:00 08:45 HYD 563 Lower Completion, / Surface — T/ 1,375' MD Make up to 3,800 FTILBS 9/6/2019 9/6/2019 1.50 COMPZN CASING PUTS T Troubleshoot GBR Tongs, swap out 1,375.0 1,375.0 08:45 10:15 1 1 1 power tongs with back ups. 9/6/2019 916/2019 7.75 COMPZN CASING PUTB P Pick up/Make up 4.5", #12.6, L-80, 1,375.0 5,500.0 10:15 18:00 HYD 563 Lower Completion, 11,375— T/ 5,500' MD Make up to 3,800 FT/LBS 9/6/2019 9/7/2019 6.00 COMPZN CASING PUTB P Pick up/Make up 4.5", #12.6, L-80, 5,500.0 8,799.0 18:00 Woo HYD 563 Lower Completion, 15,500' MD — T/ 8,799' MD Make up to 3,800 FT/LBS 917/2019 9/7/2019 1.00 COMPZN CASING PUTB P Pick up/Make up Baker seal bore 8,799.0 8,799.0 00:00 01:00 1 1 extension & flex lock hanger. 9/7/2019 9/7/2019 0.50 COMPZN CASING CIRC P RIH with one stand out ofthe derrick, 8,799.0 8,893.0 01:00 01:30 break circ. @ 8,893' MD, stage rate up to 6bpm 615 psi. 30 % F/O P/U 115k S/O 67k (500 strktotaled pumped) 917/2019 9/7/2019 2.25 COMPZN CASING TRIP P RIH with 4" Drill pipe F/ 8,893'- T/ 8,893.0 11,265.0 01:30 03:45 11,265' MD 1200' fph (Fill pipe on the fry, top off every 5 stands) 9/7/2019 9/712019 4.25 COMPZN CASING TRIP P RIH with 4"HWDP drift with 2" DID 11,265.0 14,165.0 03:45 08:00 drift out of the derrick F/ 11,266- T/ 14,165' MD 1200' fph P/U = 168k SIO = 78k (Fill pipe on the fly, top off every 5 stands) 9/7/2019 9/7/2019 1.00 COMPZN CASING RURD P Rig up to circulate through the cement 14,165.0 14,165.0 08:00 09:00 hose. 9/7/2019 9/7/2019 3.00 COMPZN CASING CIRC P Break circulation staging rate up to 14,165.0 14,165.0 09:00 12:00 5bpm 1035 psi. 20% F/O, pump 5bbl. spacer, displace well with 9.2 brine, 4 bpm 700 psi. 6900 total strokes. 9/7/2019 9/7/2019 1.00 COMPZN CASING SFTY P Pre -job safety meeting with all parties 14,165.0 14,165.0 12:00 1300 involved in the Formic Acid job. 9/7/2019 9/7/2019 1.00 COMPZN CASING OTHR T Troubleshoot computer 14,165.0 14,165.0 13:00 14:00 communication with pump truck. Changed out cable. Page 15/18 Report Printed: 912 012 01 9 Uperations Summary (with Timelog Depths) 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our hr ( ) Phase O Code p AcWi Code tY Time P -T- X OpereBan Sten Depth (WB) End Depth (flKB) 9/7/2019 9/7/2019 1.00 COMPZN CASING SEQP T Pressure test line failed due washed 14,165.0 14,165.0 14:00 15:00 out low torque valve, changed out, retest, (good test) 9/7/2019 9/7/2019 2.00 COMPZN CASING CIRC P SLB pump 320bbl. of formic acid @ 14,165.0 14,165.0 15:00 17:00 4bpm 700 psi. followed with 178bbl. og 9.2ppg. brine. @ 4bpm 530 psi. 9/7/2019 9/7/2019 4.50 COMPZN CASING OWFF P Allow acid to soak and monitor well for 14,165.0 14,165.0 17:00 21:30 losses until losses achieved 12bbl. static loss rate 9/7/2019 9/7/2019 2.25 COMPZN CASING CIRC P Displace well with 270bbi. of 9.2 take 14,165.0 14,165.0 21:30 23:45 returns to the Tiger tank pumping @ 4 bpm 620 psi. 2686 strokes pumped. 9/7/2019 9/812019 0.25 COMPZN CASING OWFF P Open the annular monitor well with the 14,165.0 14,165.0 23:45 00:00 trip tank. 9/8/2019 918/2019 0.50 COMPZN CASING CLEN P Remove all equipment not being used, 14,165.0 14,165.0 00:00 00:30 1 1while waiting on brine trucks. 9/8/2019 9/8/2019 1.00 COMPZN CASING CIRC P SLB pump 189bbi. of formic acid @ 14,165.0 14,165.0 00:30 01:30 4bpm 800 psi., Shut down to divert flow to tiger tank due to PH in the returns being to low. 9/8/2019 9/8/2019 3.00 COMPZN CASING RURD P Blow down lines and flush with soda 14,165.0 14,165.0 01:30 04:30 ash pill, R/U choke house skid and pressure test lines to 2000 psi. (good test) 9/8/2019 9/8/2019 1.00 COMPZN CASING CIRC P SLB pump 81bbl. of formic acid @ 14,165.0 14,165.0 04:30 05:30 4bpm 781 psi., taking returns to tiger tank. (270bbi. pumped during second stage) 9/8/2019 9/8/2019 0.50 COMPZN CASING CIRC P Flush surface lines with l Obbl. of soda 14,165.0 14,165.0 05:30 06:00 ash pill 9/8/2019 9/8/2019 1.00 COMPZN CASING CIRC P Pump 168bbl. of 9.2 ppg. @ 4bpm 14,165.0 14,165.0 06:00 07:00 800 psi., taking returns to tiger tank to spot pill across open hole. 9/8/2019 9/8/2019 5.00 COMPZN CASING OWFF P Blow down lines, dg down floor 14,165.0 14,165.0 07:00 12:00 manifold, circ over the top of the hole to monitor well for loss rate. (10bph) 9/8/2019 9/8/2019 1.00 COMPZN CASING CIRC P Displace well with 162bbl. of 9.2 take 14,165.0 14,165.0 12:00 13:00 returns to the Tiger tank pumping @ 4 bpm 638 psi. 9/8/2019 9/8/2019 2.50 COMPZN CASING CIRC P Pump 390 bbl. of 9.2 ppg. Cl, Brine @ 14,165.0 14,165.0 13:00 15:30 4bpm 790 psi., taking returns to tiger tank 9/8/2019 9/8/2019 1.50 COMPZN CASING CIRC P Drop 1.25 ball down drill string, stage 14,165.0 14,165.0 15:30 17:00 pumps up to 3bpm, dropped rate to 2bpm before ball seals. 9/8/2019 9/8/2019 0.50 COMPZN RPCOMP PACK P Pressure up the drill pipe to 1200 psi. 14,165.0 5,367.0 17:00 17:30 pick up drill string to 168k verify string weight. Stage pump up to 4000 psi. swap to the lest pump and bring the pressure to 4800 psi. slack off to 30k to set packer. Verify packer is released new string weight 130k 9/8/2019 9/8/2019 0.50 COMPZN CASING RURD P Rig up to test ZXP Packer 5,367.0 5,367.0 17:30 18:00 9/8/2019 9/8/2019 1.00 COMPZN CASING PRTS P Pressure test ZXP packer to 3500 psi. 5,367.0 5,367.0 18:00 19:00 hold foe 10 min. (Good test) 9/8/2019 9/8/2019 0.50 COMPZN WELLPR CIRC P UD 3 joint. P/U 130k 5,367.0 5,284.0 19:00 19:30 Page 16118 ReportPrinted: 9120120191 Uperations Summary (with Timelog Depths) fT�a 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code Anvity Code Time P -T-% Operation (ftKB) End Depth (ftKB) 9/8/2019 9/8/2019 0.75 COMPZN WELLPR CIRC P Circ. 20bbl. @ 5,284' MD @ 6bpm 5,284.0 5,284.0 19:30 2015 700 psi. 30Ze/ F/O shut down to take returns to the tiger tank. 9/8/2019 9/8/2019 1.50 COMPZN WELLPR RURD P R/U aTiger Tank, pressure test lines to 5,284.0 5,284.0 20:15 21:45 2000 psi. (no leaks) monitor well circ. over the top of the hole. 9/8/2019 9/8/2019 0.75 COMPZN WELLPR CIRC P Circ. 89.4 bbl. of Cl Brine @ 5bpm 5,284.0 5,284.0 21:45 2230 710 psi. followed by 53bbl. of filtered brine to spot Cl brine. At the end of circulating, 9.5 ph coming back. 9/812019 9/8/2019 0.50 COMPZN WELLPR OWFF P Monitor well (static) Blow down TD 5,284.0 5,284.0 22:30 2300 9/8/2019 9/9/2019 1.00 COMPZN WELLPR PULD P POOH on elevators L:/D HWDP F/ 5,284.0 5,027.0 23:00 00:00 5,284'-T/5,027' 9/9/2019 9/9/2019 5.25 COMPZN WELLPR PULD P POOH on elevators laying down pipe 5,027.0 31.0 00:00 05:15 in pipe shed F/ 5,286' -T/ BHA 9/9/2019 9/912019 0.50 COMPZN WELLPR BHAH P Laydown Baker running tool 31.0 0.0 05:15 05:45 9/9/2019 9/9/2019 0.25 COMPZN WELLPR RURD P Remove wear ring 0.0 0.0 05:45 06:00 9/9/2019 9/9/2019 1.00 COMPZN RPCOMP RURD P Rig up casing equipment, 4.5" 12.6 # 0.0 0.0 06:00 07:00 j HYD 563 tubing. 9/9/2019 9/9/2019 5.00 COMPZN RPCOMP RCST P RIH with 4.5" 12.6 #, HYD 563 0.0 5,400.0 07:00 12:00 tubing. from surface to 5,400' MD P/U = 87k S/O= 79k. 9/9/2019 9/9/2019 4.50 COMPZN RPCOMP HOSO P Locate seal assembly on joint #131, 0.0 5,360.3 12:00 16:30 laydown joints # 131, 130, 129.and 128 pick up and make up space out joints. and joint 128. 9/9/2019 9/9/2019 0.50 COMPZN RPCOMP THGR P Make up hanger and land, 0.0 0.0 16:30 1700 9/9/2019 9/9/2019 1.75 COMPZN RPCOMP PRTS P Test tubing to 3500 psi, hold for ten 0.0 0.0 17:00 18:45 min. bleen pressure to 2000 psi. test the IA to 3500 psi. hold for 30 min. (good test) 9/9/2019 9/9/2019 1.25 COMPZN RPCOMP CIRC P Bleed pressure to 0 psi. attempt to 0.0 0.0 18:45 20:00 shear SOV by pressuring up on the annulus to 2500 psi. but Failed. Discussing the problem with town. We put 2000 psi. on the tubing and 3500 on the I.A, then bled the off tubing fast shearing the SOV 9/9/2019 9/9/2019 0.25 COMPZN RPCOMP CIRC P Pumped 10bbl. down thel/A taking 0.0 0.0 20:00 20:15 returns through the tubing, 100 strokes pumped @ 500 psi. 9/9/2019 9/9/2019 0.75 COMPZN RPCOMP RURD P B/D, R/D head pin and cement line, 0.0 0.0 20:15 21:00 landing joint. 9/9/2019 9/9/2019 1.00 COMPZN WHDBOP MPSP P Make up BPV, RIH and set. Pressure 0.0 0.0 21:00 22:00 test to 2500 charted for 5 min. 9/9/2019 9/10/2019 2.00 COMPZN WHDBOP RURD P N/D BOPE, lay down mouse hole, 0.0 0.0 22:00 00:00 remove choke/kill lines, break out Annular with potato masher, start breaking flanges. 9/10/2019 9/10/2019 2.00 COMPZN WHDBOP NUND P Continue ND BOP stack, and lines. 0.0 0.0 00:00 02:00 Rack back BOP's on the stump. Remove spacer spools. 9/10/2019 9/10/2019 1.75 COMPZN WHDBOP NUND P NU Tree as per Vetco rep. INstall 0.0 0.0 02:00 0345 adapter flange & tree. 9/10/2019 9/10/2019 2.25 COMPZN WHDBOP PRTS P Rig up to pressure test tree. Test tree 0.0 0.0 03:45 06:00 to 250 15000 PSI - 15 minutes. SIMOPS: Rig to Tiger tank for LRS. Page 17118 Report Printed: 9/20/2019 Operations Summary (with Timelog Depths) e R%_1 qW 3R-106 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tlme End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth(HKB) 9/10/2019 9/10/2019 1.00 COMPZN WHDBOP FRZP P Rig up LRS lines to tree. Pressure test 0.0 0.0 06:00 0700 lines to 3500 PSI. PJSM with crew and LRS. SIMOPS - Prepare for rig move. 9/10/2019 9/10/2019 1.00 COMPZN WHDBOP FRZP P With LRS, pump 90 BBLS of diesel 0.0 0.0 07:00 08:00 down IA, taking returns through the tubing to tiger tank. Final pressure = 90 PSI on IA. SIMOPS - Prepare for rig move. 9/10/2019 9/10/2019 1.00 COMPZN WHDBOP FRZP P Allow well to U-tube until dead. 0.0 0.0 08:00 09:00 Recorded pressure TBG x IA = 0 PSI. 9/10/2019 9/10/2019 1.00 COMPZN WHDBOP MPSP P Install BPV as per Vetco Rep. 0.0 0.0 09:00 10:00 9/10/2019 9/10/2019 1.00 DEMOB MOVE OTHR P Secure tree and all valves. Secure 0.0 0.0 10:00 11:00 cellar. Install blanking flanges. Rig Released at 1100 HRS 9-10-2019 Page 18118 Report Printed: 9120/2019 NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-106 3R-106 ConocoPhillips Definitive Survey Report 18 September, 2019 3R-106 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. E, Yes ❑ No I have checked to the best of my ability that the following data is correct: ❑ Surface Coordinates D Declination & Convergence M GRS Survey Corrections ❑ Survey Tool Codes Stephen.fell@contra'=„.;."-'-.-.-.:.<:- - =®- SLB DE: ctor.conocophillips.c�-- . om Client Representative. Date. [�EN �o�p^nry 911912019 ConocoPhillips ConocoPhiliips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-106 Project: Kuparuk River Unit TVD Reference: 3R-106 actual ® 49.29usft (D142) She: Kuparuk 3R Pad MD Reference: 3R-106 actual ® 49.29usft (D142) Well: 3R-106 North Reference: True Wellbore: 3R-106 Survey Calculation Method: Minimum Curvature Design: 3R-106 Database: EDT 14 Alaska Production rroject Kupamk River Unit, North Slope Alaska, United States nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level iso Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Wed 3R-106 Well Position +NIS 0.00 usft Northing: To -EI-W 0.00 usft Easting: Position Uncertainty Version: 1.0 0.00 usft Wellhead Elevation: Wsllllors 3R-106 Magnetics Model Name Sample Date BGGM2018 8/25/2019 6,031,666.09 usft Latitude; 520,649.00 usft Longitude: usft Ground Level: Declination Dip Angle 0 (°) 16.46 60.95 70'29'51.621 N 149° 49'52.103 W 9.80 usft Field Strength (nn 57,415 Design 3R-106 Date Audit Notes: To Version: 1.0 Phase: ACTUAL Tie On Depth: 39.49 Vertical Section: Depth From (TVD) +WS +EI4N Direction 2,189.803R-106 Srvy 2-SLB_MWD+GMAG(3R- (usfq (usft) (usft) (h 2,323.633R-106 Srvy 3- SLB _MWD_Inc_Ony_Fi 39.49 0.00 0.00 90.00 Survey Program Date From To (usft) (usft) Survey (Well Tool Name Description Survey Date 93.93 1,490.42 3R-106 Srvy 1 - SLB GYRO-MWD+SAG GYD-GC-SS Gyrodata gyro single shots 8/20/2019 8:55:- 1,531.85 2,189.803R-106 Srvy 2-SLB_MWD+GMAG(3R- MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Corred8/21/2019 8:55- 2,228.65 2,323.633R-106 Srvy 3- SLB _MWD_Inc_Ony_Fi MWD -INC -ONLY MWD -INC -ONLY -FILLER 8/25/2019 8:55:- 2,417.31 5,470.423R-106 Srvy 4-SLB_MWD+GMAG(3R- MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Mul[FStation Corred8/25/2019 8:55:, 5,570.18 5,570.183R-106 Srvy 5- SLB_MWD_Inc_Ony_Fi MWD -INC -ONLY MWD-INC_ONLY_FILLER 8/30/2019 855- 5,647.12 14,094.723R-106Envy 6-SLB_MWD+GMAG(3R- MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station CorrectB/30/2019 8:55: - Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +EFW Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (unit) (usft) (ft) (it) (°1100') (ft) Survey Tool Name 39.49 0.00 0.00 39.49 -9.80 0.00 0.00 6,031,666.D9 520,649.00 0.00 0.00 UNDEFINED 93.93 0.29 322.60 93.93 44.64 0.11 -0.08 6,031,666.20 520,648.92 0.53 -0.08 GYD-GCSS(1) 120.DD 0.20 321.86 120.00 70.71 0.20 -0.15 6,031,666.29 520,648.85 0.35 -0.15 GYD-GCSS(1) 167.44 0.10 349.60 167.44 118.15 0.30 -0.21 6,031.666.39 520,648.79 0.25 -0.21 GYD-GCSS(1) 262]9 0.11 40.84 262.79 213.50 0.45 -0.17 6,031,666.54 520,648.83 0.10 -0.17 GYD-GC-SS(1) 356.34 0.16 20.61 356.34 307.05 0.64 -0.06 6,031,666.73 520,648.94 0.07 -0.06 GYD-GC-SS(1) 450.00 0.15 329.23 450.00 400.71 0.87 -0.08 6,031,666.96 520,648.92 0.14 4].DB GYD-GC-SS(1) 546.11 0.25 345.92 546.11 496.82 1.18 -0.19 6,031,667.27 52Q64880 0.12 -0.19 GYD-GC-SS(1) 640.33 1.83 359.58 640.31 591.02 2.89 -0.25 6,031,668.98 520,648.74 1.69 4).25 GYD-GC-SS(1) 733.52 2.95 10.77 733.42 684.13 6.73 0.18 6,031,672.82 520,649.16 1.30 0.18 GYD-GC-SS(1) 91182019 1:22:41PM Page 2 COMPASS 5000.14 Build 85H ConocoPhiliips Definitive Survey Report Company: NADConvelsion Local Coordinate Reference: Well 3R-106 Project: Kuparuk River Unit TVD Reference: 3R-106 actual Q 49.29usft (D142) Sfte: Kuparuk 3R Pad MD Reference: 311-106 actual @ 49.29usft (D142) Well: 3R-106 North Reference: True Wellbore: 3R-106 Survey Calculation Method: Minimum Curvature Design: 3R-106 Database: EDT 14 Alaska Production Survey 91162019 1:22:41PM Page 3 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Aid TVD TVDSS +NIS +E/ -W Northing Easting OLS Section (uaft) 0 (1) (usft) (uaft) (uaft) lost" lm (ft) (o/100') (ft) Survey Tool Name 829.16 3.77 12.72 828.89 779.60 12.22 1.34 6,031,678.31 520650.30 087 1.34 GYDGC-SS(1) 924.10 5.36 27.22 923.53 874.24 19.21 4.05 6,031,685.30 520,653.00 2.06 4.05 GYD-GGSS(Ii 1,018.33 7.36 32.97 1,017.18 967.89 28.18 9.35 6,031,694.30 520,658.27 2.22 9.35 GYD-GC-SS(1) 1,113.% 10.44 27.02 1,111.62 1,062.33 41.04 15.62 6,031,707.17 520,665.50 3.36 16.62 GYD-GC-SS(1) 1,207.70 14.34 22.39 1,203.19 1,153.% 59.35 24.91 6,031,725.51 520,673.74 4.29 24.91 GYD-GC-SS(1) 1,302.39 16.63 19.83 1,294.44 1,245.15 82.94 33.97 6,031749.12 520,682.74 2.52 33.97 GYD-GC-SS (1) 1397.84 20.13 22.89 1,385.00 1,335.71 110.93 45.00 6,031,777.14 520,693.68 3.80 45.00 GY0-GCSS(1) 1,490.42 21.64 18.84 1,471.50 1,422.21 141.7] 56.71 6,031,808.00 520,705.31 2.26 56.71 GYDGCSS(1) 1,531.85 21.25 23.23 1,510.07 1,460.78 155.90 62.13 6,031,822.15 520,710.69 3.99 62.13 MWD+IFR2+SAG+MS (2) 1,626.13 23.23 24.13 1,597.33 1,548.04 188.57 76.48 6,031,854.85 520,724.94 2.13 76.48 MWD+IFR2+SAG+MS (2) 1,720.12 24.81 25.17 1,683.18 1,633.89 223.34 92.44 6,031,889.66 520,740.81 1.74 92.44 MWD+IFR2+SAG+MS(2) 1,814.91 25.86 26.32 1,766.85 1,719.56 259.87 110.07 6,031,926.24 520,758.33 1.22 110.07 MWD+IFR2+SAG+MS(2) 1,909.57 30.53 24.69 1,852.26 1,802.97 300.24 129.27 6,031,%6.66 520,777.43 5.00 129.27 MWD+IFR2+SAG+MS(2) 2,004.12 33.56 24.65 1,932.39 1,883.10 345.82 150.21 6,032012.29 520,798.23 3.20 150.21 MWD+IFR2+SAG+MS(2) 2,098.71 34.05 22.39 2,010.99 1,%1.]0 394.07 171.20 6,032,060.60 520,819.09 1.43 171.20 MWD+IFR2+SAG+MS(2) 2,189.80 35.10 22.95 2,085.99 2,036.70 441.77 191.13 6,032,108.34 520,838.88 1.20 191.13 MWD+IFR2+SAG+MS(2) 2,228.65 36.35 23.06 2,117.53 2,068.24 462.65 200.00 6,032,129.24 520,847.69 3.22 200.00 MWD-INC_ONLY (3) 2,290.00 37.54 23.28 2,166.56 2,117.27 4%.54 214.51 6,032,163.18 520,862.11 1.% 214.51 MM -INC _ONLY (3) 10 3/4" z 13 1/T' 2,323.63 38.20 23.39 2,193.11 2143.82 515.50 222.69 6,032182.16 520,87024 1.96 222.69 MWD -INC ONLY(3) 2,417.31 39.83 23.93 2,265.89 2,216.60 569.51 246.36 6,032,236.23 520,893.75 1.78 246.36 MWD+IFR2+SAG+MS(4) 2,512.12 43.75 24.14 2,336.57 2,287.28 627.20 272.09 6,032,293.98 520,919.32 4.14 272.09 MWD+IFR2+SAG+MS (4) 2,606.45 47.89 23.21 2,402.30 2,353.01 689.15 299.23 6,032,356.00 520,946.29 4.45 299.23 MWD+IFR2+SAG+MS(4) 2,701.07 50.98 21.57 2,463.82 2,414.53 755.61 326.59 6,032422.53 520,973.45 3.52 326.59 MWD+IFR2+SAG+MS(4) 2,795.46 53.52 19.47 2,521.61 2,472.32 825.50 352.72 6,032,492.49 520,999.39 3.21 352.72 MWD+IFR2+SAG+MS(4) 2,890.27 56.52 19.51 2,575.% 2,526.67 898.73 378.64 6,032,565.78 521,025.10 3.16 378.64 MWD+IFR2+SAG+MS(4) 2,984.69 58.36 19.26 2,626.77 2,577.48 973.79 405.05 6,032640.91 521,051.30 1.96 405.05 MWD+11FR2+SAG+MS(4) 3,079.37 58.13 19.54 2,676.60 2,627.31 1,049.73 431.79 6,032,716.91 521,077.83 0.35 431.79 MWD+IFR2+SAG+MS(4) 3,173.37 57.76 17.44 2,726.49 2,677.20 1,125.28 457.06 6,032,792.52 521,102.88 1.93 457.06 MWD+IFR2+SAG+MS(4) 3,268.15 57.82 19.41 2777.02 2,727.73 1,201.35 482.40 6,032,668.66 521,128.01 1.76 482.40 MWD+IFR2+SAG+MS(4) 3,363.44 57.74 20.53 2,827.82 2,778.53 1,2]].12 509.93 6,032,944.49 521,155.33 1.00 509.93 MWD+IFR2+SAG+MS(4) 3,457.91 57.77 22.04 2,878.23 2,828.94 1,351.57 538.94 6,033,019.01 521,184.13 1.35 538.94 MWD+IFR2+SAG+MS(4) 3,552.43 57.83 23.02 2,928.60 2,879.31 1,425.44 569.58 6,033,092.97 521,214.56 0.88 569.58 MWD+IFR2+SAG+MS(4) 3,646.90 58.55 24.28 2,978.39 2,929.10 1,498.98 601.79 6,033,166.58 521,246.56 1.37 601.79 MWD+IFR2+SAG+MS(4) 3,741.02 59.16 26.61 3,027.08 2,977.78 1,571.71 636.0 6,033,239.40 521,280.97 2.22 636.40 MWD+IFR2+SAG+MS(4) 3,636.04 59.83 30.14 3,075.32 3,026.03 1,643.72 675.30 6,033,311.51 521,319.67 3.28 675.30 MWD+IFR2+SAG+MS(4) 3,930.33 60.06 34.19 3,122.56 3,073.27 1,712.78 718.74 6,033,380.69 521,362.91 3.73 718.74 MWD+IFR2+SAG+MS (4) 4,025.48 61.06 38.25 3,169.34 3,120.06 1,779.60 767.70 6,033,447.64 521,411.68 3.86 767.70 MWD+IFR2+SAG+MS(4) 4,119.73 61.09 41.50 3,214.94 3,165.65 1,842.90 620.58 6,033,511.07 521, 6.37 3.02 820.58 MWD+IFR2+SAG+MS(4) 4,214.37 61.83 42.80 3,260.15 3,210.% 1,904.53 876.37 6,033,572.86 521,519.99 1.44 876.37 MWD+IFR2+SAG+MS(4) 91162019 1:22:41PM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-106 Project: Kuparuk River Unit TVD Reference: 3R-106 actual 2 @1 49.29usft (13142) Site: Kuparuk 31R Pad MD Reference: 3R-106 actual @ 49.29usft (0142) Well: 3R-106 North Reference: True Wellbore: 3R-106 Survey Calculation Method: Minimum Curvature Design: 3R-106 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Ari TVD TVDSS *W -S +EI -W Northing Easting DLS Section (usft) (1) (') (usR) (usft) (usft) Net" (1M (ft) ('/1001 (ft) Survey Tool Name 4,308.18 62.21 46.56 3,304.18 3,254.89 1,96342 934.61 6,033,631.90 521,578.6 3.56 934.61 MWD+IFR2+SAG+MS(4) 4,402.79 69.02 49.69 3,346.97 3,297.68 2,019.75 997.42 6,033,688.40 521,640.70 3.48 997.42 MWD+IFR2+SAG+MS (4) 4,497.82 65.16 52.70 3,387.75 3,338.6 2,073.55 1,064.28 6,033,742.38 521,707.41 3.15 1,064.28 MWD+IFR2+SAG+MS (4) 4,592.66 66.09 57.36 3,426.91 3,377.62 2,123.03 1,135.05 6,033,792.06 521,778.03 4.58 1,135.05 MND+IFR2+SAG+MS(4) 4,687.02 67.20 63.11 3,464.34 3,415.05 2,166.00 1,210.21 6,033,835.23 521,853.07 5.72 1,210.21 MND+IFR2+SAG+MS(4) 4,783.32 68.47 66.04 3,500.68 3,451.39 2,204.27 1,290.75 6,033,873.72 521,933.50 3.11 1,290.75 MWD+IFR2+SAG+MS(4) 4,877.59 69.93 69.30 3,534.16 3,484.87 2,237.74 1,372.26 6,033,907.41 522,014.90 3.58 1,372.26 MWD+IFR2+SAG+MS (4) 4,972.56 70.45 72.90 3,566.36 3,51207 2,266.67 1,456.77 6,033,936.57 522,099.33 3.61 1,456.77 MWD+IFR2+SAG+MS (4) 5,067.22 72.27 77.42 3,596.63 3,547.34 2,289.61 1,543.45 6,033,959]5 522,185.93 4.92 1,543.45 MWD+IFR2+SAG+MS (4) 5,161.74 74.81 81.12 3,623.41 3,574.12 2,306.47 1,632.49 6,033,976.85 522,274.92 4.62 1,632.49 MWD+IFR2+SAG+MS(4) 5,256.38 76.68 84.18 3,646.72 3,597.43 2,318.19 1,723.45 6,033,988.83 522,365.83 3.70 1,723.45 MWD+IFR2+SAG+MS(4) 5,351.04 78.75 85.41 3,666.86 3,617.57 2,326.58 1,815.55 6,033,997.47 522,457.90 2.53 1,815.55 MWD+IFR2+SAG+MS(4) 5,445.61 82.40 87.29 3,682.35 3,633.06 2,332.51 1,908.64 6,034,003.66 522,550.96 4.33 1,908.64 MWD+IFR2+SAG+MS (4) 5,470.42 84.53 87.82 3,685.17 3,635.88 2,333.56 1,933.26 6,034,004.78 522,575.58 8.84 1,933.26 MWD+IFR2+SAG+MS (4) 5,528.84 85.85 87.68 3,690.07 3,640.78 2,335.84 1,991.43 6,034,007.22 522,633.74 2.28 1,991.43 MWD -INC _ONLY (5) 7 SIB"z 9.875" 5,570.18 86.79 87.58 3,692.72 3,643.43 2,337.55 2,032.65 6,034,009.04 522,674.95 2.28 2,032.65 MWD-INC_ONLY (5) 5,647.12 86.31 86.23 3,697.35 3,648.06 2,341.70 2,109.34 6,034013.40 522,751.61 1.86 2,109.34 MWD+IFR2+SAG+MS(6) 5,741.68 86.31 85.41 3,703.44 3,654.15 2,348.57 2,203.45 6,034020.54 522,845.70 0.87 2,203.45 MWD+IFR2+SAG+MS(6) 5,767.95 86.35 84.83 3,705.12 3,655.83 2,350.80 2,229.57 6,034022.84 522,871.81 2.21 2,229.57 MWD+IFR2+SAG+MS (6) 5,836.34 86.77 87.15 3,709.22 3,659.93 2,355.58 2,297.66 6,034,027.81 522,939.BB 3.44 2,297.66 MWD+IFR2+SAG+MS(6) 5,936.40 91.36 86.80 3,710.86 3,661.57 2,360.86 2,397.55 6,034033.36 523,039.74 4.60 2,397.55 MWD+IFR2+SAG+MS(6) 6,026.28 93.49 87.67 3,707.05 3,657.76 2,365.19 2,487.23 6,034037.94 523,129.41 2.56 2,487.23 MND+IFR2+SAG+MS(6) 6,121.17 91.52 86.75 3,702.91 3,653.62 2,369.80 2,581.92 6,034042.82 523,224.07 2.29 2,581.92 MWD+IFR2+SAG+MS(6) 6,216.0 90.33 86.79 3,701.37 3,652.08 2,375.14 2,676.58 6,034048.42 523,318.71 1.26 2,676.58 MWD+IFR2+SAG+MS(6) 6,310.96 89.27 85.43 3,701.71 3,652.42 2,381.59 2,771.32 6,034,055.13 523,413.42 1.82 2,771.32 MWD+IFR2+SAG+MS(6) 6,405.78 86.35 87.26 3,705.33 3,656.4 2,387.63 2,865.86 6,034061.43 523,507.93 3.63 2,865.86 MWD+IFR2+SAG+MS(6) 6,501.29 85.73 88.14 3,711.93 3,662.64 2,391.45 2,961.07 6,034,065.52 523,603.12 1.13 2,961.07 MWD+IFR2+SAG+MS(6) 6,596.03 87.26 88.20 3,717.72 3,668.43 2,394.47 3,055.58 6,034068.80 523,697.61 1.62 3,055.58 MWD+IFR2+SAG+MS(6) 6,691.20 89.86 90.95 3,720.11 3,670.82 2,395.18 3,150.70 6,034,069.77 523,792.72 3.98 3,150.70 MWD+IFR2+SAG+MS(6) 6,784.96 91.79 92.01 3,718.76 3,669.47 2,392.75 3,244.41 6,034067.61 523,886.43 2.35 3,244.41 MWD+IFR2+SAG+MS (6) 6,880.95 94.62 91.26 3,713.39 3,664.10 2,390.02 3,340.20 6,034065.14 523,982.22 3.05 3,340.20 MWD+IFR2+SAG+MS (6) 6,975.37 97.29 88.39 3,703.60 3,654.31 2,390.30 3,434.09 6,034,065.68 524,076.10 4.14 3,434.09 MND+IFR2+SAG+MS(6) 7,069.98 97.14 89.57 3,691.71 3,642.42 2,391.97 3,527.94 6,034067.61 524,169.93 1.25 3,527.94 MWD+IFR2+SAG+MS(6) 7,165.53 97.00 88.19 3,679.95 3,630.66 2,393.82 3,622.74 6,034,6973 524,264.72 1.44 3,622.74 MWD+IFR2+SAG+MS(6) 7,260.43 97.21 86.25 3,668.21 3,618.92 2,398.39 3,716.80 6,034074.56 524,358.75 2.04 3,716.50 MWD+IFR2+SAG+MS(6) 7,355.97 97.23 64.76 3,656.21 3,606.92 2,405.82 3,811.28 6,034082.25 524,453.21 1.55 3,811.28 MWD+IFR2+SAG+MS (6) 7,451.60 96.37 85.26 3,644.88 3,595.59 2,414.08 3,905.88 6,034,090.77 524,547.77 1.04 3,905.88 MWD+IFR2+SAG+MS(6) 7,546.54 94.26 86.71 3.636.09 3,586.80 2,420.69 4,000.17 6,034097.65 524,642.03 2.69 4,000.17 MND+IFR2+SAG+MS (6) 7,641.54 91.68 87.42 3,631.17 3,581.88 2,425.55 4,094.91 6,034,102.77 524,736.75 2.82 4,094.91 MWD+IFR2+SAG+MS(6) 9/182019 1:22:41PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report company: NADConversion Local Coordinate Reference: Well 3R-106 Project: Kuparuk River Unit TVD Reference: 3R-106 actual ® 49.29usft (D142) SRO: Kuparuk 3R Pad MD Reference: 3R-106 actual @ 49.29usft (D142) Well: 3R-106 North Reference: True Waltham: 3R-106 Survey Calculation Method: Minimum Curvature Design: 3R-106 Database: EDT 14 Alaska Production Survey 9/183019 1:22:41PM Page 5 COMPASS 5000.14 BuRd 85H Map Map Vertical MD Inc AZI TVD TVDSS +WS +FJ -W Northing Easting DLS Section (usft) P) P) (Usti) (USR) (usft) (usft) (1t) (ft) (-Mow) (ft) Survey Tool Name 7,736.25 87.05 88.75 3,632.22 3,582.93 2,428.72 4,189.53 6,034,106.19 524.631.35 5.09 4,189.53 MWD+IFR2+SAG+MS(6) 7,831.32 86.34 91.49 3,637.70 3,588.41 2,428.66 4,284.44 6,034,106.30 524,926.25 2.92 4,284.44 MWD+IFR2+SAG+MS(6) 7,925.73 86.38 91.05 3,643.69 3,594.40 2,426.51 4,378.63 6,039,104.51 525,020.44 0.41 4,378.63 MWD+IFR2+SAG+MS(6) 8,020.51 86.66 89.96 3,649.44 3,600.15 2,425.68 4,473.23 6,034,103.94 525,115.03 1.19 4,473.23 MWD+IFR2+SAG+MS(6) 8,115.55 85.24 90.81 3,656.16 3,606.87 2.425.04 4,568.03 6,034,103.57 525,209.82 1.74 4,568.03 MWD+IFR2+SAG+MS (6) 8,210.18 84.61 93.00 3,664.53 3,615.24 2,421.91 4,662.23 6.034100.70 525,304.02 2.40 4,662.23 MWD+IFR2+SAG+MS (6) 8,304.08 87.33 93.58 3,671.13 3,621.84 2,416.53 4,755.74 6,034095.58 525,397.53 2.96 4,755.74 MWD+IFR2+SAG+MS(6) 8,399.56 89.21 91.87 3,674.01 3,624.72 2,412.00 4,851.06 6,034091.31 525,492.85 2.66 4,851.06 MWD+IFR2+SAG+MS(6) 8,495.48 88.21 91.30 3,676.17 3,626.88 2,409.34 4,946.91 6,03,088.93 525,588.71 1.20 4,946.91 MWD+IFR2+SAG+MS(6) 8,589.37 87.16 91.60 3,679.96 3,630.67 2,406.97 5,040.70 6,034,086.81 525,682.49 1.16 5,040.70 MIND+IFR2+SAG+MS (6) 8,685.10 87.26 92.38 3,684.62 3,635.33 2,403.65 5,136.25 6,034,083.76 525,778.05 0.82 5,136.25 MWD+IFR2+SAG+MS(6) 8,778.83 86.61 91.60 3,689.63 3,640.34 2,400.40 5,229.79 6,034080.n 525,871.58 1.08 5,229.79 MWD+IFR2+SAG+MS(6) 8,874.40 86.91 90.68 3,695.03 3,645.74 2,398.50 5,325.19 6,034,079.14 525,966.98 1.01 5,325.19 MWD+1FR2+SAG+MS (6) 8,968.48 87.03 90.78 3,700.01 3,650.72 2,397.31 5,419.13 6,034078.20 526,060.91 0.17 5,419.13 MWD+IFR2+SAG+MS(6) 9,063.87 88.11 90.46 3,704.05 3,654.76 2,396.27 5,514.43 6,D34077.43 526,156.20 1.18 5,514.43 MWD+IFR2+SAG+MS(6) 9,158.38 88.52 91.73 3,706.83 3,657.54 2,394.47 5,608.88 6,034075.89 526,250.65 1.41 5,608.88 MWD+IFR2+SAG+MS (6) 9,253.49 90.48 92.63 3,707.66 3,658.37 2,390.85 5,703.91 6,034,072.54 526,345.68 2.27 5,703.91 MWD+IFR2+SAG+MS(6) 9,349.12 91.90 91.87 3,705.68 3,656.39 2,387.10 5,799.44 6,034069.05 526,441.21 1.68 5,799.4 MWD+IFR2+SAG+MS(6) 9,444.06 91.89 93.46 3,702.54 3,653.25 2,382.69 5,894.22 6,03,064.90 526,536.00 1.67 5,894.22 MWD+IFR2+SAG+MS(6) 9,538.65 89.17 96.83 3,701.66 3,652.37 2,374.20 5,988.41 6,034056.68 526,630.19 4.58 5,988.41 MWD+IFR2+SAG+MS(6) 9,633.66 88.75 99.71 3,703.39 3,654.10 2,360.54 6,082.40 6,034,043.28 526,724.22 3.06 6,082.40 MWD+IFR2+SAG+MS(6) 9,728.57 88.72 97.80 3,705.48 3,656.19 2,346.10 6,176.18 6,034029.10 526,818.02 2.01 6,176.18 MWD+IFR2+SAG+MS(6) 9,823.14 87.13 %.91 3,708.90 3,659.61 2,334.00 6,269.91 6.34017.27 526,911.77 1.93 6,269.91 MWD+IFR2+SAG+MS(6) 9,919.31 84.69 98.46 3,71516 3,666.47 2,321.16 6,364.96 6,034,004.69 527,006.85 3.01 6,364.96 MWD+IFR2+SAG+MS(6) 10,014.11 83.27 99.17 3,725.71 3,676.42 2,306.70 6,458.12 6,033,990.49 527,100.04 1.66 6,458.12 MWD+IFR2+SAG+MS(6) 10,109.6 87.02 98.49 3,733.74 3,684.45 2,292.18 6,551.59 6,033,976.23 527,193.54 4.01 6,551.59 MWD+IFR2+SAG+MS(6) 10,203.92 88.23 96.39 3,737.67 3,688.38 2,279.91 6,645.56 6,033,964.22 527,287.54 2.55 6,645.56 MWD+IFR2+SAG+MS(6) 10,298.58 88.03 97.64 3,740.76 3,691.47 2,268.35 6,739.46 6,033,952.93 527,387.46 1.34 6739.46 MWD+IFR2+SAG+MS(6) 10,392.26 88.16 100.20 3,743.88 3,694.59 2,253.84 6,831.95 6,033,938.67 527,473.98 2.73 6,831.95 MWD+IFR2+SAG+MS (6) 10,487.05 87.09 103.18 3,747.80 3,698.51 2,234.65 6924.68 6,033,919.75 527,566.76 3.34 6,924.68 MWD+IFR2+SAG+MS (6) 10,583.27 86.91 106.64 3,752.84 3,703.55 2,209.93 7,017.52 6,033,895.29 527,659.65 3.60 7,017.52 MWD+IFR2+SAG+MS(6) 10,677.52 86.13 110.52 3,758.56 3,709.27 2,179.96 7,106.67 6,033,865.57 527,748.88 4.19 7,106.67 MWD+1FR2+SAG+MS(6) 10,771.75 88.39 115.12 3,763.07 3,713.78 2,143.47 7,193.40 6,033,829.32 527,835.70 5.43 7,193.40 MWD+IFR2+SAG+MS(6) 10,866.84 90.17 118.00 3,764.27 3,714.98 2,100.96 7,278.44 6,033,787.05 527,920.85 3.56 7,278.44 MWD+IFR2+SAG+MS(6) 10,962.72 89.59 119.74 3,764.47 3,715.18 2,054.67 7,362.40 6,033,741.00 528,004.93 1.91 7,362.40 MWD+IFR2+SAG+MS(6) 11,057.35 88.74 122.40 3,765.85 3,716.66 2,005.84 7,443.43 6,033,692.40 528,086.09 2.95 7,443.43 MWD+IFR2+SAG+MS (6) 11,152.26 88.74 126.15 3,767.93 3,718.64 1,952.41 7,521.83 6,033,639.20 528,164.63 3.95 7,521.83 MWD+IFR2+SAG+MS(6) 11,246.80 89.51 129.80 3,769.38 3,720.09 1,894.26 7,596.33 6,033,581.26 528,239.28 3.95 7,596.33 MWD+IFR2+SAG+MS(6) 11,338.48 90.58 130.4 3,769.31 3,720.02 1,835.43 7,666.64 6,033,522.62 528,30915 1.20 7,666.64 MWD+IFR2+SAG+MS(6) 11,429.88 89.53 128.15 3,769.22 3,719.93 1,777.79 7,737.57 6,033,465.19 528,380.84 2.37 7,737.57 MWD+IFR2+SAG+MS (6) 9/183019 1:22:41PM Page 5 COMPASS 5000.14 BuRd 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-106 Project: Kuparuk River Unit ND Reference: 3R-106 actual Q 49.29usft (D142) Site: Kuparuk 3R Pad MD Reference: 3R-106 actual @ 49.29usft (D142) Well: 3R-106 North Reference: True Wellbore: 3R-106 Survey Calculation Method: Minimum Curvature Design: 3R-106 Database: EDT 14 Alaska Production Survey 911WO19 1.22:41PM Page 6 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N15 +El -W Northing Pasting DLS Section (usft) (') (1 (-ft) (usft) (usft) (usft) (ft) (it) (.1100') (ft) Survey Tool Name 11,519.32 89.27 127.38 3,770.16 3,720.87 1,723.02 7,808.27 6,033,410.62 528,451.68 0.91 7,808.27 MWD+IFR2+SAG+MS(6) 11,613.65 87.05 126.98 3,773.18 3,723.89 1,666.05 7,883.39 6,033,353.87 528,526.99 2.39 7,883.39 MWD+IFR2+SAG+MS(6) 11,706.42 86.40 128.43 3,778.48 3,729.19 1,609.41 7,956.65 6,033,297.43 528,600.37 171 7,95&66 MWD+IFR2+SAG+MS(6) 11,796.81 88.84 130.24 3,782.24 3,732.95 1,552.17 8.026.50 6,033,240.39 528,670.36 3.36 8,026.50 MWD+IFR2+SAG+MS(6) 11,888.80 92.11 129.09 3,781.48 3,732.19 1,493.46 8,097.30 6,033,181.89 528,741.32 3.77 8097.30 MWD+IFR2+SAG+MS(6) 11,981.62 91.93 124.40 3,778.20 3,728.91 1,437.98 8,171.61 6,033,126.62 528,81578 5.05 8,171.61 MWD+IFR2+5AG+MS(6) 12,071.86 92.57 119.20 3,774.66 3,725.37 1,390.48 8,248.22 6,033,079.39 528,892.51 5.80 8,248.22 MWD+IFR2+SAG+MS(6) 12,163.63 94.69 116.35 3,76B.85 3,719.56 1,347.81 8,329.24 6,033,036.89 528,973.64 3.87 8,329.24 MWD+IFR2+SAG+MS(6) 12,255.73 91.65 116.99 3,76375 3,714.46 1,306.54 8,411.41 6,032,995.86 529,055.91 3.37 8,411.41 MWD+1FR2+SAG+MS(6) 12,348.50 88.45 118.46 3,763.67 3,714.38 1,263.38 8,493.51 6,032,952.94 529,138.13 3.80 8,493.51 MWD+IFR2+SAG+MS(6) 12,440.77 85.53 119.02 3,768.52 3,719.23 1,219.08 8,574.30 6,032,908.86 529,219.02 3.22 8,574.30 MWD+IFR2+SAG+MS(6) 12,533.77 86.72 116.52 3,774.80 3,725.51 1,175.86 8,656.39 6,032,865.87 529,301.23 2.97 8,656.39 MWD+IFR2+5AG+MS(6) 12,623.65 88.48 112.33 3,778.57 3,729.28 1,138.74 8,738.13 6,032,828.98 529,383.07 5.05 8,736.13 MWD+IFR2+SAG+MS(6) 12,715.30 90.48 109.58 3,779.40 3,730.11 1,105.96 8,823.71 6,032,796.45 529,468.72 3.71 8,823.71 MWD+1FR2+SAG+MS(6) 12,807.47 91.70 106.06 3,777.65 3,728.36 1,077.77 8,911.42 6,032,768.50 529555.51 4.04 8,911.42 MWD+IFR2+SAG+MS(6) 12,899.46 89.37 103.43 3,776.79 3,727.50 1,054.36 9,000.36 6,032,745.34 529,645.51 3.82 9,000.36 MWD+IFR2+SAG+MS(6) 12,992.83 89.45 99.35 3,777.75 3,728.46 1,035.93 9,091.87 6,032,727.16 529,737.05 4.37 9,091.87 MWD+IFR2+SAG+MS(6) 13,011EW 86.93 94.09 3,780.66 3,731.37 1,025.15 9183.32 6,032,716.64 529,828.53 6.32 9,183.32 MWD+IFR2+$AG+M$(6) 13,175.97 85.20 90.05 3,786.91 3,737.62 1,021.87 9,274.00 6,032,713.61 529,919.20 4.82 9,274.00 MWD+IFR2+SAG+MS(6) 13,268.54 B4.67 87.73 3,795.06 3,745.79 1,023.65 9,366.18 6,032,715.65 530,011.37 2.56 9,366.18 MWD+IFR2+SAG+MS (6) 13,358.89 85.93 86.86 3,802.48 3,753.19 1,027.90 9,456.12 6,032,720.15 530,101.29 1.69 9,456.12 MWD+IFR2+SAG+MS(6) 13,450.82 85.78 87.84 3,809.13 3,759.84 1,032.14 9,547.71 6,032,724.65 53.192.86 1.08 9,547.71 MWD+IFR2+SAG+MS(6) 13,542.46 83.06 88.86 3,818.04 3,76875 1,034.77 9,638.87 6,032,727.53 530,284.00 3.17 9,638.87 MWD+IFR2+SAG+MS(6) 13,634.99 87.82 89.22 3,825.39 3,776.10 1,036.31 9,731.07 6,032,729.33 530,376.19 5.16 9,731.07 MWD+IFR2+SAG+MS(6) 13,727.38 88.74 88.37 3,828.17 3,778.88 1,038.25 9,823.40 6.032,731.53 530,468.50 1.36 9,823.40 MWD+IFR2+SAG+MS(6) 13,818.73 88.75 90.16 3,830.17 3,780.88 1,039.43 9,914.71 6,032,732.95 530,559.80 1.96 9,914.71 MWD+IFR2+SAG+MS(6) 13,911.08 89.08 90.08 3,831.92 3,782.63 1,039.23 10,007.05 6,032,733.01 53.652.12 0.37 10,007.05 MWD+IFR2+SAG+MS(6) 14,003.13 88.35 87.88 3,833.98 3,784.69 1,040.87 10,099.05 6,032,734.91 530,744.12 2.52 10,039.05 MWD+IFR2+SAG+MS (6) 14,094.72 89.22 87.80 3,835.92 3,786.63 1,044.32 10,190.56 6,032,738.61 53.835.60 0.95 10,190.56 MWD+IFR2+SAG+MS(6) 14,165.00 8922 87.80 3,836.88 3,787.59 1,047.02 10,260.78 6,032,741.50 530,905.81 0.00 10,260.78 PROJECTED IOTD 4.6" x 6.76" 911WO19 1.22:41PM Page 6 COMPASS 5000.14 Build 85H Cement Detail Report 3R-106 String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/19/2019 14:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/23/2019 09:15 8/23/2019 14:15 3R-106 Comment Line up & SLB pump 5,1 bbls CW 100r. Pressure test lines to 3500 psi - good test. Pump 34.9 bbls of CW 100 @ 4.1 bpm, 142 psi, Flo 26%. Batch up and pump 80.1 bbls of 10.5 ppg MP II @ 6 bpm, 190 psi, Drop bottom plug & start batching lead. Pump 044.2 bbls of 11.0 ppg Desperate lead cement at 6 bpm, 309 psi, F/O 27%. Land bottom plug at 217 bbls pumped. Land hanger at 370 MIS lead pumped Batch and pump 58.4 bbls of 12 ppg tail cement @ 5.5 bpm, 270 psi, F/O 43%. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 9.5 ppg spud mud @ 8 bpm, 553 psi, F/O 38%. @ 192.5 bbl. reduced rate to 3 bpm 370 psi. Bump plug with 2009 strokes,fnal circ. psi. 380 Pressure up to 950 psi & hold for 5 minutes. Bleed off pressure, Check floats good. CIP 12:37 hrs 08/23/19. 222 BDIs cement to surface. Tagged hard cement 3.7"' below conductor, .5' below 4" outlets. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Realm? Vol Cement... Top Plug? Stan Plug? Surface Casing Cement 40.0 2,290.1 Yes 222.0 No Yes Q Pump but (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/.,, P Pump Final (psi) P Plug Bump (psi) Recip7 Stroke (ft) Rotated? Pipe RPM (rpm) 6 8 7 380.0 380.0 Yes 20.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Line up & SLB pump 5,1 bbls CW 100r. Pressure test lines to 3500 psi - good test. Pump 34.9 bbls of CW 100 @ 4.1 bpm, 142 psi, F/O 26%. Batch up and pump 80.1 bbls of 10.5 ppg MP II @ 6 bpm, 190 psi, Drop bottom plug & start batching lead. Pump 404.2 bbls of 11.0 ppg Desperate lead cement at 6 bpm, 309 psi, F/O 27%. Land bottom plug at 217 bbis pumped. Land hanger at 370 bbls lead pumped Batch and pump 58.4 bbls of 12 ppg tail cement @ 5.5 bpm, 270 psi, F/O 43%. Drop top plug & kick out with 10 We of fresh H2O. Swap to rig & displacew/ 9.5 ppg spud mud @ 8 bpm, 553 psi, F/O 38%. @ 192.5 bbl. reduced rate to 3 bpm 370 psi. Bump plug with 2009 strokes,final circ. psi. 380 Pressure up to 950 psi & hold for 5 minutes. Bleed off pressure, Check Floats good. CIP 12:37 hrs 08123/19. 222 Bbls cement to surface. Tagged hard cement 3.7"' below conductor, .5' below 4" outlets. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks) ClassVolume Pumped (bbl) Lead Cement 43.7 1,790.0 1,199 G 404.2 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.90 6.69 1 11.00 71.2 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Son (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,790.0 2,290.0 199 G 58.4 Yield (ft'/sack) Mix H2O Ratio fil l/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.65 5.60 1 12.00 98.9 Additives Additive Type Concentration Cone Unit label Page 1/1 ReportPrinted: 10/1/2019 Cement Detail Report 3R-106 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 8/19/2019 14:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 8/28/2019 10:15 8/28/2019 14:47 3R-106 Comment Load 1st bottom plug. Pump 5 bills Mud Push. Test lines to 4000 psi. Pump 45bbls of 13.5 ppg Mud Push II, 4 bpm, 260 psi. 20% Flow out. Load 2nd bottom plug. (Cmt Wet @ 11:40hrs) Balch up and pump 110.5 bbls 15.8 ppg Class G cement - pump rate 5.6 bpm, 260 psi, 38% Flow out. Load top plug. Schlumberger pump 10.0 bbls water. Swap to dg and displace with 9.2 ppg. LSND. @ 7 bpm 148 psi. 17% F/O. Decreased rate to 6bpm @ 79.9 bbl. Pumped, 123 psi. 32% F/O decreased rate to 5 bpm @ 179.9 bbl. pumped 549 psi. 28% F/O decreased rate to 2bpm @ 229.9 bbl. pumped 800 psi. 12% F/O, Bumped plug @ 237.8 bbl. pumped (2362 stks.) 900 psi. pressured up to 1400 psi. hold for 5 min. Bled down pressure to check floats. Could not confirm floats were holding. Pressure up the casing to 1400 psi. held for 5 min, bled presser off floats held. Pumped 2 bbl. and bled off 2 bbl. CIP @ 14:47 Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 3,549.0 5,528.0 Yes 0.0 Yes Yes Cement Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 2 6 900.0 1,400.0 Yes 25.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To IRKS) Drill Out Diameter (in) Comment Load tat bottom plug. Pump 5 bbls Mud Push. Test lines to 4000 psi. Pump 45bbls of 13.5 ppg Mud Push II, 4 bpm, 260 psi. 20% Flow out. Load 2nd bottom plug. (Cmt Wet @ 11:40his) Batch up and pump 110.5 bbls 15.8 ppg Class G cement - pump rate 5.6 bpm, 260 psi, 38% Flow out. Load lop plug. Schlumberger pump 10.0 bbls water. Swap to rig and displace with 9.2 ppg. LSND. @ 7 bpm 148 psi. 17% F/O. Decreased rate to 6bpm @ 79.9 bbl. Pumped, 123 psi. 32% F/O decreased rate to 5 bpm @ 179.9 bbl. pumped 549 psi. 28% F/O decreased rate to 2bpm @ 229.9 bbl. pumped 800 psi. 12% F/O, Bumped plug @ 237.8 bbl. pumped (2362 stks.) 900 psi. pressured up to 1400 psi. hold for 5 min. Bled down pressure to check floats. Could not confirm floats were holding. Pressure up the rasing to 1400 psi. held for 5 min, bled presser off floats held. Pumped 2 bbl. and bled off 2 bbl. CIP @ 14:47 Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks) ClassVolume Pumped (boll Mud Push 11 2,374.0 3,549.0 45.0 Yield (IF/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprsV 1 (psi) 13.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 3,549.0 5,536.0 535 G 110.5 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.0 1 15.80 4.30 Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 10/112019 Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Friday, September 20, 2019 5:55 PM�/3D/L To: Regg, James B (CED) Cc: Well Integrity Compliance Specialist WNS & CPF3; NSK Prod Engr Specialist; NSK Optimization Engr; NSK West Sak Prod Engr; CPF3 Maint Supv; CPF3 DS Lead Techs; Valentine, Doug K; Jolley, Liz C; CPF3 Ops & DOT Pipelines Supt; CPF3 Ops Supv Subject: Defeated LPP/SSV on well 3R-106 Mr. Regg, / The low-pressure pilot (LPP) on injection well 311-106 (PTD# 219-097) was defeated Friday evening 9/20/2019. 311-106 is a grassroots injection well that was brought online 9/20/2019. 3R-106 is currently at a wellhead injection pressure of 283 psi and an injection rate of 1060 bbls of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased to above 250 psi and the LPP/SSV function is returned to normal operation, in accordance with "Administrative Approval No. CO 4068.001" Kaelin Ellis/ Kenneth Lloyd Martin CPF3 Production Engineer ConocoPhillips Alaska Ph: 907-659-7871 PTD a./c! —D4:� Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Friday, September 6, 2019 5:36 PM To: Woodard, Madeline E Subject: Re: 3R-106 Intermediate Cement Job Evaluation Follow Up Flag: Follow up Flag Status: Flagged Good cement job, Thanx, Victoria Sent from my iPhone On Sep 6, 2019, at 4:13 PM, Woodard, Madeline E <Madeline.E.Woodard@conocophillios.com> wrote: Victoria, Please see the attached document on the 311-106 intermediate cement job per the PTD Conditions of Approval. Let me know if you would like any more information. Thanks and have a good weekend, Madeline Woodard Drilling Engineer ConocoPhillips Alaska, Inc Office: 907-265-6086 Mobile: 907-764-8095 <311-106 Cement Review.pdf> 1 �' �' q � .. tit :� t-- I'' H' s. Cement Intermediate Casing Ceme it 3R-106 Cement Oetalls Description Cememhgarartwas Cementkm End D0"e WeOeera fbme Intem Uffifle Casing Cement 828201910:15 828201914:47 3R-106 Comment Load 1st bottom plug. Pump 5 bola Mud Push. Test lines to 4000 Psi. Pump 45bols of 13.5 ppg Mud Push 11. 4 bpm, 280 psi. 20% Flow out. Load 2nD bottom plug. (Cml Wet 0 11 401mrs) Batch upend pump 110.5 stile 15.8 PPB Class G cement - pump rete 5.6 bpm, 20 psi, 38% Flow out Logo top plug. Schlumberger pump 10.0 bole water. Swap to dg and displace with 9.2 ppg. LSND. ® 7 bpm 148 psi. 17% FIO. Oecreased rete to 8bpm ® 79.9 bbl. Pumped, 123 psi. 32% F/O decreased rata to 5 bpm 0179.9 bol. Pumped 549 psi. 28% F/O decreased rete to 2bpm a 229.9 bbl. pumped 800 psi. 12% F/O. Bumped plug @ 237.8 bbl. p to 14off 00 psi. iuoff ® gCoold not confirm floats were holding. Pressure up the 5 sed preminssuredbled d (2362(1400 tat 9 hold for Cpe kg for 5 Blest. tl Metl 2 bbl Cement Stages stage N 1 Beacdgbn objective Top Oogh mKs) edtom Degh lets) F0 Return? Vol CameoL Tsp Pill PWpi Yes Intennedlate Casing 3,549.0 5,528.0 Yes 00 Yes Isms Cement O Pune Mk IbWm... 4 Pump flrW IMw... O Pump Avg (EEv IF Fume Final (FeltP Plug Bumf (roil .pi eases IRI ROMsdi Pipe RPM (rpm) 7 2 B 900.0 1.400.0 Yes 25.00 No Tagged Dean(MIS) Tp Meed Daps Flu, DdMd Out To IXKB) on" oq"easesr6nl Comment Load 1st bottom plug. Pump 5 bbis Mud Push. Test lines to 4000 psi. Pump 45bbls of 13.5 ppg Mud PuN111, 4 bpm, 260 psi. 20%Flow out. Load 2nd bottom plug. (Cmt Wet @ 11:4MM) Batch up and pump 110.5 bale 15.8 ppg Gose G cement - pump rete 5.6 bpm. 280 psi. 3B% Flow out Load top plug, SCMumberger pump 10.0 bola water. Swap to rig and displace with 9.2 ppg. LSND. @ 7 bpm 148 psi. 17% F20. Decreased rete to 8bpm @ 79.9 bbl. Pumped. 123 psi. 32% FtO decreased late to 5 bpm® 179.9 bol. pumped 549 psi. 28% FIO decreased rate to 2bpm @ 229.9 bbl. pumped 800 pa. 12% FC, Bumped plug ® 237.8 Mi. pumped (2362 elks.) 900 psi. pressured up to 1400 psi. hdtl for 5 min. Bled dawn pressure to check floats. Could hol confirm floats were holding. Pressure up the casing to 1400 psi. held for 5 min. bled presser all Boats held. Pumped 2 bbl, and bled o82 bol. CIP ® 14:47 Cement Fluids A Mc hives Flue fluid Tyq Flultl Option Expressed!.374.0Top lkKBl lkKBl Amwunt (aecbl Claae Pumped ibMl Mud Pusn 11 2.374.0 1 9. 3.599.0 45.0 45.0 YMM(Mlwcp Mix R20 Ratio(geaWck) Free Water l%1 Motor Pi. mu..'1c 1 Moss 1. Fame, This. IMI CmpnnlI to.,)13.50 Additives Addeve Tyq ConuntMXon Cent UnX YEeI Fluid Fluid Typo Fetid Descripden Eetlmolod Tap lkK01 Eat sbn hoes) Amoe leackal CMoo Yokew PumgdlEW) fntennedlats Cement 3,549.0 5,536.0 535" G 110.5 YsfdlMluck)Mex Rte RNlo(,e,eeck)Frw WNer(%) Demlly(WOO PMstic Y4coeXy (cFl mickemM, 1-1.11Cmproui lash 1.18 5.05 15.80 4.30 Additives Additive Tyne Cmumrstbn Core Unit MEN Page 111 Report Printed: 91812018 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc.a laska.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 3R-106 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-097 Surface Location: 16971 I'NL, 2937' FEL, SEC. 09, T13N, R9E, UM Bottomhole Location: 693' FNL, 3204' FEL, SEC. 11, TI 3N, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, JTsie L. Chmielowski Commissioner DATED this day of July, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL I �w"V D JUL G 2 2019 LV Ia. Type of Work: 1b. Proposed Well Class: Exploratory - Gas LJ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: ❑ Hydrates ❑ Drill ❑' Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑' Single Zone ❑ Coalbed Gas Gas ❑ ❑ Redrill ❑ Reentry ❑ Exploratory -Oil ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ I Geothermal Shale Gas 5. Bond: Blanket ❑� Single Well ❑ 11. Well Name and Number: 2. Operator Name: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 3RA06 3. Address: 6. Proposed Depth: _ 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14,220 TVD: 3,822 Kuparek River Field West Bak Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: - Surface: 1697' FNL & 2937' FEL, Sec 9, TI SIN, R9E, UM ADL355023 8. DNR Approval Number: 13, Approximate Spud Date'. Top of Productive Horizon: 4642' FNL & 1057' FEL, Sec 4, T1 3N, R9E, UM 931933000 8/4/2019 14. Distance to Nearest Property: Total Depth: 9. Acres in Property' 693' FNL & 3204' FEL, Sec 11, T13N, R9E, UM 3255 564'to ADL388235 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 48.9' 15. Distance to Nearest Well Open Surface: x- 520649.00 y- 6,031,666.09 Zone- 4 GL / BF Elevation above MSL (ft): 9.8' to Same Pool: 5021'to NIK OP05-061-1 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92.37 degrees Downhole: 1,730 psi Surface: 1,348 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 1Hale 42" 20" 94# H-40 Welded 80' Surf Surf 119' 119' Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 HYD563 2408' Surf Surf 2408' 2238' 1232 sx 11.0 ppg, 192 sx 12.0 ppg 9-7/8" 7-5/8" 29.7# L-80 HYD563 5825' ISuff Surf 5825'3708' 618 sx Class G 15.8 ppg 6-3/4" 4-1/7' 12.6# L-80 HYD563 8545' 5675' 3703' 14220' 3822 N/A 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No Q 20. Attachments: Property Plat ❑ BOP Sketch v Drilling Progrem v Time v. Depth Plot �, e rj ��B Shallow Hazard Analysis FL-yI/ AAC 25.050 requirements v Diverter Sketch Seabed Report Drilling Fluid Program 0 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: Chip Alvord Contact Email: madeline.e.woodard CO .Com Authorized Title: Alaska Drilling Manager Contact Phone: 907-265-6086 1 Date.~ Authorized Signatu mmission Use Only Permit to Drill API Number:'- Permit Approval (] See cover letter for other -1 requirements. Number: -• Q 50- Q Z Ltl -00 - 10o Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: N� Other: %3OP �{.5� fD ,j tj ©r5 <-5 _� Sa'-a-�m�plas req'd: Yes ❑ NorQy� Mud log req'U: Yes❑ Nolte J-0 25 dg02easures: Directional svy req'd: Yes YNo �f't ✓t USG✓piC ✓<n i'r✓ f>!•5t Yes E] Nols ,❑-,/ I Yes [IInclination-onlyNoY Inclination -only svy req'd: Yes E]No LL Spacing exception req'd: D%✓C! fti 11A r% A n t f iG[ n t<!J Post initial injection MIT mq'd: Yes H No[] P trap A�tc zS n35v('h)!z) a Pro v1 cit -r-" If ?Cmtn� Job SvmMa2/a.5soon else<m�hyJoby3 v `� 1. Sre attachccQ con 4o,iirmS of �9 rm✓tt APPROVED BY �G'��/�� .__�.._..... ,'.li°wiA-t�, J(-,( �/✓ COMMISSIONER _ THE COMMISSION Date:SLLbmit fffonn and • •rv,....,., s. - t 0RIGINAL111Z11� 61 utivil- KRU 3R-106(PTD 219-097) Conditions of Approval: Approval is granted to run the (USIT)Sonic on upcoming well KRU 311-106 (with the following provisions: 1. CPA] will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPA] is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. (USIT)Sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. Application for Permit to Drill, Well 3R-106 Saved: 2 -Jul -19 July 2, 2019 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well 311-106, a West Sak D Sand Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots injector well from the 3R pad. The expected spud date for this well is August 4, 2019. Itis planned to use rig Doyon 142. 3R-106 is planned to be a horizontal injector in the West Sak D sand. The surface section will be drilled with a 13-1/2" bit and cased with 10-3/4" casing to ±2,408' MD / 2,238' TVD. The intermediate section will be drilled with a 9-7/8" bit and cased with 7-5/8" casing to ±5,825'MD / 3,708' TVD. The production section will be drilled with a 6-3/4" bit in the West Sak D sand +/- 14,220' MD / 3,822' TVD and lined with a 4-1/2" ICDs every 500' MD, isolated with 6-1/8" swellpackers and 4-1/2" 12.6# blank pipe. The upper completion will be run with 4-1/2" 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 10401 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@cop.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 311-106 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 3R-106 Location Summary Requirements of 20 AAC 25.005(:)(2) An application for a Permit m trill nnut he accompanied by each ol7he fallowing items. exceptJor an near already a, file mil, Uwe commission and identified in the application: (2) a plat identifying the property and the property's in, and showing (A) the coordinates of the proposed location mf the well at the surface. at the top of each objecive fornralion. and at total depth. referenced to governmental section lines. (B) the com'dirmtes of the proposed location oJ'the well at the surface, refeenced to the ,nate plane coordinate system for this state as maintained by the National Geodetic Survey to the National Oceanic and .4noospherie Administration: ICJ the proposed depth of die ur ell at the top ofeach object,ve formation and at total depth: Location at Surface 1697' FNL & 2937' FEL, Sec 9, T 13N, R9E, UM NGS Coordinates Northings: 6,031,666.09' Easlings: 520649.00' RKB Elevation 48.9' AMSL Pad Elevation 9.8' AMSL Location at Top of Productive Interval West Sak D Sand 4642' FNL & 1057' FEL, Sec 4, T 13N, R9E, UM NGS Coordinates Northings: 6,034,005.43' Eastings. 522515.73' Measured Depth, RKB: 5,434' Total Vertical De !h, RKB: 3,674' Total Vertical Depth, SS: 3,625' Location at Total Depth 693' FNL & 3204' FEL Sec 11, T13N R9E, UM NGS Coordinates Northings: 6,032,705.69' Eastings: 530935.56' Meas:a'ed De th, RKB: '4,220' Total Vertical De th, RK'B: 3,822' Tota! Vertical De th, SS: 3,773' and (D) other information required by 20 AAC 25.050(12): Requirements of 20 AAC 25.050(6) [fa tar// ie to be,menttan,I/) de..aled, the application Intit Permit to Drill (borm 10-401) most ,�, !n2); a plat. drown to n sunrable scu/r. J;..,;r,�..Or lnrlh ofttie proposed n•elliore. including tilt adleicett wellbor-es within 200 feel ofaty por'lion of Please see Attachment: Directional Plan And llhnre . ,..0 .. .n. i. ri m the extent hurt those mmnes are Amino ar Iiscm�erable hr prtbhc records, and shoe that each ncaued opd anon leu lw,o jw nuhed o o p) thr applirallan by Car'Ilf ed moll; or (B) state that the applicant is the ooh, agfecled owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Reauirements of 20 AAC 25.005(:)(3) An apphcat,oi,fora Per'mtet to Drill mist be acconyrasied by each t)j the jotlorirrg riems, esce,pt,foran item already on file with the eons nission and identified in the applicano: (3) it diagram and dev...piian of itte hlowotn preverr6on equipment (DOPE) as required by 20 ; IAC 25.031. 20.fAC 25.036 or 20 AAC 25.037, as applicable: Please reference BOP schematics on file for Doyon 142 and attachment 5. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An opph4 arron faa Pernin to Drill nuist he accon ponied by each of7lie following items. except for nn item all on file with the commission and identified ni the application: (4) information on drilling ha_urds. including GU the mu innon downhole pressure that may be encomuered. criteria used to determine it. and marionme potential. surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 3R-106 is calculated using an estimated maximum reservoir pressure of 1,730 psi (based on 3R-102 downhole gauge data and reservoir modeling), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Salk D sand at 3,822' TVD: D Sand Estimated. BHP = 1,730 psi i 130 D Sand estimated depth = 3,822' TVD v32� Gas Gradient — 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) CO Hydrostatic of full gas column = 382 psi (3,822 TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,348 psi • (1,730 psi — 382 psi) (B) data on potential gas =otter. The well bore is not expected to penetrate any shallow gas zones. .And (C) data concerning potential causes of hole problemx such as abmrrmallr geo-pressured strum, lost circulation cares, and cones that bore.a propensil), for differential slicking: See attached 3R-106 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An upp6cation for a Perrnu to Urdl utast be acecnnpoured by eat It of the following items, except lir an tient already onfile with the commission and identified in the applualion: (5) a description gfdre noeedure fa' 4 omhrctinglorrnanon unegrin tests. us required ander 20 AAC 25.030(l); A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a permit ro Drill must be uccamounted by each of the following items, melt for an irea already onfile u' ah the commission and identified in the applicatton: (6) a complete proposed casing and cementing program us required he 20 AAC 15.030, and it desn'pnmrr yl'ony slotted liner. pre -pe (orated liner. or screen to be installed Casing and Cement Program Casing and ementing Program Csg/78g OD Hole S -e Weight Grade Conn. Length Top MD/TVD Bum MD/TVD Cement Program (in) Rb7t) 00 01) �) 20 42 94 H-40 Welded 80 Surf 119/119 Existing Cement to Surface with 10-3/4 13-12 45.5 L-80 HYD563 2,408 Surf 2,408/2,238 1232 sx LiteCRETE Lead 11.0 ppg, 192 sx Dee CRETE Tail 12.0 ppg 7-5/8 9-7/8 29.7 L-80 HYD563 5,825 Surf 5,825 3,708 618 sx Class G at 15.8 ppg w/ TOC at 3,458' MD 4-12 6-3/4 116 L-80 HYD563 8,545 5,675 / 3,703 14,220 / 3,822 N/A 10-3/4" Surface casine run to 2.408' MD / 2.238' TVD Cement from 2,408' MD to 1,908'(5001 of tail) with 12.0 ppg DeepCRETE, and from 1,908'to surface with 11.0 ppg LiteCRETE. Assume 250% excess annular volume for lead in the permafrost and 50% annular excess below the permafrost, 0% excess in 20" conductor, and 50% excess for tail. 10-3/4" Surface Casing Design: Single stage 15.8 ppg Class G slurry with 35% excess in OH Design: 11.0 ppg lead slurry from 1908' to surface and 500' of 12.0 ppg tail slurry Cement yield Lead Cement yield= 1.91 ft3/sk Tail Cement yield = 1.65ft3/sk 11.0 ppg LiteCRETE Lead Slurry (5825'- 3458')'x 0.03825 bbl/ft x 1.35 (35% excess) Conductor Shoetrack 119'x 0.24302 bbl/ft x 1.0 (0% excess) 5.5 bbis 28.9 bbis Base permafrost to conductor 717.2 ft3 (1788'- 119') x 0.06478 bbl/ft x 3.5 (250% excess) 378.4 bbis Btm of lead to base permafrost (1908'- 1788') x 0.06478 bbl/ft x 1.5 (50% excess) 11.7 bbis Total Lead Cement 419.0 bbls 2352.6 ft3 1232 sx 12.0 ppg DeepCRETE Tail Slurry Shoe to Top of Tail 500'x 0.06478 bbl/ft x 1.5 (50% excess) 48.6 bbis Shoetrack 80'x 0.096175 bbl/ft x 1 (0% excess) 7.7 bbis Total Tail Cement 56.3 bbis 316.0 ft3 192 sx 7-5/8" Intermediate casine run to 5,825' MD / 3.708' TVD Single stage slurry is designed to be placed from TD to 3,458' MD, which is 500' MD above top of the Ugnu B with 35% excess annular volume. 7-5/8" Intermediate Casing Design: Single stage 15.8 ppg Class G slurry with 35% excess in OH Cement yield 1.16 ft3/sk 15.8 ppg Class G Slurry Shoe to TOC (5825'- 3458')'x 0.03825 bbl/ft x 1.35 (35% excess) 122.2 bbis Shoetrack 120'x 0.0.04592 bbl/ft x 1 (0% excess) 5.5 bbis Total Tail Cement 127.7 bbis 717.2 ft3 618 sx Diverter System Information Requirements of 20 AAC 25.005(c)(7) .-In appbcmron jor a Terni! u> 17,!11 must be act ompanled In each afthe following items. ester! for art hent ah-eady onfile uah tire commission and identified in the application: (7) a diagram and deserrpdon of the diver ter system a-equa-ed hp 20 AIC 25.035. unless This requirement is waived by the canmission raider 20 AAC 25.035(h)(2)t It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At 3R, there has not been an indication of shallow gas or gas hydrates through the surface hole interval. The previously drilled West Sak 3R-101 and 3R-102 wells are within 500' from the proposed 3R-106 base of permafrost location, these wells did not encounter any shallow gas. VP 15- �1121 Drilling Fluid Program Requirements of 20 AAC 25.005(c)(81 An upplicution Jor a Perrntl to Drill umst be accanpanied by each of the following items. except, %r an iten ah'eadv on file vuh flie commission and identified in the appitcation: (8) a ofAng fluid program, inchrding it diagraat and description ofdre do-illingiluid system. as required by >0 AAC 25.033: Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. ✓ �.r'"WuIWe j 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 (x)(10) N/A -Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Reouirements 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 (x)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (x)(13) In application lora Permit to Drill ntasl he accompanied by each of following item', eraeptff, nrr item oh-endy on file wifh the eoomu.rston and ideniifred in the application: Surface 13-1/2" Hole 10-3/4" Casing Intermediate 9-7/8" Hole 7-5/8" Casing Production 6-3/4" Hole 4-1/2" Liner Mud System Spud WBM) LSND (WBM) FloPro NT (WBM Density 8.8-9.5 9.0-9.5 9.0 — 9.5 ppg PV ALAP ALAP ALAP yP 30-80 20-30 15-20 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 9 - 11 7-10 10 -minute Gel 30-50 < 20 8-16 API Filtrate NC <6 <6 HTHP Fluid Loss at 160° F N/A < 10 <10 H 10.8-11.2 9.5-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. ✓ �.r'"WuIWe j 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 (x)(10) N/A -Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Reouirements 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 (x)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (x)(13) In application lora Permit to Drill ntasl he accompanied by each of following item', eraeptff, nrr item oh-endy on file wifh the eoomu.rston and ideniifred in the application: The proposed drilling program is included below. Please refer to Attachment 4 for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. Notify AOGCC 24 hrs before test. 2. Spud and directionally drill 13-1/2" hole to surface TO as per directional plan. Run GWD/MWD/LWD tools [gamma ray & resistivity] required for directional monitoring. 3. Run and cement 10-3/4", 45.5#, L80, HYD563 casing to surface. Displace cement with mud and check floats upon bumping plug. Notify AOGCC if top job is required. 4. Remove diverter system and install wellhead. Install and test 13-5/8" x 5,000 psi BOP'S to 250 psi low and 3,500 psi high (annular preventer to 3,500 psi). Notify AOGCC 24 hrs before test. 5. PU 9-7/8" bit and 6-3/4" drilling assembly, with MWD/LWD [gamma ray & resistivity]. RIH, clean out cement to top of float equipment and test casing to 3,000 psi for 30 min. 6. Drill out shoe track and 20' of new hole. Perform shoe test to a minimum of 11.5ppg EMW LOT and maximum �L 14.0 ppg EMW FIT, recording results. 7. Displace to 9.2 ppg LSND water-based drilling fluid. 8. Directionally drill to intermediate TD. 9. Circulate hole clean. BROOH. 10. Run and cement 7-5/8", 29.7#, L80, HYD563 casing to surface. (Top of cement to be 500' MD above the Ugnu B sand) 11. Install 7-5/8" packoff and test to 5,000 psi. 12. Flush 10.75" x 7.625" annulus with water and freeze protect. 13. PU 6-3/4" bit and 4-3/4" drilling assembly, with MWD/LWD [gamma ray, resistivity, and sonic (only for cement evaluation)]. Log top of cement. Clean out cement to shoe track and test casing to 3,500 psi for 30 min. 14. Drill out shoe track and 20' of new hole. Perform shoe test to a minimum of 11.5 ppg EMW LOT and maximum 13.5 ppg EMW FIT, recording results. 15. Directionally drill to production TD. 16. Circulate hole clean. BROOK 17. P/U and run 4-1/2", 12.6#, blank liner, ICDs, swell packers, and liner -top packer. 18. Set liner hanger. Pump formic acid and allow to soak for 6 hours. 19. Displace formic acid with seawater. 20. Set liner -top packer and pressure test for 10 minutes, chart results. 21. POOH and lay down running tools. 22. Pull wear bushing & run 4-1/2" 12.6# upper completion tubing. 23. Land hanger, run in lock screws, and test seals to 5,000 psi. 24. Set BPV and test in the direction of flow. 25. Nipple down BOPE, nipple up tree and test. Pull BPV. 26. Freeze protect 4.5" x 7.625" annulus 27. Set BPV and move off rig. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25,005 (c)(141 An application faa Perrmt to Drill rwrat he accompanied by each of the follmring items. ercepffor an aew alreadi on ale srilh the cmnwssmn and idenn/ied in the application: (/ 4) a general description pfhaw the opewror p/aura to dispose ofdriiliig mud and cuilings and a statement o/'whether the operator intends to request authoricalion wider 20 AA( 25. 080fin' nn annular (/ispn.cal operation in the a elL: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class 11 disposal well (DS IB CRI), Milne Point, Prudhoe DS -4. All cuttings generated will be hauled to the DS IB CRI, Milne Point, 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 AOR Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 BOP Configuration Attachment 1 AOR An Area of Review plot is shown below of the 3R-106 planned wellpath and offset wells. There are no offset wellbores within the v mileviewof3R-106. °' du1y01019 - 3R-106wp05 Raw=QU- nan, Quarter Mile View ^ Aa m°° w air, A W4,oy ' 7500 y .�. u ''.. 5000 K J rg' 3RjI 2500 a C i 0 I j G � O _ X2500 _ II, -5000 —]R.te -10000 -7500 -5000 -2500 0 2500 5000 7500 10000 11 6,219 3R-106wp05 Permit Pack l Plan Summa c5 v , m 7-518 9-7/ 3000 6000 9000 12000 150 �/ ... _... u Equivalent Magnetic Distance Measured Depth Its flat iFb 3S61'.la9al D 1 H W%51 SMt3.1 OT 0.6, 13133' 1F. b 1191 Plan: 9.8+39.10 @ 48.90usft (Doyon 142) v 0.0 6 I s1aM 1 430 1610 Degh Fra. Depls To SurveY=5 Mood 31 Iawp05 (Plan: 3R�ta) TW39.10 GTD 110000 21008 30.-tO6wp05 (Plan 30.-1051 MW➢ 24 779 3R R-106) i4 240700 79 3907.79 30.-IW0P05 (Pan 3R -m8) .50 00 o O o 0 125.24 732524 M-taxp05 (Plan: M-ta MWC 125.24 14220.17 3R-taxpa (Phil[ 211) MWC Faun , UG -C 30..18 T105f719AV 3340 - 3850 _101 O F' 10-3/4 x 13-1/2' or 1 0 39 500 0 2000 4000 6000 8000 10000 12000 331x- 08 30 So890 0 6 - 690 ,0 7-5/8" x 9-7/8'Harizontal 530 0 �/ ... _... u Equivalent Magnetic Distance U Its flat iFb 3S61'.la9al D 1 H W%51 SMt3.1 OT 0.6, 13133' 1F. b 1191 0 2000 4000 601 M 6 I s1aM 1 430 1610 Degh Fra. Depls To SurveY=5 Mood 31 Iawp05 (Plan: 3R�ta) TW39.10 GTD 110000 21008 30.-tO6wp05 (Plan 30.-1051 MW➢ 24 779 3R R-106) MWC 240700 79 3907.79 30.-IW0P05 (Pan 3R -m8) MW➢ 2407.79 5825.24 30.-11x1105 (Plan: 30.-11/ MWL 125.24 732524 M-taxp05 (Plan: M-ta MWC 125.24 14220.17 3R-taxpa (Phil[ 211) MWC Per i 3parture 4-1/2" x 6-3/4 3R-1 r 5'" 870 - 1060 ION 1240 son T ed 0 S..2199 TF, b 413 3&IW TO M19 AV flat iFb 3S61'.la9al H W%51 SMt3.1 OT 0.6, 13133' 1F. b 1191 1246 1430 K15 300 6 I s1aM 1 430 1610 30.106 tt5 am19 AV p03 1610 - 1800. 1810 2310 add b 3825 3815 TO6 L610f9AV 2830 30.2310 3; 28N 3340 Faun , UG -C 30..18 T105f719AV 3340 - 3850 fjW 1Fb1]6.9'.b499 a, Sam -4370 36>36TlOXW9AV D TF, 0.A , 431 - 1870 3R.tO6T1209D19 AV w5 b 187 lis14-11WOLS al 14 e C1w 41170 - 53M las b 46157 N ]R_ 1. 02 1m - side Sort 1'11W 0.s, 0.7. a X78 V INT14033019AV 5900 - aW6 240 1wp02 6940 - 7880 ,gad - 9020 120 8000 10000 12000 14000 the audit III& I approve it as the basis for the final we11 plan add wellsite di I 9020 - 10060 Depth 3R 3R.1 pot a 210 wp04 mad - ntoo 11106 12140 12140 m180 13180 141= surface LCpGon Pad Elevation: 9.80 '.MS TVD MD Name Magnetic Model &Date: BGGM20taAug-1 S+Ms 2zazeoz4o7.7910-3/4• x 13-10 3.Ms 3707.935825.24 7518•• x 9-718•• Magnetic North is 16.48° East of True North (Magnetic Declination) 3822.024220.17 4-12'x64VC Magnetic Dip & Field Strength: 80.95° 57415nT �1 000 0. ea 9m lad 000 0.00 O.a. Oro XCI'. ga115'/11 Rs. 15'TF. aalP Lithoid Cdumn gY 'a 135 150 15.1 15 aa125'll1 qS.9 iF, b1UA18 163 034 21 ON 71.34 1 W li48i• 123 9197 01 001 9197 dust £5'111MS. 0' V, b 53371 L68 1738 250 000 Inn sddbsa 181 17663 000 000 17780 mn,r1100 as, Ow7.. b vul p� IW E6N 300 0.64 Tax Iddidwhr 11 32629 ON 000 3529 also 3.1110.5. AW 7. b 216.21' 1 mY" 187543 300 9.1187543 30.-1519 MOM19AV md33V1IO10.S3!i"TF.1or15A' PFROST '73 a5 1059.& 3m 3ONWe85 Su136'n1 OLS 1959'1£, b256a3 102 505.11 01 ON 2995.11 n V Osara I i H. B. Anh 3615162 063319AV WMlxw Stat 3-11W 0.3. IOT TF• b AN H fa 93155 son T ed 0 S..2199 TF, b 413 3&IW TO M19 AV flat iFb 3S61'.la9al H W%51 SMt3.1 OT 0.6, 13133' 1F. b 1191 38-106 TO1 f63019AV K15 Sb12.111 Di d9P 7,, b019 Nstl br, imi 30.106 tt5 am19 AV S612Y11O&V!24° TFb9% add b 3825 3815 TO6 L610f9AV sen 35.1 to 01 d WU.. b 5331 Ia3 821459 36106718053019AV wRbrOLS, few 7, b8a131' x75.5 Faun , UG -C 30..18 T105f719AV 7oM tx 5%OB SW 35'1110.$ 1551 TF,btBffi fjW 1Fb1]6.9'.b499 a, IMabal.u' UG -6 36>36TlOXW9AV D TF, -86W 6273295 W1Fn =.W00 UG -A 3R.tO6T1209D19 AV w5 b 187 lis14-11WOLS al 14 e sal Snl5N. in890.. U1 las b 46157 N 3 MT13063119AV S,, YI110.s, IN 51.7. b 24%1 Sort 1'11W 0.s, 0.7. a X78 V INT14033019AV IkHb 1544 ki�78.0 shgnhng hs gal t eve mfo risks, urroofall sito Bala is correct, ensured its completeness, and all surrounding wells are assignetl to re and am assigned the proper position and I approve the stn and collision avoidant plan as set out ih the audit III& I approve it as the basis for the final we11 plan add wellsite di I also acxnW.dge that unless notified otlha iue all targets have a 100 feet lateral ccepted by: Approved by: J. Ryan Madeline Woodard 01 2015 3R-106wp05 39.10 To 14220.17 I Spider Easting (6000 ustVin) 3R-106wp05 Plan Vuew While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4500- 3000 7-5/8" x 9-7/8" 0 0 0 0 0 0 0 0 A OHO 0 0 0 0 + 0 0 0 0 Y 000 Op 0 O 01500 zo LO 3000 3: s 0 o 10-3/4" x 13-1/2" ➢ % 2000 M 4-1/2" x 6-3/4" 0 000 -1500- 0 1500 3000 4500 6000 7500 9000 10500 West( -)/East(+) 3R-106wp05 Section View 1500 1 4500 FROST K15 O 7-5/8" x 9-7/8" 0 0 O o 0 O+ O 00M� , 00 00 0 1500 3000 4500 6000 Vertical Section at 90.00° SII WS-mvs-C 0 0 00 Oo O O N d O MO N app W V V N —a 0 4-1/2" x 6-3/4" 0 io a 3 m 0 CO 7500 9000 10500 0j T 1000 Q 0 1500 JI Ieoo 10-3/4" x 13-1/ " 90i F= 3000 4500 FROST K15 O 7-5/8" x 9-7/8" 0 0 O o 0 O+ O 00M� , 00 00 0 1500 3000 4500 6000 Vertical Section at 90.00° SII WS-mvs-C 0 0 00 Oo O O N d O MO N app W V V N —a 0 4-1/2" x 6-3/4" 0 io a 3 m 0 CO 7500 9000 10500 ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit _2 Kuparuk 3R Pad Plan: 3R-106 50029xxxxx00 Plan: 3R-106 Plan: 3R-106wp05 Standard Proposal Report 01 July, 2019 ConocoPhillips ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska Inc_ Kuparuk Project. Kuparuk River Unit 2 Site: Kuparuk 3R Pad Well: Plan: 3R-106 Wellbore: Plan: 3R-106 Design: 3R-106wp05 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-106 ND Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) MD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit 2, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kupamk 3R Pad Depth From (ND) Site Position: (usft) Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well Plan: 3R-106 Well Position +N/ -S Northing: +E/ -W Easting: Position Uncertainty Wellhead Elevation: Wellbore Plan. 3R-106 Magnetics Model Name Sample Date BGGM2018 8/15/2019 Design 3R-106Wp05 Audit Notes: Version: Vertical Section: Latitude: Longitude: 0.000 in Grid Convergence: Declination 16.48 Phase: PLAN Depth From (ND) +N/ -S (usft) (usft) 39 10 0 00 Latitude: Longitude: Ground Level: Dip Angle 80.95 Tie On Depth: 39.10 +E/ -W Direction (usft) 0 00 90 00 0.16' Field Strength rT) 57,415 71112019 10' 10.33AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-106 ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska Inc—Kuparuk Project: Kuparuk River Unit -2 Site: Kuparuk 3R Pad Well: Plan: 3R-106 Wellbore: Plan: 3R-106 Design: 3R-106wp05 Plan Survey Tool Program Date 71112019 Depth From Depth To (usft) (usft) Survey (Wellbore) 1 39.10 1,110.00 3R-106wp05 (Plan: 3R-106) 2 1,100.00 2,100.00 3R-106wp05 (Plan: 3R-106) 3 1,100.00 2,407.79 3R-106wp05 (Plan: 3R-106) 4 2,407.79 3,907.79 3R-108wp05 (Plan: 3R-106) 5 2,407.79 5,825.24 3R-106wp05 (Plan: 3R-106) 6 5,825.24 7,325.24 3R-106wp05(Plan: 3R-106) 7 5,825.24 14,220.17 3R-106wp05(Plan: 3R-106) ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-106 TVD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) MD Reference: Plan: 9.8+39.10 (d 48.90usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature ..._... _..... .. ... Tool Name Remarks GYD-GC-SS Gyrodata gyro single shots MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD+ IFR2+Sag +A MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD + IFR2+Sag + A MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD+IFR2+Sag +t 71112019 10.10: 33AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Database: Company: Project Site: Welt: Wellbore: Design: Plan Sections Measured Depth (usft) OAKEOMPt ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Kuparuk 3R Pad Plan: 3R-106 Plan: 3R-106 3R-106wp05 Vertical Inclination Azimuth Depth +Nl-S C) 11 (usft) (usft) ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 3R-106 TVD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) MD Reference: Plan. 9.8+39.10 @ 48.90usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Dogleg Build Turn .El -W Rate Rate Rate TFO (usft) (olt0ousft) (o1100usft) (`1100usft) (I Target 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 Goo 0.00 0.00 0.00 000 0,00 700.00 3.00 15.00 699.91 5.06 1.35 1.50 1.50 0.00 15.00 1,759.18 29.48 15.00 1,707.80 288.63 77.34 2.50 2.50 0.00 0.00 1,874.05 29.48 15.00 1,807.80 343.23 91.97 0.00 0.00 0.00 0.00 2,407.79 42.82 15.00 2,237.80 646.68 173.28 2.50 2.50 0.00 0.00 2,427.79 42.82 15.00 2,252.47 659.81 176.80 0.00 0.00 0.00 0.00 2,832.64 54.97 15.17 2,518.14 953.80 256.07 3.00 3.00 0.04 0.64 3,160.45 54.97 15.17 2,706.31 1,212.88 326.29 0.00 0.00 0.00 0.00 5,436.66 80.00 85.58 3,674.69 2,334.73 1,875.43 3.00 1.10 3.09 87.08 3R-106 T01 VISO 05" 5,563.05 83.65 82.84 3,692.66 2,347.36 1,999.85 3.60 2.89 -2.17 -36.83 5,568.38 83.65 82.84 3,693.25 2,348.02 2,005.11 0.00 0.00 0.00 0.00 5,625.24 89.80 89.76 3,707.93 2,364.51 2,260.74 3.60 2.39 2.69 48.59 3R-106 T02 Heel 053 5,845.24 89.80 89.76 3,708.00 2,364.59 2,280.74 0.00 0.00 0.00 0.00 5,874.93 90.69 89.78 3,707.87 2,364.71 2,310.43 3.00 3.00 005 1.02 6,805.48 90.69 89.78 3,696.66 2,368.34 3,240.91 0.00 0.00 0.00 0.00 6,858.61 92.17 89.18 3,695.33 2,368.82 3,294.02 3.00 2.78 -1.12 -21.98 3R-106 T03 053019 F 6,668.30 92.37 88.97 3,694.95 2,368.98 3,303.70 3.00 2.10 -2.15 -45.61 7,464.16 92.37 86.97 3,670.28 2,379.66 3,898.95 0.00 0.00 0.00 0.00 7,582.19 89.89 91.50 3,667.95 2,379.17 4,016.94 3.00 -2.10 2.14 134.39 3RA 06 T04 053019 F 7,582.38 89.90 91.50 3,667.95 2,379.17 4,017.12 2.00 1.99 -0.17 4.94 8,650.94 89.90 91.50 3,669.87 2,351.17 5,085.32 0.00 0.00 0.00 0.00 8,670.88 89.50 91.54 3,669.97 2,350.64 5,105.26 2.00 -1.99 0.17 175.05 3R-106 T05 053019 F 8,755.12 89.78 89.45 3,670.50 2,349.92 5,189.48 2.50 0.34 -2.48 -82.24 9,138.00 89.78 89.45 3,671.93 2,353.60 5,572.34 0.00 0.00 0.00 0.00 9,463.73 88.11 99.08 3,677.93 2,329.42 5,896.72 3.00 -0.51 2.96 99.93 3R-106 TO6 053019 f 9,727.07 87.06 89.91 3,689.06 2,308.81 6,158.73 3.50 -0.40 -3.48 -96.75 9,941.66 87.06 89.91 3,700.08 2,309.13 6,373.04 0.00 0.00 0.00 0.00 10,801.87 88.67 120.00 3,732.87 2,089.71 7,193.94 3.50 0.19 3.50 87.56 3R-106 T08053019A 10,903.95 88.77 123.57 3,735.14 2,035.97 7,280.67 3.50 0.10 3.50 88.48 11,443.01 88.77 123.57 3,746.69 1,737.94 7,729.71 0.00 0.00 0.00 0.00 11,461.87 88.27 124.00 3,747.18 1,727.46 7,745.37 3.50 -2.67 2.27 139.62 3R-106 T09 053019 F 11,511.77 86.53 124.10 3,749.45 1,699.55 7,786.68 3.50 -0.49 0.21 176.62 11,593.91 86.53 124.10 3,754.42 1,653.58 7,854.56 0.00 0.00 0.00 0.00 11,886.66 90.83 135.00 3,761.20 1,467.51 8,079.83 4.00 1.47 3.72 68.64 3R-106 T10 053019 A 12,349.40 90.94 116.49 3,753.99 1,198.40 8,453.72 4.00 0.02 41.00 -89.51 12,433.26 90.94 116.49 3,752.61 1,161.00 8,528.77 0.00 0.00 0.00 0.00 13,099.81 87.87 90.00 3,759.64 1,009.63 9,171.70 4.00 -0.46 -3.97 -96.643R-106 T12053019A 13,211.49 85.67 89.64 3,765.94 1,009.98 9,283.19 2.00 -1.97 -0.32 -170.68 13,673.06 85.67 89.64 3,800.82 1,012.90 9,743.44 0.00 0.00 0.00 0.00 13,697.89 85.50 90.11 3,802.73 1,012.95 9,768.19 2.00 -0.67 1.89 109.54 3R-106 T13 053019 F 14,065.65 89.16 90.11 3,819.80 1,012.27 10,135.49 1.00 1.00 0.00 0.00 14,220.17 89.18 90.11 3,822.02 1,011.98 10,289.99 0.00 0.00 0.00 0.00 3R-106 T14053019A 7/12019 10.1O'33AM Page 4 COMPASS 5000.14 Build 85D i ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan 3R-106 Company: ConocoPhillips Alaska inc_Kuparuk ND Reference: Plan: 9.8+39.10 @48.90usft (Doyon 142) Project. Kuparuk River Unit _2 MD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-106 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-106 Design: 3R-106wp05 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth -NI-S +EI -W Section Rate Rate Rate (usft) (°) C) (usft) (usft) (usft) (usft) (`I100usft) (01100ustt) ('1100usft) 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 000 100.00 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 0.00 0.00 460.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.60 0.00 0.00 0.00 0.00 KOP: Start 1.5°1100' OLS, IS' TF, for 200' 600.00 1.50 15.00 599.99 1.26 0.34 0.34 1.50 1.50 0.00 700.00 3.00 15.00 699.91 5.06 1.35 1.35 1.50 1.50 0.00 Start2.5°/700' DLS, 0° TF, for 1059.18' 800.00 5.50 15.00 799.63 12.21 3.27 3.27 2.50 2.50 0.00 900.00 8.00 15.00 898.92 23.57 6.31 6.31 2.50 2.50 0.00 1,000.00 10.50 15.00 997.62 39.09 10.47 10.47 2.50 2.50 0.00 1,100.00 13.00 15.00 1,095.51 58.76 15.74 15.74 2.50 2.50 0.00 1,200.00 15.50 15.00 1,192.43 82.54 22.12 22.12 2.50 2.50 0.00 1,300.00 18.00 15.00 1,288.18 110.37 29.57 29.57 2.50 2.50 0.00 1,400.00 20.50 15.00 1,382.58 142.21 38.11 38.11 2.50 2.50 0.00 1,500.00 23.00 15.00 1,475.45 176.00 47.70 47.70 2.50 2.50 0.00 1,600.00 25.50 15.00 1,566.62 217.67 58.33 58.33 2.50 2.50 0.00 1,700.00 28.00 15.00 1,655.91 261.15 69.97 69.97 2.50 2.50 0.00 1,724.75 28.62 15.00 1,677.70 272.48 73.01 73.01 2.50 2.50 0.00 13 1,759.18 29.48 15.00 1,707.80 268.63 77.34 77.34 2.50 2.50 0.00 Hold for 114.87' 1,787.71 29.48 15.00 1,732.64 302.19 80.97 80.97 0.00 0.00 0.00 PFROST 1,800.00 29.48 15.00 1,743.34 308.03 82.54 82.54 0.00 0.00 0.00 1,874.05 29.48 15.00 1,807.80 343.23 91.97 91.97 0.00 0.00 0.00 Start 2.5°/100' DLS, 0° TF, for 533.74' 1,900.00 30.13 15.00 1,830.32 355.69 95.31 95.31 2.50 2.50 0.00 2,000.00 32.63 15.00 1,915.69 405.98 108.78 108.78 2.50 2.50 0.00 2,067.84 34.32 15.00 1,972.27 442.13 118.47 118.47 2.50 2.50 0.00 K15 2,100.00 35.13 15.00 1,998.70 459.82 123.21 123.21 2.50 2.50 0.00 2,200.00 37.63 15.00 2,079.21 517.11 138.56 138.56 2.50 2.50 0.00 2,300.00 40.13 15.00 2,157.05 577.73 154.80 154.80 2.50 2.50 0.00 2,400.00 42.63 15.00 2,232.08 641.58 171.91 171.91 2.50 2.50 0.00 2,407.79 42.82 15.00 2,237.80 646.68 173.28 173.28 2.50 2.50 0.00 Hold for 20'- 10-314" x 13-1/2" 2,427.79 42.82 15.00 2,252.47 659.81 176.80 176.80 0.00 0.00 0.00 Start 3°1100' DLS, 0.84° TF, for 404.86' 2,500.00 44.99 15.03 2,304.49 708.18 189.77 189.77 3.00 3.00 0.05 2,600.00 47.99 15.08 2,373.33 778.20 208.61 20861 3.00 3.00 0.04 2,700.00 50.99 15.12 2,438.29 851.60 228.41 228.41 3.00 3.00 0.04 2,800.00 53.99 15.15 2,499.17 928.16 249.12 249.12 3.00 3.00 0.04 2,83264 54.97 15.17 2,518.14 953.60 256.07 256.07 3.00 3.00 0.03 Hold for 327.81' 2,900.00 54.97 15.17 2,556.80 1,007.04 270.50 270.50 0.00 0.00 0.00 3,000.00 54.97 15.17 2,614.21 1,086.07 291.92 291.92 0.00 0.00 0.00 3,100.00 54.97 15.17 2,671.61 1,165.10 313.34 313.34 0.00 0.00 0.00 7/12019 10:10'33AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan'. 3R-106 Company. ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Plan: 9.8+39.10@ 48.90usft(Doyon 142) Project: Kuparuk River Unit-2 MD Reference: Plan. 9.8+39.10 @ 48.90usft (Doyon 142) Site'. Kuparuk 3R Pad North Reference: True Well: Plan: 3R-106 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-106 Design: 3R-106wp05 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N1-S +E/-W Section Rate Rate Rate (usft) (1) (1) (usft) (usft) (usft) (usft) (11100usft) (1/100usft) (1/100usftl Start 311100' DLS, 87.08° TF, for 2276.21' 3,200.00 55.04 16.61 2,728.99 1,244.03 335.16 335.16 3.00 0.17 366 3,300.00 55.29 20.25 2,786.13 1,321.88 361.10 361.10 3.00 0.25 3.64 3,400.00 55.65 23.87 2,842.83 1,398.20 392.04 392.04 3.00 0.36 3.62 3,455.27 55.89 25.85 2,873.93 1,439.66 411.25 411.25 3.00 0.44 3.59 UG-C 3,500.00 56.11 27.45 2,898.94 1,472.80 427.89 427.89 3.00 0.49 3.57 3,600.00 56.67 30.99 2,954.31 1,545.46 468.54 468.54 3.00 0.57 3.54 3,700.00 57.34 34.48 3,008.77 1,616.00 513.89 513.89 3.00 0.66 3.49 3,800.00 58.10 37.91 3,062.19 1,684.20 563.81 563.81 3.00 0.76 3.43 3,900.00 58.95 41.28 3,114.41 1,749.90 618.16 618.16 3.00 0.85 3.37 3,958.71 59.49 43.23 3,144.46 1,787.23 652.08 652.08 3.00 0.92 3.32 UG-B 4,000.00 59.89 44.59 3,165.30 1,812.90 676.60 676.80 3.00 0.96 3.29 4,100.00 60.90 47.84 3,214.71 1,873.04 739.57 739.57 3.00 1.02 3.25 4,200.00 62.00 51.02 3,262.51 1,930.15 806.29 806.29 3.00 1.09 3.16 4,200.34 62.00 51.03 3,26267 1,930.34 805.52 806.52 3.00 1.13 3.15 UGA 4,300.00 63.16 54.13 3,308.57 1,984.08 876.77 876.77 3.00 1.17 3.11 4,400.00 64.40 57.18 3,352.76 2,034.67 950.84 950.84 3.00 1.23 3.05 4,500.00 85.69 60.17 3,394.95 2,081.76 1,028.28 1,028.28 3.00 1.29 2.99 4,528.11 66.07 60.99 3,406.44 2,D94.38 1,050.63 1,050.63 3.00 1.33 2.95 N 4,600.00 67.04 63.09 3,435.05 2,125.30 1,108.88 1,108.88 3.00 1.36 2.91 4,700.00 68.45 65.95 3,472.92 2,165.09 1,192.43 1,192.43 3.00 1.40 2.86 4,800.00 69.90 68.76 3,508.48 2,201.06 1,278.68 1,278.68 3.00 1.45 2.81 4,900.00 71.40 71.52 3,541.62 2,233.09 1,367.41 1,367.41 3.00 1.50 2.76 5,000.00 72.93 74.23 3,572.25 2,261.11 1,458.38 1,458.38 3.00 1.54 2.71 5,100.00 74.50 76.89 3,600.29 2,285.04 1,551.32 1,551.32 3.00 1.57 2.66 5,200.00 76.11 79.51 3,625.66 2,304.81 1,646.00 1,646.00 3.00 1.60 2.62 5,300.00 77.73 82.10 3,648.30 2,320.36 1,742.14 1,742.14 3.00 1.53 2.59 5,400.00 79.39 84.65 3,668.13 2,331.66 1,839.49 1,839.49 3.00 1.65 2.55 5,434.37 79.96 65.52 3,674.29 2,334.56 1,873.17 1,873.17 3.00 1.67 2.53 W5-D 5,436.66 80.00 85.58 3,674.69 2,334.73 1,875.43 1,875.43 3.00 1.67 2.53 Start 3.81/100' DLS, -36.931 TF, for 126.38- 5,500.00 81.83 84.20 3,684.69 2,340.30 1,937.72 1,937.72 3.60 2.89 -2.18 5,544.98 83.13 83.23 3,690.58 2,345.19 1,982.04 1,982.04 3.60 2.89 -2.16 WS-C 5,563.05 83.65 82.84 3,692.86 2,347.36 1,999.85 1,999.85 3.60 2.90 -2.15 Hold for 6.33' 5,568.38 83.65 82.84 3,693.25 2,348.02 2,005.11 2,005.11 0.00 0.00 0.00 Start 3.611100' DLS, 48.591 TF, for 256.86- 5.600.00 84.41 83.70 3,698.54 2,351.71 2,036.34 2,036.34 3.60 2.38 2.71 5,700.00 86.80 86.40 3,704.21 2,360.31 2,135.66 2,135.66 3.60 2.39 2.70 5,800.00 89.19 89.08 3,707.71 2,364.25 2,235.51 2,235.51 3.60 2.40 2.69 5,825.24 89.80 89.76 3,707.93 2,364.51 2,260.74 2,260.74 3.60 2.40 2.68 Hold for 20'. 7-518" x 9-7/8" 5.845.24 89.80 89.76 3,708.00 2,364.59 2,280.74 2,280.74 0.00 0.00 0.00 Start 311100' DLS, 1.021 TF, for 29.69- 5,874.93 90.69 89.78 3,707.87 2,364.71 2,310.43 2,310.43 3.00 3.00 0.05 Hold for 930.55' 7/1/2019 10,10'33AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 3R-106 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Project: Kuparuk River Und 2 MD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad North Reference: True Well: Plan3R-106 Survey Calculation Method: Minimum Curvature Wellbore: Plan'. 3R-106 Design: 3R-106wp05 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usftl (°1100usft) (°/t00usft) 5,900.00 90.69 89.78 3,707.57 2,364.81 2,335.50 2,335.50 0.00 0.00 0.00 6,000.00 90.69 89.78 3,706.37 2,365.20 2,435.49 2,435.49 0.00 0.00 000 6,100,00 90.69 89.78 3,705.16 2,365.59 2,535.48 2,535.48 0.00 0.00 0.00 6,200.00 90.69 89.78 3,703.95 2,365.98 2,635.48 2,635.46 0.00 0.00 0.00 6,300.00 90.69 89.78 3,702.75 2,366.37 2,735.47 2,735.47 0.00 0.00 0.00 6,400.00 90.69 89.78 3,701.54 2,366.76 2,835.46 2,835.46 0.00 0.00 0.00 6,500.00 90.69 89.78 3,700.34 2,367.15 2,935.45 2,935.45 0.00 0.00 0.00 6,600.00 90.69 89.78 3,699.13 2,367.54 3,035.44 3,035.44 0.00 0.00 0.00 6,700.00 9069 89.78 3,697.93 2,367.93 3,135.44 3,135.44 0.00 0.00 0.00 6,800.00 90.69 89.78 3,69672 2,368.32 3,235.43 3,235.43 0.00 0.00 0.00 6,805.48 90.69 89.78 3,696.66 2,368.34 3,240.91 3,240.91 0.00 0.00 0.00 Start 3°/100' OLS, -21.98° TF, for 53.13' 6,858.61 92.17 89.18 3,695.33 2,368.82 3,294.02 3,294.02 3.00 2.78 -1.12 Adjust TF to -45.61°, for SAW 6,868.30 92.37 88.97 3,694.95 2,368.98 3,303.70 3,303.70 3.00 2.10 -2.15 Hold for 596.86' 6,900.00 92.37 88.97 3,693.63 2,369.55 3,335.37 3,335.37 0.00 0.00 0.00 7,000.00 92.37 88.97 3,689.50 2,371.34 3,435.26 3,435.26 0.00 0.00 0.00 7,100.00 92.37 88.97 3,685.36 2,373.13 3,535.16 3,535.16 0.00 0.00 0.00 7,200.00 92.37 88.97 3,681.22 2,374.92 3,635.06 3,635.06 0.00 0.00 0.00 7,300.00 92.37 88.97 3,677.08 2,376.72 3,734.96 3,734.96 0.00 0.00 0.00 7,400.00 92.37 88.97 3,672.94 2,378.51 3,834.86 3,834.86 0.00 0.00 0.00 7,464.16 92.37 88.97 3,670.28 2,379.66 3,898.95 3,898.95 0.00 0.00 0.00 Start 3°/100' DLS, 134.39° TF, for 118.03- 7,500,00 91.62 89.74 3,669.04 2,380.06 3,934.77 3,934.77 3.00 -2.10 2.14 7,582,19 89.89 91.50 3,667.95 2,379.17 4,016.94 4,016.94 3.00 -2.10 2.14 7,582.38 89.90 91.50 3,667.95 2,379.17 4,017.12 4,017.12 2.00 1.99 -0.17 Start 2°1100' DLS, -4.94° TF, for 0.18' 7,600.00 89.90 91.50 3,667.98 2,378.70 4,034.74 4,034.74 0.00 0.00 0.00 7,700.00 89.90 91.50 3,668.16 2,376.08 4,134.71 4,134.71 0.00 0.00 0.00 7,800.00 69.90 91.50 3,668.34 2,373.46 4,234.67 4,234.67 0.00 0.00 0.00 7,900.00 89.90 91.50 3,668.52 2,370.64 4,334.64 4,334.64 0.00 0.00 0.00 8,000.00 89.90 91.50 3,668.70 2,368.22 4,434.60 4,434.60 0.00 0.00 0.00 8,100.00 89.90 91.50 3,668.88 2,365.60 4,534.57 4,534.57 0.00 0.00 0.00 8,200.00 89.90 91.50 3,669.06 2,362.98 4,634.54 4,634.54 0.00 0.00 0.00 6,300.00 89.90 91.50 3,669.24 2,360.36 4,734.50 4,734.50 0.00 0.00 0.00 8,400.00 89.90 91.50 3,669.42 2,357.74 4,834.47 4,834.47 0.00 0.00 0.00 8,500.00 89.90 91.50 3,669.59 2,355.12 4,934.43 4,934.43 0.00 0.00 0,00 8,600.00 89.90 91.50 3,669.77 2,352.50 5,034.40 5,034.40 0.00 0.00 0.00 8,650.94 69.90 91.50 3,669.87 2,351.17 5,085.32 5,085.32 0.00 0.00 0.00 Hold for 1068.57' 8,670.88 89.50 91.54 3,669.97 2,350.64 5,105.26 5,105.26 2.00 -1.99 0.17 Start 2°1100' DLS, 175.05° TF, for 19.94' 8,700.00 89.60 90.81 3,670.20 2,350.04 5,134.37 5,134.37 2.50 0.34 -2.48 8,755.12 89.78 89.45 3,670.50 2,349.92 5,189.48 5,189.48 2.5D 0.34 -2.48 Start 2.5°1100' DLS, -82.24' TF, for 84.24' 8,800.00 89.78 89.45 3,670.66 2,350.35 5,234.36 5,234.36 0.00 0.00 0.00 8,900.00 89.7(1 89.45 3,671.04 2,351.31 5,334.36 5,334.36 0.00 0.00 0.00 9,000.00 89.78 89.45 3,671.42 2,352.27 5,434.35 5,434.35 0.00 0.00 0.00 9,100.00 89.78 89.45 3,671.79 2,353.23 5,534.35 5,534.35 0.00 0.00 0.00 9,138.00 89.78 89.45 3,671.93 2,353.60 5,572.34 5,572.34 0.00 0.00 0.00 Hold for 382.88' 9,200.00 89.46 91.28 3,672.34 2,353.20 5,634.34 5,634.34 3.00 -0.52 2.96 71112019 f 0:10:33AM Page 7 COMPASS 5000.14 Build 85D `. ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI local Co-ordinate Reference: Well Plan: 3R-106 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Project Kuparuk River Unit_2 MD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad North Reference: True Well: Plan: 3R-106 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-106 Design: 3R-106wp05 - _- Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NI-S +E/-W Section Rate Rate Rare (usft) (°) (°) (usft) (usft) (usft) (usft) I°1100usft) ('1100usft) I'1100usft) 9,300.00 88.95 94.24 3,673.73 2,348.39 5,734.20 5,734.20 3.00 -0.52 2.96 9,400.00 88.44 97.19 3,676.01 2,338.44 5,833.67 5,833.67 3.00 -0.51 2.96 9,463.73 88.11 99.08 3,677.93 2,329.42 5,896.72 5,896.72 3.00 -0.51 2.96 Start 3°1100' DLS, 99.93° TF, for 325.73' 9,500.00 87.96 97.82 3,679.17 2,324.10 5,932.58 5,932.58 3.50 -0.41 -3.48 9,600.00 87.56 94.34 3,683.08 2,313.52 6,031.92 6,031.92 3.50 -040 -3.48 9,700.00 87.16 90.86 3,687.89 2,308.99 6,131.70 6,131.70 3.50 -0.40 -3.48 9,727.07 87.06 89.91 3,689.06 2,308.81 6,158.73 6,158.73 3.50 -0.39 -3.48 Start 3.6°1100' OLS, -96.75° TF, for 263.34' 9,800.00 87.06 89.91 3,692.80 2,308.92 6,231.57 6,231.57 0.00 0.00 0.00 9,900.00 87.06 89.91 3,697.94 2,309.07 6,331.44 6,331.44 0.00 0.00 0.00 9,941.66 87.06 69.91 3,700.08 2,309.13 6,373.04 6,373.04 0.00 0.00 0.00 Hold for 214.59' 10,000.00 87.14 91.96 3,703.03 2,308.18 6,431.30 6,431.30 3.50 0.15 3.50 10,100.00 87.31 95.46 3,707.87 2,301.73 6,530.95 6,530.95 3.50 0.16 3.50 10,200.00 87.48 98.96 3,712.43 2,289.20 6,630.05 6,630.05 3.50 0.17 3.50 10,300.00 87.66 102.45 3,716.67 2,270.64 6,728.20 6,728.20 3.50 0.18 3.50 10,400.00 87.84 105.95 3,720.60 2,246.13 6,825.05 6,825.05 3.50 0.19 3.50 10,500.00 88.04 109.45 3,724.19 2,215.75 6,920.24 6,920.24 3.50 0.20 3.50 10,600.00 88.24 112.94 3,727.44 2,179.61 7,013.41 7,013.41 3.50 0.20 3.50 10,700.00 88.45 116.44 3,730.32 2,137.86 7,104.22 7,104.22 3.50 0.21 3.50 10,800.00 88.67 119.93 3,732.83 2,090.65 7,192.32 7,192.32 3.50 0.22 3.49 10,801.87 88.67 120.00 3,732.87 2,089.71 7,193.94 7,193.94 3.50 0.22 3.49 Start 30/100' DLS, 87.56° TF, for 860.21' 10,900.00 88.77 123.43 3,735.06 2,038.14 7,277.36 7,277.38 3.50 0.10 3.50 10,903.95 88.77 123.57 3,735.14 2,035.97 7,280.67 7,280.67 3.50 0.10 3.50 Adjust TF to 88.48°, for 102.08' 11,000.00 88.77 123.57 3,737.20 1,982.86 7,360.68 7,360.68 0.00 0.00 0.00 11,100.00 88.77 123.57 3,739.34 1,927.58 7,443.98 7,443.98 0.00 0.00 0.00 11,200.00 88.77 123.57 3,741.49 1,872.29 7,527.28 7,527.28 0.00 0.00 0.00 11,300.00 88.77 123.57 3,743.63 1,817.00 7,610.58 7,610.58 0.00 0.00 0.00 11,400.00 88.77 123.57 3,745.77 1,761.72 7,693.88 7,693.88 0.00 0.00 0.00 11,443.01 88.77 123.57 3,746.69 1,737.94 7,729.71 7,729.71 0.00 0.00 0.00 Hold for 639.06' 11,461.87 88.27 124.00 3,747.18 1,727.46 7,745.37 7,745.37 3.50 -2.87 2.27 Start 3.6°1100' DLS, 139.62° TF, for 18.86' 11,500.00 86.94 124.08 3,748.77 1,706.13 7,776.95 7,776.95 3.50 -3.49 0.21 11,511.77 86.53 124.10 3,749.45 1,699.55 7,786.68 7,786.68 3.50 -3.49 0.21 Adjust TF to 176.62°, for 49.9' 11,593.91 86.53 124.10 3,754.42 1,653.58 7,854.56 7,854.56 0.00 0.00 0.00 Hold for 82.14' 11,600.00 86.61 124.33 3,754.79 1,650.16 7,859.59 7,859.59 4.00 1.46 3.73 11,700.00 88.08 128.06 3,759.42 1,591.18 7,940.19 7,940.19 4.00 1.46 3.73 11,800.00 89.55 131.78 3,761.49 1,527.04 8,016.86 8,016.86 4.00 1.47 3.72 11,886.66 9083 135.00 3,761.20 1,467.51 8,079.83 8,079.83 4.00 1.47 3.72 Start 4°1100' DLS, 68.64° TF, for 292.76' 11,900.00 90,83 134.47 3,761.01 1,458.13 8,089.30 8,089.30 4.00 O.D3 -0.00 12,000.00 90.86 130.47 3,759.52 1,390.63 8,163.04 8,163.04 4.00 0.03 -0.00 12,100.00 90.89 126.47 3,757.99 1,328.45 8,241.32 8,241.32 4.00 0.03 -0.00 12,200.00 90.92 122.47 3,756.41 1,271.87 8,323.74 8,323.74 4.00 0.02 4.00 12,300.00 90.93 118.46 3,754.80 1,221.19 8,409.90 8,409.90 4.00 0.02 4.00 12,34940 90.94 116.49 3,753.99 1,198.40 8,453.72 8,453.72 4.00 0.02 -4.00 Adjust TF to -89.51°, for 462.73' 7/12019 10:10:33AM Page 8 COMPASS 5000.14 Build 85D i ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan. 3R-106 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Plan 9.8+39.10 @ 48.90usft (Doyon 142) Project: Kuparuk River Unit _2 MD Reference: Plan: 9.8+39.10 @48.90usft (Doyon 142) Site: Kupawk 3R Pad North Reference: True Well: Plan: 3R-106 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-106 Design: 3R-106wp05 _ � Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth -NI-S +EI -W Section Rate Rate Rate (usft) (^) V) (usft) (usft) (usft) (usft) ('1100usft) ('1100usft) ('1100usft) 12,400.00 90.94 116.49 3,753.15 1,175.84 8,499.00 8,499.00 0.00 0.00 0.00 12,43326 90.94 116.49 3752.61 1,161.00 8,52877 8,528.77 0.00 0.00 0.00 Hold for 83.87' 12,500.00 90.63 113.84 3,751.69 1,132.63 8,589.16 8,589.16 4.00 -0.46 -3.97 12,600.00 90.17 109.86 3,750.99 1,095.42 8,681.96 8,681.96 4.00 -0.47 -3.97 12,700.00 89.70 105.89 3,751.11 1,064.73 8,777.11 6,777.11 4.00 -0.47 -3.97 12,800.00 89.23 101.92 3,752.04 1,040.70 8,874.15 8,874.15 4.00 -0.47 .3.97 12,900.00 88.77 97.94 3,753.78 1,023.46 8,972.62 8,972.62 4.00 -0.46 -3.97 13,000.00 88.32 93.97 3,756.32 1,013.09 9,072.03 9,072.03 4.00 -0.46 -3.98 13,099.81 87.87 90.00 3,759.64 1,009.63 9,171.70 9,171.70 4.00 -0.45 -3.98 Start 4°1100' DIS, -98.64° TF, for 666.54' 13,100.00 87.87 90.00 3,759.65 1,009.63 9,171.89 9,171.89 0.00 0.00 0.00 13,200.00 85.89 89.67 3,765.09 1,009.92 9,271.74 9,271.74 2.00 -1.98 -0.33 13,21149 8567 89.64 3,765.94 1,009.98 9,283.19 9,283.19 2.00 -1.97 -0.33 Start 2°1100' DLS, .170.68' TF, for 111.68' 13,300.00 85.67 89.64 3,772.63 1,010.54 9,371.45 9,371.45 0.00 0.00 0.00 13,400.00 85.67 89.64 3,780.18 1,011.17 9,471.16 9,471.16 0.00 0.00 0.00 13,500.00 85.67 89.64 3,787.74 1,011.80 9,570,88 9,570.88 0.00 0.00 0.00 13,600.00 85.67 89.64 3,795.30 1,012.44 9,670.59 9,670.59 0.00 0.00 0.00 13,673.06 85.67 89.64 3,800.82 1,012.90 9,743.44 9,743.44 0.00 0.00 0.00 Hold for 461.57' 13,697.89 85.50 90.11 3,802.73 1,012.95 9,768.19 9,768.19 2.00 -0.67 1.89 Start 2°1100' DLS, 109.54° TF, for 24.83' 13,700.00 85.52 90.11 3,802.90 1,012.95 9,770.30 9,770.30 1.00 1.00 0.00 13,800.00 86.52 90.11 3,809.83 1,012.76 9,87D.05 9,870.05 1.00 1.00 0.00 13,900.00 87.52 90.11 3,815.03 1,012.58 9,969.92 9,969.92 1.00 1.00 0.00 14,000.00 88.52 90.11 3,818.48 1,012.39 10,069.86 10,069.88 1.00 1.00 0.00 14,065.65 89.18 90.11 3,819.80 1,012.27 10,135.49 10,135.49 1.00 1.00 0.00 Start 1°1100' DLS, 0° TF, for 367.76' 14,100.00 89.18 91DA1 3,820.30 1,012.20 10,169.84 10,169.84 0.00 0.00 0.00 14,200.00 89.18 90.11 3,821.73 1,012.02 10,269.83 10,269.83 0.00 0.00 0.00 14,220.17 89.18 90.11 3,822.02 1,011.98 10,289.99 10,289.99 0.00 0.00 0.00 Hold for 164.62' 7/1/2019 10'10-33AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI Company: ConocoPhiliips Alaska Inc_Kuparuk Project: Kupawk River Unit 2 Site: Kuparuk 3R Pad Well: Plan: 3R-106 Wellbore: Plan: 3R-106 Design: 3R-106wp05 Design Targets Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: target Name -hit/miss target Dip Angle Dip Dir. TVD -NI-S -El-W -Shape (1) (1) (usft) (usft) (usft) 3ase Permafrost @ 173: 0.00 0.00 1,732.64 302.19 80.97 - plan hits target center -Circle (radius 500.00) SR -106 T04053019 AV 0.00 0.00 3,667.95 2,379.17 4,016.94 - plan hits target center -Circle (radius 100.00) 3R-106 T05 053019 AV 0.00 0.00 3,669.97 2,350.64 5,105.26 - plan hits target center - Circle (radius 100.00) 3R-106 T01 WSD 05301 0.00 0.00 3,674.69 2,334.73 1,875.43 - plan hits target center - Circle (radius 100.00) 3R-106 T06 053019 AV 0.00 0.00 3,877.93 2,329.42 5,896.72 - plan hits target center -Circle (radius 100.00) 311-106 T03 053019 AV 0.00 0.00 3,695.33 2,368.82 3,294.02 -plan hits target center -Circle (radius 100.00) 3R-106 T07 053019 AV 0.00 0.00 3,695.89 2,243.52 6,434.33 - plan misses target center by 64.96usft at 10006.86usft MD (3703.37 TVD, 2307.93 N, 6438.14 E) -Circle (radius 10D.00) 3R-106 T02 Heel 05301, 0.00 0.00 3,707.93 2,364.51 2,260.74 - plan hits target center -Circle (radius 100.00) 3R-106 TOB 053019 AV 0.00 0.00 3,732.87 2,089.48 7,293.79 - plan misses target center by 51.99usft at 10886.93usft MD (3734.78 TVD, 2045.30 N. 7266.44 E) -Circle (radius 100.00) 3R-106 T09053019 AV 0.00 0.00 3,747.18 1,727.22 7,795.22 - plan misses target center by 27.77usft at 11503.22usft MD (3748.95 TVD, 1704.33 N. 7779.61 E) -Circle (radius 10200) 3R-106 TI1 061019 V0 0.00 0.00 3,751.53 1,050.18 8,831.22 - plan misses target center by 0.26usft at 12756.03usft MD (3751.53 TVD, 1050.43 N, 8831.28 E) -Circle (radius 100.00) 3R-106711053019 AV 0.00 0.00 3,751.53 1,075.63 8,721.96 - plan misses target center by 5.73usft at 12644.16usft MD (3750.94 TVD, 1081.05 N. 8723.71 E) - Circle (radius 100.00) 3R-106712053019 AV 0.00 0.00 3,759.84 1,009.40 9,171.55 - plan misses target center by 0.23usft at 13099.67usft MD (3759.63 TVD, 1009.63 N. 9171.56 E) -Circle (radius 100.00) 3R-106 T10053019 AV 0.00 0.00 3,761.20 1,467.28 8,179.68 - plan misses target center by 68.61 usft at 11960.49usft MD (3760.12 TVD, 1416.68 N. 8133.35 E) -Circle (radius 100.00) 3R-106 713053019 AV 0.00 0.00 3,802.73 1,D12.95 9,768.19 - plan hits target center -Circle (radius 100.00) 3R-106 714053019 AV 0.00 0.00 3,822.02 1,011.98 10,289.99 - plan hits target center - Circle (radius 100.00) ConocoPhillips Standard Proposal Report Well Plan: 3R-108 Plan', 9.8+39.10 @ 48.90usft (Doyon 142) Plan: 9.8+39. 10 @ 48.90usft (Doyon 142) True Minimum Curvature 71112019 10,10:33AM Page 10 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan. 3R-106 Company: ConocoPhillips Alaska Inc_ Kuparuk TVD Reference: Plan: 9.8+39.10@48.90usft(Doyon 142) Project: Kuparuk River Unit -2 _ (usft) MD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad 1,67770 North Reference: True Well: Plan: 3R-106 PFROST Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3R-106 0.00 3,455.27 2,873.93 Design: 3R-106wp05 3,958.71 3,144.46 UG -B Casing Points 4,200.34 3,262.67 UG -A 0.00 4,528.11 Measured Vertical N 0.00 Casing Hole 3,674.29 Depth Depth 0.00 5,544.98 Diameter Diameter WS -C (usft) (usfq Name (in) (in) 2,407.79 2,237.80 10-3/4"x 13-1/2" 10.750 13.500 5,825.24 3,707.93 7-5/8" x 9-7/8" 7.625 9.875 14,220.17 3,822.02 4-1/2" x 6-3/4" 4.500 6.750 Formations Measured Vertical Dip Depth Depth Dip Direction _ (usft) (usft) Name Llthology (1) (1) 1,72475 1,67770 T3 0.00 1,787.71 1732.64 PFROST 0.00 2,067.84 1,972.27 K15 0.00 3,455.27 2,873.93 UG -C 0.00 3,958.71 3,144.46 UG -B 0.00 4,200.34 3,262.67 UG -A 0.00 4,528.11 3,408.44 N 0.00 5,434.37 3,674.29 WS -D 0.00 5,544.98 3,690.58 WS -C 0.00 7/1/2019 10:10: 33AM Page 11 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit_2 Site: Kuparuk 3R Pad Well: Plan. 3R-106 Wellbore: Plan: 3R-106 Design: 3R-106wp05 i Plan Annotations Measured Vertical Depth Depth (usft) (usft) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Local Coordinates +N/ -S +E/ -W (usft) (usft) Comment ConocoPhillips Standard Proposal Report Well Plan3R-106 Plan: 9.8+39.10 Q 48.90usft (Doyon 142) Plan' 9.8+39.10 @ 48.90usft (Doyon 142) True Minimum Curvature 500.00 500.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 15° TF, for 200' 700.00 699.91 5.06 1.35 Start 2.5°/100' DLS, 0° TF, for 1059.18' 1,759.18 1,707.80 288.63 77.34 Hold for 114.87' 1,874.05 1,807.80 343.23 91.97 Start 2.5°/100' DLS, 0° TF, for $33.74' 2,407.79 2,237.80 646.68 173.28 Hold for 20' 2,427.79 2,252.47 659.81 176.80 Start 3°/100' DLS, 0.64" TF, for 404.86' 2,832.64 2,518.14 953.80 256.07 Hold for 327.81' 3,160.45 2,706.31 1,212.88 326.29 Start 3°/100' DLS, 87.08" TF, for 2276.21' 5,436.66 3,674.69 2,334.73 1,875.43 Start 3.6°/100' DLS, -36.83' TF, for 126.38' 5,563.05 3,692.66 2,347.36 1,999.85 Hold for 5.33' 5,568.38 3,693.25 2,348.02 2,005.11 Start 3.6°/100' DLS, 48.59° TF, for 256.86' 5,825.24 3,707.93 2,364.51 2,260.74 Hold for 20' 5,845.24 3,708.00 2,364.59 2,280.74 Start 3°/100' DLS, 1.02° TF, for 29.69' 5,874.93 3,707.87 2,364.71 2,310.43 Hold for 930.55' 6,805.48 3,696.66 2,368.34 3,240.91 Start 3/100' DLS, -21.98° TF, for 53.13- 6,858.61 3,695.33 2,368.82 3,294.02 Adjust TF to -45.61°, for 9.ti9' 6,868.30 3,694.95 2,368.98 3,303.70 Hold for 595.86' 7,464.16 3,670.28 2,379.66 3,898.95 Start 3'1101134.39' 134.39° TF, for 118.03' 7,582.38 3,667.95 2,379.17 4,017.12 Start 2°/100'DLS,-4.94"TF, for 0.18' 8,650.94 3,689.87 2,351.17 5,065.32 Hold for 1068.57' 1 8,670.88 3,669.97 2,350.64 5,105.26 Start 2°/100' DLS, 175.05° TF, for 19.94' 8,755.12 3,670.50 2,349.92 5,189.48 Start 2.5'/100' DLS, -82.24° TF, for 84.24' 9,138.00 3,671.93 2,353.60 5,572.34 Hold for 382.88' 9,463.73 3,677.93 2,329.42 5,896.72 Start 3°/100' DLS, 99.93° TF, for 325.73' 9,727.07 3,689.06 2,308.81 6,158.73 Start 3.5°/100' DLS, -96.75° TF, for 263.34' 9,941.66 3,700.08 2,309.13 6,373.04 Hold for 214.59' 10,801.87 3,732.87 2,089.71 7,193.94 Start 3.5°/100' DLS, 87.56° TF, for 860.21' 10,903.95 3,735.14 2,035.97 7,280.67 Adjust TF to 88.48°, for 102.08' 11,443.01 3,746.69 1,737.94 7,729.71 Hold for 539.06' 11,461.87 3,747.18 1,727.46 7,745.37 Start 3.5°/100' DLS, 139.62" TF, for 18.86' 11,511.77 3,749.45 1,699.55 7,786.68 Adjust TF to 176.62°, for 49.9' 11,593.91 3,754.42 1,653.58 7,854.56 Hold for 82.14' 11,886.66 3,761.20 1,467.51 8,079.83 Start 4°/100' DLS, 68.64° TF, for 292.76' 12,349.40 3,753.99 1,198.40 8,453.72 Adjust TF to -89.51°, for 462.73' 12,433.26 3,752.61 1,161.00 8,528.77 Hold for 83.87' 13,099.81 3,759.64 1,009.63 9,171.70 Start 4'/100' DLS, -96.64° TF, for 666.54' 13,211.49 3,765.94 1,009.96 9,283.19 Start 2`/100' DLS, -170.68° TF, for 111.68' 13,673.06 3,800.82 1,012.90 9,743.44 Hold for 461.57' 13,697.89 3,802.73 1,012.95 9,768.19 Start 2°/100' DLS, 109.54° TF, for 24.83' 14,065.65 3,819.80 1,012.27 10,135.49 Start 1 °/100' DLS, 0° TF, for 367.76' 14,220.17 3,822.02 1,011.98 10,289.99 Hold for 154.52' 7/1/2019 10:10:33AM Page 12 COMPASS 5000.14 Build 85D ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit -2 Kuparuk 3R Pad Plan: 3R-106 Plan: 3R-106 50029xxxxx00 3R-106wp05 ConocoPhillips Clearance Summary Anticollision Report 01 July, 2019 Trmt. Cylinder North Proximity Scan on Current Survey Data (North Reference( Reference Design: Kuparuk 3R Pad - Plan: 3R -106 -Plan: 3R-106-3R-106wp06 Well Coordinates: Datum Height: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Scan Range: 0.00 to 14,220.17 usft. Measured Depth. Scan Radius is 1,618.11 usR. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 850 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: ConocoPhillips ConocoPhillips Anticollision Report for Plan: 3R-106 - 3R-1O6wpO5 Tra, Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R-106 - Plan: 3R-106-3R-106wp05 Scan Range: 0.00 to 14,220.17 usft. Measured Depth. Scan Radius is 1,618.11 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Site Name Depth Distance Depth Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) Kuparuk 3R Pad 3R-10 - 3R-10 - 313-10 3R-10 - 3R-10 - 3R-10 3R-10- 3R -10A- 3R -10A 3R-10- 3R -10A- 3R -10A 3R-101 -3R-101 -3R-101 3R -101 -3R -101-3R-101 313-101 -3R-101 -3R-101 3R-101 - 3R-101 L1 - 3R-101 L1 3R -101-3R-101 L1 -3R-101 L1 3R-101 - 3R-101 111 - 3R-101 L1 3R -101-3R-101 LI PBI -3R-101 L1 PB1 3R -101-3R-101 Li PBI -3R-101 L1 PB1 3R-101 - 3R-101 Lt PBI - 3R-101 L1 PB1 3R-102 - 3R-102 - 3R-102 3R-102 - 3R-102 - 3R-102 3R-11 D - 3R-11 D - 3R-11 D 3R -11D -3R -11D -3R -11D 3R -11D -3R -11D -3R -11D 3R -12D - 3R -12A - 3R -12A 3R -12D - 3R -12A- 3R -12A 3R -12D - 3R -12A - 3R -12A 3R -12D - 3R -12D - 3R -12D 3R -12D - 3R -12D - 3R -12D 3R -12D - 3R -12D - 3R -12D 3R-14 - 3R-14 - 3R-14 3R-14 - 3R-14 - 3R-14 3R-14 - 3R-14 - 3R-14 3R-15 - 3R-15 - 3R-15 ConocoPhillips Alaska Inc-Kuparuk Kuparuk River Unit -2 Ellipse @Measured Clearance Summary Based on Separation Depth Factor Minimum Separation Warning (usft) usft 396.83 20.09 396.83 14.81 400.00 3.807 Ellipse Separation Pass - 496.62 21.55 496.62 14.96 500.00 3.270 Clearance Factor Pass - 396.83 20.09 396.83 14.81 400.00 3.807 Ellipse Separation Pass - 496.62 21.55 496.62 14.96 500.00 3.270 Clearance Factor Pass - 39.10 69.97 39.10 67.67 39.10 30.322 Centre Distance Pass - 99.90 70.06 99.90 67.57 100.00 28.232 Ellipse Separation Pass - 2,091.35 228.69 2,091.35 208.60 2,100.00 11.384 Clearance Factor Pass - 39.10 69.97 39.10 67.67 39.10 30.322 Centre Distance Pass - 99.90 70.06 99.90 67.57 100.00 28.232 Ellipse Separation Pass - 2,091.35 228.69 2,091.35 208.60 2,100.00 11.384 Clearance Factor Pass - 39.10 69.97 39.10 67.67 39.10 30.322 Centre Distance Pass - 99.90 70.06 99.90 67.57 100.00 28.232 Ellipse Separation Pass - 2,091,35 228.69 2,091.35 208.60 2,100.00 11.384 Clearance Factor Pass - 299.90 39.34 299.90 37.00 300.00 16.839 Ellipse Separation Pass - 600.20 45.83 600.20 42.09 800.00 12.251 Clearance Factor Pass - 396.90 43.96 396.90 40.93 400.00 14.503 Centre Distance Pass - 595.93 44.72 595.93 40.42 600.00 10.411 Ellipse Separation Pass - 792.83 52.07 792.83 46.51 800.00 - 9.366 Clearance Factor Pass - 496.89 67.79 496.89 61.20 500.00 10.279 Centre Distance Pass - 595.48 68.30 595.48 60.39 600.00 8.640 Ellipse Separation Pass - 791.10 76.71 791.10 66.23 800.00 7.317 Clearance Factor Pass - 496.89 67.79 496.89 61.20 500.00 10.279 Centre Distance Pass - 595.48 68.30 595.48 60.39 600.00 8.640 Ellipse Separation Pass - 791.10 76.71 791.10 66.23 800.00 2317 Clearance Factor Pass - 96.90 185.10 96.90 162.06 100.00 60.892 Centre Distance Pass - 496.89 186.33 496.89 179.50 500.00 27.308 Ellipse Separation Pass - 2,148.01 268.16 2,148.01 240.99 2,300.00 9.872 Clearance Factor Pass - 196.90 210.05 196.90 207.39 200.00 78.959 Centre Distance Pass - 01 July. 2019 - 9:33 Page 2 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 3R-106 - 3R-1O6wpO5 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R406 - Plan: 311-106 - 3R-106wp05 Scan Range: 0.00 to 14,220.17 daft. Measured Depth. Scan Radius is 1,618.11 usR. Clearance Factor cutoff is Unlimited, Max Ellipse Separation is Unlimited ConocoPhillips Alaska Inc-Kuparuk Kuparuk River Unit -2 01 July, 2019 - 9:33 Page 3 of 7 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 (usR) lush) )usR) (usR) ush 3R -15 -3R -15-3R-15 592.68 211.45 592.68 203.55 600.00 26.760 Ellipse Separation Pass - 3R -15 -3R -15-3R-15 1,142.44 276.21 1,142.44 260.94 1,200.00 18.091 Clearance Factor Pass - 3R -17- 3R-17- 3R-17 96.90 260.14 96.90 257.34 100.00 92.841 Centre Distance Pass - 3R -17 -3R -17-3R-17 591.65 262.36 591.65 254.47 600.00 33.277 Ellipse Separation Pass - 3R -17 -3R -17-3R-17 1,131.44 330.16 1,131.44 314.85 1,200.00 21.561 Clearance Factor Pass - 3R -25- 3R-25- 3R-25 96.90 235.15 96.90 232.55 100.00 90.276 Ellipse Separation Pass - 3R -25- 3R-25- 3R-25 1,135.64 310.01 1,135.64 302.91 1,200.00 43.657 Clearance Factor Pass - 3R -26- 3R-26- 3R-26 396.15 158.38 396.15 155.36 400.00 52.508 Ellipse Separation Pass - 3R -26- 3R-26- 3R-26 679.52 194.86 679.52 189,18 700.00 34.346 Clearance Factor Pass - 3R -26 - 3R-26PB1 - 3R-26PB1 396.15 158.38 396.15 155.27 400.00 50.926 Ellipse Separation Pass - 3R-26 - 3R-26PB1 - 3R-26PB1 679.52 194.86 679.52 189.09 700.00 33,788 Clearance Factor Pass - Plan: 3R-103 - 3R-1 03 - 3R-1 03wp06 99.00 131.63 99.00 129.25 100.00 55.524 Ellipse Separation Pass - Plan :3R-103-3R-103-3R-103wp06 299.00 131.63 299.00 129.30 300.00 56.630 Centre Distance Pass - Plan: 3R-103 - 3R-1 03 - 3R-1 03wp06 905.32 176.24 905.32 170.64 900.00 31.471 Clearance Factor Pass - Plan :3R-103-3R-103L1-3R-103L1wp02 99.00 131.63 99.00 129.25 100.00 55.524 Ellipse Separation Pass - Plan: 3R-103-3R-103L1-3R-103L1wp02 299.00 131.63 299.00 129.30 300.00 56.630 Centre Distance Pass - Plan: 3R-103- 3R-10311 - 3R-103Llwp02 905.32 176.24 905.32 170.64 900.00 31.471 Clearance Factor Pass - Plan: 3R-104-3R-104-3R-104wp05 99.00 147.80 99.00 145.43 100.00 62.348 Ellipse Separation Pass - Plan: 3R-104-3R-104-3R-104wp05 299.00 147.80 299.00 145.48 300.00 63.590 Centre Distance Pass - Plan: 3R-104-3R-104-3R-104wp05 998.72 218.06 998.72 211.77 1,000.00 34.661 Clearance Factor Pass - Plan :3R-104-3R-104PB1-3R-104PB1wp01 99.00 147.80 99.00 145.43 100.00 62.348 Ellipse Separation Pass - Plan: 3R-104-3R-104PB1-3R-104PB1wp01 299.00 147.80 299.00 145.48 300.00 63.590 Centre Distance Pass - Plan :3R-104-3R-104PB1-3R-104PB1wp01 998.72 218.06 998.72 211.77 1,000.00 34.661 Clearance Factor Pass- Plan: 3R -105 -Plan: 3R-1 05 - 3R-1 05wp08 100.00 20.06 100.00 17.30 100.00 7.275 Ellipse Separation Pass - Plan: 3R-105 - Plan: 3R-105-3R-105wp08 300.00 20.06 300.00 17.73 300.00 8.620 Centre Distance Pass - Plan :3R -105 -Plan: 3R-105-3R-105wp0B 14,203.14 1,396.29 14,203.14 978.00 15,617.14 3.338 Clearance Factor Pass - Plan: 3R-107 - Plan: 3R-107 - 3R-107wp04 to Update 509.81 31.23 509.81 27.86 500.00 9.283 Ellipse Separation Pass - Plan :3R -107 -Plan: 3R-107-3R-107wp04 to Update 14,154.65 1,324.08 14,154.65 1,002.61 14,000.00 4.119 Clearance Factor Pass- Plan: 3R -107 -Plan: 3R-107L1-3R-107L1wp01 509.81 31.23 509.81 27.75 500.00 8.990 Ellipse Separation Pass - Plan* 3R -107 -Plan: 3R-107Li-3R-107L1wp01 12,800.00 749.42 12,800.00 414.53 12,300.00 2.238 Clearance Factor Pass - 01 July, 2019 - 9:33 Page 3 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 311-106 - 3R-106wp05 ConocoPhillips Alaska Inc-Kuparuk Kuparuk River Unit -2 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R-106 - Plan: 3R-106 - 3R406wp05 Scan Range: 0.00 to 14,220.17 usft. Measured Depth. Scan Radius is 1,618.11 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Plan: 3R-108-3R-108-3R-108wp03 1,112.13 85.25 1,112.13 78.45 1,100.00 12.540 Clearance Factor Pass - Plan: 3R-1 09 - 3R-1 09 - 3R-1 09wp04 2,146.88 77.02 2,146.88 62.23 2,100.00 5.208 Clearance Factor Pass - Plan: 3R-1 09 - 3R-1 09L1wp02 - 3R-1091_1 wp02 2,146.88 77.02 2,146.88 62.23 2,100.00 5.208 Clearance Factor Pass - Plan: 3R-111 -Plan: 3R-111 - 3R-111wp04.1 499.79 54.35 499.79 50.85 500.00 15.543 Ellipse Separation Pass - Plan: 3R-1 11 - Plan: 3R-111-3R-ll1wp04.1 6,311.78 632.99 6,311.78 557.37 6,300.00 8.370 Clearance Factor Pass- Plan: 3R -111 -Plan: 3R-111 L1 -3R-111 Liwp02 499.79 54,35 499.79 50.85 500.00 15-543 Ellipse Separation Pass - Plan :3R -111 -Plan: 3R-111 L1 -3R-111 Liwp02 6,311.78 632.99 6,311.78 557.52 6,300.00 8.387 Clearance Factor Pass - Plan :3R -112 -3R -112-3R-112 wp04 100.00 89.78 100.00 87.41 100.00 37.851 Ellipse Separation Pass - Plan: 3R-11 2 - 3R-112 - 3R-11 2 wp04 200.00 89.78 200.00 88.02 200.00 51.135 Centre Distance Pass - Plan :3R -112 -3R -112-3R-112 wp04 4,557.25 235.72 4,557.25 202.46 5,500.00 7.086 Clearance Factor Pass- Kuparuk Oliktok Oliktok Point State 1 - Oliktok Point State 1 - Oliktok P 110.10 4.97 110.10 2.31 100.00 1.870 Clearance Factor Pass - Survey toolyrourarn From To Survey/Plan Survey Tool (usft) (usft) 39.10 1,110.00 3R-106wp05 GYD-GC-SS 1,100.00 2,100.00 3R-106wp05 MWD OWSG 1,100.00 2,407.79 3R-106wp05 MWD+IFR2+SAG+MS 2,407.79 3,907.79 3R-106wp05 MWD OWSG 2,407.79 5,825.24 3R-106wp05 MWD+IFR2+SAG+MS 5,825.24 7,325.24 3R-106wp05 MWD OWSG 5,825.24 14,220.17 3R-106wp05 MWD+IFR2+SAG+MS 01 July, 2019 - 9:33 Page 4 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 3R-106 - 3R-1O6wpO5 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 I(Distance Between Profiles- Ellipse Separation) All station coordinates were calculated using the Minimum Curvature method. ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 01 July. 2019 - 9:33 Page 5 017 COMPASS ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit -2 Kuparuk 3R Pad Plan: 3R-106 Plan: 3R-106 50029xxxxx00 3R-106wp05 ConocoPhillips Clearance Summary Anticollision Report 01 July, 2019 Trm,. Cylinder North Proximity Scan on Current Survey Data (North Reference( Reference Design: Kuparuk 3R Pad - Plan: 3R-106 - Plan: 3R-106 - 3R-106wp05 Well Coordinates: Datum Height: Plan: 9.8+39.10 @ 48.90usR (Doyon 142) Scan Range: 0.00 to 14,220.17 usft. Measured Depth. Scan Radius is 1,618.11 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85D Scan Type: • • - Scan Type: 25.00 ConocoPhillips �' ConocoPhillips Anticollision Report for Plan: 3R-106 - 3R-1O6wpO5 Tray. Cylinder North Proximity Scan on Current Survey Data )North Reference) Reference Design: Kuparuk 31t Pad - Plan: 3R-106 - Plan: 3R406 - 3R.106wp05 Scan Range: 0.00 to 14,220.17 usft. Measured Depth. Scan Radius is 1,618.11 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Site Name Depth Distance Depth Comparison Well Name - Wellbore Name - Design (usft) )usft) (usft) Kuparuk 3R Pad 3R-10 - 3R-10 - 3R-10 3R-10 - 3R-10 - 3R-10 3R-10 - 3R-10 - 3R-10 3R-10 - 3R -10A - 3R -10A 3R-10 - 3R -10A - 3R -10A 3R-10 - 3R-1 OA - 3R -10A 3R-101 -3R-101 -3R-101 3R-101 - 3R-101 - 3R-101 3R -101 -3R -101-3R-101 3R-101 - 3R-101 Lt - 3R-101 Lt 3RA 01-3R-101 Lt -3R-101 L1 3RA 01-3R-101 L1 -3R-101 L1 3R-101-3R-101LiPB1-3R-101L1PB1 3R-101 - 3R-101 Ll PB1 - 3R-101 L1 PB1 3R -101-3R-101 L1 PB1-3R-101 Ll PB1 3R-102 - 3R-102 - 3R-102 3R-102 - 3R-102 - 3R-102 3R-102 - 3R-102 - 3R-102 3R-11 D - 3R-11 D - 3R-11 D 3R-11 D - 3R-11 D - 3R-11 D 3R -11D -3R -11D -3R -11D 3R -12D - 3R -12A- 3R -12A 3R -12D - 3R -12A - 3R -12A 3R -12D - 3R -12A - 3R -12A 3R -12D - 3R -12D - 3R -12D 3R -12D - 3R -12D - 3R -12D 3R -12D - 3R -12D - 3R -12D 3R-14 - 3R-14 - 3R-14 ConocoPhillips Alaska Inc _Kuparuk Kuparuk River Unit -2 Ellipse @Measured Clearance Summary Based on Separation Depth Factor Minimum Separation Warning (usft) usft 346.88 20.01 346.88 15.39 350.00 4.329 Centre Distance Pass - 446.75 20.54 44675 14.61 450.00 3.462 Ellipse Separation Pass - 521.49 22.38 521.49 15.47 525.00 3.236 Clearance Factor Pass - 346.88 20.01 346.88 15.39 350.00 4.329 Centre Distance Pass - 446.75 20.54 446.75 14.61 450.00 3,462 Ellipse Separation Pass - 521.49 22.38 521.49 1547 525.00 3.236 Clearance Factor Pass - 49.90 69.98 49.90 67.64 50.00 29.921 Centre Distance Pass - 149.90 70.25 149.90 67.53 150.00 25.834 Ellipse Separation Pass - 2,091.35 228.69 2,091.35 208.60 2,100.00 11.384 Clearance Factor Pass - 49.90 69.96 49.90 67.64 50.00 29.921 Centre Distance Pass - 149.90 70.25 149.90 67.53 150.00 25.634 Ellipse Separation Pass - 2,091.35 228.69 2,091.35 208.60 2,100.00 11.384 Clearance Factor Pass - 49.90 69.98 49.90 67.64 50.00 29.921 Centre Distance Pass - 149.90 70.25 149.90 67.53 150.00 25.834 Ellipse Separation Pass - 2,091.35 228.69 2,091.35 208.60 2,100.00 11.384 Clearance Factor Pass - 299.90 39.34 299.90 37.00 300.00 16.839 Centre Distance Pass - 349.89 39.44 349.89 36.88 350.00 15.412 Ellipse Separation Pass - 625.24 47.32 625.24 43.45 625.00 12.219 Clearance Factor Pass - 421.90 43.94 421.90 40.75 425.00 13.778 Centre Distance Pass - 571.18 44.54 571.18 40.41 575.00 10.770 Ellipse Separation Pass - 768.40 50.24 768.40 44.84 775.00 9.296 Clearance Factor Pass - 521.58 67.70 521.58 60.78 525.00 9.780 Centre Distance Pass - 570.85 67.96 570.85 60.38 575.00 8.968 Ellipse Separation Pass - 815.29 78.74 815.29 67.94 825.00 7.293 Clearance Factor Pass - 521.58 67.70 521.58 60.78 525.00 9.780 Centre Distance Pass - 570.85 67.96 570.85 60.38 575.00 8.968 Ellipse Separation Pass - 815.29 78.74 815.29 67.94 825.00 7.293 Clearance Factor Pass - 46.90 185.04 46.90 182.57 50.00 74.777 Centre Distance Pass - 01 July, 2019 - 9:33 Page 2 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 3R-106 - 3R-106wpO5 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R-106 - Plan: 3R-106 - 3R-106wp05 Scan Range: 0.00 to 14,220.17 usft. Measured Depth. Scan Radius is 1,618.11 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips Alaska Inc-Kuparuk Kuparuk River Unit -2 01 July, 2019 - 9:33 Page 3 of 7 COMPASS Measured Minimum CMeasured Ellipse @Measuretl 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 3R -14 -3R -14-3R-14 521.04 186.52 521.04 179.37 525.00 26.086 Ellipse Separation Pass - 3R -14- 3R-14- 3R-14 2,126.53 266-07 2,126.53 239.12 2,275.00 9.871 Clearance Factor Pass - 3R -15 -3R -15-3R-15 246.90 210.04 246.90 206.72 250.00 63.336 Centre Distance Pass - 3R -15 - 3R-15 - 3R-15 544.86 210.60 544.86 203.35 550.00 29.051 Ellipse Separation Pass - 3R -15 -3R -15-3R-15 1,120.44 271.83 1,120.44 256.80 1,175.00 18.091 Clearance Factor Pass- 3R -17 -3R -17-3R-17 46.90 260.05 46.90 257.57 50.00 105.106 Centre Distance Pass - 3R -17- 3R-17- 3R-17 568.01 261.92 568.01 254.36 575.00 34.644 Ellipse Separation Pass - 3R -17 -3R -17-3R-17 1,131.44 330.16 1,131.44 314.85 1,200.00 21.561 Clearance Factor Pass - 3R -25- 3R-25- 3R-25 46.90 235.10 46.90 232.65 50.00 96.183 Centre Distance Pass - 3R -25- 3R-25- 3R-25 96.90 235.15 96.90 232.55 100.00 90.276 Ellipse Separation Pass - 3R -25- 3R-25- 3R-25 1,092.21 299.70 1,092.21 292.76 1,150.00 43.203 Clearance Factor Pass - 3R -26- 3R-26- 3R-26 346.58 158.19 346.58 155.56 350.00 60.143 Centre Distance Pass - 3R -26 - 3R-26 - 3R-26 396.15 158.38 396.15 155.36 400.00 52.508 Ellipse Separation Pass - 3R -26 -3R -26-3R-26 702.02 201.58 702.02 195.71 725.00 34.328 Clearance Factor Pass - 3R -26- 3R-26PB1- 3R-26PB1 346.58 158.19 346.58 155.47 350.00 58.073 Centre Distance Pass - 3R-26-3R-26PB1-3R-26PB1 396.15 158.38 396.15 155.27 400.00 50.926 Ellipse Separation Pass - 3R-26-3R-26PB7-3R-26PB1 679.52 194.86 579.52 189.09 700.00 33.788 Clearance Factor Pass- Plan: 3R-103-3R-103-3R-103wp06 149.00 131.63 149.00 128.97 150.00 49.579 Ellipse Separation Pass - Plan :3R-103-3R-103-3R-103wp06 299.00 131.63 299.00 129.30 300.00 56.630 Centre Distance Pass - Plan* 3R-103-3R-103-3R-103wp06 880.08 172.39 880.08 166.91 875.00 31.438 Clearance Factor Pass - Plan :3R-103-3R-103L1-3R-103L1wp02 149.00 131.63 149.00 128.97 150.00 49.579 Ellipse Separation Pass - Plan- 3R -103 -3R -10311-3R-1031-1 wp02 299.00 131.63 299.00 129.30 300.00 56.630 Centre Distance Pass - Plan: 3R-103 - 3R-1 03LI - 3R-10311 wp02 880.08 172.39 880.08 166.91 875.00 31.438 Clearance Factor Pass- Plan: 3R-104-3R-104-3R-104wp05 149.00 147.80 149.00 145.15 150.00 55.673 Ellipse Separation Pass - Plan :3R-104-3R-104-3R-104wp05 299.00 147.80 299.00 145.48 300.00 63.590 Centre Distance Pass - Plan- 3R-104-3R-104-3R-104wp05 950.10 206.71 950.10 200.73 950.00 34.544 Clearance Factor Pass - Plan: 3R-104-3R-104PB1-3R-104PB1wp01 149.00 147.80 149.00 145.15 150.00 55.673 Ellipse Separation Pass - Plan :3R-104-3R-104PB1-3R-104PB1wp01 299.00 147.80 299.00 145.48 300.00 63.590 Centre Distance Pass - Plan: 3R-104-3R-104PBi-3R-104PB1wp01 950.10 206.71 950.10 200.73 950.00 34.544 Clearance Factor Pass- Plan: 3R -105 -Plan: 3R-105-3R-105wp08 100.00 20.06 100.00 17.30 100.00 7.275 Ellipse Separation Pass - 01 July, 2019 - 9:33 Page 3 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 311-106 - 3R-106wp06 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R-106 - Plan: 3R-106 - 3R406wp05 Scan Range: 0.00 to 14,220.17 usft. Measured Depth. Scan Radius is 1,618.11 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips Alaska Inc-Kuparuk Kuparuk River Unit -2 Kuparuk Oliktok Oliktok Point State 1 - Oliktok Point State 1 - Oliktok P 60.10 4.94 60.10 2.46 50.00 1.987 Centre Distance Pass - Oliktok Point State 1 - Oliktok Point State 1 - Oliktok P 110.10 4.97 110.10 2.31 100.00 1.870 Clearance Factor Pass - 01 July, 2019 - 9:33 Page 4 of 7 COMPASS Measured Minimum @Measured Ellipse QMeasured 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 Plan: 3R -105 -Plan: 3R-105-3R-105wp08 300.00 20.06 300.00 1773 300.00 8.620 Centre Distance Pass - Plan :3R-105 -Plan : 3R-105-3R-105wp08 14,186.02 1,395.38 14,188.02 977.90 15,600.00 3.342 Clearance Factor Pass - Plan :3R -107 -Plan: 3R-107-3R-107wp04 to Update 534.58 31.22 534.58 27.72 525.00 8.920 Ellipse Separation Pass- Plan:3R-107-Plan : 3R-107-3R-107wp04 to Update 14,204.64 1,323.28 14,204.64 999.96 14,050.00 4.093 Clearance Factor Pass - Plan: 3R-107 - Plan: 3R-1071_1 - 3R-107L1wp01 534.58 31.22 534.58 27.61 525.00 8.650 Ellipse Separation Pass - Plan:3R-107-Plan: 3R-1071_1-3R-107L1wpO1 12,809.67 75248 12,809.67 415.64 12,325.00 2.234 Clearance Factor Pass - Plan 3R-108-3R-108-3R-108wp03 1,112.13 85.25 1,112.13 78.45 1,100.00 12.540 Ellipse Separation Pass - Plan :3R-108-3R-108-3R-108wp03 1,161.60 86.37 1,161.60 79.43 1,150.00 12.456 Clearance Factor Pass - Plan :3R-109-3R-109-3R-109wp04 2,097.52 76.28 2,097.52 60.73 2,050.00 4.904 Clearance Factor Pass - Plan :3R-109-3R-109L1wp02-3R-109L1wp02 2,097.52 76.28 2,097.52 60.73 2,050.00 4.905 Clearance Factor Pass - Plan: 3R-111 - Plan: 3R-111-3R-11lwp04.1 474.86 54.29 474.86 50.93 475.00 16.161 Centre Distance Pass - Plan: 3R-111 - Plan: 3R-111 - 3R-111wp04.l 499.79 54.35 499.79 50.85 500.00 15.543 Ellipse Separation Pass - Plan 3R-111 - Plan: 3R-111 - 3R-111wp04.1 6,286.23 652.00 6,286.23 573,84 6,350.00 8.342 Clearance Factor Pass - ass -Plan: Plan 3R -111 -Plan: 3R-111 L1 -3R-111 Llwp02 474.86 54.29 474.86 50.93 475.00 16.161 Centre Distance Pass - Plan :3R -111 -Plan: 3R-111 L1 -3R-111 Llwp02 499.79 54.35 499.79 50.85 500.00 15.543 Ellipse Separation Pass - Plan :3R -111 -Plan: 313-111 L1 -3R-111 L1wp02 6,286.23 652.00 6,286.23 574.01 6,350.00 8.359 Clearance Factor Pass - Plan: 3RA1 2 - 3R-1 12 - 3R-1 12 wp04 150.00 89.78 150.00 87.12 150.00 33.782 Ellipse Separation Pass - Plan :3R -112 -3R -112-3R-112 wp04 250.00 89.78 250.00 87.74 250.00 43.979 Centre Distance Pass - Plan :3R -112 -3R -112-3R-112 wp04 4,563.70 244.76 4,563,70 210.01 5,475.00 7.043 Clearance Factor Pass- Kuparuk Oliktok Oliktok Point State 1 - Oliktok Point State 1 - Oliktok P 60.10 4.94 60.10 2.46 50.00 1.987 Centre Distance Pass - Oliktok Point State 1 - Oliktok Point State 1 - Oliktok P 110.10 4.97 110.10 2.31 100.00 1.870 Clearance Factor Pass - 01 July, 2019 - 9:33 Page 4 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 3R-106 - 3R-106wp05 Survey tool program From To SumeylPlan Survey Tool (usft) (usR) 39.10 1,110.00 3R-106wp05 GYD-GC-SS 1,100.00 2,100.00 3R-106wp05 MWD OWSG 1,100.00 2,407.79 3R-106wp05 MWD+IFR2+SAG+MS 2,407.79 3,907.79 3R-106wp05 MWD OWSG 2,407.79 5,825.24 3R-106wp05 MWD+IFR2+SAG+MS 5,825.24 7,325.24 3R-106wp05 MWD OWSG 5,825.24 14,220.17 3R-106wp05 MWD+IFR2+SAG+MS 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_Kuparuk Kuparuk River Unit -2 01 July, 2019 - 9:33 Page 5 of 7 COMPASS 13:24, Jury 01 2e19 3R-106wp05 Ladder View v oN a a m ry c o p o 300 i I � c o - a� to y 150 U o c _ U °® Equivalent Magnetic Distance 1 i 0 0 2000 4000 6000 8000 10000 12000 14000 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool VD MD Name 39.10 1110.00 3R-106wp05 (Plan: 3R-106) GYD-GC-SS 1100.00 2100.00 3R-106wp05 (Plan: 313-106) MWD OWSG 2237.80 2407.79 10-3/4" x 13-1/2" 1100.00 2407.79 3R-106wp05 (Plan: 3R-106) MWD+IFR2+SAG+MS 3707.93 5825.24 7-5/8" x 9-7/8" 2407.79 3907.79 3R-106wp05 (Plan: 3R-106) MWD OWSG 3822.0214220.17 4-1/2" x 6-3/4" 2407.79 5825.24 3R-106wp05 (Plan: 3R-106) MWD+IFR2+SAG+MS 5825.24 7325.24 3R-106wp05 (Plan: 3R-106) MWD OWSG 6926.244 422o 106) MWID-IF.R24-8.4-Q-P-42N o o n J � N O 8 O r 60— 0 O .2 J) N I w 0 30- -- L) 0 U Equivalent Magnetic Distance 0 0 550 1100 1650 2200 2750 Partial Measured Depth 13:27, July 01 2019 3R-106wp05 TC View SURVEY PROGRAM SECTION DETAILS From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 39.101110.00 GYD-GC-SS 39.10 0.00 0.00 39.10 0.00 0.00 1100.002100.00 MWD OWSG 500.00 0.00 0.00 500.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 15° TF, for 200' 7100.002407.79 MWD+IFR2+SAG+MS 700.00 3.00 15.00 699.91 1.50 15.00 Start 2.5°/100' OLS, 0° TF for 1059.18' 2407.793907.79 MWD OWSG 1759.18 29.48 15.00 1707+80 2.50 0.00 Hold for 114.8T 2407.795825.24 MWD+IFR2+SAG+MS 1874.05 29.48 15.00 180T80 0.00 0.00 Start 2.5°/100' DLS, 0' TF, for 533.74' 5325.247325.24 MWD OWSG 2407.79 42.82 15.00 2237.80 2.50 0.00 Hold for 20' 5825.2M220 17 MWD+IFR2+SAG+MS 2427.79 42.82 15.00 2252.47 0.00 0.00 Start 3°/100' DLS, 0.64' TF, for 404.86' 2832.64 54.97 15.17 2518.14 3.00 0.64 Hold for 327.81' 3160.45 54.97 15.17 2706.31 0.00 0.00 Start 3.1100' DLS, 87.08° TF, for 2276.21- 5436.66 80.00 85.58 3674.69 3.00 87.08 3R-106 T01 WSD 0530MOM21.6°/100' DLS, -36.83° TF, for 126.38' 5563.05 83.65 82.84 3692.66 3.60 -36.83 Hold for 5.33' 5568.38 83.65 82.84 3693.25 0.00 0.00 Start 3.6°/100' DLS, 48.59° TF, for 256.86' 5825.24 89.80 89.76 3707.93 3.60 48.59 3R-106 T02 Heel 0530110wor 20' 5845.24 89.80 89.76 3708.00 0.00 0.00 Start 3°/10(Y DLS, 1.02° TF, for 29.69' 5874.93 90.69 89.78 3707.87 3.00 1.02 Hod for 930.55' 6805.48 90.69 89.78 3696.66 0.00 0.00 Start 3.1100' DLS, -21.98' TF, for 53.13' 6858.61 92.17 89.18 3695.33 3.00 -21.98 3R-106 T03 053019 A\Adjust TF to .45+61', for 9.69' 6868.30 92.37 88.97 3694.95 3.00 -45.61 Hold for 595.86' 7464.16 92.37 7582.19 89.89 7582.37 89.90 88.97 3670.28 91.50 3667.95 91.50 3667.95 0.00 0.00 3.00 134.39 2.00 -4.94 Start 3°/100' DLS, 134.39° TF, for 118.03! 3R-106 T04 053019 AWart 2°/100' DLS, -4.94° TF, for 0.18' Start 2°/107 DLS, -4.94° TF, for 0.18' CASING DETAILS TVD MD Name 8650.94 89.90 91.50 3669.87 0.00 0.00 Hold for 1068.ST 8670.88 89.50 91.54 3669.97 2.00 175.05 3R-706 TOS 053019 A\5tart 2.1107 DLS, 175.05° TF, for 19.94' 2237. eD707.791-3/4" x 13-1/2" 8755.12 89.78 89.45 3670.50 2.50 -82.24 Start 2.5°/100' DLS, -82.24' TF, for 64.24' 3707.E2407.24 7-5/8" x 9-1/8" 9138.00 89.78 89.45 3671.93 0.00 0.00 Hold for 382.88' 3822..15220.17 4-1/2" x 6-3/4" 9463.73 88.11 99.08 3677.93 3.00 99.93 3R-106 T06 053019 A1Start 3°/100' DLS, 99.93° TF, for 325.73 9727.07 87.06 89.91 3689.06 3.50 -96.75 Start 3.5'/100' DLS, -96.75° TF, for 263.34' 9941.66 87.06 89.91 3700.08 0.00 0.00 Hod for 214.59 10801.87 88.67 120.00 3732.87 3.50 87.56 3R-106 T08 053019 A76tart 3.5°/100' DLS, 87.56° TF, for 860.21' 10903.95 88.77 123.57 3735.14 3.50 88.48 Adjust TF to 88.48', for 102.08- 11443.01 88.77 123.57 3746.69 0.00 0.00 Hold for 539.06' 11461.87 88.27 124.00 3747.18 3.50 139.62 3R-106 T09 053019 A6tart 3.5°/100' DLS, 139.62° TF, for 18.66' 11511.77 86.53 124.10 3749.45 3.50 176.62 Adjust TF to 176.62', for 49.9 11593.91 86.53 124.10 3754.42 0.00 0.00 Hod for 82.14' 11886.66 90.83 135.00 3761.20 4.00 68.64 3R-106 T10 053019 A\6tart 4°/100' DLS, 68.64' TF, for 292.76 12433.26 95)94 116.493752.61 0.00 0.00 Hold for 83.87' 13099.81 8787 90.00 3759.64 4.00 -96.64 3R-106 T12 053019 A16tart 4°/100' DLS, -96. ° TF, for 666.54' 13211.49 8467 89.64 3765.94 2.00-170.68 Start 2"/100' DLS, -170. - TF, for 111.68' 13673.06 B 67 89.64 3800.82 0.00 0.00 Hold for 46157' 33� 73697.8 90.11 3802.73 2.00 109.58 ( R-106 T13 053019 A18tart 2°/100' DLS, 109. ' TF, for 24.83' 65 8qq88�� 80 1.00 O.Ofi v Start 1'/100' DLS, 0' TF for 367.76' 3R- g 14220.17 8 1e" .11 3822. .00 0.00 3R-106 T14 053019 AViold for 154.52 39 500 ))r 500-690 3R-103 02 rl.l 690-870. i' I• 870- 1060 1�I R-104 9 1060 - 1240 int State 1 1240- 1430 1430- 1610 1610 1800 'i - i 3 ^ 1800-2310 R-10 B1 "� ^ ^ A^ ,n 2310 2830 9162 3 410 3R- -, 1 2830 - 3340 2D�5;31037 3340 - 3850 8wp03 p 3850 - 4360 4360 - 4870 4870 5390 �\�_ 1wp02 5390 - 5900 :. 3i X79 5900 - 6940 - - 240 _ :" 31 3R--1139L1wp02 6940 7980 307 = 7980 - 9020 . +gs 9020 - 10060 3R- R-1 wp01 ate 1 3 wp04 10060 - 11100 144 11100 12140 210 16-'14-, 150 12140 13180 B19)� r 2D 13180 - 14220 13:38, July 012019 3R-106wp05 39.10 To 14220.17 Spider Oliktok Point State 1 (60 3R-10 L 3R-403iv"02 01 Ll 3R -101L 50 3R- 4 3R-104wp05 3R-102 60 ,,63R-1 30 3 3 OA o 30 3R-1,560 E 3R-112 p04 0 30 3R-105wp06 w � 0 0 0 3R-106wp05 N_ p� c O � 0 3R 3R,107L1wp01 Z 3R-107wp04 to Update 3R-104PB1 F5 03 11D 3R-10 wp�_ 30 3R26PB1 40 }w02 50 60 3R-26 Easting (2500 usfthn) AC Flipbook 1145. July 01 2019 3R-106wp05 39.00 To 2500.00 AC Flipbook SURVEY PROGRAM 3R-105wp08 39 500 pth Fror®epth To Tool 39.101110.00 GYD-GC-SS 1100.002100.00 MWD OWSG 500 690 1100.002407.79 MWD+IFR2+SAG+ 3R-101L1P61 0 2407.793907.79 MWD OWSG ," 9a^.,.... 690 870 2407 795825.24 MWD+IFR2+SAG+ 5825.247325.24 MWD OWSG 7 MWD+IFR2+SAG+ 5825.2414220.13 3R-101 L1 - - ------- 30 870 1060 3R-101 3R-108wp03 1060 1240 'ktok Point State 1 1240-14-- 240 14°'TVD CASING DETAILS 60 TVDMD Name 1430 1610 2237.80407.7ID-314" x 13-vz" 300 60 1610 1800 3707 95825.24 7-5/8" x 9-7/8" _ 3822 M20.17 4-1/2" x 6-3/4" 3R-1oz -' % 1800 2310 3 MD Azi TFace 2310 2830 39.10 0.00 0.00 500.00 0.00 0.00 3R-10A 2830 3340 700.00 15.00 15.00 1,,.- 1759.18 15.00 0.00 3R-10 3340 3850 1874.05 15.00 0.00 270 so 2407.79 15.00 0.00 3850 4360 2427.79 15.00 0.00 - / 2832.64 15.17 0.64 / 4360 4870 3160.45 15.17 MCI 5436.66 85.58 87.08 3R.-109wp04 4870 5390 5563.05 82.84 -36.83 3R-109L1wp02 59k- 5568.38 82.84 0.00 5390 5825.24 89.76 48.59 5845.24 89.76 0.00 5900 6940 5874.93 89.78 1.02 240 120 6940 7980 6805.48 89.78 0.00 . -'� 6858.61 89.18 -21.98 6868.30 88.97 -45.617980 3R-111wp04.1 9020 7464.16 88.97 0.00 9OZO 10060 7582.19 91.50 134.39 7582.37 91.50 -4.94 3R-111L1wp02 0 10060 11100 8650.94 91.50 0.00 210 150 8670.88 91.54 175.05 11100 12140 8755.12 89.45 -8224 3R-107w 9138.00 89.45 0.00 P000 Update p 180 12140 13180 9463.73 99.08 99.93 9727.07 89.91 -96.75 3R-107L1wp01 3R-11D 342-12A 3R-112 wp04 13180 14220 9941.66 89.91 0.00 3R-12D 10801.87 120.00 87.56 13:42 July 01 zms 3R-1 06wpO5 2500.00 To 14220.17 AC Flipbook SURVEY PROGRAM 39 500 pth FrorDepth To Tool 39.101110.00 GYD-GC-SS 1100.002100.00 MWD OWSG0 500 690 1100.002407.79 MWD+IFR2+SAG+ 2407.793907.79 MWD OWSG 90 690 870 2407.795825.24 MWD+IFR2+SAG+ 5825.247325.24 MWD OWSG 330 30 870 1060 5825.244220.17 MWD+IFR2+SAG+ 1060 1240 1240 _ 14'" CASING DETAIL 60 TVD MD Name 1430 1610 2237.80407.797-3/4" x 13-1/2" 300 60 1610 1 800 3707,93825.24 7-5/8" x 9-7/8" 3822.M20.17 4-1/2" x 6-3/4" 1800 2310 MD Azi TFace 30 2310 2830 39.10 0.00 0.00 500.00 0.00 0.00 2830 3340 700.00 15.00 15.00 1759.18 15.00 0.00 3340 3850 1874.05 15.00 0.00 270 90 2407.79 15.00 MID 3850 _ 4360 2427.79 15.00 0.00 2832.64 15.17 0.64 4360 4870 3160.45 15.17 0.00 5436.66 85.58 87.08 4870 5390 5563.05 82.84 -36.8330 5568.38 82.84 0.00 5390 59�. 5825.24 89.76 48.59 5845.24 89.76 0.00 5900 6940 5874.93 89.78 1.02 240 120 6940 7980 6805.48 89.78 0.00 6858.61 89.18 -21.98 60 7980 9020 6868.30 88.97 -45.61 7464.16 88.97 0.00 9020 10060 7582.19 91.50 134.39 7582.37 91.50 -4.94 _ 10060 _ 11100 8650.94 91.50 0.00 210 150 8670.88 91.54 175.05 11100 12140 8755.12 89.45 -82.24 90 9138.00 89.45 0.00 180 12140 13180 9463.73 99.08 99.93 9727.07 89.91 -96.75 13180 14220 9941.66 89.91 0.00 10801.87 120.00 87.56 ConocoPhillips Alaska Inc _Kuparuk Kuparuk River Unit -2 Kuparuk 3R Pad Plan: 3R-106 50029xxxxx00 Plan: 3R-106 Plan: 3R-106wp05 Error Ellipse Survey Report 01 July, 2019 Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kupamk River Unit _2 Site: Kuparuk 3R Pad Well: Plan: 3R-106 Wellbore: Plan: 3R-106 Design: 3R-106wp05 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3R-106 Plan: 9.8+39.10 ® 48.90usft (Doyon 142) Plan: 9.8+39.10 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMP1 Project Kuparuk River Unit_2, North Slope Alaska, United States 3R-106wp05 (Plan'. Map System: 1,100.00 System Datum: Mean Sea Level Geo Datum: Alaska Zone 4 2,407.79 Using Well Reference Point Map Zone: 2,407.79 3,907.79 Using geodetic scale factor 3R-106) 2,407.79 5,825.24 3R-106wp05 (Plan: Site Kupawk 3R Pad 7,325.24 31R-106wp05 (Plan: Site Position: 5,825.24 Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.16 ° Well Plan: 3R-106 - Well Position +Nl-S Northing: Latitude: +El -W Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 9.80 usft Wallbole Plan: 3R-106 Magnetics Model Name Sample Date Declination Dip Angle Field Strength rj rl Inn BGGM201B 8/15/2019 16.48 80.95 57,415 Design 3R-106wpD5 Audit Nates: Version: Phase: PLAN Tie On Depth: 39.10 Vertical Section: Depth From (TVD) -NI-S +El -W Direction (usft) (usft) (usft) r) 39.10 0.00 0.00 9000 Survey Tool Program Data 7/1/2019 From To (usft) (usft) Survey(Weliborel 39.10 1,110.00 3R-106wp05 (Plan'. 3R-106) 1,100.00 2,100.00 3R-106wp05(Plan: 3R-106) 1,100.00 2,407.79 3R-106wp05(Plan: 3R-106) 2,407.79 3,907.79 3R-106wp05(Plan: 3R-106) 2,407.79 5,825.24 3R-106wp05 (Plan: 3R-106) 5,825.24 7,325.24 31R-106wp05 (Plan: 3R-106) 5,825.24 14,220.17 3R-106wp05 (Plan: 3R-106) Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD+IFR2+Sag +Multi -Station Correction MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD +IFR2+Sag +Multi -Station Correction MWD OWSG OVVSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD +IFR2+Sag +Multi -Station Correction 7112019 10:28:02AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well Plan: 3R-106 Project: Kupawk River Unit -2 TVD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: Plan: 9.6+39.10 Q 48.90usft (Doyon 142) Well: Plan: 3R-106 North Reference: True Wellbore: Plan: 3R-106 Survey Calculation Method: Minimum Curvature Design: 3R-106wpO5 Output errors are at 2.00 sigma Database: OAKEDMP7 Plan Survey Tool program Date 7/1/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.10 1,110.00 3R-106wpO5 (Plan: 3R-106) GYD-GC-SS Gymdata gyro single shots 2 1,100.00 2,100.003R-1 G6wp05(Plan: 3R-106) MWD OWSG OWSG MWD -Standard 3 1,100.00 2,407.79 3R-1 06wpO5 (Plan: 3R-106) MWD+IFR2+SAG+MS OWSG MWD+ IFR2+Sag + 4 2,407.79 3,907.79 3R-106wp05 (Plan: 3R-106) MWD OWSG OWSG MWD - Standard 5 2,407.79 5,825.24 3R-106wpO5 (Plan: 3R-106) MWD+IFR2+SAG+MS OWSG MWD+IFR2+Sag + 6 5,825.24 7,325.24 3R-106wp05 (Plan: 3R-106) MWD OWSG OWSG MWD - Standard 7 5,825.24 14,220.17 3R-106wp05 (Plan: 3R-106) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Position uncertainty and bias at survey station Measumd Inclination Aumuq var6wl Mi9hsrda "..I vemoi Ma9mmm semi -mayor Senv- ,n.r Depq Depq Error Bias Error Bias Error Bus .,Bias Error Error aamuq Ta01 I (usnl C) O) luslg luso) lase) lural (.s1) (usft) (usft) (uso) (usft) lu:m fl 39.10 000 0.00 39.10 0.00 0.00 0.00 0.00 am 0.00 000 0.00 DOD 0.0D UNDEFINED WOOD 0.00 000 100.00 0.09 000 0.09 0.00 230 O.OD 000 0.09 0.09 0.00 GY -DGss(1, 1) 200➢0 OW 000 200.00 038 000 038 000 230 000 000 0.38 038 0.00 GYDGGSS(1. 1) 300.00 0.00 000 300.00 067 000 067 000 2.30 001 0.01 067 067 0.00 GYDGGs6(1. 1) 40000 0.00 0.00 400.00 090 0.00 0.96 0.00 230 0.02 0.02 0.96 096 0.00 GYDGC-SS(1, 1) 50000 000 0.00 50.00 1.25 0.00 1.25 0.00 231 0.03 003 125 125 000 GYo-GCSS(1, 1) 600.00 1.50 15.00 599.99 1.53 000 1.53 OW 2.31 0.04 004 I'M 1.53 135.00 GYo-GGSS{1. 1) 700.00 3.00 15.00 699.91 1.82 000 1.02 0.00 2.32 0.06 0.06 1.82 1.82 10534 GYD-GC-as(1, 1) 800.00 5.50 15.00 799.63 2.11 -001 2.11 0.00 232 008 0.00 2.12 2.11 105.65 GYDGC-SS(1. 1) 900.00 8,00 15.00 000.92 239 -0.01 2.41 0.00 2.32 0.10 0.10 342 241 10746 GYD-GCSS(1, 1) 1,000.00 10.50 15.00 997.62 267 -001 273 000 2.31 0.12 0.12 213 212 13.65 GYD.GC-SS(1. 1) 1.10000 13.00 15.00 1,09551 2.96 -002 3.00 0.00 2.31 0.15 0.15 3.07 3.03 1444 GYDGC-SS(1, 1) 1.200.00 15.50 15.00 1.19243 205 -002 3.12 0.00 2.57 0.00 0.02 3.12 2.97 1486 MWD OWED (2.2) 1,300.00 18,00 15.00 1,200.18 2.94 -002 3.55 0.00 2.62 000 002 355 3.10 14.93 MWD OWED (2,2) 1.400.00 2050 15.00 1.382.50 3.08 -002 4.20 000 2.67 000 002 4.20 3.27 1495 MWD OWED (2.2) 11500.00 2300 15.00 1,475.45 3.28 -DM 506 000 2.73 000 002 505 349 14.96 MWD OWSG(2, 2) 1,000.00 2550 15.00 1,560.62 3.52 -002 6.09 000 2.01 000 002 809 175 14.97 MWD OWSG (2, 2) 1)00.00 2800 15.00 1.05.91 3.01 -DM 7.27 000 2.91 O5D 002 727 4.04 14.7 MWD OWSG (2,2) 1124.75 28.62 15.00 1.67770 4.00 -0.01 8.03 0.00 2.98 000 002 8.03 423 14.97 MWD OWSG (2.2) 1,759.18 2948 15.DO 1.707.00 4.00 -0.01 803 000 2.90 0.00 002 8.03 4.23 14.97 MWD OWSG (2.2) 1,78771 2948 Ism 1,73264 4.16 -O.D1 858 000 3.03 0.00 002 0.58 430 14.97 MWD OWSG(2. 2) 1.800.00 2948 15.00 1.743.34 4.16 -0.01 858 0.00 3.03 0.00 002 0.58 4.36 14.97 MWD OWED (2.2) 1,87405 2948 15.00 1,807.60 4.45 -0 In 958 0.00 3.16 0.00 002 9.58 4.59 14.97 MWD Ow8G (2.2) 7112019 10:28,02AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc_Kuparuk local Co-ordinate Reference: Well Plan: 3R-106 Project: Kupawk River Unit_2 TVD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Weft: Plan: 3R-106 North Reference: True Wellborn: Plan: 3R-106 Survey Calculation Method: Minimum Curvature Design: 3R-106wpO5 Output errors are at 2.00 sigma Database: OAKEDMPI Position uncertainty and bias at survey station Measured Indinalbn RzImIM Verucal Hghal4e lahnl Vei ical Magniwae semimajo/ semlminor Depth Oepth Ener BMs Error Bias Error Blas at Blas En., EB01 AzfmuM Tool (usN) 1°1 PI (use) (usft) fuse) (usn) (usel to%n) (usft) (usn) lose) Win M 1,900.00 30.13 15.00 1,K0 32 454 -0.01 9.93 0W 3.29 000 092 9.93 4.68 1497 MWD OWSG(2, 2) 2,000.00 3263 1500 1,91569 4.93 -0.01 1139 Duo 337 0.00 0.02 1139 5.03 1497 MWD 0WSG(2. 2) 2.067.84 34.32 1500 1,9]2.2] 533 -001 12.98 000 3.56 000 002 12.96 5.40 14.98 MWD OWSG(2, 2) 2,100.00 35.13 150D 1,99810 5.33 -0.01 12.96 0.00 3.56 000 0.02 1296 5.40 1498 MWD OWSG(2. 2) 2,20000 37,63 15.00 2,079.21 489 -001 7,36 0.00 3.51 0.00 002 7.36 5.08 1485 MWD+1FR2+5AG+MS(3, 2) 2.30000 40.13 150D 2,157.05 5.18 -0.01 809 000 3.68 0.00 0.02 8.09 5.35 1486 MWD+1FR2+SAG+MS(3, 2) 2,40000 4263 1500 2,232.08 50 -001 0.88 000 3.87 000 002 888 562 14N MWD+1FR2+8AG+MS(3, 2) 2,407.79 42.82 1500 2.23]80 5.50 -0.01 am D.W 389 000 0.02 8.94 5.64 1487 MWD OWSG(3, 3) 2,42779 42.82 1500 2,252.47 553 -001 9.09 000 3.64 000 002 909 5.95 1486 MWD OWSG(3, 3) 2150000 44.99 1503 2.304.49 548 -001 9.79 000 3.68 0.00 002 979 5.99 1489 MWD 0WSG(3. 3) 2.60000 4799 15.00 2,373.33 5.46 -001 1107 000 3.77 0.00 0.02 11.07 608 1493 MWD OWSG(3, 3) 2,700.00 50.99 15.12 2.43829 5.51 -0.01 12.68 0.00 3.92 000 002 12.66 6.20 1497 MWD OWSG(3, 3) 2,800.00 53.99 15.15 2,499.17 5.64 -001 1451 0,011 4.13 000 002 1451 6.35 1500 MWD OWSG(3, 3) 2,83284 54.97 15.17 2,518.14 570 AM 15.16 0.00 4.21 000 002 15.18 061 15.01 MWD 0W5G(3. 3) 2,900.00 54.97 15.17 2.55880 5.92 -001 16.54 000 462 000 002 16.54 6.51 1503 MWD 0VNGG(3, 3) 3,000.00 54.97 15.17 2.81421 830 -0.01 18.67 am 478 0.00 0.02 1867 6.67 1505 MWD 0NSG(3, 3) 3,100.00 54,97 15.17 2,671.61 6.72 -001 2088 0.00 5.17 0.00 0.02 2086. BBB 1507 MND OWSG(3, 3) 3,16045 54.97 15.17 2.70631 7.00 4)Ot 22.21 000 542 000 0.02 22.21 890 15.07 MWD Owso(3. 3) 3,200.00 55.04 16,81 2,72899 ].19 -001 23.08 000 5.59 0.00 0.02 23.09 7.06 1510 MWD OWSG(3, 3) 3,300.00 55.29 20.25 2,786.13 7.78 -001 25.27 0.00 604 000 002 25.35 728 15.41 MWD OWSG(3, 3) 3,40000 5565 23.07 2,842.83 8.43 41.01 27.40 0.00 6.50 0.00 0.02 2784 7.52 1599 MWD OWSG(3. 3) 3,455.27 55.69 25.85 2,87393 9.19 -001 29.47 000 ass 000 0.02 29.95 777 16.78 MWD OMG(3, 3) 3,500.00 58.11 27.45 2.89894 9.19 -0Ot 29.0 000 8.99 0.00 0.02 29.95 777 16.78 MND OWSG(3, 3) 3,600.00 56.67 30.99 2.95431 1003 AM 31.47 am 7.48 000 0.02 3227 803 17.74 MWD OWSG(3, 3) 3,700.00 5234 3448 3,00837 10.93 4)01 33.0 001 8.00 000 0.02 34.62 6.31 1885 MV03 OWSG(3, 3) 3,800.00 Win 37.91 3.062.19 11.86 4,01 35.33 0.01 8.52 000 002 37.00 861 20.08 MWD OWSG(3. 3) 3,900.00 58.95 41.28 3,114.41 12.80 4,01 37.21 001 9.07 000 002 3943 8.95 21.43 MWD OW5G(3, 3) 3,958.71 59.49 43.23 3,14446 9.00 -001 19.45 001 6.93 000 002 20.54 7.87 21.76 MWD+1FR2+SAG+MS(4. 3) 4.000.00 59.89 44.59 3.18530 9.00 401 19.45 001 8.93 000 0.02 20.84 7.87 21.76 ~+lFR2+SAG+MS(4, 3) 4,10000 now 47.04 3,21471 9.42 -001 20.16 001 7.26 0.00 0.02 21.06 8.09 2326 MWD+1FR2+SAG+MS(4, 3) 4,200.00 62.00 51.02 3,28251 9.83 401 20.90 001 7.59 0.00 002 22.92 8.33 2487 MWD+1FR2+SAG+MS(4, 3) 420034 8300 51.03 3.262.6] 983 -0.01 20.90 0.01 759 0.00 0.02 22.92 8.33 2487 MWD+IFR2+SAG+MS(4, 3) 4.300.00 63.16 54.13 3308.57 10.23 4Ot 21.66 0.01 7.92 000 0.02 24.02 8.59 2658 MwD+1FR2+SAG+MS(4,3) 4.40000 8460 57.18 3,352.76 10.61 -0.01 MAS 001 8.27 0.00 0.02 25.16 8.88 28A0 MWD+1FR2+SAG+MS(4,3) 4,500.00 0.69 60.17 3,394.95 low -0.01 23.30 0.01 8.62 000 002 28.34 9.19 30.30 MWD+1FR2+SAG+MS(4. 3) 4,520.11 68.07 60.99 3.406.44 11.29 -0.01 24.18 0.01 6.97 0.00 002 27.57 9.53 3229 MWD+1FR2+SAG+MS(4. 3) 4,60000 67.04 83.09 3,435.05 11.29 -001 2418 001 8.97 0.00 0.02 27.57 9.53 3229 MWD+IFR2+SAG+MS(4, 3) 4,700.00 68.45 65.95 3,472.92 11.59 -0.01 25.11 0.01 sm 0.00 002 2885 9.91 3434 MWD+1FR2+SAG+MS(4, 3) 4.800.00 6993 68M 3,50848 Was 4,.01 2609 001 970 000 002 30.17 10.30 36.45 MWD+1FR2+8AG+MS(4, 3) 4,900.00 71.40 71.52 3.541.62 12.12 0.00 27.12 0.01 1006 0.00 002 3155 10.72 3861 MWD+1FR2+SAG+MS(4, 3) 5,00000 7293 74.23 3.572.25 1234 0,00 2820 0.01 10.46 0.00 0.02 32.97 11.17 4080 1AWD+1FR2+SAG+MS(4, 3) 5,100.00 74.50 78.89 3,600.29 12,55 000 29.32 0.01 10.84 000 0.02 34.44 1163 43.02 1AWD+1FR2+SAG+MS(4, 3) 5.200.00 76.11 79.51 3,625.60 1274 0.00 3069 0,01 1123 000 0.02 35.96 12.10 4524 MWD+1F1W+SAG+MS(4, 3) 5,300.00 A.73 82.10 3.648.30 1291 0.00 31.70 0.01 1162 000 002 37.53 12.59 4246 MWD+1FR2+SAG+MS(4. 3) 5,40000 79.38 8465 3,668.13 13.00 0.00 3293 0.02 12.02 000 0.02 39.13 13.09 4968 MWD+1FR2+SAG+MS(4, 3) 5,434.37 79.96 85.52 3674.29 13.14 0.00 3339 0.02 12.16 000 0.02 3913 13.27 60.48 MWD+1FR2+SAG+MS(4. 3) 5.436.66 8000 85.% 3,674.69 13.14 0.00 3339 0.02 12.16 0.00 0.02 39.73 13.27 WAS ~+1F1U+SAG+MS(4, 3) 5,500.00 81.83 84.20 3684.69 13.13 0.00 3521 0.02 12.41 000 002 4079 13.58 5183 MWD+1FR2+SAG+MS(4, 3) 5.54498 83.13 83.23 3,690.50 13.16 0.00 37.01 0.01 12.67 am 0.02 4190 13.85 5308 1ffiWD+1FR2+SAG+MS(4, 3) 5,583.05 83.65 82.M 3,69266 13.16 0.00 37.01 0.01 1267 am 002 41.90 13.88 5306. 1AWD+IFR2+SAG+MS(4. 3) 5,58838 8365 82.64 3,693.25 13.18 0.00 37.12 0.01 12.69 000 0.02 4199 13.89 53.18 MWD+IFR2+SAG+MS(4, 3) 5,600.00 84.41 83.70 31895.54 13.23 0.03 3753 0.01 12.81 000 002 4258 14.01 53.75 M-IFR2+SAG+MS(4. 3) 5,70000 88.80 86.40 3,704.21 13.41 0.00 38.82 0.02 13.22 0.00 002 4436 14.42 5581 MWD+IFR2+SAG+MS(4, 3) 5.800.00 89.18 new 3,707.71 13.65 0.00 40.08 0.02 1362 000 0.02 46.18 14.84 57.44 MWD+1F1U+SAG+MS(4. 3) 7112019 10:28:02AM Page 4 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit _2 Site: Kuparuk 3R Pad Well: Plan: 3R-108 Wellbore: Plan: 3R-106 Design: 3R-106wpO5 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: Well Plan: 3R-106 TVD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) MD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Database: OAKEDMPI Position uncertainty and bias at survey station Measured Inclination AZ,..M Verr¢al Hig6sid, Lateral Vertical Ma9niWJe Semlmajor Bemiminor Depth Depth Ertor Bias Error Bias Ertor Bos of Bias Ertor Error Anmusi Tool (ush) 1°I PI (Ban) (usf) (usB) lush) (us") luta) lush) (usp (uss9 lush) 1°) 5,825.24 89.80 8976 3,]0].93 13.73 000 40.39 0.02 13,72 000 0.02 4664 14.94 5790 MWD OWSG 14, 4) 5,645.24 89.80 89.m 3]08.00 13.77 090 40.71 0.02 1175 000 002 47.29 15.36 5722 MWD 0WSG(4, 4) 5,874.93 9069 89.78 3,]07.8] 13.71 ow 41.02 0.02 1176 0.00 002 47.59 1530 57,42 MWD OWW(4,4) 5,90000 9069 Ban 3.]07.5] 13.72 000 41.34 002 13.76 000 0.02 41.01 15.28 5]63 MWD 0WSG(4, 4) 8,00000 9069 89.78 3.706,37 13.77 000 43.03 002 1381 0.00 0.02 49.20 1552 58.88 MWD OWW (4, 4) 8.100.00 Wes 8938 3.705.16 13.07 0,00 4532 002 13.91 000 0.02 51.11 16.16 60.61 MWD OWSG (4,4) 6,20D.00 Bass 8938 3.703.95 1401 000 48.12 002 1405 0.00 002 5336 1703 62.66 MWD OWSG(4, 4) 6.300.00 Was 8918 3.70235 14.19 000 5136 002 1423 000 0.02 53.00 18.01 64.88 MWD OWSG(4. 4) 6,40D.00 W69 89.78 3]01.54 1441 0.00 5495 0.02 1445 000 002 59.02 1900 67.11 MWD OWBG(4.4) 6.50000 W69 89.78 3,7(N34 14fi7 0.00 58.84 0.02 14.71 0.00 0.02 6238 19.93 69126 MWD 0MG(4, 4) 6,600.00 goes 89.78 3,699.13 1497 000 62.96 0.02 1501 0.W 002 65.03 20]8 7125 MWD OViW(4.4) 6,70000 9069 8918 3,69793 15.30 0(10 67.27 002 15.4 0.00 002 69.95 21,53 7106 MWD OWSG(4.4) 8890.00 9069 89.78 359332 15M 000 7135 0.02 15.70 0.00 002 74.08 22.20 7467 MWD OWSG(4,4) 6,805.40 9069 8970 3.696.66 I&M 000 72.00 002 15.72 000 002 74.31 22.23 7415 MWD OWSG (4,4) 6,858.61 92.17 89.18 3.69533 1583 0.00 7460 0.02 15.93 0.00 0.02 16.50 2254 75.51 MWD GWSG (4,4) 8.8138.30 9237 88.97 3.69495 15.05 0.00 75.10 002 1596 000 002 77.00 2259 75.64 MM OWSG(4,4) 6,900.011 9237 00.97 3,09363 15913 0.00 ]8.56 0.02 lee 000 002 78.38 2218 76.05 MWD OWSG(4.4) 7.000.00 92.37 Bow 3.689.50 1641 000 81.25 002 16.51 000 002 8284 23.24 77.25 MWD OWSG(4, 4) 7,100.00 92.37 88.97 3.685.36 1606 000 8602 002 16.98 000 0.02 8]43 2167 7029 MWD OWSG(4, 4) 7.20000 92.37 88.97 3,681.22 1733 000 90.87 002 17.43 000 0.02 92.12 24.90 7921 MWD OWSG(4, 4) 7,300.00 92.37 8897 3,6]].08 17,83 0.00 9579 D.02 17,92 O.W D02 96.90 24.37 80.01 MWD OWSG(4. 4) 7,400.00 9287 Ws7 3,672.94 15.37 000 59.25 002 15.40 DW 0.02 6225 21.24 6892 M 11FR2+SAG+MS(5, 4) 7.464A6 92.37 88.97 167028 15.51 000 60.40 0.02 15.62 O00 0.02 63.27 21.50 70.52 MWD+IFR2+SAG+MS(5, 4) 7,50000 9162 8974 3.66904 1562 000 60.81 002 1569 000 0.02 63.85 21.65 70.64 MWO+1FR2+SAG+M6(5, 4) 7,582.19 8989 91.50 3.857 95 15.88 000 61.76 0.02 15.88 0.00 0.02 6520 21.99 7161 MWD+1FR2+SAG+MS(5.4) ].58238 89.90 91.50 3.667,95 15.88 0,00 61.76 0.02 1588 0.00 O.D2 6520 21.99 ]161 MWD+1FR2+6AG+MS(5, 4) 7,690.90 8990 91.50 3.657 90 15.92 a30 62.10 0.02 15.92 0.00 0.02 6549 2207 71.78 MWD+1FR2+SAG+MS(5,4) 7,700.00 89.90 91.50 3.668.16 1616 0.00 64.02 D02 1615 000 002 67.19 22.49 7269 MWD+1FR2+SAG+MS(5,4) 7,000.00 89W 91.90 3.868.34 16AD 000 6597 002 1839 0.00 0.02 68.94 2288 73.57 MW0+1FR2+SAG+MS(5.4) 7,9W.DO 89.90 9150 3.668.52 1885 000 67.96 002 1865 000 002 7074 2325 74.40 MWD+1FR2+SAG+M5(5.4) 8,000.00 89.80 9150 3.138810 16.91 am 6998 0.02 1691 0.00 002 72.58 2361 75.18 MWD+1FR2+6AG+MS (5.4) 8,100.00 0990 9150 3,668.88 11.18 000 72.02 002 17.17 000 0.02 74.47 23.94 7593 1AWD+1FR2+SAG+MS(S. 4) 8,200.00 8990 9150 3,85906 17,45 000 74.09 0.02 17.45 0.00 002 76.39 24.25 7663 MViV+W 2+SAG+1AS (5, 4) BW0.00 8990 9150 3,669.24 1774 000 78.19 0.02 1733 0.00 002 78.35 24.55 77,29 MWD+1F1U+SAG+MS (5, 4) 840000 89.90 91.50 3,669.42 18.03 000 78.31 0.02 10.02 000 0.02 80.34 24.83 ]]92 MWD+IFR2+SPG+MS(5, 4) 8.500.00 8990 91.50 3,669.59 1832 0.00 0044 002 18.32 000 002 82.36 25.09 7850 MWD+IFR2+SAG+MS(5, 4) 8,fiW.W 8990 91.50 3,689]] 1863 0.0 6280 0.02 1862 0.00 002 84.40 2535 79.06 MWD+1FR2+SAG+MS(5, 4) 8.650.94 8990 91.50 3,66907 18.78 0,w 83.10 002 18.78 000 0.02 6545 25A7 7932 MWD+1FR2+SAG+MS(5.4) 8,670.88 89.90 91.54 3.66997 18.05 000 84.13 002 1884 000 0.02 8587 25.52 79.43 MWD+1FR2+SAG+MS(6, 4) 8,70000 8990 90.81 3.67020 18.95 000 8496 002 18.93 000 0.02 W47 25.58 79.57 MWD+1FR2+SAG+MS(5, 4) 8,755.12 0978 89,45 3,670.50 19.12 000 8fi50 0.02 19.11 000 002 87.63 25.70 7983 M 1FR2+SAG+MS(5.4) 8,800,00 89.78 89A5 3.870.88 1926. 000 87.47 0.02 19.25 0,00 002 8851 25.79 8002 MWD+IFR2+SAG+MS(5, 4) 8,900.00 8978 8945 3,8]104 1958 am 89,85 D.02 1957 000 002 9068 25.87 8042 MWDHFR2+SAG+1JS (5, 4) 900000 89.78 89.45 3,671.42 19.90 000 91.85 0.02 19.89 0.00 002 9282 26.15 8080 MWD+1FR2+6AG+MS(5, 4) 9,10000 6978 8945 3,671.79 2023 000 9405 D.02 20.23 000 002 9497 2892 81.16 MWD+1F1U+SAG+1AS(5,4) 9.13&00 8978 89.45 3,871.0 20.38 0.00 94.90 0.02 20.35 0.00 002 95.79 26.36 8129 MWD+1FR2+SAG+MS(5, 4) 9.2W.00 8946 9128 3,672.34 2058 ow 95.63 0.02 20.56 0.00 002 97.14 28,48 81.51 MWD+1FR2+SAG+MS(5.4) 9,30000 Bass 94.24 3,673.73 20.94 0.00 97.20 0.02 20.90 000 0.02 99,32 26.68 8191 MWD+1FR2+SAG+MS(5, 4) 9.400.00 Bass 97.19 3.676.01 21.30 0W 90.36 0.02 21.25 Uri 0.02 101.51 2891 82.35 MWD+IFR2+SAG+MS(5.4) 9,463.73 30.11 9990 3,67793 21.54 0.00 WOO OO2 21.47 0.00 0.02 102.90 2107 82M MWD+IFR2+SAG+MS(5, 4) 9.500.00 81.96 9782 3.6]8.1] 21.67 000 100.42 002 21.59 000 0.02 103.70 27.16 8283 MW0+1FR2+SAG+MS(5.4) 9+600,00 BZW 9434 3,66108 22.05 0.00 10407 0.02 21.95 0.0 002 105.91 27.38 8024 MWD+IFR2+SAG+M9(5, 4) 9,700.00 8].16 W.M 3.68789 22A3 BW 107.33 002 22.30 O.W 0.02 108.15 27.55 8355 1AWD+IFR2+SAG+MS(5.4) 9,]210] 8106 89.91 3,M9M 22.53 O.W 106.14 0.02 22.0 0.00 002 108.]6 27.59 8162 MWD+IFR2+8AG+MS(5,4) 7/1/2019 10:28:02AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well Plan: 3R-106 Project Kupamk River Unit_2 ND Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Site: Kupamk 3R Pad MO Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Well: Plan: 3R-108 North Reference: True Wellbore: Plan: 3R-108 Survey Calculation Method: Minimum Curvature Design: 3R-106wp05 Output errors are at 2.00 sigma Oapm Database: OAKEDMP1 Position uncertainty and bias at survey station Measured Ix11na8on Aalmum Vamal Riyhside Lateral Vedical Maanimae Samianajer Semi+ninor Oapm wpm E., Bias Error Bias Error as. dt Blas Error Error Asimum Tool (use) r) r) (usn) (usft) (usft) (uaft) (usm (.aft) (usm (usm (usm (usft) r) 980000 87 09.91 3692.80 2279 000 109.80 0.02 2286 000 002 110.39 27.68 8379 MWO+IFR2+SAG+MS(5. 4) 9,90000 87.06 8991 3.697.94 23.15 0.00 11209 002 2302 0.00 002 11265 27.81 84.01 MWD+IFR2+SAG+MS(5,4) 9.941.66 87% 8991 3,70000 23.30 000 113.04 0.02 23.17 0.00 002 113.59 27.86 84.10 MWD+IFR2+SAG+MS(5, 4) 10,000.00 87.14 91.% 37%03 23.51 0.00 11393 002 23.39 0.00 0.02 114.91 27.93 8423 MWD+IFR2+SAG+MS(5,4) 10,100.00 87.31 9546 3,]0].87 Des 000 115.18 0.02 23.76 0.00 0.02 117.19 20.09 84.51 MWD+IFR2+SAG+MS(5,4) 10,200.00 8708 9896 3.71243 2422 0.00 116.06 002 24.13 0.00 0.02 119.46 20.28 8484 MWUtlFR2+SAG+MS(5, 4) 10.300.00 87,66 10245 3,71667 24.58 000 118.57 002 24.50 0.00 0.02 121.]2 20.50 8523 MWDNFR2+SAG+MS(5,4) 10,40000 87.84 105.95 3,72060 24.94 000 116.70 002 2688 0.00 0.02 123.96 20.75 8587 MWDHFR2+SAG+MS(5, 4) 10,500.00 as." 10945 3,M AI) 25.31 OOD 11843 002 25.26 OOD 0.02 128.15 29.03 86.16 MWD+IFR2+SAG+MS(5,4) 10.60000 M24 112.94 3.]2744 2568 000 115]] 0.02 25.64 0.00 0.02 120.28 29.33 86.68 MWD+IFR2+SAG+MS(5,4) 10,700.00 88.45 11844 3,]30.32 26,06 000 11470 002 28.03 0.00 0.02 130.35 2964 0724 MWD+IFR2+SAG+MS(5.4) 10,80000 88.67 119.93 3.732.03 2643 0.00 11324 0.02 26.41 000 0.02 13205 29.97 87,83 MW0HFR2+SAG+MS(5, 4) 1D,80197 88.67 12000 3,]32.8] 26.43 0.% 113.21 002 26.42 O.OD 0.02 132.39 2998 8784 MWD+1FR2+SAG+MS(5.4) 10.90000 Be T7 123.43 3,73506 28.81 000 11130 0.02 26.80 0.00 002 134.28 3082 8845 10 D1FR2+SAG+105(5,4) 1D,90395 88.77 12357 3]35.14 26.03 0.00 111.28 002 26.82 000 002 134.33 30.33 8847 MM+IFR2+SAG+MS(5, 4) 11,00000 88.77 12357 3.73720 27,20 0.00 11352 002 2719 OM 0.02 135.13 30.67 89,07 MWD+1FR2+SAG+MS(5, 4) 11,10000 88.77 12357 3,739.34 27.59 O.% 115,85 002 2]58 0.00 002 130.01 3101 8987 MWD+IFR2+SAG+MS(5. 4) 11.20000 88.77 123.57 3,74149 27.99 0.00 118.19 0.02 27.98 000 002 139.92 3185 9026 MM+1FR2+SAG+MS(5.4) 11,30000 88.77 12357 3.74363 28.30 0.00 120.54 002 23.38 OW 0.02 141.01 31.68 9084 MWD+IFR2+SAG+MS(5, 4) 1140000 88.77 123.57 3,745.77 2878 0.% 122.89 002 2877 000 002 143.78 32.00 91.40 MWWIFR2+SAG+MS(5.4) 11,44301 88.77 123.57 3,74869 28.95 0.% 12390 002 28.95 0.00 002 14462 32.14 9163 MM+IFR2+SAG+M8(5,4) 1146187 88.27 12400 3,747.18 29.05 0.% 123.80 0.02 29.02 O% 0.02 144.98 32.20 91 ]4 MW IFR2+SAG+MS(5.4) 11.50000 86.96 12100 3.]487] 29.38 000 124.59 002 2917 000 002 14522 32.32 9L94 MM+IFR2+SAG+MS(5, 4) 11.511.]] 8653 124.10 3.74945 29.47 0.00 124.84 0.02 29.22 0.0 002 14595 32.36 9201 MWD+IFR2+SAG+MS(5.4) 11,593.91 86.53 124.10 3.75442 29.00 0.00 126.76 0.02 29.55 000 002 147.55 32.62 9245 MM+IFR2+SAG+MS(6, 4) 11.60000 8861 124.33 3,751.79 29.01 0.00 12881 002 29.57 0.00 002 14]6] 32.64 9240 MWD+IFR2+SAG+MS(5.4) 11.70000 00.08 120.% 3.75942 30.03 000 123.92 0.01 29.98 000 11.02 149.57 32.95 9302 MWWIFR2+SAG+IAS(6, 4) 11,80000 8955 131 78 3,761.49 30.37 0.% 12012 0.01 30.38 0.% 002 151.36 3328 93.58 MWD+IFR2+SAG+MS(5.4) 11.88588 Wes 135% 3.78120 30.01 0.% 117.55 0.01 3073 0.00 002 152.81 33.56 9408 MWWIFR2+SAG+MS(5,4) 11,90000 90.83 13447 3,761.01 30.07 0.% 118.71 001 30.79 0.0 002 153.03 33.61 94.16 MWD+IFR2+SAG+MS(5,4) 12,00000 90.86 13047 3.759.52 3126 0.% 127.16 0.01 31.19 0% 002 154.76 33.94 9472 MW IFR2+SAG+MS(5,4) 12.10000 90.89 12847 3,757.99 31.66 O.% 13511 0.01 3100 0.% 002 15864 3425 9523 MWD+IFR2+SAG+MS(5.4) 12,20000 90.92 12247 3.75641 32.% 0.% 14252 0.02 3201 0% 002 159.67 34.53 9569 MW0+IFR2+SAG+MS(5, 4) 12.300.00 90.93 11846 3,754.00 32.48 0.% 14932 0.02 3242 0.% 0.02 16083 3410 90.10 MWD+IFR2+SAG+MS(5.4) 12,34940 90.94 116.49 3.75399 3265 0.% 152.44 0.02 3263 0% 002 161.93 34.90 9628 MM+IFR2+8AG+MS(5, 4) 12.40000 N% 11849 3,753.15 32.86 0.% 15380 0.02 32.8.3 000 002 16308 35.00 9645 MWD+IFR2+SAG+MS(5.4) 12,43&26 90.94 11849 3,75261 33.00 0.% 15449 002 32.97 0.00 002 163.83 3507 96% MWLI+IFR2+SAG+MS(5, 4) 12.500.00 90.63 113.84 3,751.69 33.26 000 15842 0.02 33.25 O% 002 16537 35.21 96.77 MWD+IFR2+SAG+MS(5.4) 12,60000 90.17 10906 3)5099 33.66 0.% 163.73 0.02 33.88 0% 0.02 167.73 35.38 97.03 MWDHFR2+SAG+MS(5, 4) 12.700.% 6970 10589 3,751.11 34.08 O% 168.28 0.02 34.08 0.% 002 170.14 35.51 9723 MWD+1FR2+SAG+MS(5,4) 12.800.% Ben 101.92 3,752.04 34.51 0.% 172.06 0.02 3449 0.% 002 172.58 35.62 9796 MWD+IFR2+SAG+MS(5,4) 12.900.% a8.77 9791 3.753.78 34.94 O% 175.03 0.02 34.91 O% 0.02 17504 35.69 9743 MWD+IFR2+8AG+MS(5, 4) 13.00000 88.32 9397 3]58.32 35.39 0.% 177.16 002 3533 0.00 0.02 1]]47 35]3 9743 MWD+IFR2+SAG+MS(5, 4) 13.09981 8787 90.% 3.759.84 35.85 0.% 17843 0.02 M75 000 002 179.86 35.75 97.38 M +IFR2+5AG+M5(5,4) 13.100% 87.87 90% 3.75965 35.05 0.% 17843 0.02 3535 0% 002 179.86 35.]5 97.38 MW0tlFR2+SAG+MS(5,4) 13,20000 85.89 8967 3.785% 3839 0.% 18069 0.02 38.17 0% 002 18224 35.76 97.30 MWD+IFR2+SAG+MS(5, 4) 13.21149 85.67 8981 3,78594 36.45 0.% 18094 0.02 36.21 0.00 0.02 18251 35.76 9729 MWD+IFR2+SAG+MS(5,4) 13,300% 8567 8964 3.772.63 36.82 0.% 18304 0.02 3858 000 002 18400 35.77 9722 MWD+IFR2+SAG+MS(5,4) 13.400.00 85.67 8984 3,780.18 37.24 0.% 18542 0.02 37.00 0.% 002 18896 35.79 97.14 MWD+IFR2+SAG+MS(5,4) 131500.% 85.67 8964 3.787.74 3766 0.% 18].]9 0.02 37.42 0% 0.02 18933 35.81 9706 MWD+IFR2+8AG+MS(5,4) 13.800.0 85.67 89.04 3,795.30 38.DB 0.00 190.17 0.02 37.85 0.03 002 191.69 3582 96.99 MW23+IFR2+SAG+MS(5,4) 13,073.06 8587 8964 3.800.82 38.39 0.% 19191 0.02 38.15 0.0) 0.02 19342 35.84 9693 MWD+IFR2+SAG+M9(5, 4) 13.697.89 85.50 90.11 3.802.73 38.49 0.% 19289 0.02 38.26 0.% 0.02 19001 35.84 9891 MW2I+IFR2+8AG+M5(5, 4) 13,]000) 85.52 90.11 3.8029D 38.50 0.% 192.74 0.02 3827 0.c0 0.02 194.06 35.84 9691 MM+IFR+SAG+MS(54) 7/12019 10:28:02AM Page 6 COMPASS 5000 14 Build 85D Company: Project: Site: Well: Wellbore: Design: ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Kuparuk 3R Pad Plan: 3R-106 Plan: 3R-106 3R-106wp05 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: survey Calculation Method: Output errors are at Database: Well Pian: 3R-106 Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Plan: 9.8+39.10 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPt Measumal Inenna4on AzlmuM W..l Hortense Labral Valuta, Magnitude Semlmajor Semi -minor Death Depth Error in., Error alas Error sus MMus Error Emor ArimmE Tool Juan) r) r) (u%ni (u,m Idiom (dam (usnl loan) (..it) (usm (uanl (u,m r) 13,800.00 8652 90.11 380983 38.86 000 195.13 002 3869 000 0.02 19644 3586 96.84 MW -IFR21SAG+MS(5, 4) 13.900.00 8152 90.11 3,815.03 3923 000 19TU 0.02 39.11 0.00 0.02 19883 3589 96.78 MWD+1FR2+SAG+MS(5, 4) 14,000.00 88.52 %.11 3.81848 3961 000 199.92 0102 39,154 0.00 002 20121 35.91 96.71 MW0HFR2+SAG+MS(5, 4) 14.065.65 89.18 90.11 3,819.80 39.86 DAO 201.50 002 3982 0.00 0D2 20278 35.93 9867 MW0+1FR2+aAG+MS(5.4) 14,100.00 09.10 90.11 3.820.30 4000 000 202.32 002 3997 D.00 0.02 20361 35.94 96.65 MVV>lFR2+SAG+MS(6, 4) 14200.00 89.18 90.11 3.821.73 4043 Oct) 20473 002 40.39 D.00 0.02 20800 35.98 90.58 MWD+IFR2+SAG+MS(5. 4) 14,220.17 09.18 90.11 3.822.02 4052 0.00 205.21 0.02 40,48 0.00 002 20808 35.97 %.57 MW lFR2+SAG+MS(5,4) 71112019 10:28:02AM Page 7 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River UnII2 Site: Kuparuk 3R Pad Well: Plan: 3R-106 Wellbore: Plan: 3R-106 Design: 3R-106wp05 Design Targets ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Target Name -hitImiss target Dip Angle Dip Dir. TVD -NI-S +EI -W -Shape (°) (1) (usft) (usft) (usft) Base Permafrost @ 173, 0.00 0,00 1,732.64 302.19 80.97 - plan hits target center -Circle (radius 500.00) 3R-106 T04 053019 AV 0.00 0.00 3,667.95 2,379.17 4,016.94 - plan hits target center - Circle (radius 100.00) 3R-106705053019 AV 0.00 0.00 3,669.97 2,350.64 5,105.26 - plan hits target center -Circle (radius 100.00) 3R-106 T01 WSD 05301 0.00 0.00 3,674.69 2,334.73 1,875.43 - plan hits target center -Circle (radius 100.00) 3R-106 TO6 053019 AV 0.00 0.00 3,677.93 2,329.42 5,896.72 - plan hits target center - Circle (radius 100.00) 3R-106 T03053019 AV 0.00 0.00 3,695.33 2,368.82 3,294.02 - plan hits target center -Circle (radius 100.00) 3R-106 T07 053019 AV 0.00 0.00 3,695.89 2,243.52 6,434.33 - plan misses target center by 64.96usft at 10006.86usft MD (3703.37 TVD, 2307.93 N, 6438.14 E) -Circle (radius 100.00) 3R-106 T02 Heal 05301' 0.00 0.00 3,707.93 2,364.51 2,260.74 - plan hits target center - Circle (radius 100.00) 3R-106 T08 053019 AV 0.00 0.00 3,732.87 2,089.48 7,293.79 - plan misses target center by 51.99usft at 10886.93usft MD (3734.78 TVD, 2045.30 N, 7266.44 E) -Circle (radius 100.00) 3R-106709053019 AV 0.00 0.00 3,747.18 1,727.22 7,795.22 - plan misses target center by 27.77usft at 11503.22usft MD (3748.95 TVD, 1704.33 N, 7779.61 E) - Circle (radius 100.00) 3R-106 T11 061019 VO 0.00 0.00 3,751.53 1,050.18 8,831.22 - plan misses target center by 0.26usft at 12756.03usft MD (3751.53 TVD, 1050.43 N. 8831.28 E) -Circle (radius 100.00) 3R-106 T11 053019 AV 0.00 0.00 3,751.53 1,075.63 8,721.96 - plan misses target center by 5.73usft at 12644.16usft MD (3750.94 TVD, 1081.05 N. 8723.71 E) - Circle (radius 100.00) 3R-106 T12053019 AV 0.00 0.00 3,759.64 1,009.40 9,171.55 - plan misses target center by 0.23usft at 13099.67usft MD (3759.63 TVD, 1009.63 N, 9171.56 E) -Circle (radius 100.00) 3R-106 T10 053019 AV 0.00 0.00 3,761.20 1,467.28 8,179.68 - plan misses target center by 68.61 usft at 11960.49usft MD (3760.12 TVD, 1416.68 N, 8133.35 E) -Circle (radius 100.00) 3R-106 T13053019 AV 0.00 0.00 3,802.73 1,012.95 9,768.19 - plan hits target center - Circe (radius 100.00) 3R-106 T14053019 AV 0.00 0.00 3,822.02 1,011.98 10,289.99 - plan hits target center - Circle (radius 100.00) Well Plan: 3R-106 Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Plan: 9.8+39.10 @ 48.90usft (Doyon 142) True Minimum Curvature 2.00 sigma OAKEDMPI 7/12019 10.78:02AM Page 8 COMPASS 5000.14 Build 85D 7/12019 10:28:02AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc Kuparuk Local Co-ordinate Reference: Well Plan: 3R-106 Project: Kuparuk River Unit -2 TVD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Site: Kuparuk 3R Pad MO Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Well: Plan: 3R-106 North Reference: True Wellbore: Plan: 3R-106 Survey Calculation Method: Minimum Curvature Design: 3R-106wp05 Output errors are at 2.00 sigma Database: 0AKEOMPI Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,407.79 2,237.80 10-3/4" x 13-1/2" 10.750 13.500 5,825.24 3,707.93 7-5/8" x 9-7/8" 7.625 9.875 14,220.17 3,822.02 4-1/2"x6-3/4" 4.500 6750 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (I (") 1,724.75 1,677.70 T3 0.00 1,787.71 1,732.64 PFROST 0.00 2,067.84 1,972.27 K15 0.00 3,455.27 2,873.93 UG -C 0.00 3,958.71 3,144.46 UG -13 0.00 4,200.34 3,262.67 UG -A 0.00 4,528.11 3,406.44 N 0.00 5,434.37 3,674.29 WS -D 0.00 5,544.98 3,690.58 WS -C 0.00 7/12019 10:28:02AM Page 9 COMPASS 5000.14 Build 85D Conocolphillips Error Ellipse Report Company: ConocoPhillipsAlaska Inc_Kuparuk Local Co-ordinate Reference: Well Plan: 3R-106 Project: Kupawk River Unit -2 TVD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Site: Kupamk 3R Pad MD Reference: Plan: 9.8+39.10 @ 48.90usft (Doyon 142) Well: Plan: 3R-106 North Reference: True Wellbore: Plan: 3R-106 Survey Calculation Method: Minimum Curvature Design: 3R-106wp05 Output errors are at 2.00 sigma 1,759.18 1,707.80 Database: OAKEDMPI Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +FJ -W lush) (usft) lush) (usft) Comment 500.00 500.00 0.00 0,00 KOP: Start 1.5°/100' DLS, 15° TF, for 200' 700.00 699.91 5.06 1.35 Start 2.5°/100' DLS, 0° TF, for 1059.18' 1,759.18 1,707.80 288.63 77.34 Hold for 114.87' 1,874.05 1,807.80 343.23 91.97 Start 2.5°/100' DLS, 0° TF, for 533.74' 2,407.79 2,237.80 646.68 173.28 Hold for 20' 2,427.79 2,252.47 659.81 176.80 Start 3°/100' DLS, 0.64° TF, for 404.86' 2,832.64 2,518.14 953.80 256.07 Hold for 327.81' 3,160.45 2,706.31 1,212.88 326.29 Start 3"/100' DLS, 87.08° TF, for 2276.21' 5,436.66 3,674.69 2,334.73 1,875.43 Start 3.6"/100' DLS, -36.83° TF, for 126.38' 5,563.05 3,692.66 2,347.36 1,998.85 Hold for 5.33' 5,568.38 3,693.25 2,348.02 2,005.11 Start 3.6°1100' DLS, 48,59* TF, for 256.86' 5,825.24 3,707.93 2,364.51 2,260.74 Hold for 20' 5,845.24 3,708.00 2,364.59 2,280.74 Start Will 00' DLS, 1.02* TF, for 29.69' 5,874.93 3,707.87 2,364.71 2,310.43 Hold for 930.55' 6,805.48 3,696.66 2,368.34 3,240.91 Start 3°/100' DLS, -21.98° TF, for 53.13' 6,858.61 3,695.33 2,368.82 3,294.02 Adjust TF to -45.61°, for 9.69' 6,668.30 3,694.95 2,368.98 3,303.70 Hold for 595.86' 7,464.16 3,670.28 2,379.66 3,898.95 Start 3"/100' DLS, 134.39° TF, for 118.03' 7,582.38 3,667.95 2,379.17 4,017.12 Start 2°/100' DLS, -4.94° TF, for 0.18' 8,650.94 3,669.87 2,351.17 5,085.32 Hold for 1066.57' 8,670.88 3,669.97 2,350.64 5,105.26 Start 2°/100' DLS, 175.05' TF, for 19.94' 8,755.12 3,670.50 2,349.92 5,189.48 Start 2.5°/100' DLS, -82.24° TF, for 84.24' 9,138.00 3,671.93 2,353.60 5,572.34 Hold for 382.88' 9,463.73 3,677.93 2,329.42 5,896.72 Start 3°/100' DLS, 99.93° TF, for 325.73' 9,727.07 3,689.06 2,308.81 6,158.73 Start 3.5°/100'DLS, -96.75°TF, for 263.34' 9,941.66 3,700.08 2,309.13 6,373.04 Hold for 214.59' 10,801.87 3,732.87 2,089.71 7,193.94 Start 3.5°/100' DLS, 87.56° TF, for 860.21' 10,903.95 3,735.14 2,035.97 7,280.67 Adjust TF to 88.48', for 102.08' 11,443.01 3,746.69 1,737.94 7,729.71 Hold for 539.06' 11,461.87 3,747.18 1,727.46 7,745.37 Start 3.5°/100' DLS, 139.62° TF, for 18.86' 11,511.77 3,749.45 1,699.55 7,786.68 Adjust TF to 176.62°, for 49.9' 11,593.91 3,754.42 1,653.58 7,854.56 Hold for 82.14' 11,866.66 3,761.20 1,467.51 8,079.83 Start 4°/100'DLS, 68.64* TF, for 292.76' 12,349.40 3,753.99 1,198.40 8,453.72 Adjust TF to -89.51°, for 462.73' 12,433.26 3,752.61 1,161.00 8,528.77 Hold for 83.87' 13,099.81 3,759.64 1,009.63 9,171.70 Start 4°/100'DLS, -96.64°TIF, for 666.54' 13,211.49 3,765.94 1,009.98 9,283.19 Start 2°/100' DLS, -170.68" TF, for 111.68' 13,673.06 3,800.82 1,012.90 9,743.44 Hold for 461.57' 13,697.89 3,802.73 1,012.95 9,768.19 Start 2'/100' DLS, 109.54" TF, for 24.83' 14,065.65 3,819.80 1,012.27 10,13549 Start 1°/100' DLS, 0° TF, for 367.76' 14,220.17 3,822.02 1,011.98 10,289.99 Hold for 154.52' Checked By: Approved By: Date: 7/112019 10..28:02AM Page 10 COMPASS 5000.14 Build 85D Pool Report 14:01, July 01 2019 3R-106wp05 VADUMRE m Na3R-IM VMMOR AV TARGET DETAILS TV W7469 (MAP C0-ORDINATES) Cade Radius tsW 3R-108 T02 Heel MM19 AV OM 3707.93 Circe (Rectus: 1320.00) Quarter Mile View 314003 V -100 T04 UG gT03 019 AAV AV 595.33 W 388997 100.00)rcle RadlYs100.00)3R-1�T05053019 ((Radius 3R-106 TOS 053019 AV 347] 93 Cycle 100.00) Ci21e (Radius, 1 W(0) 3R-1M ITS 053018 AV 3]32.87 ci Gu (Radius: 10000) 3R-106709033019 AV 374 18 Cl¢ia (Radius: 10000) 3R-1NT1a M019 AV 3761.20 C'-1a Radius: 10000) M-108 TVG 1: AV P59.64 C'ecle (Radius: MOO) M-103 Ti13 M3018 AV 380293 Cimu (Radius 10000) VR_ IM T14 03019 AV 3522.02 CmN, (Radius: 100D) 3R-00 T02 Heel Mb19 AV 3707.93 W Cs (Rad'aus: 10000) 3R-10 T07 03019 AV 3995 59 CimAe Paul. 100Dd 3R 100 Tfl 03019 AV 3751.53 CiRk ((Rados:, 1 W.M) 3R-165T11 M1019V 375153 CimTe(Radius: 1M-06) 3R 10 T14 05'019 AV OM 3822 D2 cm, (Rados. 130.00) 4s F Olikt 7500 4 °k Point Staee t m A 5000 — c dk C tn u 113 �o ; 3R-10q rc 02500 -c s O 0— w Z A \ N � w D O -2500 3qggyy 3R-26PB1 -5000 -- - 3R-26 —10000 —7500 —5000 —2500 0 2500 5000 7500 10000 14:03, July 01 2019 1 3R-106wp05 WELLBORE 3R.;O6 TARGET DETAILS 67469 WAR C6OROINATES) T01 WS0053019 AV C...(Rapiu5.. 10000 3R-JW T02 Heel W3019 AV OM 3707,93 Cede (Rados. 132000) Quarter Mile View 3R-106 T03 W3019 AV 3R-1 W T03 053019 AV 3695.33 366].95 Curie (mw0 a loom) C9 (Radius: 100.00) 3RIN TOS W301e AV 3%9.97 Circle(RedNe. woo) 3R-IW TW MW19 AV 36]] 93 cWe (Rediae: i M-106 TOB W3019 AV 3730.87 Circle (Radius-.. 1000% n- 3019AV 0 3]18 Cimle (Radiu1 W00) R-106 T10 053019 AV 3]8120 Cede (Radui 1 W 00) M-106 712 W3D19 AV 3759.64 CB (Rados: 100.00) 3i-106 T13 %3019 AV 3802.]3 Ci,de)Radw 1mm) 3R-108 T14 W3019 AV 3822.02 Cede (RadiusMOO) 41 3R-1W T02 Hee105301P AV 3]0]93 CeVe IRedw MOD) %3 () ((IOq M1W 707053019 AV 3695.69 Cede f00.00M)) O pG�n( 3R-106 TH 06MID AV ae az (((RRRWIw ctrck O State1 3R 1008 T14 Os30i0 9 AV_oM i (Rm i 55113WM:00) 6000 w 0 - 4500 4200 '... 4100 Po 4000 U) 3900 O 311 Tr)O 3000 3R-10A n I c 3 +141 c J-- 0 O 21500 1 A w � N 1 0 w 0- -1500 -1500 3R-26PB1 3R-26 T - T-- 0 1500 3000 4500 6000 7500 9000 10500 12000 3R-106wp05 Surface Location M CPAI Coordinate Converter - ❑ x Datum: NAD83 Region:alaska . Datum: NAD27 . Region: alaska C Latitude/Longitude IDecimal Degree C Latitude/Longitude IDecimal Degrees {" UTM Zone: I — r South r UTM Zone: Tnle r South G State Plane Zone: 4 Units: us -ft 71 C• State Plane Zone: 1' Units: us -ft . C' Legal Description (NAD27 only) C' Legal Description (NAD27 only) Starting Coordinates:— - Ending Coordinates: X: 1660680.40 X: 520649.000453913 Y: 6031418.14 Y: 6031666.08596804 i TmnsFam' Quit Heb 3R -106w 05 Surface Casing M CPAI Coordinate Converter — ❑ x From: Datum: NAD83 Region alaska r Latitude/Longitude IDecimalDegrees T UTM Zone:I r South (- Stale Plane Zone: I' �-] Units: us -ft . r Legal Description (NAD27 only) Datum: NAD27 Region: alaska * Latitude/Longitude IDecimaiDegrees * UTM Zone: True r South 6 State Plane Zone: I" � Units: us -ft . r Legal Description (NAD27 only) Starting Coordinates: — Ending Coordinates X 1660851.90 X: 520820.514593722 Y: 6032065.23 Y: 6032313.16147106 r------_........................_..._...� ( Transform Quit Help 3R -106w 05 Intermediate Casing Q CPAI Coordinate Converter — 0 x 1 From: Datum: INAD83j Region: alaska C' Latitude/Longitude IDecimalDegrees C UTM Zone: �— r— South G State Plane Zone: I" J unds: usft C Legal Description (NAD27 only) Datum: NAD27Regan: alaska C Latitude/Longitude IDecimalDeguees f•UTM Zone: True r South f••State Plane Zona: q . Units: us R • Legal Description (NAD27 only) Starling Coordinates: — End'mg Coordinates: X: 11662934.46 X: r522903193267114 Y: 16033788.57 Y: 6034036.41789883 Transformm Quit Help 3R-106wp05 Top of Production Horizon jj 1 M CPAI Coordinate Converter — 0 x j r Datum: NAD83 Region: jalaska C' Latitude/Longitude Decimal Degrees r UTM Zone: F— r South C•' State Plane Zone: F-:-] Units: usit * Legal Description (NAD27 only) Datum NAD27 Region: lalaska wl • Latitude/Longitude IDecimalDegrees i UTM Zone: True r South G State Plane Zone: F--,�wl Units: us ft C Legal Description (NAD27 only) Slatting.Coordinatea: Ending Coordinates: K: 1662547.01 x' 522515.728264765 Y: 6033757.57 Y: 6034005.43003882 ( Transform i Qum Help M CPAI Coordinate Converter Datum: NAD83 - Region. alaska [" Latitude/Longitude IDecimaiDegrees r UTM Zone: F— r South t Slate Plane Zone: 4 . units: us -it (' Legal Description (NAD27 only) - ❑ x Datum: NAD27 Region: jalaska f Latitude/Longitude IDecimalDegiees t` UTM Zone: True r South r State Plane Zone: F-'.] Units: usft * Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X 1670966.57 X: 530935.561799758 y 16032458.07 Y: 6032705.69182449 Transtam Dul Help 3R -106w 05 Surface Location M CPAI Coordinate Converter — ❑ X From: -- -- r To: — Datum: NAD83 . Region: alaska Datum: NAD27 Region: alaska • Lalitude/Longitude IDecimalDegiees r Latitude/Longitude Decimal Degrees • UTM Zane: F— r South r UTM Zone: True F South G State Plane Zone: rq � Units: urft C State Plane Zone: q . Units: us -ft r Legal Descuption (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates- l- Legal Description - X: 1660680.40 Township: 013 N . Range: 009 E Y: 6031418.14 Meridian: F-71 Sectim F9— FNL . 1696.6416 FEL 2936.5728 i L Transform ! Quit Help i 3R-106wp95 Surface Casing M CPA[ Coordinate Converter — ❑ X From. To Datum: NAD83Region: falak, j Datum: NAD27 j Region: alaska * Latitude/Longitude Ibecimal Degrees r Latitude/Longitude IDecimal Degrees C UTM Zone: F_ r South r UTM Zone: True r South G State Plane Zone: I'D Units:F7Dr State Plane Zone: �� Units: us -ft C Legal Deaauphon INA.0.7 onlyl G Legal Description (NAD27 only) Staling Coordinates: X: Legal Description — --,l 1660851.90 Township: 013 FN Range: 009 E Y: 6032065.23 Meridian: Section: l9 — - FNL 1049.9773 FEL . 2761.6140 �F Quit Hep 3R-106wp05 Intermediate Casing CPAI Coordinate Converter — ❑ X Datum: NAD83 Region: alaska C Latitude/Longitude Decimal Degrees f UTM Zone: [— r South 0' State Plane Zone: F—':-] Units: us -ft r Legal Dezcnphon INAlJ27 only) --Starting Coordinates: X: 1662934.46 Y: 6033788.57 Datum: NAD27 Region: alaska C' Latitude/Lorgitude IDecimaiDegrees !" UTM Zane: True r South * State Plane Zone:Units: us -H H Legal Description (NAD27 only) —a WO. Township: 013 [RJ Range: 009 I` _] Meidiam Fu ----7, SectiomF4— FNL � 4612.2433 FEL 669.61411 L__... Transform ...I Quit Heb 3R -106w 05 Top of Production Horizon M CPAI Coordinate Converter — ❑ X Datum: NAD83 Region: alaska C- Latitude/Longitude IDecimaiDegfees • UTM Zone: r— r South G State Plane Zone: F-':-:1 Units: us -ft • Legal Description IPJ.AD27 o* l Starting Coordinates: -- X: 1662547.01 Y: 16033757.57 Datum: NAD27 . Region: alaska C' Latitude/Longitude IDecimalDegrees, • UTM Zone: True f South • State Plane Zone: Iq � Units: us -ft C Legal Desaiption (NAD27 only) Legal Description -- Township: 013 FN-�:] Range: 009 Meridian: 1" -1 Section f4 FNL 4642.0465 FEL 1057.2606 I_ ,Transform _j Quit I Help 3R-106wp05 TD Q CPAI Coordinate Converter — ❑ X Datum: NADB3 Region: alaska r Latitude/Longitude IDecimalDegrees * UTM Zone: F– r South G Slate Plane Zone: F4--] Units: us -ft r Legal Desoriptron (N4D27 only( Starting Coordinates: X 1670966.57 Y: 6032458.07 Datum: NAD27 Region: alaska r Latitude/Longitude IDecimal Degrees r UTM Zone: True r South r State Plane Zone: 1" J Units: us -ft r Legal Description jNAD27 o*j Legal Desaiption Township: Ota I" J Range: 009 Meridian: I" -------Section:—11 FNL . 69263728 FEL 3203.6093 Transform quit Help Tollerable Collision Risk Worksheet As -built 3 5/5/1 CC I JLS I jUpdated Per K190005ACS 12 112/18/i JAH I JFC I IPER K160005ACS NOTES: T14NR9E VICINITY MAP T13NR9E STP 4 6 1. BASIS OF LOCATION AND ELEVATION IS DS3R MONUMENTATION PER & ATE 5 PROJECT RE ALASKA P 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 6 10640 9 ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES OP LOCATION ARE N.A.D. 27. 3. ELEVATIONS ARE B.P.M.S.L. ® 12 4. ALL CONDUCTORS ARE LOCATED WITHIN 112 -- si PROTRACTED SECTION 9, TOWNSHIP 13 NORTH, rE RANGE 9 EAST, UMIAT MERIDIAN, ALASKA. • 26 DATES OF SURVEY: 5/03/19 — 5/05/19. • 14 g3R5. ALL DISTANCES SHOWN ARE GROUND. 15 86. • 25 • 17 5 14 E 6 Ar 5 VICINITY MAP 101 $ 6 1"= 1 MILE 102 k 1051 7 8 10640 9 • 107 10� 11 N ® 12 112 • 26 • 14 • 15 • 25 • 17 • 18 • 19 LEGEND • 20 • 21 • EXISTING CONDUCTOR LOCATION • 22 O AS—BUILT CONDUCTOR LOCATION x PLUGGED AND ABANDONED GRAPHIC SCALE 0 75 150 300 1 inch = 150 ft. LOUNSBURY SEE SHEET 2 AND 3 FOR LOCATION INFORMATIONs ASSOCIATES, INC. A84V YORK ENGINEERS P1ANN616 AREA: 3R MODULE: XXXX UNIT: D3 ConocoPhillips DS3R WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. I DRAWING N0. __ , _ __„ _ _. __ . _ PART: I REV: Appendix ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ DriIIingwithin 30' of horizontal inclination AND driIli ngwithin 300 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 7 ConocoPhillips 3R -10o Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strate Washouts / Hole Sloughing Moderate Cool mud temperatures, minimize circulating times Concretions when possible. Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Control drill, Reduced pump rates, Reduced drilling Stuck Pipe Low fluid temperatures, Additions of ScreenKleen. Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, Abnormal Reservoir Pressure Low use wei hted swee s. Hole swabbing on trips Low Trip speeds, proper hole filling (use of trip sheets), Lost circulation Low pumping out. Anti -Collision Low Follow real time surveys very closely, shut in nearby Lost Circulation Moderate wells that have collision concerns, utilize gyro survey to ensure survey accuracy through zone with magnetic interference. 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), Concretions pumping out. Directional — Achieving Build Moderate Get ahead of plan early. If RSS is not yielding adequate Rates Moderate DLS, trip for a motor. Stuck Pipe Low Good hole cleaning, monitor real time T&D, stabilized BHA, decreased mud weight. Abnormal Reservoir Pressure Low Normally pressured, ensure adequate mud weight prior to drilling into reservoir. BOP training and drills. Lost circulation Low Monitor ECD, mud rheology, LCM. Tight Hole Low Control with proper drilling practices. Perform wiper Lost Circulation Moderate trip if hole conditions dictate. 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Fault Crossings and Moderate Use developed best practices for concretion drilling: 1-2klbs Concretions WOB, 80-100 rpm with RSS in neutral. Geosteer with PeriSco a HD. Getting Liner to Bottom Moderate Properly clean hole on trip out with BHA, ensure lubes @ 3% prior to tripping out to aid in torque and drag, and keep DLS to a minimum. Utilize Su erSliders if necessary. Wellbore Placement Moderate If any issues with azimuthal accuracy in surveys while drilling in east to west orientation, increase survey frequency. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or backreamin . Lost Circulation Moderate Monitor ECD, mud rheology, LCM program, additional fluid stored on location during completion run. 3R-106 Drilling Hazards Summary.doc 7/2/201911:52:00 AM Differential Sticking ,...,derate Follow mud program, kee z moving when able. Anti -Collision Low Follow real time surveys very closely, shut in nearby wells that are of concern for collision. Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight if higher Pressure pressure encountered. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight. 3R-106 Drilling Hazards Summarydoc 7/21201911:52:00 AM 0 8 3 - u N G Y J c g c o a C V= - H _ U ` 2 F n 3g i N r / f � 9 � � E � UV S ConocoPhillips 3R-106 Schematic Kaska Attachment 5 BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. KRU 3R-106 I ==Data Input <== Data <== Data weaK point or w t - measurea aeptn (n) Weak point or LOT True vertical depth (ft) Weak point or LOT - Hole angle (deg) Weak point or LOT - Hole size (in) Weak point pressure or LOT - EMW (ppq) 5,SZ5" — uata Input <== Data Input <== Data Input <== Data Input <_= Data Input 3,708' MZ,406 7.625" 9.20 or Interest - measureo ceptn (tt) of interest - True vertical depth (ft) of interest - Hole angle (deg) of interest - Hole size (in) of interest - Pore pressure EMW (pool 5,SZ5" <_= Data Input <_= Data Input <_= Data Input <_= Data Input <== Data Input 3,708' 89.80 7.625" 9.20 <== tSottom nae assemDly Uu (In) tl.D'• <_= Data Input Bottom hole assembly length (ft) 200' <_= Data Input Drill pipe OD (in) 5.500" 1<_= Data Input 6HA annular vol. L zone of interest (bbl/tt) -0.0057 DP annular vol. @ zone of interest (bbl/ft) 0.0271 DP annular vol. 0 weak point (bbVf) 1 0.0829 <== Data Weak point pressure (psi): PIo 1,338 psi Weak point pressure -Safety margin: Pmax Pfnax EMW 1,338 psi 11.50 ppg Max anticipated formation pressure (psi): Pf 1, Weak Pt to Zone of Interest distance (TVD ft): OH D 1,470' Weak Pt to Zone of Interest distance (MD ft): OH {MD) 3,417' Maximum influx height at the bit (TVD ft): H (TVD) 651' Maximum influx height at the bit (MD ft): H (MD) 186,524' Calc. volume of {H) around BHA: Calc. volume of (H) around drill pipe: Calc. volume that H equals @ initial shut in: Vlbha Vldp V1 -1.1 bbl 5048.2 bbl 5047.1 bbl Calc. vol. that H equals @ weak point (MD ft): VWp 73.5 bbl Calc. volume of Vwp @ Initial shut in: V2 55.5 bbl Kick Tolerance: V2 55.5 bbl NOTE: Boyer, David L (CED) From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Sent: Wednesday, July 3, 2019 11:55 AM To: Boyer, David L (CED) Subject: RE: [EXTERNAL)PTD for KRU 3R-106 West Sak Well Attachments: 3R-106 Directional.xlsx Hi Dave, I meant to send those to you this morning. Sorry about that. See attached. This well is a water injector that will not be pre -produced. The H2S readings on 311-101 were below 20 ppm, 10 ppm on 10/27/17 and 3 ppm on 10/20/18. Thanks, Madeline From: Boyer, David L (CED) <david.boyer2@alaska.gov> Sent: Wednesday, July 3, 2019 11:28 AM To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Subject: [EXTERNAL]PTD for KRU 311-106 West Sak Well Hi Madeline, Would it be possible to e-mail over a digital copy of the proposed surveys for KRU 3R-106 in Excel or ASCII for loading into the database at AOGCC? Also, do you have any H2S data from other West Sak target wells on 3R pad.? If the H2S readings are 20 ppm or over, the well must be flagged for H2S measures per the regulations. Thank you, Dave Boyer Transform Points Source coordinate system Target coordinate system State Plane 1927 - Alaska Zone 4 KRU 3R- t o6 Albers Equal Area (-154) A' b & 5 Datum: CV✓ SatC> Datum: NAD 1927 - North America Datum of 1927 (Meanj— / NAD 1927 - North America Datum of 1927 (Mean) X Type values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to ropy and Ctd+Vto paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. I < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: {1 K u ---3R— t OG PTD: _;?, [ _I, " 0 17— / Development /Service —Exploratory _ Stratigraphic Test —Non -Conventional FIELD: Ku cu' u I fe l/ POOL: \,✓e--5 Sa Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50- - _- (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- _-_� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(dx2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC V/ within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 PTD#:2190970 Company ConocoPhillps Alaska Inc -_ _ Initial Class/Type Well Name: KKt P FUK RIV U_WSAK 3R-106 Program SSR Well bore seg SER / PEND GeoArea $99 Unit 11160 On/Off Shore On Annular Disposal L Administration 1 Permit fee attached_ _ _ _ _ _ - - - _ _ _ NA Commissioner: Date Commissioner Date 2 Lease number appropriate_ _ _ _ _ _ _ Yes - - - - - - - - - - - - Unique well-name and number .. _ ... _ _ _ _ _ _ _ _ Yes 4 Well located ina.defined pool.. _ _ _ _ .. _ _ Yes 5 Well located proper distance from drilling unit boundary _ _ _ _ _ _ _ Yes 6 Well located proper distance from other wells _ _ _ _ Yes 7 Sufficient acreage available in drilling unit _ _ _ _ _ _ _ .. Yes 8 If deviated, is, wellbore plat included _ _ _ _ Yes Directional-plan view.& wellbore profile enclosed. 9 Operator only affected party.. _ _ _ _ _ _ _ _ _ _ .... Yes 10 Operator has. appropriate bond in force ..... _ _ _ Yes 11 Permit. can be issued without conservation order _ _ .. _ _ _ _ .. _ Yes Appr Date 12 Permit can be Issued without administrative approval _ _ _ _ _ _ Yes _ 13 Can permit be approved before 15-day wait _ Yes DLB 7/3/2019 ... _ _ _ _ 14 Well located within area and strata authorized by Injection Order # (pot 10# in. comments)(For. Yes Area Injection Order No., 28 15 All wells within 1/4. mile area of review identified (For service well only) _ ... Yes 16 Pre-produced injector; duration of pre production less. than 3 months (For service well only) .. Yes Well will not be pre-produced, 17 Nonconven, gasconforms to AS31.05.03ft1.A),O2.A-D) ....... . . . . . . . . . . . . . . NA - -- 18 Conductor stringprovided___________ _ _ _ _ _ _ __ Yes _ 80' conductor set_ Engineering 19 Surface casing. protects all. known USDWs.. _ . . . . . . ....... . . . .. Yes _ Surface casing set to 240$' MD 20 CMT vol. adequate to circulate on conductor & surf -csg _ _ _ _ _ _ _ _ _ _ _ _ _ Yes .. _ _ . 205 % excess cement planned 21 CMT. vol. adequate to tie-In long string to surf csg_ _ .. . . . . . .. . . .. . . . No 22 CMT. will cover all known productive horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No. - - - . - Productive.interval will be completed with uncemented slotted liner 23 Casing designs adequate for C, T, B &_ permafrost.. .... . . . . . .. . . . . ..... Yes ----- 24 Adequate tankage. or reserve pit _ _ _ _ _ _ _ _ _ _ _ _____ _ _ ___ _ _ _ _ _ Yes _ _ _ Rig has steel tanks; all waste. to approved disposal wells 25 lf.a_re-drill, has a 10-403 for abandonment been approved _ _ _ ____ _ _ _ ____ _ _ _ _ _ NA 26 Adequate wellbore separation proposed. _ _ _ . . . ........ . .. . . . . . . . Yes _ Antircollision analysis complete; no major risk failures 27 If diverter required, does it meet regulations. . . . ... . . . . .. . . . . .... NA- Diverter variance granted per 20 AAC 25,035(h)(2) Appr Date 28 Drilling fluid program schematic & equip list adequate_ _ _ _ _ .. _ _ .. _ _ Yes - _ Max formation. pressure is-1730 psig(8.7 ppg EMW ); wjll drill w/ 8.8-9.5 ppg EMW VTL 7/12/2019 29 BOPEs._do they meet regulation - - - - - - - _ - _ - - -- - - - - - - - - - - - -- Yes 30 BOPE.press rating appropriate; test to _(put psig in comments). _ _ _ ___ _ _ _ _ _ Yes _ MPSP is 1348 psig; will test BOPS. to 3500psig- - _ ... 31 Choke. manifold complies w/API RP-53 (May 84)- - _ _ _ _ _ _ _ _ _ _ ... _ Yes 32 Work will or without operation sbutdown_ _ _ _ _ .... _ _ ___ _ _ _ _ _ _ _ _ Yes 33 Is presence of H2S gas probable__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ... _ _ _ No.. 34 Mechanical condition of wells within AOR verified (For service well only) - - - --- - - - - - - - - Yes .. _ _ . no wells in 1/4 mile,AOR. _ _ . 35 Permit can be issued w/o hydrogen sulfide measures ______ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes .. _ _ _ .. 1:12S is 10 ppm or less in the West Sak on 3R Pad. Geology 36 Data. presented on potential overpressure zones - - Yes .. ... Appr Date 37 Seismic analysis of shallow ges.zones- _ _ _ - - NA DLB 7/3/2019 38 Seabed condition survey (if off-shore) _ _ . . . . .... . . . . ... . . NA.. . 39 Contact name/phone for weeklyprogress reports [exploratory only] NA. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date I D/ s '31 z� 119 9C 3�l ill