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218-160
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 23, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. MT6-02 GMTU MT6-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/23/2024 MT6-02 50-103-20792-00-00 218-160-0 W SPT 7888 2181600 1972 1500 1500 1500 1500 440 500 500 500 4YRTST P Brian Bixby 9/29/2024 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:GMTU MT6-02 Inspection Date: Tubing OA Packer Depth 670 2300 2250 2250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240930151318 BBL Pumped:1.6 BBL Returned:1.6 Wednesday, October 23, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.23 09:55:41 -08'00' MEMORANDUM To: Jim Regg � t?' ) P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 10, 2020 SUBJECT: Mechanical Integrity Tests ConocoP6illips Alaska, Inc. MT&02 GM1UMf6-02 Sre: Inspector Reviewed By: P.I. Sup" Comm Well Name GMTU MT6-02 API Well Number 50-103-20792.00.00 Inspector Name: Lou Laubenstem Permit Number: 218-160-0 Inspection Date: 6/23/2020 ' Insp Num: mitLOL200708111536 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Mr6 oaType Inj w TVD 7888. Tubing 2812 2812 ' 28127 2812 ' PTD 2181600 r Type Test I SPT Test psi 1972 IA 850 2220 2165 - 21*�]-- BBLPumped: zs 'BBL Returned: z.3 OA 000 aoo aoo a Interval- 4YRTST Notes: OOA 100/100/100/100 Friday, July 10, 2020 Page 1 of 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet 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. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 DATA SUBMITTAL COMPLIANCE REPORT 5/24/2019 Permit to Drill 2181600 Well Name/No. GMTU MT6-02 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20792-00-00 MD 22228 TVD 7834 Completion Date 2/13/2019 Completion Status WAGIN Current Status WAGIN UfC Yes REQUIRED INFORMATION / Mud Log No ✓ / Samples No✓ / Directional Survey Yes,/ DATA INFORMATION List of Logs Obtained: GR/Res/Density/CBL (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type MedlFrmt Number Name Scale Media_ No Start p StoCH _ _ _ Received Comments ED C 30322 Digital Data _ _ 8320 8687 1/7/2019 Electronic Data Set, Filename: CPAI_MT6- 02_ CBL _ 03JAN19_ConCu_R01_L010_Repeat Pass.las ED C 30322 Digital Data 7460 8662 1/7/2019 Electronic Data Set, Filename: CPAIMT6- 02_ CBL_ 03JAN19_ConCu_R01_L01_2_Main Pass.las ED C 30322 Digital Data 1/7/2019 Electronic File: CPAI MT6- 02 CBL_ 03JAN19_ConCu_R01_L010_Repeat Pass.dlis ED C 30322 Digital Data 1/7/2019 Electronic File: CPAI _MT6- 02_ CBL_ 03JAN19_ConCu_R01_L012_Main Pass.dlis ED C 30322 Digital Data 1/7/2019 Electronic File: CPAI MT6- 02 CBL 03JAN19 Field Print.Pdf Log C 30322 Log Header Scans 0 0 2181600 GMTU MT6-02 LOG HEADERS ED C 30382 Digital Data 10880 7589 2/20/2019 Electronic Data Set, Filename: MT6-02 MEMORY SCMT 10FEB2019_PASS UP 30FPM_PSP_016PUC.las ED C 30382 Digital Data 2/20/2019 Electronic File: MT6-02 MEMORY SCMT IOFEB2019_PASS UP 30FPM_PSP_016PUC.DLIS ED C 30382 Digital Data 2/20/2019 Electronic File: MT6-02 MEMORY SCMT IOFEB2019 FIELD PRINT.PDF Log C 30382 Log Header Scans 0 0 2181600 GMTU MT6-02 LOG HEADERS ED C 30440 Digital Data 3/13/2019 Electronic File: MT6-02 EOW - NAD27.pdf ED C 30440 Digital Data 3/13/2019 Electronic File: MT6-02 EOW - NAD27.txt AOGCC Page I of 3 Friday, May 24, 2019 DATA SUBMITTAL COMPLIANCE REPORT 5/24/2019 Permit to Drill 2161600 Well Name/No. GMTV MT6-02 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20792-00-00 MD 22228 TVD 7834 Completion Date 2/13/2019 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 30440 Digital Data 3/13/2019 Electronic File: MT6-02 EOW - NAD83.pdf ED C 30440 Digital Data 3/13/2019 Electronic File: MT6-02 EOW - NAD83.txt Log C 30440 Log Header Scans 0 0 2181600 GMTU MT6-02 LOG HEADERS ED C 30829 Digital Data 73 22228 5/22/2019 Electronic Data Set, Filename: MT6-02 LTK Memory Drilling Data.las ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 Drilling Mechanics Depth Log.cgm ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 LTK 2MD Memory Log.cgm ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 LTK 5MD Memory Log.cgm ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 LTK 5TVD Memory Log.cgm ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 LTK Memory Drilling Data.dls ED C 30829 Digital Data 522/2019 Electronic File: MT6-02 Drilling Mechanics Depth Log.pdf ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 LTK 2MD Memory Log.pdf ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 LTK 5MD Memory Log.pdf ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 LTK 5TVD Memory Log.pdf ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 EOW - NAD27.pdf ED C 30829 Digital Data 522/2019 Electronic File: MT6-02 EOW - NAD27.txt ED C 30829 Digital Data 5/22/2019 Electronic File: MT6-02 EOW - NAD83.pdf ED C 30829 Digital Data 522/2019 Electronic File: MT6-02 EOW - NAD83.txt Log C 30829 Log Header Scans 0 0 2181600 GMTU MT6-02 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments AOGCC Page 2 of 3 Friday, May 24, 2019 DATA SUBMITTAL COMPLIANCE REPORT 5/24/2019 Permit to Drill 2181600 Well Name/No. GMTV MT6-02 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20792-00-00 MD 22228 TVD 7834 Completion Date 2/13/2019 Completion Status WAGIN Current Status WAGIN UIC Yes INFORMATION RECEIVED Completion Report 0 Directional / Inclination Data Mud Logs, Image Files, Digital Data Y /� Core Chips Y/6 Production Test Information Y / Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y /r(VRj YOGeologic Markers/Tops Daily Operations Summary Cuttings Samples Y le Laboratory Analyses Y /lN COMPLIANCE HISTORY Completion Date: 2/13/2019 Release Date: 12/17/2018 Description Comments: Date Comments Compliance Reviewed By: --- ._ - -Date Z L -. A( GCC Page 3 of 3 Friday, May 24, 2019 PiD a/6—/roo Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Wednesday, April 3, 2019 3:58 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]GMTU MT6-02(PTD 218-160); 10-407 Submission Attachments: MT6-02 WV Cement Report_Int2.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Good catches and I apologize for the errors. Correct set depth for the 7" liner should be 11,059' MD / 7,902' TVD. Cement report is attached. Let me know if you need anything else. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, April 03, 2019 3:02 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]GMTU MT6-02(PTD 218-160); 10-407 Submission Andrew, Please review the 10-401 form for MD of Int liner. Also, there is not cement summary for the liner cement. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeDoiQ7alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use of disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loepp@alaskaacv Winston, Hugh E (DOA) From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod@contractor.conocophillips.com> Sent: Thursday, March 21, 2019 3:20 PM To: Winston, Hugh E (DOA) Cc: Beat, Andrew T Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Attachments: MT6-02 10-407 PTD NEW WELL Completion.pdf, MT6-021-1 10-407 PTD NEW WELL COMPLETION.pdf Good afternoon, I have attached copies of the updated page 1 of both MT6-02 and MT6-021-1 and I will come by with hard copies after work today. I will put them in an envelope addressed to you. Again my apologies for this inconvenience and thank you very much for your patience. Thanks, Ann From: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Sent: Thursday, March 21, 2019 9:39 AM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Haggerty -Sherrod @contractor.conocophillips.com> Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Sounds good, tet me know when you hear back Q Huey From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Sent: Wednesday, March 20, 2019 3:32 PM To: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Hi, It is looking very much like I will need to reprint page one for both MT6-02 and MT6-021-1 because we may need to swap the liner (box 24). I am waiting to hear back from the engineer. I am so sorry for this delay. From: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Sent: Tuesday, March 19, 2019 1:13 PM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Cc: Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Hi Ann, Great, that fixed both! Thanks for the quick reply. No need to send a new copy, I will hand edit the form we have. Thanks Huey From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Sent: Tuesday, March 19, 2019 12:20 PM To: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Hi Huey, I am so sorry, I have no clue how I made this error but I have checked this morning twice and these boxes are incorrect for both MT6-02 and MT6-02L1 API# 50103207920000 PTD#218-160 Well: MT6-02 Box 4a Total dept 4802' FNL, 1732' FEL, Sec 13, T11N, R2E, UM API# 50103207926000 PTD#219-009 Well: M76-021-1 Box 4a Total dept 2359' FNL, 1641' FEL, Sec 24, T11N, R2E, UM Do these calculate with your coordinates? And if so should I send you a new top sheet. I will change ours if you agree that these are correct. From: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Sent: Tuesday, March 19, 2019 11:56 AM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Cc: Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Subject: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Hi Ann, My name is Huey, I'm a Stat Tech for the AOGCC. I am inputting data from a well completion report and I was hoping you could verify that the coordinates given in the report are accurate. Our database calculates the state coordinates and compares them with what is given in box 4b and the numbers aren't aligning for location at total depth. The survey report has the same numbers as what is listed is 4b so perhaps the problem is with the coordinates in box 4a. Could you please verify the information is both boxes for the TD? Thanks API# 50103207920000 PTD#218-160 Well: MT6-02 Huey PL),�UL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ E]WINJ ElWAG❑+ WDSPL El No. of Completions: 1b. Well Class: Development [[�.H Exploratory LJ Service ❑� Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 2114!2019 14. Permit to Drill Number / Sundry: 218-160 . 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 12/22/2018 15. API Number: 50-103-20792-00-00 ' 4a. Location of Well (Governmental Section): Surface: 239' FNL, 3115' FEL, Sec 6, TION, R3E, UM Top of Productive Interval: 4260' FNL, 1847' FEL, Sec 30, T1 IN, R3E, UM Total Depth: 4802' FNL, 1732' FEL, Sec 13, T11N, R2E, UM 8. Date TO Reached: 1/24/2019 16. Well Name and Number: MT6-02 9. Ref Elevations: KB: 89 GL: 37 . BF: 17. Field / Pool(s): Greater Mooses Tooth UnidLookout Pool . 10. Plug Back Depth MD1 VD: N/A 18. Property Designation: AA 81818, 92346, 81798, 92345, 81743 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317115 y- 5945564 • Zone- 4 TPI: x- 318516 y- 5952070 Zone- 4 Total Depth: x- 313890 y- 5962204 Zone- 4 11. Total Depth MD/1VD: , 2222817834 ' 19. DNR Approval Number: 932563. 340761. 932533, 340760 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD1TVD: 1198/1189 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) I 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Density/CBL 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH ND CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20 94 H-40 37 115 37 115 42 10 yds 13.375 68 L-80 36 2080 36 2020 16 1101 sx 11.0ppg, Class B, 352 sx 15.8ppq Class G 9.625 40 L-80 34 8742 34 7070 12.25 239 sx 12.2ppg, Class G 7 26 L-80 32 mg 1105 32 4 �0 8.75 263 sx 15.8ppg, Class G 4.5 12.6 L-80 14966 20905 V'Fli 7895 7857 y rL., 6 Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: 14917-20905 MD and 7895-7857...1129/2019 COMPLETION 2�(Y � %ARIFED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD1 VD) 41/2 10909 10897/7888 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? n Yes E]No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): INJECTION ONLY - NOT PRE -PRODUCED Date of Test: Hours Tested: 113roduction for Test Period Oil -Bbl: Gas -MCF: Water-Bbl:Choke Size: Gas -Oil Ratio: Flow Tubing P Casino Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 V'T-L -f/IL//17/ OONTINUED ON PAGE 2 Submit ORIGINAL only ,fid 1/RBDMS�"MAR 211019 .s� Yip a STATE OF ALASKA n ALAS*&WI&AND GAS CONSERVATION COMMISSION WELL COMPLET101 PR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil❑ Gas❑ SPLUG ❑ 17 Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110W GINJ❑ WINJ❑ WAG❑✓ WDSPL❑ No. of Completions: 1b. Well Class: Development , N>: Exploratory ❑ Service [21 Stratigraphic Test F_] 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 2/13/2019 14. Permit to Drill Number/ Sundry: 218-160 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 12/22/2018 15. API Number: 50-103-20792-00-00 4a. Location of Well (Governmental Section): Surface: 239' FNL, 3115' FEL, Sec 6, TION, R3E, UM Top of Productive Interval: 4260' FNL, 1847' FEL, Sec 30, T11 N, R3E, UM Total Depth: - f./�N, .z,' 11321 (f.EW 1s+FNL, 2406' FEL, Sec 13, T1 IN, R2E, UM 8. Date TD Reached: 1/24/2019 16. Well Name and Number: MT6.02 9. Ref Elevations: KB: 89 GL: 37 BF: 17. Field / Pool(s): Greater Mooses Tooth Unit/Lookout Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: AA 81818, 92346, 81798, 92345, 81743 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317115 y- 5945564 Zone- 4 TPI: x- 318516 y- 5952070 Zone- 4 Total Depth: x- 313890 y- 5962204 Zone- 4 11. Total Depth MD/TVD: 22228/7834 19. DNR Approval Number: 932563. 340761. 932533, 340760 12. SSSV Depth MDlrVD: N/A 20. Thickness of Permafrost MD(rVD: 1198/1189 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: I N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Density/CBL 23. CASING, LINER AND CEMENTING RECORD WT. PER CASING FT GRADSETTING DEPTH MD SETTING DEPTH TVD E HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20 94 H-40 37 115 37 115 42 10 yds 13.375 68 L-80 36 2080 36 2020 16 1101 sx 11.0ppg, Class B, 352 sx 15.8ppq Class G 9.625 40 L-80 34 8742 34 7070 12.25 239 sx 12.2ppg, Class G 7 26 L-80 32 7885 32 6454 8.75 263 sx 15.8ppg, Class G 4.5 12.6 L-80 10897 19391 7888 7904 6 Slotted Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/TVO of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: COMPLETION 11723.19391 MD and 7932-7904 D • E 2 ( V (l RIFT 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDITVD) 41/2 10909 10897/7888 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27, PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): INJECTION ONLY - NOT PRE -PRODUCED Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API (torr): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 RBDMS Submit ORIGINAL only MAR 191019 28. CORE DATA Conventional Core(s): Yes ❑ No 2 • Sidewall Cores: Yes ❑ No 21 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1198 1189 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 11000 7897 information, including reports, per 20 AAC 25.071. Formation @ TPI -Alpine C C-30 2144 2078 C-10 2574 2455 K-3 3702 3406 K-2 4025 3669 Albian 96 4479 4218 HRZ 8361 6797 LCU 6264 7406 Top Alpine C 10714 7872 TO 22228 7834 Formation at total depth: ALPINE 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, paleontological report. oroduct on or well test results. per 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: Andrew Beat Authorized Title: Alaska Drilling Manager Contact Email: andrew.t.beatatco .cem Authorized /n� Contact Phone: 265-6341 Signature: lel. Date: 3llei I Z-0 It 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 form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, Fluid composition, Fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Page 1 of 1 TOO at best 300' MD �� 4'A" 12M L-66 Te Slue above Packer a 8W vVnn Parr Pup. MD .bwa mpm. C. Sidetrack Point MTS-02LI Plonnae V U., Tao. 11,728' MO / 7.932' TVD 10.530' MD / 7,888' TVD Top Alpine C 11,000 M0 r 7.097' TVD 7- n ppr Lao MTB -02 TD 22.228' MD / 7,834' TVD FnbrVery 7019 - AT9 file:///S:/ANC/Longterm/Drilling%20&%20 W ells%200ps/Alpine/MT6/MT6-02%D20(E)/S... 3/19/2019 96• re pp? HMO m.mafae Canaueter 80 feet. pamentad to rurlaw 13-3/8" 88 ppf L-80 T%PISTCM euHaaa C.alnp a 1!]" 110 ppf L-10 Ten.08 114. 9 ye" 40 ppf L40 T)(P (to -0,980' MD) 0 0/8" e0 ppf TN -80 H8 T%P (to TO) TOO at best 300' MD �� 4'A" 12M L-66 Te Slue above Packer a 8W vVnn Parr Pup. MD .bwa mpm. C. Sidetrack Point MTS-02LI Plonnae V U., Tao. 11,728' MO / 7.932' TVD 10.530' MD / 7,888' TVD Top Alpine C 11,000 M0 r 7.097' TVD 7- n ppr Lao MTB -02 TD 22.228' MD / 7,834' TVD FnbrVery 7019 - AT9 file:///S:/ANC/Longterm/Drilling%20&%20 W ells%200ps/Alpine/MT6/MT6-02%D20(E)/S... 3/19/2019 WNS INJ WELLNAME MT6-02 WELLBORE MT6-02 91Iti..'°. Well Attributer Max AngleP TD COIIOCUPI(ll(PS L'oNama We11WreAPVVwI WeIIWreSww- cl(°1 Mb(n, FCIBim('KBI Alaska. Inc. LOOKOUT 5010320]9200 INJ 5.15 197217o 22228.0 NIPPLE AST WO MTafQ, MYA1p 13714 PM Last Tag VV 1ecM,umc(.., Annotation hapM(nXa) EM Oe1e porkI Lim Mon By ................................ ..__.._.._... _... 1.1111, ................. EAST TAG j,dermin HA .A m.9- Last Rev Reason Annopen end pate WeIIW,e Lxuynon, REV REASON: PostRig Well Work D182019 I IV6-02 pennon 1__111_.... 1111.._._.... ............. Casing Strings Gslrg Donco kin Op III In (in) Top"won eel Depth (one) per "Wit rr... WULen n... G,atle Top Tho,xi """"""""""""""""'..""""""" ""' " " "" " CONDUCTOR 20 19.12 36.8 115.0 115.0 9400 H40 Welded Cuing Oeacriplion On lin) In in) Top ME) SN Extra IME) sN peMn lrvp)... wNLen 11... GrMe Top IDreatl SURFACE 133/8 12.40 36.0 2,080A 2,0202 6800 L$0 TXP CUInp Oucriplion OO lin) 10 (in) Top ME) SN Depth LMB) ant Gptn )10)11. L'NLxn n... GrMe Tap iM1rntl INTERMEDIATE 9518 8.84 343 8,7425 7,0704 40.00 TN$0 TXP CONEUCTON�E. at 150 I hnnuh, iNiNfine[d�ID6 Gain, D.Hinien OD (in) IO (in) TIE BACK STRING 7 6.18 Top(MB) SNMp1cti SN Dep+n)111)1,, Y1pbn 0...GMe Tap TM1rotl 32.3 2.885.1 6.453.9 29.00 T.H563 GSInp Oescnption 00(in) ID gn) Top(MB) BM Depth MRS) S=LD.pin lrv0)... p1BLen EL..OMe Topmuewl , aLtNA1p Annum vera-o.ax'. p2.0 INTERMEDIATE 2 SDE 7 628 2,8724 11,0599 2,9022 32.00 L.80 Tenaria Blue ynWOL+YN19 Casing Description 00(in) 10(n) Top(MaI SN opth lane) Set coast IND)...- ll...Orade Tap TM1eaa LINER 4112 396 10.897.7 19,3910 7,9042 1260 L-80 TXP NWPLE: 2=ri Liner Details NomIa110 INJECTIONVALVE:2=8 Top Me) Top(NO)MLB) Top Incl(') Ilam On com nin iopaA E:33az0e04 10,8977 7,888.1 84.91 PACKER HRDE ZXP 575' SBE (16.10') 5000 10,924.2 7,890.5 84.90 HANGER 4-12" x T'Flex Lack Hgr 11521 Box x TXP Pin 3.875 Anwr 1.-s.I Exi 11,9973 7,924.2 92.88 CROSSOVER X0412' TXP B x Wi P, 12611, LA0 3.958 xo+D.ma.a: vinmle 119992 7924.1 92.90 EXTERNAL Swell Packer Baker Water Expanding Elastemer 3.958 CASING PACKER TIEWKSTelxvaxs- 12,019.3 2,923.0 93.01 CROSSOVER X04112" 563 B x TXP P, 12 6# L-80 3958 a9 l Tubing Strings Tubme 0=e=npnon soma Ma... m lip rot nxe set Depra In.. sn Deptn IrvOI P. wgllunl Grade rot Cannecpon TUBING WATER 4 V2 396 28.9 10908.2 2,889.1 12 fi0 L -BO Tblue NJECTION Completion Details Top (Tom) Top m=l Nominzl INTERMEDIATE; aa.aa,l4zs Top(mc8) MCB) 1°) uem Dea com to np 8. HANGER FMC 4-12°Tubing Hanger 3958 2027.8 1,9725 2458 NIPPLE 3813" X LANDING NIPPLE, TSH Blue 3813 9,8432 7,6813 68.11 INJ x - Comm ell pinned for 2000 3865 Ixa: e.e4as psi mg, to big shear, TSH Blue @ 682- @ 9.849'MD 7,683' TVD 10,0289 7.7443 72.11 NIPPLE 3.813" XN LANDING NIPPLE wl3725" NOLO, TSH Blue 3725 MPPlel Maza.9 10,8934 78877 84.91 LOCATOR Locator No -Go 575"OD 3930 10°8944 7,887.8 IN 91 SEALASSY Seal Assembly 39M LOCPTOR: Mardi Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tnv.) mpon To(one) rl I; ons com Nun pate eaAL nese +oee4a 2,027.8 1985 2.W1 24.58 MJ CT1 N 3.813"XLock6A-1 Injection Valve (SINHRS-66) 2/18/2019 1250 I VALVE Mandrel Inserts sd kneveEgATE 2 SDLi.!Z4 ® 1.059.9 N rop(XKeI Top;IVO) (NIMake Model 00 (In) 9ery VdNe Tow GttM1 type PoX8i2a TRO lin) flan Ipso Nun Pate Coo. in 1 9,8432 7681.3 LammKBG2 i GAS UFT DMV BK 2h&2019 so Notes: General & Safety End pale annotation NOTE LINER t0,P8l.T-19=9� WN$ INJ WELLNAME MT6-02 WELLBORE MT6-02L1 ConocoPhillips Alaska, Im Mr6ceLl. sRazm9,3o,. PM Casing Strings vuWlvlwmeclxti+p L-S'D—o'lmn LINER oo M) 012 m(IS 3.96 IT (NN9) 14,8963 see Geoln (ltKe) Sel Gepm trvG)... Men lL_Goee 20,9050 12.60 IL40 Tne rnrcaa TXP ............................................_.............................................. N9NGER:49 Liner Details xoml al l0 ToP rytNP) Top1NG)IXNP Top IMl1°) Ibm OGs Gom lin) ......._.............._......................_............ .. .........._. 14,896.3 )9399 91.05 HANGER HROE Lip61 SSM!" Sleeve 4200 149120 )9396 91.29X05 -H521 Pinx 4TO' TXP PIn 3.959 REDUCING LONOIILTOR�361+60 �^ Wnib FQY�-dash: m.0 MnW FLM-daN:A0. ye3oo', v+vzole : ? INJECDONNIPPI-Ev0.YE:? .. VALW SURFACE; 3663 M4 Pmubr Rmq-& .Alnm: 9G.0M.p .i/.. TIE PACK STRING. W S. 'GRIT INTERMEDIATE: 91.88,7028 INJ: S.M2 NIpPLE:Io... LOCATOR; 10 M4 VAL ASSY; IO,894d INTERMEOWTE25O1;7.812.1 039 LINER:1 O,3'.'-I9,MJ,9� lE�r V LINER,14. RRI Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depdr Stmt Time I End Tmle our (hr) Phase Op Code Activhy Code 71m PJ -X Operatlan (110) End Deplh(aKB) 12/22/2018 12/22/2018 8.00 MIRU MOVE MOB P Spot MPD equipment in cellar. Move 0.0 0.0 00:00 08:00 sub over well. Skid rig floor. Spot pits & motors complex. 12/22/2018 12/22/2018 2.00 MIRU MOVE MOB P Connect service lines & spot ball mill. 0.0 0.0 08:00 10:00 12/22/2018 12/22/2018 2.00 MIRU MOVE RURD P Accept dg & finalize rig acceptance 0.0 0.0 10:00 12:00 - check list. 12/22/2018 12/22/2018 5.00 MIRU MOVE RURD P Connect service lines. Rig on high line 0.0 0.0 12:00 17:00 @ 14:00 Hrs. N/U slip lock adaptor. N/U riser & flow line. Hook up bleeder & hole fill lines. Take on spud mud. 12/22/2018 12/22/2018 0.50 MIRU MOVE BHAH P Bring BHA tools & equipment to dg 0.0 0.0 17:00 17:30 floor. 12/22/2018 12122/2018 3.00 MIRU MOVE BHAH P M/U & rack back NMFC. M/U mud 0.0 115.0 17:30 20:30 motor, MWD, & UBHO & scribe as per Baker reps. MIU 1 stand of HWDP. 12/22/2018 12/22/2018 0.50 MIRU MOVE SFTY P Pre -Spud Meeting 115.0 115.0 20:30 21:00 12/22/2018 12/22/2018 0.50 MIRU MOVE RURD P Make final lap around rig. Double 115.0 115.0 21:00 21:30 check dg up. Install 4" valve on conductor. 12/22/2018 12/22/2018 0.25 MIRU MOVE SEOP P Fill riser w/spud mud & check for 115.0 115.0 21:30 21:45 leaks. Test surface equipment to 3500 psi (good) 12/2212018 12/22/2018 0.25 MIRU MOVE REAM P W&R to base of conductor @ 115' 115.0 115.0 21:45 22:00 w/525 gpm, 650 psi, 40 rpm, 2 k trq. 12122/2018 12/23/2018 2.00 SURFAC DRILL DDRL P Drill ahead f1115'to 184' MD / 184' 115.0 184.0 22:00 00:00 TVD, ADT .7 Hrs, 525 gpm, 700 psi, PU wt 77 k, SO wt 74 k, ROT wt 75 k, 40 rpm, Trq On/Off 3/2 k ft/Ibs 122312018 12123/2018 12.00 SURFAC DRILL DDRL P Drill ahead f/184'to 1,320' MD / 1,308' 184.0 1,320.0 00:00 12:00 TVD, ADT 8.6 Hm, ECD 10.48 ppg, 750 gpm, 2080 psi, PU wt 107 k, SO wt 107 k, ROT wt 107 k, 60 rpm, Trq On/Off 3/1.5 k ftllbs 12/23/2018 12/23/2018 8.50 SURFAC DRILL DDRL P Drill ahead 111,320'to TD of 2,090' 1,320.0 2,090.0 1200 20:30 MD / 2,029' TVD, ADT 7.5 Hrs, ECD 10.8 ppg, 900 gpm, 2750 psi, PU wt 117 k, SO wt 112 k, ROT wt 115 k, 60 rpm, Trq On/Off 3/1.5 k ff/Ibs 1223/2018 12/232018 0.25 SURFAC CASING CIRC P Pump sweep & circ hole clean for 1 2,090.0 2,090.0 20:30 20:45 B/U w/900 gpm, 2670 psi, 40 rpm, 2 k trq 1223/2018 1223/2018 0.25 SURFAC CASING OWFF P F/C(static) 2,090.0 2,090.0 20:45 21:00 12232018 1224/2018 3.00 SURFAC CASING BKRM P BROOH f/2,090'to 1,203'w/900-525 2,090.0 1,203.0 21:00 00:00 gpm, 2620 - 970 psi, 40 rpm. 3 k trq. Steady flow of cuttings on shakers. Pumped sweep @ 1,500' 12/24/2018 12/242018 1.75 SURFAC CASING BKRM P BROOH f/1,203'to 547'w/525 gpm, 1,203.0 547.0 00:00 01:45 900 psi, 40 rpm. 1.5 k trq. Steady flow of cuttings on shakers. 12/24/2018 12/242018 1.25 SURFAC CASING PMPO P Pump OOH f/547' to 180'w/300 gpm, 547.0 180.0 0145 03:00 420 psi (Rack back HWDP & Jars) 12/24/2018 12/24/2018 0.50 SURFAC CASING BHAH P Rack Back NMFC's (retrieve gyro tool) 180.0 91.0 03:00 03:30 1 1 1 f/180'to 91' 12/242018 12/24/2018 0.50 SURFAC CASING CIRC P Pump 30 bbl nut plug ddll zone sweep 91.0 91.0 03:30 04:00 to clean up BHA 12/242018 12/242018 1.75 SURFAC CASING SHAH P UD BHA as per Baker reps U91' 91.0 0.0 04:00 05:45 12/242018 1224/2018 1.25 SURFAC CASING BHAH P Clean & Gear floor of BHA tools & 0.0 0.0 05:45 07:00 equipment. Page 1/29 Report Printed: 2119/2019 Operations Summary (with Timelog Depths) Ad11 ft"L, I P MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sean Depth Stmt-hme End Time Our (hr) Phase Op Code AcWy Cade Time P-T-X Operabon (ftKB) EM Depth (ta(B) 12/24/2018 12/24/2018 3.00 SURFAC CASING RURD P Mobilize casing tools & equipment to 0.0 0.0 07:00 10:00 rig floor. R/U to run casing. R/U Volant & casing tongs, slips & elevators. 12/24/2018 12124/2018 6.00 SURFAC CASING PUTB P WU shoe track & check floats (good). 0.0 1,262.0 10:00 16:00 RIH w/13-3/8" 68# L-80 BTC/TXP casing to 1,262'. 12/24/2018 12/24/2018 0.50 SURFAC CASING CIRC P Break circ @ base of perfafrost w/6 1,262.0 1,262.0 16:00 16:30 1 1 1 bpm, 100 psi. 12/24/2018 12/24/2018 2.00 SURFAC CASING PUTS P RIH w/13-3/8"68# L-80 BTC/TXP 1,262.0 2,042.0 16:30 18:30 casing 1/1,262' to 2,042' 12/24/2018 12/24/2018 0.50 SURFAC CASING HOSO P M/U landing jt & land casing on 2,042.0 2,080.0 18:30 19:00 hanger @ 2,080. PU wt 185 k / SO wt 150 k 12/24/2018 12/24/2018 2.00 SURFAC CEMENT CIRC P Circ & cond mud for cement job w/8 2,080.0 2,080.0 19:00 21:00 bpm 1130 psi. Reciprocate pipe. (PU wt 170k/SO wt 155 k) 12/24/2018 12/24/2018 0.50 SURFAC CEMENT RURD P BID top drive. R/U thru cement lines. 2,080.0 2,080.0 21:00 21:30 Clean suction screens on mud pump. 12/24/2018 12/24/2018 0.50 SURFAC CEMENT CIRC P Break circ lhru cement lines w/6 bpm, 2,080.0 2,080.0 21:30 22:00 300 psi. PJSM on cementing. 12/24/2018 12/25/2018 2.00 SURFAC CEMENT CMNT P Dowell pump 2.1 bbis H2O & PT to 2,080.0 2,080.0 22:00 00:00 3500 psi (good). Dowell pump 100.1 bbis 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 300 bbis 11.0 ppg 1.95 ft31sx yield LiteCRETE lead cement w/5 bpm, 250 psi at report time 12/25/2018 12125/2018 1.50 SURFAC CEMENT CMNT P Dowell cont. to pump total of 382.5 2,080.0 2,080.0 00:00 01:30 bbis 11.0 ppg 1.95 ft3lsx yield LiteCRETE lead cement and 72.7 Dials 15.8 ppg 1.16 ft3/sx yield tail cement @ 5 bpm. Drop top plug. Dowell pump 20 bbis H2O. Rig displace with 279.6 bbis 12,798 stks 10 ppg DrillPlex with 8 bpm / 700 psi. Reduce pumps to 3 bpm /400 psi. last 10 bbis. Bump plug, pressure 500 psi over to 900 psi for 5 min. Check floats. F/C good. CIP @ 1:29 Hrs. Calculate 150 bbis good cement to surface. Full returns & reciprocated pipe during cementjob. 12/25/2018 12/25/2018 2.00 SURFAC CEMENT RURD P Flush riser w/black water. RID Volant 0.0 0.0 01:30 03:30 & casing running tools & equipment. UD landing jl. 12/25/2018 1225/2018 2.50 SURFAC CEMENT NUND P RID bleeder & hole fill lines. RID 0.0 0.0 03:30 06:00 surface riser asst' SIMOPS - clean pits. 12/252018 1225/2018 2.50 SURFAC WHDBOP NUND P N/U speed lock head adaptor.. NIU 0.0 0.0 06:00 08:30 well head & test to 1000 psi for 10 min (good). SIMOPS - clean pits. 1225/2018 12/25/2018 3.50 SURFAC WHDBOP NUND P N/U SOPE & N/U choke/kill lines. 0.0 0.0 08:30 12:00 1 1 SIMOPS - clean pits. 1225/2018 12/25/2018 4.00 SURFAC WHDBOP MPDA P N/U RCD clamps & orbit valve. NIU 0.0 0.0 12:00 16:00 flow line & flow box. Install annulus valves. Obtain RKB's. Install trip nipple. Install KatchKan. 1225/2018 1225/2018 2.00 SURFAC WHDBOP MPDA P R/U lest equipment. Test MPD 0.0 0.0 16:00 18:00 equipment 250/1500 psi. RID testing equipment & in stall trip nipple. SIMOPS - M/U choke & flare lines. 12/25/2018 12/25/2018 1.50 SURFAC WHDBOP RURD P RIU to test BOPE. Install test plug. Fill 0.0 0.0 18:00 19:30 1 1 1 1 stack w/1120. Purge air from system. Page 2/29 Report Printed: 2119/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time DW(hr) Phase Op Code Actively Code Time P -T -x Operation (IMB) End Depth(MKB) 12/25/2018 12/2612018 4.50 SURFAC WHDBOP BOPE P Test BOPE w/5 test joint. Annular 250 0.0 0.0 19:30 00:00 psi for 5 min / 2500 psi for 10 min, Remaining test 250 psi for 5 min / 3500 psi for 10 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper/lower 3-112" X 6" VBR's, 5" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 2,950 psi, final 1,500 psi, 1st 200 psi recharge = 31 sec's, full recharge = 162 seconds. Nitrogen Bottles x4 = 2,175 psi. Gas alarms and PVT alarms tested. 12/26/2018 12/26/2018 0.50 SURFAC WHDBOP ROPE P Test blind rams. Perform poorboy gas 0.0 0.0 00:00 00:30 buster flush. Draw down on chokes t/1100 psi. AOGCC Lou Laubenstein & BLM Mutasim Elganzoory waived witness. 12/26/2018 12/26/2018 1.50 SURFAC WHDBOP RURD P B/D choke, kill lines & mud lines. R/D 0.0 0.0 00:30 02:00 BOPE testing equipment. Retrieve test plug. Install wear ring. UD running tools. 12/26/2018 12/26/2018 2.00 SURFAC CEMENT SHAH P M/U 12-1/4" Intermediate#1 BHA as 0.0 620.0 02:00 04:00 1 1 per Baker reps. (up -Load MWD) 12/26/2018 12/26/2018 2.00 SURFAC CEMENT TRIP P RIH f/620'to 1,743' 620.0 1,743.0 04:00 06:00 12/26/2018 12126/2018 1.00 SURFAC CEMENT CIRC P Circ B/U w/250 gpm, 200 psi, Thick 1,743.0 1,743.0 06:00 07:00 cement contaminated mud. SIMOPS- PJSM on slip & cut. 12/26/2018 12/26/2018 1.00 SURFAC CEMENT SLPC P Slip & cut drill line 1,743.0 1,743.0 07:00 08:00 12/26/2018 12126/2018 0.50 SURFAC CEMENT SVRG P Service rig & drawworks. 1,743.0 1,743.0 08:00 08:30 12/26/2018 12126/2018 0.25 SURFAC CEMENT DHEQ P Shallow hole test MWD w/800 gpm, 1,743.0 1,743.0 08:30 08:45 1640 psi 12126/2018 12/26/2018 2.00 SURFAC CEMENT PRTS P R/U to test casing. Pressure test lines 1,743.0 1,743.0 08:45 10:45 to 2700 psi. Test casing to 2500 psi & chart for 30 min (good), R/D testing equip. 12/26/2018 12126/2018 0.25 SURFAC CEMENT TRIP P RIH f/1,743'101,932' 1,743.0 1,932.0 10:45 11:00 12/26/2018 12/26/2018 5.00 SURFAC CEMENT DRLG P Drill float collar, shoe track, & rat hole 1,932.0 2,090.0 11:00 16:00 to 2,090'w/500 gpm, 720 psi, 50 rpm, 3 - 6 k trq. Circ out thick contaminated mud. Float collar & shoe track on depth. 12/26/2018 12/26/2018 0.25 SURFAC CEMENT DDRL P Drill 20' new formation f/2,090' to 2,090.0 2,110.0 16:00 16:15 2,110' MD / 2,047' TVD, ADT. 25 Hrs. Start displacing to new 9.5 ppg LSND 12126/2018 12/26/2018 0.75 SURFAC CEMENT DISP P Cont. to displace to new 9.5 ppg 2,110.0 2,027.0 16:15 17:00 LSND w/550 gpm, 800 psi, 60 rpm, 5 k trq. BROOH f/2,110' to inside 13-318" casing shoe at 2,027' 12/26/2018 12/26/2018 0.75 SURFAC CEMENT FIT P FIC. R1U testing equipment. FIT to 2,027.0 2,027.0 17:00 17:45 18.5 ppg. (957 psi @ 2,046' TVD M/9.5 ppg mud) RID tetsing equipment 12/26/2018 12126/2018 0.50 INTRM1 DRILL REAM P Install 5.57' ghost reamer in stand #16 2,027.0 2,110.0 17:45 18:15 @ 2,062' behind bit. SPR's W&R f/2,027'to 2,110' 12126/2018 12127/2018 5.75 INTRM1 DRILL DDRL P Drill ahead f/2,110'to 2745' MD / 2,110.0 2,745.0 18:15 00:00 2,598' TVD, ADT 3.95 Hrs, ECD 10.12 ppg, 850 gpm, 1370 psi, PU wt 130 k, SO wt 120 k, ROT wt 125 k, 140 rpm, Trq On/Off 5/2 k KAbs, 5/10 k wob. Page 3129 Report Printed: 2119120191 . Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sten Depth Start Thno End Time Our(hr) phew Op cotle N Ity CM. Tim P -T -X Operation (MKB) EM Depth (19<13) 12/27/2018 12/27/2018 9.75 INTRMI DRILL DDRL P Drill ahead f/2745'to 4,103' MD / 2,745.0 4,103.0 00:00 09:45 3,729' TVD, ADT 7.6 Hrs, ECD 10.4 ppg, 920 gpm, 2000 psi, PU wt 154 k, SO wt 135 k, ROT wt 140 k, 150 rpm, Trq On/Off 8/3.5 k f/lbs, 10 k wob. 12/27/2018 12/27/2018 0.75 INTRMI DRILL CIRC P Circ B/U w/920 gpm, 2050 psi, 50 4,103.0 4,103.0 09:45 10:30 rpm, 3.5 k trq. (Install 7.32' ghost reamer in stand #37 @ 4,044" behind bit). 12/27/2018 12/27/2018 1.50 INTRMI DRILL DDRL P Drill ahead f/4,103'to 4,172' MD/ 4,103.0 4,172.0 10:30 12:00 3,782' TVD, ADT 1.0 Hrs, ECD 10.2 ppg, 920 gpm, 2000 psi, PU wt 154 k, SO wt 135 k, ROT wt 140 k, 150 rpm, Trq On/Off 8/3.5 k f albs, 10 k wob. 12/27/2018 12/28/2018 12.00 INTRMI DRILL DDRL P Drill ahead F/ 4172' To 5764'md / 4928 4,172.0 5,764.0 12:00 00:00 TVD, ADT 9.2 hrs, ecd 10.5 ppg, 922 gpm 2280 spp, Flu wt 190, S/O 150, rot wt 155, rpm 150, lorq on 10.5k torq off 6/8 k, wob 15k, 12/28/2018 12128/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/5,764'to 7,057' MD / 5,764.0 7,057.0 00:00 12:00 5,857' TVD, ADT 9.1 Hrs, ECD 10.54 ppg, 925 gpm, 2360 psi, PU wt 200 k, SO wt 160 k, ROT wt 165 k, 150 rpm, Trq On/Off 15/7 k fUlbs, 25 k wob. 12/28/2018 12/28/2018 10.50 INTRMI DRILL DDRL P Drill ahead F/ 7057'to 8162' MD / 7,057.0 8,162.0 12:00 22.30 6,653' TVD, ADT8.5 hrs, ECD 10.37 ppg, 955 gpm, 2560 psi, PIU wt 225 k, SIO wt 200 k, ROT wt 175 k, 150 rpm, Trq ONOff 18/8 k/fUlbs, 25 k wob 12/28/2018 12/29/2018 1.50 INTRMI DRILL CIRC P Circ & cond mud while waiting up to 8,162.0 8,162.0 22:30 00:00 10.5 ppg w/spike fluid w/950 gpm, 2560 psi 12/29/2018 12/29/2018 6.00 INTRMI DRILL CIRC P Cord to circ & cond mud while waiting 8,162.0 8,162.0 00:00 06:00 up to 10.5 ppg w/spike fluid w/Initial 950 gpm, 2500 psi, Final 850 gpm, 2550 psi. 12/2912018 12/29/2018 0.50 INTRMI DRILL MPDA P F/C. PJSM. Remove trip nipple & 8,162.0 8,162.0 06:00 06:30 install RCD bearing. Break in bearing as per MPD advisor. 12/29/2018 12/2912018 5.50 INTRMI DRILL DDRL P Drill ahead f/8,162'to 8,556" MD / 8,162.0 8,556.0 06:30 12:00 6,937' TVD, ADT 3.7 Hrs, ECD 11.3 ppg, 950 gpm, 3200 psi, PU wt 260 k, SO wt 160 k, ROT wt 200 k, 150 rpm, Trq On/Off 14/13 k ff/lbs, 25 k wob. MPD connections 12/29/2018 12/29/2018 7.50 INTRMI DRILL DDRL P Drill ahead (/8,556' to 9026" MD / 8,556.0 9,026.0 12:00 19:30 7261' TVD, ADT 5.4 Hrs, ECD 11.06 ppg, 960 gpm, 3270 psi, PU wt 275 k, SO wt 170 k, ROT wt 200 k, 150 rpm, Trq On/Off 18/13 k ft/lbs, 25 k wob. MPD connections 12/29/2018 12/29/2018 3.00 INTRMI CASING CIRC P Pump sweep & circ hole clean for 2 9,026.0 9,026.0 19:30 22:30 B/U w/950 gpm, 2370 psi, 150 rpm, 13 k trq. 12/29/2018 12/2912018 0.25 INTRMI CASING OWFF P F/C(static) 9,026.0 9,026.0 22:30 22:45 12/29/2018 12/29/2018 0.75 INTRMI CASING CIRC P Spot 135 bbls 11.2 ppg across HRZ, 9,026.0 9,026.0 22:45 23:30 and 10 bbls in drill pipe. SIMOPS - Line up MPD equipment to strip out of hole. 12/29/2018 12/3012018 0.50 INTRM1 CASING SMPD P StripOOH f/9,026'to 8,917' as per 9,026.0 8,917.0 23:30 00:00 1 1 1 1 MPD schedule Page 4129 Report Printed: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Smrt Depth Start Tone End Tone Dur (hr) Phase Op Code Activity Code Time P-T-X Cperation (RKB) End Deplh (flK8) 12130/2018 12130/2018 4.50 INTRMI CASING SMPD P StripOOH f/8,917'to 6,184'as per 8,917.0 6,184.0 00:00 04:30 MPD schedule. Work light hole with no improvement. 12/30/2018 1213012018 0.25 INTRMI CASING TRIP T RIH f/6,184'to 6,277' 6,184.0 6,277.0 04:30 04:45 12/30/2018 12/30/2018 1.75 INTRMI CASING CIRC T Circ 2X B/U w/950 gpm, 2670 psi, 120 6,277.0 6,277.0 04:45 06:30 rpm, 9.5 k trq. Start to observe psi increase & MPD chokes were packed off with cuttings. 12/30/2018 12130/2018 0.25 INTRM1 CASING OWFF P FIC (static). Mobilize trip nipple to rig 6,277.0 6,184.0 06:30 06:45 floor. 12/3012018 12/30/2018 0.75 INTRMI CASING MPDA P Pull RCD bearing & install trip nipple. 6,277.0 6,184.0 0645 07:30 Rack back 1 stand f/6,277'to 6,184' 12/30/2018 12/30/2018 4.50 INTRMI CASING BKRM P BROOH f/6,184' to 3,444'w/900 gpm, 6,184.0 3,444.0 07:30 12:00 2390 psi, 120 rpm, 9 k trq. 12/30/2018 12/30/2018 7.25 INTRMI CASING BKRM P BROOH 0,444'to708' w/950-925 3,444.0 708.0 12:00 19:15 gpm, 2390 - 2025 psi, 120 - 60 rpm, 9 - 5 k trq. Once BHA was at 2,800' started having issues with hole packing off and caving's across shakers. Once BHA was inside casing shoe hole un-loaded softball size caving's & continued all the way to the BHA. 12/30/2018 12/30/2018 0.25 INTRMI CASING CIRC P Pump nut plug sweep &circ casing & 708.0 708.0 19:15 19:30 BHA clean. Hole un-loaded medium size cuttings & clay. 12/30/2018 12/30/2018 0.25 INTRMI CASING OWFF P FIC (static). SIMOPS - function rams 708.0 708.0 19:30 19:45 12/30/2018 12/3012018 1.50 INTRMI CASING TRIP P POOH f/708'to 160'. Racked back 708.0 160.0 19:45 21:15 HWDP & Jars. L/D 2 jts HWDP not needed for next hole section. 12/30/2018 12/30/2018 1.00 INTRMI CASING BHAH P UD BHA as per Baker reps. 160.0 0.0 21:15 22:15 12/30/2018 12/30/2018 0.50 INTRMI CASING BHAH P Clean & clear floor of BHA tools & 0.0 0.0 22:15 22:45 equipment. 12/30/2018 12/30/2018 0.75 INTRMI CASING WWWH P Pull wear ring & M/U Johnny Wacker 0.0 0.0 22:45 23:30 & flush stack. 12/3012018 12/31/2018 0.50 INTRM1 CASING RURD P Drain stack. Close blind rams. Prep to 0.0 0.0 23:30 00:00 C/O rams. 12/31/2018 12/31/2018 1.00 INTRMI CASING BOPE P PJSM-Change out upper pipe rams to 0.0 0.0 00:00 01:00 9 5/8". Set test plug & R/U to test ROPE. SIMOPS - Clean & clear floor. Mobilize casing running tools to rig Floor. 12/31/2018 12/31/2018 1.50 INTRMI CASING BOPE P Test BOPE w/9-5/8" test jt. Annular 0.0 0.0 01:00 02:30 preventer to 250 for 5 min 112500 psi for 10 min. Test upper pipe rams to 250 for 5 min / /3500 psi for 10 min. 12/31/2018 12/31/2018 0.50 INTRMI CASING BOPE P R/D testing equipment. Set 13.125" 0.0 0.0 02:30 03:00 wear ring. 12/31/2018 12/31/2018 2.00 INTRMI CASING RURD P R/U to run casing. R/U Volant, spider's 0.0 0.0 03:00 05:00 & elevators. 12131/2018 12/31/2018 7.00 INTRMI CASING PUTS P RIH 9-5/8" 40# TN-80 TXP casing 0.0 2,442.0 05:00 12:00 RIH T/ 2442' s/o 125k, @ 2080 (shoe) observed 20k s/o loss, establish circ @ 160 gpm, 3000 psi was through shoe 12/31/2018 12/31/2018 8.50 INTRMI CASING PUTB P RIH 9-5/8" 40# TN-80 TXP Casing 2,442.0 8,314.0 12:00 20:30 1 I I I f/2,442' to 8,314'. 12/31/2018 12/31/2018 2.25 INTRMI CASING PUTB T Wash down 9-5/8" 40# TN-80 TXP 8,314.0 8,717.0 20:30 22:45 1 f/8,317 to 8,719'w/3 bpm, 510 psi. Hole attempting to pack off Page 6129 ReportPrinted: 211912019 Operations Summary (with Timelog Depths) MT6-02 • Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stad'nme Erod Tma Dur(hr) Phase op Code Activit' Code Tore P -T -X Cpera5on (flKB) End Depth(N(B) 12/31/2018 111/2019 1.25 INTRMI CASING PUTB T Work tight hole & casing packing off. 8,717.0 8,717.0 22:45 00:00 Stage rate to 3.5 bpm, 400 psi. PU wt 390 k / SO wt 220 k 1/1/2019 1/1/2019 6.00 INTRM1 CASING PUTB T Work tight hole & casing packing off. 8,717.0 8,739.0 00:00 06:00 Stage rate to 3.5 bpm, 400 psi. PU wt 390 k I SO wt 220 k, continue working with tight hole & casing packing off to 8739' 1/1/2019 1/1/2019 1.00 INTRMI CASING CIRC T Circulate and gel pump rale up to 8,739.0 8,739.0 06:00 07:00 18bbVmin, circulate bottoms up 1/1/2019 1/1/2019 5.00 INTRMI CASING PUTS T Continue working with tight hole& 8,739.0 8,739.0 07:00 12:00 casing packing off to 8739' pump rates - Ibbl/min 190/240 psi, 2 bbl/min 260 psi, 3bbVmin 320 psi, 4.5 bbl/min =380 5bbVmin 350/380,6.6 bbl/min 360 psi 8 bbV min 420 psi, 1/1/2019 1/1/2019 4.00 INTRM1 CEMENT PUTS T Continue working with tight hole& 8,739.0 8,742.0 12:00 16:00 casing packing off , work with clean up hole f/ 8739 11 8751', circ.and regain rates, 336 gpm, 400 psi, 410/235k p/u 225 s/o, attempt to was down casing. ICP - 84 gpm, 105 psi, FCP 135 gpm, 210 psi, MW 10.5+ in, 10.6 out final depth 8742 111/2019 1/1/2019 1.00 INTRMI CEMENT CMNT P PJSM, rig up cement equip. test 8,742.0 8,742.0 16:00 17:00 cement lines @ 3900 psi. 111/2019 1/1/2019 2.00 INTRMI CEMENT CMNT P Mer and pump 60 bbls 12.5 ppg Mud 8,742.0 8,742.0 17:00 19:00 Push II, drop bottom plug, mix and pump 98 bbls class G 12.2 ppg lead cement, mix and pump 48.8 bbls, 15.8 tail cement, drop top plugs. (two plugs, regular NRP and HEWP) pump 20 bbls H2O 1/1/2019 1/1/2019 4.00 INTRMI CEMENT CMNT P Displace with dg pumps, pump 628 8,742.0 8,742.0 19:00 23:00 bbls mud @ 4bbls/min. 7 % returns, bottom plug bumped @ 4858 stks, sheared @ 460 psi, pump psi increased to 1850 psi @ 4984 stks pump @ 5002 stks pump rate reduced to 1/2 bbl/min 2030 psi. no returns. Notify drilling engineer, continue displacing cement, @ 1 bpm -3 bpm, 2500-3100 psi, no returns. Bumped plug @ 6380 stks, 110 bbls total lost ( pit strap). Pressure up to 3500 psi and hold 5 minutes. Cement in place @ 22:55 him 1/112019. 1/1/2019 1/1/2019 0.50 INTRM1 CEMENT OWFF P Bleed off psi check floats, float 8,742.0 8,742.0 23:00 23:30 holding, rig down cementing equipment. 1/1/2019 1/2/2019 0.50 INTRMI CEMENT RURD P Rig down and blow down cement 8,742.0 8,742.0 23:30 00:00 lines. 1/2/2019 1/2/2019 2.75 INTRMI CEMENT WOC T Waiting on cement to cure to 500 psi 8,742.0 8,742.0 00:00 02:45 compressive strength. SIMOPS-Load pipe shed with 84jts XT 39 4" 14# DP, Perform MP2's on rig equipment, Prep tools, equipment and review procedure for emergency slips, 1/2/2019 111212019 4.25 INTRMI CEMENT WOC T Continue WOC. 8,742.0 8,142.0 02:45 07:00 SIMOPS - PIU and rack back 28 stds 4" 14# DP in derrick , contingency for SDL inner string. Page 6129 ReportPrinted: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Shit Depth Start Time EM Time our (hr) phase Op Code AcbvM Code Tim P -T -x Operetim (fit®) End Depth (KKB) 1/2/2019 1/2/2019 4.00 INTRMI CEMENT WAIT T WOO from office regarding path 8,742.0 8,742.0 07:00 11:00 forward. SIMOPS- Continue to moblize tools and equipment for setting emergency slips, MP2'S, rig maintenance, clean work areas, monitor well on trip tank. Recieve orders to continue with setting slips on 9-5/8" casing. 1/2/2019 1/212019 0.25 INTRMI CEMENT OWFF T OWFF- Static, slight drop. 8,742.0 8,742.0 11:00 11:15 1/2/2019 1/2/2019 0.75 INTRMI CEMENT RURD T Drain stack, unsting Volant CRT F/ 8,742.0 8,742.0 11:15 12:00 casing, rig dwn trip nipple, prep stack for picking up. Total static loss 12 bbl for 12 hr. 1/2/2019 1/2/2019 1.75 INTRMI CEMENT RURD T Monitor annulus, (1 bbl loss) continue 8,742.0 8,742.0 12:00 13:45 preping stack F/ removal 1/2/2019 1/2/2019 2.25 INTRMI CEMENT CPBO T PJSM- Break well head install 8,742.0 0.0 13:45 16:00 emergency slips, (set 50k on slips) cut CSG, pull cut joint to floor, make final cut on mg per FMC, lay down cut joint (17.34' of joint #217), remove elevators, and bail extensions. 1/2/2019 1/2/2019 1.25 INTRMI CEMENT W WSP P Set slack down, pull wear bushing, set 0.0 0.0 16:00 17:15 9-5/8" pack off, run in lock down screws. 1/2/2019 112/2019 2.25 INTRM1 CEMENT NUND P PJSM - nipple down flow box, pick up 0.0 0.0 17:15 19:30 stack, install 7" well head spool, set stack down, & align tubing outlet to production flow line. 1/2/2019 1/2/2019 1.25 INTRMI CEMENT PRTS P Torque lower wellhead flange bolts, 0.0 0.0 19:30 20:45 Test packoff to 250 / 2500 psi F/ 10 min. CPAI witnessed (test good). 1/2/2019 1/2/2019 2.00 INTRMI CEMENT MPDA P Continue torque up bolts, Install flow 0.0 0.0 20:45 22:45 line, flow box, turn buckles, trip nipple and obtain new RKB's. SIMOPS- Clean casing equip. continue monitoring annulus, 1 bbl/hr loss 1/2/2019 1/3/2019 1.25 INTRMI WHDBOP RURD P Change out upper rams to 4%" x 7" 0.0 0.0 22:45 00:00 VBR's. SIMOPS- Rig down Volant CRT. Continue monitoring annulus. Total loss for lour -7 bbl static loss, total for day 19 bbl via 13-3/8"x9-5/8" annulus. 1/3/2019 1/3/2019 3.00 INTRMI WHDBOP RURD P Install 4.5 X 7" Upper VBR's, cln/clr rig 0.0 0.0 00:00 03:00 floor excess tools/equip., install min and trip nipple, tighten choke line connection, gtrease IBOP, B/D lines confirm dr, install Nur test plug, fill bop's and choke. monitor annulus - 3 bbls loss in 12 hr 1/3/2019 1/3/2019 4.00 INTRMI WHDBOP BOPE P Test BOPE with 3.5", 5" & 7" test jts. 0.0 0.0 03:00 07:00 AOGCC Brian Bixby waived witness. With 5" TJ, test annular preventer to 250/2500 psi for 5/10 min, 41/2" x 7" Upper VBR's, 3W" x 6" lower VBR's to 250/3500 psi for 5/10 min.Test 4" Demoo Kill valve, Auto and manual IBOP valves, HCR and Manual Choke and Kill valves, floor safety valves 2- XT39 and 1-NC50, Dart Valves 1- XT39 and 1- NC50, Choke Valves 1- 14 and Needle valve to 250/3500 psi for 5/10 min. Test gas alarms, Flow paddle and High level pit alarms Page 7129 Report Printed: 2/19/2819 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X operation (f KB) End Depth (ftM) 1/3/2019 1/3/2019 0.50 INTRM1 WHDBOP BOPE P Peform accumulator test, System 0.0 0.0 07:00 07:30 Pressure=2900 psi, Pressure after functioning all rams, annular and HCR's=1500 psi, 200 psi attained=36 sec, Full System Recovery=169 sec. 4 bottle NRrigen average=2150 psi. 1/3/2019 1/3/2019 3.25 INTRM1 WHDBOP BOPE P Change to 7" test joint, test annular to 0.0 0.0 07:30 10:45 250/2500 psi for 5/10 min, Upper VBR's to 250/3500 psi for 5/10 min. Swap to 3W" test joint, lest annular to 250/2500 and lower VBR's to 250/3500 psi for 5/10 min. Test blind rams to 250/3500 5/5 min. Test Manual and Super Auto chokes to 1100 psi. 1/3/2019 1/3/2019 0.50 INTRM1 WHDBOP RURD P Pull lower test plug, drain stack, B/D 0.0 0.0 10:45 11:15 choke, kill & HCR lines, RID test equip. set 8.875" wear bushing as per FMC, L/D test joint. 1/3/2019 1/3/2019 0.75 INTRMI CEMENT FLOG T P/U and mobilize E -line tools to dg 0.0 0.0 11:15 12:00 Floor 1/3/2019 1/3/2019 1.00 INTRM1 CEMENT FLOG T PJSM - dg up E- Line cable, sheaves, 0.0 0.0 12:00 13:00 M/U E -Line Tools, in mouse hole, 1/3/2019 1/3/2019 2.00 INTRMI CEMENT FLOG T Test E- Line tools, weight indacalor 0.0 0.0 13:00 15:00 not working on E -Line, order parts for E Line unit. 1/3/2019 1/3/2019 1.75 INTRM1 CEMENT TRIP T M/U BHA#3 & bit, RIH T/2,063' while 0.0 2,063.0 15:00 16:45 waiting for E Line parts. 1/3/2019 1/3/2019 1.00 INTRM1 CEMENT CIRC T Circulate @ 900 gpm, SPP 1900 psi to 2,063.0 2,063.0 16:45 17:45 warm annular Fluids while waiting F/ E Line parts. 1/3/2019 1/3/2019 3.75 INTRMI CEMENT SVRG T Work on MP2, lest MPD chokes, P/U 2,063.0 0.0 17:45 21:30 & stand back 3stds of 14# - 4" dp while waiting on E line parts and repairs. 1/3/2019 1/3/2019 0.50 INTRM1 CEMENT ELOG T Rig up wire line sheaves, P/U CBL log 0.0 0.0 21:30 22:00 1 1 tools 1/3/2019 1/4/2019 2.00 INTRM1 CEMENT ELOG T RIH with CBL tools on E line. Work 0.0 0.0 2200 00:00 through one obstruction @ 7,055' MD. RIH to 8,660' MD. Correlate with Gamma. Begin logging up. SIMOPS- Test MPD chokes, clean rig, MP2's. 1/4/2019 1/4/2019 1.00 INTRM1 CEMENT ELOG T Continue running CBL, to 8660', 0.0 0.0 00:00 01:00 1/4/2019 1/4/2019 0.50 INTRM1 CEMENT ELOG T R/D CBL tools, and E -Line equip. 0.0 0.0 01:00 01:30 1/4/2019 1/4/2019 1.00 INTRM1 CEMENT PULD P P/U 2 stds 4" DP and std in derrick F/ 0.0 0.0 01:30 02:30 33 stds total, 1/4/2019 1/4/2019 2.25 INTRM1 CEMENT BHAH P P/U clean out BHA #4 per Baker rep to 0.0 541.0 02:30 04:45 541' MD. 1/4/2019 1/4/2019 5.75 INTRM1 CEMENT TRIP P Trip in hole T/ 8447, fill pipe every 20 541.0 8,447.0 04:45 10:30 aids, shallow test MWD @ 2387', 1/4/2019 1/4/2019 0.75 INTRMI CEMENT COCF P Trip in hole F/ 8447 T/ 8512', circ. and 8,447.0 8,447.0 10:30 11:15 condition mud, wash dwn @ 450 gpm, 1450 psi, 10.5 MW 10.5 in, & out. @ 8512' observe psi increase. no SIO observed, pickup to 8447' & std back 1 std in derrick. 1/4/2019 1/4/2019 0.75 INTRM1 CEMENT SLPC P Hang blocks, cut & slip 60' drlg line. 8,447.0 8,447.0 11:15 12:00 1/4/2019 1/4/2019 0.50 INTRMI CEMENT SVRG P Service rig, blocks, drawworks, T/D, 8,447.0 8,447.0 12:00 12:30 1 I Dynamatic, MP'S Page 8129 ReportPrinted: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time I End Time Dur (hr) Phase Op Code Ac#vity Code Time P-T-% Operation Mot End DepN(ftKB) 114/2019 1/4/2019 1.50 INTRMI CEMENT PRTS P Rig up and test 9 518 casing @ 3500 8,447.0 8,447.0 12:30 14:00 psi, 7.6 bbl; pumped chart test for 30 min, test good, B/D lines & test equip. 1/4/2019 1/4/2019 2.25 INTRM7 CEMENT COCF P Wash down F/ 8447 T/ 8635', ddg 8,447.0 8'635-0- 14:00 16:15 stringer @ 8510', 540 gpm, 1950 psi, 40 rpm, 13/15 torq 1/4/2019 1/4/2019 0.50 INTRM1 CEMENT EQRP T B/D top drive, change out Baker 8,635.0 8,635.0 16:15 16:45 MWD encoder on drawworks, & cal. block height. 1/4/2019 1/412019 0.50 INTRMI CEMENT COCF P Wash and ream down to float collar 8,635.0 8,661.0 16:45 17:15 from 8,635' MD to 8,661' MD tag up on plugs. 1/4/2019 1/4/2019 1.75 INTRMI CEMENT DRLG P Drill out plugs, float equipment, shoe 8,661.0 8,665.0 17:15 19:00 track and shoe to 8,742' MD @ 540 gpm, 2015 psi, 40 rpm, 13.5k TQ. 1/4/2019 1/4/2019 0.25 INTRM1 CEMENT DRLG P Drill I clean rathole to 8,762' MD @ 8,742.0 8,762.0 19:00 19:15 540 gpm, 1990 psi, 40 rpm, 13.5k Tq. 1/4/2019 1/4/2019 0.75 INTRM1 CEMENT BKRM P BROOH from 8,762' MD to 8,730' MD, 8,762.0 8,730.0 19:15 20:00 working through shoe twice to clean up. 1/412019 1/4/2019 0.25 INTRM1 CEMENT RURD P Blow down topdrive and R/U for FIT. 8,730.0 8,730.0 20:00 20:15 1/4/2019 1/4/2019 0.50 INTRM1 CEMENT FIT P Perform 'preliminary'FIT to 14.0 ppg 8,730.0 8,730.0 20:15 20:45 EMW, pumped 3.3 bbl to 1290 psi, 1/4/2019 1/4/2019 0.25 INTRM2 DRILL OWFF P OWFF static and PJSM on installing 8,730.0 8,730.0 20:45 21:00 RCD. 1/4/2019 1/4/2019 0.75 INTRM2 DRILL MPDA T Pull trip nipple and install RCD 8,730.0 8,730.0 21:00 21:45 element. 1/4/2019 1/5/2019 2.25 INTRM2 DRILL WASH T Wash down, cleaning out rathole from 8,730.0 8,919.0 21:45 00:00 8,730' MD to 8,919' MD, 540 gpm, 1990 psi, 60 rpm, 14.5k Tq, .3-1 k WOB, Minor torque and pressure events at 8,745', 8,775', 8,810' MD. 1/5/2019 1/5/2019 1.25 INTRM7 DRILL WASH T Wash / Ream F/ 8919' TI 9026', 540 8,919.0 9,026.0 00:00 01:15 gpm, 1920 spp. ROT= 195k,14k Tq, rpm 60, continue with 550 bbl dilution with 10.5 ppg LSND. 1/5/2019 1/5/2019 0.75 INTRM7 DRILL DDRL T Drlg F 9026 T/ 9046', 540 gpm, 1920 9,026.0 9,046.0 01:15 02:00 spp. ROT=195k, trq 14k, rpm 60, 1/5/2019 1/5/2019 0.50 INTRMI DRILL CIRC T Circulate bottoms up, 550 gpm, 1870 9,046.0 9,016.0 02:00 02:30 spp. ROT=195k, trq 14k, rpm 60, MW 10.5 ppg, condition for FIT, 10.5 ppg n/out. 1/5/2019 1/5/2019 1.50 INTRM1 DRILL BKRM T BROOH F/9016'T/8923', holding 9,016.0 8,923.0 02:30 04:00 11.3 ppg with MPD, 550 gpm, 1910 psi,12k trq, Pack off @ @ 8923'. Open chokes, work string, 72k overpull, 51 k s/o, U/D wt 2531<1151 K,. LID double, work free. Attempt to continue backreaming, packing off. 1/5/2019 1/5/2019 1.00 INTRM2 DRILL PMPO T Pump out to 8661'. Circ/recip @ 550 8,923.0 8,734.0 04:00 05:00 gpm, 1870 psi, 14k Tq, rpm 60, Shakers unloaded shale then cleaned up after BU. 1/5/2019 1/5/2019 0.25 INTRM2 DRILL CIRC T OWFF ( static) R/U for FIT. 8,734.0 8,734.0 05:00 05:15 1/512019 1/5/2019 0.50 INTRM2 DRILL FIT T Perform FIT to 14.0 ppg EMW. Drillers 8,734.0 8,734.0 05:15 05:45 TO @ 9,046' MD/ 7,273' TVD. Pumped 3.4 bbl 10.5 ppg mud to 1300 psi. Good test, bleed off, dg down and blow down. Page 9129 Report Printed: 2/1912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Dept, Stan Tie End Tie Dur (hr) Phase Op Cade Activity Code Time P -T -X Operator, (11106) End Depth (WEI) 1/5/2019 1/5/2019 1.00 INTRM2 DRILL WAIT T Prepare to SOOH while waiting on 8,734.0 8,734.0 05:45 06:45 decision regarding plan forward due to hole conditions Clean and clear dg floor. 1/5/2019 1/5/2019 3.25 INTRM2 CSGDRL REAM T Wash and ream F/ 8734 T/ 9046, 550 8,734.0 9,046.0 0645 10:00 gpm, 1850 spp. rpt 195k, trq 14k, rpm 60, P/U 238k, SIO 167k, MW 10.5 ppg, holding 11.3 EMW via MPD, 1/5/2019 1/5/2019 1.00 INTRM2 CSGDRL BKRM T BROOH F/ 9046 T/ 90141, CBU, 550 9,046.0 9,014.0 10:00 11:00 gpm, 1820 spp, 12.5k trq, 60 rpm, weight up F/ 10.5 T/ 10.8 1/5/2019 1/5/2019 1.00 INTRM2 CSGDRL PMPO T Continue pump out of hole F/ 9014' T/ 9,014.0 8,730.0 11:00 12:00 8739, hold 11.4 EMW with MPD, 90 gpm/ 400 psi 1/5/2019 1/5/2019 2.00 INTRM2 CSGDRL CIRC T Continue circulate and weight mud up 8,730.0 8,730.0 12:00 14:00 to 10.8 ppg @ 8730'. 1/5/2019 1/5/2019 0.50 INTRM2 CSGDRL TRIP P OWFF, B/D top drive, line up MPD to 8,730.0 8,730.0 14:00 14:30 SOOH. Obtains SPR's. SIMOPS-Annular LOT to 16.0 ppg EMW, flush and freeze protect annulus with 300 bbl water and 84 bbl diesel. 1/5/2019 1/5/2019 5.00 INTRM2 CSGDRL SMPD P Strip out of hole with MPD from 8,730' 8,730.0 1,005.0 14:30 19:30 MD to 1,005' MD per stripping schedule, holding 180 psi in slips, 270 psi pulling. Maintaining 11.3 ppg CBHP. 1/5/2019 1/5/2019 0.50 INTRM2 CSGDRL OWFF P Observe well for flow, static. 1,005.0 1,005.0 19:30 20:00 Function upper and lower rams. 1/5/2019 1/5/2019 0.75 INTRM2 CSGDRL MPDA P Pull RCD and install trip nipple 1,005.0 1,005.0 20:00 20:45 1/5/2019 1/5/2019 1.75 INTRM2 CSGDRL PULD P POOH on trip tank from 1,005' MD to 1,005.0 203.0 20:45 22:30 203' MD, laying down HWDP to pipe shed. 1/512019 1/6/2019 1.50 INTRM2 CSGDRL BHAH P PJSM and lay down BHA# 4 per 203.0 0.0 22:30 00:00 Baker DO / MWD. Function blind rams. Total trip Calc Fill=87 bbl, Acual Fill= 100.5 bbl. 1/6/2019 1/6/2019 1.75 INTRM2 CSGDRL SHAH P UD BHA tools / equip. clean and clear 0.0 0.0 00:00 01:45 RF, P/U SDL BHA tools I Equip. 1/6/2019 1/6/2019 5.00 INTRM2 CSGDRL SHAH P PJSM, P/U SDL inner sung. BHA, M/U 0.0 0.0 01:45 06:45 flow DIV - N- stab F/SDL ddg string. M/U back up str head easy. W/ 6" PDC bit UO in shed. P/U -N- M/U pdmarry SDL inner string BHA per Baker rep. Plug in BHA and test (good), STD back in DRK, M/U short kick std. w? 4" FOSV, P/U SDL false table tools and equip. 1/6/2019 1/6/2019 1.75 INTRM2 CSGDRL RURD P R/U 7" SDL liner running tools/ equip., 0.0 0.0 06:45 08:30 trq turn equip. DBL stack tongs, bail eaten. , 7" elevators, handling equip. PJSM F/ RIH with 7" 26# casing. 1/6/2019 1/6/2019 3.50 INTRM2 CSGDRL PUTS P M/U 8-1/2" EZ Reamer shoe, M/U and 0.0 1,519.0 08:30 12:00 RIH with 7" 26# L-80 TN Blue casing to 1,519' MD, torque turning to 15k ft/Ibs per program. 1/6/2019 1/6/2019 2.50 INTRM2 CSGDRL PUTB P Continue Running in hole W/ 7" 26# L- 1,519.0 3,140.0 12:00 14:30 80 Ten. Blue liner F 1519'T/ 3140'. II Cal disp = 30, ACT 28bbls, S/0 113k 1/6/2019 1/6/2019 0.50 INTRM2 CSGDRL RURD P WD 7" /inner handling equip. 3,140.0 3,140.0 14:30 15:00II Page 10129 Report Printed: 211912019 -• Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our(hr) Phase Op Code Activity Code Time P -T -X Cperatlon YK61, End Depth(XkB) 1/6/2019 1/6/2019 2.50 INTRM2 CSGDRL BHAH P PJSM, R1U & RIH with AutoTrak inner 3,140.0 3,140.0 15:00 17:30 string BHA T/ 50'( load sources) 1/6/2019 1/6/2019 1.25 INTRM2 CSGDRL BHAH P Cont. T/ M/U inner BHA F/ 50'T1 180' 3,140.0 3,140.0 17:30 18:45 1/6/2019 1/6/2019 0.25 INTRM2 CSGDRL TRIP P RIH F/ 180' T/465' w/4" dip inner strg, 3,140.0 3,140.0 18:45 19:00 1/6/2019 1/6/2019 0.25 INTRM2 CSGDRL SFTY P Perform SDL kick while tripping drill 3,140.0 3,140.0 19:00 19:15 1 1 Iwith long kick stand. 1/6/2019 1/6/2019 1.75 INTRM2 CSGDRL TRIP P Continue RIH F/465'T/3040'p/u wt 3,140.0 3,140.0 19:15 21:00 90k, S/O wt 87k. 1/6/2019 1/6/2019 1.00 INTRM2 CSGDRL HOSO P M/U std 4" dip & tag up 2' in on joint 3,140.0 3,140.0 21:00 22:00 #97, set 10k dwn. POOH & R/B std #97, M1U space out pups 1/6/2019 1/6/2019 1.00 INTRM2 CSGDRL BHAH P M/U HRDE liner running tools, Baker 3,140.0 3,258.0 22:00 23:00 flow diverter, stab & float sub, dg down false table & work plafform. 1/6/2019 1/6/2019 0.50 INTRM2 CSGDRL TRIP P RIH wt SDL on 5" dip F/ 3258'T/ 3,258.0 3,723.0 23:00 23:30 1 1 13258'( new BHA depth 3723) 1/6/2019 1/7/2019 0.50 INTRM2 CSGDRL DHEQ P Shallow hole test Si dir Assy. W/ 3,723.0 3,723.0 23:30 00:00 225 gpm, 1200 psi 1/712019 1/7/2019 0.50 INTRM2 CSGDRL DHEQ P Shallow test MWD 225 gpm, 3,723.0 3,723.0 00:00 00:30 TRPM=3450. Increase to 350 gpm, TRPM=5538. Rotate 50 rpm, 5k, ROT=160k. Attempt to open diverter, too shallow. Blow down top drive. 1/7/2019 1/7/2019 1.00 INTRM2 CSGDRL TRIP P RIH F/ 3723'T/ 5138' with SDL BHA 3,723.0 5,138.0 00:30 01:30 #5. 1/7/2019 1!7/2019 0.25 INTRM2 CSGDRL DHEQ P Verify flow diverter open @ 5138', 5,138.0 5,138.0 01:30 01:45 3001600 gpm, 2150/ 3300 psi, 50 rpm, ROT=180k, torq. 7k, 600 gpm, TRPM - 5313 psi 1/7/2019 1/7/2019 2.50 INTRM2 CSGDRL TRIP P Cont. RIH F/ 5138'T/ 8620', 5,138.0 8,620.0 01:45 04:15 1/7/2019 1/7/2019 0.50 INTRM2 CSGDRL OWFF P OWFF, @ 8620', pull T/N install MPD 8,620.0 8,620.0 04:15 04:45 RCD. P/U 252k, SIO 196k. 1/7/2019 1/7/2019 1.75 INTRM2 CSGDRL TRIP P Cont. RIH F/ 8620' T/ 8880' with SDL 8,620.0 8,880.0 04:45 06:30 liner DRLG Assy. ( no s/o loss working through shoe trk. w/ str head assy, 7" reamer shoe. P/U 295, S/0 194k, ROT=252k, 16.5k Tq, 30 rpm 30, Calc disp= 47.28 bbls, Actual Disp= 44 bbis 1/7/2019 1/7/2019 2.00 INTRM2 CSGDRL REAM P Wash/ ream F/8880' T7 9033', circ, 8,880.0 9,033.0 06:30 08:30 spm 80, gpm 225, 630/1610 psi, not 226, trot 13.5k, rpm 10, ( flow diverter opened 2X, cycle pump T/ close. pressure indicated possible packoff, P/U 30k, SIO to 175k, hole packing off, attempt to work slrg free pump rates 40/ 275 gpm, P/U=291 k, S/0=188k, ROT=232k. 1/7/2019 1/7/2019 2.00 INTRM2 CSGDRL CIRC P Work string free F/ 9028 T/ 9008', est. 9,033.0 9,028.0 0830 10:30 circ, rot/ recip SDL liner volume @ 40- 275 gpm, 460-1860 psi, rot wt 227k, trq 15k, rpm 15, circ btms up 1/7/2019 1/7/2019 1.50 INTRM2 CSGDRL REAM P F/ 9028'T1 9037' cont. wash/ ream w/ 9,028.0 9,037.0 10:30 12:00 SDL liner drlg assy. 550 gpm, 2430 psi, rot 230k, trq 16.2k, 1/7/2019 1/7/2019 0.50 INTRM2 CSGDRL REAM P Continue washing down to bottom 9,037.0 9,046.0 12:00 12:30 9,046' MD @ 570 gpm, 2450 psi, diverter open, 30 rpm 16.6k To. Page 11129 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 'Wg: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Cale Tina P-T-x operates (fIKB) End Depth (111(8) 1/7/2019 1/8/2019 11.50 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8'/." SDL 9,046.0 9,330.0 12:30 00:00 assembly from 9,046' MD to 9,330' MD, 7,444' TVD @ 575 gpm, 2485 psi, 45 rpm, 13.5k Tq. Under-reamer open @ 9,117' MD pilot depth, 9,049' reamer depth. ADT=10.7 hrs, 1/8/2019 118/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8'/P SDL 9,330.0 9,705.0 00:00 12:00 assembly from 9,330' MD to 9,705' MD, 7,626' TVD @ 575 gpm, 2485 psi, 45 rpm, ECD=11.61 ppg, Tq onloff= 13.5k/12.4k, 5-7k WOB, ROT=227k, ADT=11.0 his. 1/8/2019 1/9/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8'/." SDL 9,705.0 10,046.0 12:00 00:00 assembly from 9,705' MD to 10,046' MD, 7,710' TVD @ 575 gpm, 2470 psi, 45 rpm, ECD=11.60 ppg, Tq on/off= 13.5k/12.4k, 5-7k WOB, ROT=230k, ADT=10.5 his. 1/9/2019 1/9/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8'/." SDL 10,046.0 10,390.0 00:00 12:00 assembly from 10,046' MD to 10,390' MD, 7,833' TVD @ 575 gpm, 2580 psi, 45 rpm, ECD=11.50 ppg, Tq onloff= 13k/14.5k, 5-7k WOB, ROT=235k, ADT=11.1 hrs. 1/9/2019 1/10/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8e/." SDL 10,390.0 10,699.0 12:00 00:00 assembly from 10,390' MD to 10,699' MD, 7,858' TVD @ 575 gpm, 2550 psi, 45 rpm, ECD=11.54 ppg, Tq on/off= 13.7k/14.7k, 5-7k WOB, ROT=226k, ADT=10.5 hrs. 1/10/2019 1/10/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8Y4" SDL 10,699.0 11,020.0 00:00 12:00 assembly from 10,699' MD to 11,020' MD, 7,899' TVD @ 575 gpm, 2480 psi, 45 rpm, ECD=11.43 ppg, Tq on/off= 15.3k/13.1k, 5-7k WOB, ROT=226k, ADT=11.0 his. Note: Alpine C Top 10,999' MD 7,897' TVD. 1/10/2019 1/10/2019 4.50 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8W SDL 11,020.0 11,132.0 12:00 16:30 assembly from 11,020' MD to 11,118' MD, Down link and close 8-3/4" under reamer, Continue drilling from 11,118' MD to section TD at 11,132' MD 7909' TVD, Observed static reamer land on ledge @ 11,132' bit depth, 11,050' MD 7901.9' TVD 7" shoe depth. 7" TOL 7,863' MD 6'438.7' TVD. 575 gpm, 2480 psi, 45 rpm, ECD=11.34 ppg, Tq ontoff= 15.3k/13.1 k, 5-7k WOB, ROT=226k, ADT=4.5 his. Max gas 2985 units. 1110/2019 1/10/2019 7.00 INTRM2 CEMENT CIRC P Final TD survey, Down link and close 11,132.0 11,132.0 16:30 23:30 ribs. ROT =228k, PUW =275k, SOW =165k. Continue circulate and weight up in stages from 10.3 ppg to 11.0 ppg. 585 gpm, 2480 psi, ECD=11.34 ppg. Final circulation 245 gpm, 1150 psi. ECD= 11.7 ppg. 1/10/2019 1111/2019 0.50 INTRM2 CEMENT OTHR P Shut down, break out tool joint and 11,132.0 11,132.0 2330 00:00 drop 1.75" Bronze release ball per BOT rep. Slack off string from 228K to 140K, Continue to circulate ball down at 84 gpm 1450 psi. Ball landed on seat @ 317 strokes, continue pressure up to 3440 psi to blow ball seat and release from 7" liner. Page 12129 Report Printed: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start1'me End Time our (hr) Phase Op code Activity code Tme P -T -X Operation (IIKB) End Depth (flKB) 1111/2019 1/11/2019 0.75 INTRM2 CEMENT PMPO P Continue pump 126 gpm 745 psi. P/U 11,132.0 10,975.0 00:00 00:45 string from 11,132'to 10,975' bit depth and verify release @ 2121k per BOT. 7" liner reamer shoe Cts 11,050' MD 7,901 TVD. TOL 7863' MD 6,438.9' TVD. 1/11/2019 1/11/2019 1.00 INTRM2 CEMENT CIRC P Continue pump out hole from 10,975' 10,975.0 10,882.0 00:45 01:45 MD to 10,882' MD @ 100 fph circulate btms up @ 370 gpm 1240 psi. ROT = 190k, Torque 7k with 30 rpm. ECD =11.65 ppg. 1/11/2019 1/11/2019 0.50 INTRM2 CEMENT OWFF P Flow check well static, Blow down top 10,882.0 10,882.0 01:45 02:15 drive. Line up MPD. 1/11/2019 1/11/2019 5.00 INTRM2 CEMENT SMPD P Strip out of hole with MPD per 10,882.0 3,543.0 02:15 07:15 schedule from 10,882' MD to 3,543' MD, maintaining 11.7 ppg with 200 psi in slips, 345 psi pulling. (No drag observed SOOH with SDL BHA through 7" liner top) 1/11/2019 111112019 0.25 INTRM2 CEMENT OWFF P Flow check well static, PJSM for MPD, 3,543.0 3,543.0 07:15 07:30 RCD/Trip nipple, Prep tools and equipment. 1/11/2019 1/11/2019 0.50 INTRM2 CEMENT MPDA P Pull MPD bearing and install trip 3,543.0 3,543.0 07:30 08:00 nipple. P/U and S/O 1071k. 1/11/2019 1/11/2019 1.25 INTRM2 CEMENT BHAH P POOH from 3,543' MD to 3,215' MD. 3,543.0 3,215.0 08:00 09:15 P/U and S/O 101k. Lay down flow diverter assembly, stabilizer and liner running tool. 1111/2019 1/11/2019 2.25 INTRM2 CEMENT TRIP P POOH from 3,215' MD to 272' MD. 3,215.0 272.6- 09:16 11:30 1/11/2019 1/11/2019 0.25 INTRM2 CEMENT OWFF P Monitor for flow, static 272.0 272.6- 11:30 11:45 Function test annular, upper and lower rams. (weekly) 1/11/2019 1/11/2019 3.25 INTRM2 CEMENT BHAH P Lay down BHAand unload/secure 272.0 0.0 11:45 15:00 sources from MWD from 272' MD. Function test blind rams. 1/11/2019 1111/2019 1.00 INTRM2 CEMENT BHAH P Clean and clear rig floor. P/U tools and 0.0 0.0 15:00 16:00 equipment for cement retainer / liner hanger and packer run. 1/11/2019 1/11/2019 2.50 INTRM2 CEMENT TRIP P Make up K-1 Cement retainer as per 0.0 3,055.0 16:00 18:30 BOT rep. RIH with 4" DP to 3,055' MD 1/11/2019 1/11/2019 1.25 INTRM2 CEMENT PUTS P Rig up double stack tongs, change to 3,055.0 3,055.0 18:30 19:45 5" handling equipment. P/U SLZXP, make up 10.62' pup on bottom. Make up latching seal assy to packer, Torque turn to 12k. Make up to inner string. P/U and S/0 951k. 1/11/2019 1/11/2019 0.25 INTRM2 CEMENT TRIP P RIH from 3,055' MD to 3,228' MD. 3,055.0 3,228.0 19:45 20:00 1/11/2019 1/11/2019 0.25 INTRM2 CEMENT CIRC P At 3,228' MD fill pipe and circulate 3,228.0 3,228.0 20:00 20:15 string volume at 189 gpm 300 psi. P/U and S/O 95k. 1/11/2019 1/12/2019 3.75 INTRM2 CEMENT TRIP P RIH with assembly from 3,228' MD to 3,228.0 7,843.0 20:15 00:00 7,843' MD on 5" DP. Fill pipe every 20 stands. S/0=150k. 1/12/2019 1112/2019 0.50 INTRM2 CEMENT CIRC P Make up to top drive, establish 7,898.0 7,898.0 00:00 00:30 circulation and wash through TOL 7,898' MD with retainer. 2 bpm @ 250 psi. Observed no loss of S/0 weight going into TOL. Blow down top drive. 1/12/2019 1112/2019 4.25 INTRM2 CEMENT TRIP P Continue RIH to 10,951' MD. P/U 7,898.0 10,951.0 00:30 04:45 =218k S/0=175k. Page 13129 Report Printed: 211 912 01 9 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth tta Time End Time Dw(m) Please Op Code ActMty Code Time P-T-X Operation (aKa) End Depth(WB) 1/12/2019 1/12/2019 0.75 INTRM2 CEMENT WASH P Make up tag stand, Break circulation 10,951.0 10,999.0 0445 05:30 42-84 gpm 30OA30 psi. P/U=218k 8/0 175k, Wash down slow at 42 gpm 300 psi. Noticed 30psi increase from 300 psi to 330 psi and seals intered TOL. at 7,863' MD. K-1 at 10,999' MD. Rack back tag stand and Blow down top drive. 1/12/2019 1/12/2019 1.00 INTRM2 CEMENT RURD P Space out, Make up single 5" drill pipe 10,999.0 10,999.0 05:30 06:30 and two 5" pup joints with cement swivel. 1/12/2019 1/12/2019 0.25 INTRM2 CEMENT WASH P Break circulation at .8 bpm 300 psi, 10,999.0 10,999.0 06:30 06:45 Wash in and noticed 30 psi increase from 300 - 330 psi as seals intered TOL at 7,898' (K-1 @ 10,999') Continue to slack off to 11,004.95' as Nogo lands and latch seal easy. Bleed off string pressure and Pull test to 2501k, S/O to 175k to confirm latch. 1/12/2019 1/12/2019 2.25 INTRM2 CEMENT CIRC P Break circulation at .5 bpm 270 psi, 10,999.0 10,999.0 06:45 09:00 stange pumps up in .5 bbl increments to 2.5 bpm 450 psi. Observed no mud losses. 1/12/2019 1/12/2019 0.50 INTRM2 CEMENT CIRC P Drop 1.75" bronze release ball, pump 10,999.0 11,004.0 09:00 09:30 dawn @ 2 bpm, 400 psi. Ball on seal @ 287 stks. Pressure up to 4000 psi, bleed down to 500, Observed pressure drop to 0 psi in 5 minutes for DOBS to open. 1/12/2019 1/12/2019 0.50 INTRM2 CEMENT MPSP P P/U from 11004.95 MD to 10,988' MD 11,004.0 10,988.0 09:30 10:00 and set cement retainer with RH rotation per Baker rep. Un-sting from retainer. P/U=240k, S/0=145k. 1112/2019 1/12/2019 1.00 INTRM2 CEMENT CIRC P Break circulation with 3 bpm 500 psi, 10,988.0 10,988.0 10:00 11:00 stage up pumps to 7 bpm 1070 psi, (SIMOPS- PJSM on cementing) 1112/2019 1/12/2019 2.50 INTRM2 CEMENT CMNT P Monitor well for flow (static) Pump 2 10,988.0 10,988.0 11:00 13:30 bbis water, Test lines to 3,000 psi. Pump 38.4 bbis 11.5 ppg mud push II, Mix and pump 55.1 bbls 15.8 ppg cement, Pump 20 bbis water. Sting in and displace with 142 bbis 10.9 ppg LSND mud. Final circulation pressure at 2 bpm 720 psi. 300 psi lift pressure. Cement in place at 13:30 hrs. Observed no mud losses. 1/12/2019 1/12/2019 0.25 INTRM2 CEMENT CIRC P P/U 20'to expose rotating dog sub. 10,988.0 10,965.0 13:30 13:45 S/0=125k. Set 60k down to set liner hanger/ packer easy, observe shear @ 160k, P/U, rotate 20 rpm (ROT =200k) 6.5K torque and repeat t0 confirm as per BOT Rep. 1/1212019 1/12/2019 0.75 INTRM2 CEMENT CIRC P Circulate out 20 bbis water and 2.7 10,965.0 10,965.0 13:45 14:30 bbis cement at 10,965' 13 bpm 2700 psi. 1/12/2019 1/12/2019 1.00 INTRM2 CEMENT RURD P Pump 20 bbis water surface/surface at 10,965.0 10,965.0 14:30 15:30 1 1 1 A 1 115.5 bpm 3640 psi. 1/12/2019 1/12/2019 1.25 INTRM2 CEMENT RURD P Blow down mud system, Flush and 10,965.0 10,965.0 15:30 16:45 1 1 I UD cement swivel and 5" pup joints. 1/12/2019 1/12/2019 5.50 INTRM2 CEMENT PULD P PJSM, POOH UD 5" drill pipe from 10,965.0 7,933.0 16:45 22:15 1 10,965'to 7,933'. Cleaning out cement rings from tool joints. Page 14129 Report Printed: 211912019 - Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stad Depth Stall Tune End Tore our (hr) Phase Op Code AdO*Code Tone P -T -X Operation (ftKB) End Depth(flXa) 1/12/2019 1/12/2019 1.25 INTRM2 CEMENT CIRC P Wash accross 7" liner top from 7,933' 7,933.0 7,841.0 22:15 23:30 to 7,841'@ 15.5 bpm 2200 psi. Pump 22 bbls 12.9 ppg slug. Blow down lop drive. 1/12/2019 1/13/2019 0.50 INTRM2 CEMENT PULD P POOH UD 5" drill pipe from 7,841' to 7,841.0 7,748.0 23:30 00:00 7, 748'. Cleaning out cement rings from tool joints. 1/13/2019 1/13/2019 4.75 INTRM2 CEMENT PULD P Continue POOH with liner running 7,748.0 3,139.0 00:00 04:45 tools and cement stinger, laying down 5" drill pipe from 7,748' MD to 3,139' MD. Cleaning out cement rings from tool joints. 1/13/2019 1113/2019 1.00 INTRM2 CEMENT BHAH P Lay down Baker liner running tools 3,139.0 3,055.0 04:45 05:45 from 3,139' MD to 3,055' MD. Observe dog sub sheared. Change out to 4" running tools. 1/13/2019 1/13/2019 1.50 INTRM2 CEMENT TRIP P POOH from 3,055' MD, racking back 3,055.0 0.0 05:45 07:15 4" DP. 1/13/2019 1/13/2019 0.50 INTRM2 CEMENT BHAH P Lay down cement retainer running tool 0.0 0.0 07:15 07:45 and stinger, 1/13/2019 1/13/2019 0.50 INTRM2 CEMENT CLEN P Clean and clear rig floor. UD excess 0.0 0.0 07:45 08:15 tools and equipment. 1/13/2019 1/13/2019 1.00 INTRM2 CEMENT RURD P Make up tesljoint, FMC pull 6.812" ID 0.0 0.0 08:15 09:15 wear ring. 1/13/2019 1/13/2019 1.00 INTRM2 CEMENT PRTS P Rig up and test liner top packer and 0.0 0.0 09:15 10:15 retainer to 1000 psi for 10 minutes charted, (good test.) RID test equipment. Blow down lines. 1/13/2019 1/13/2019 2.50 INTRM2 CEMENT RURD P Mobilize 7" casing handling equipment 0.0 0.0 10:15 12:45 to rig floor, R/U to mn tie -back. M/U Volant CRT. 1/13/2019 1/13/2019 0.25 INTRM2 CEMENT PUTB P Make up seal assembly, X/O and 7" 0.0 0.0 1245 13:00 29#, H563 Dopeless 1/13/2019 1/13/2019 6.25 INTRM2 CEMENT PUTB P Continue P/U and RIH with 7" 29# TN- 0.0 4,884.0 13:00 19:15 110 563 dopeless Torque to 12,100ft- Ibs. to 4,884' MD. 1/13/2019 1/13/2019 1.50 INTRM2 CEMENT RURD P R/U torque turn equipment, test same 4,884.0 4,884.0 19:15 20:45 while clen and clear rig floor. 1/13/2019 1/14/2019 3.25 INTRM2 CEMENT PUTB P Continue P/U and RIH with 7" 26# L- 4,884.0 6,165.0 20:45 00:00 80 TSH- Blue, Torque to 9,01 Oft -lbs. From 4,884' MD to 6,165' MD. 5,259' joint #132 improper torque, Back out and clean connection (no issues) retorqued same. 1/14/2019 1/14/2019 1.50 INTRM2 CEMENT PUTB P Continue P/U and RIH with 7" 26# L- 6,165.0 6,708.0 00:00 01:30 80 TSH- Blue, Torque to 9,010ft-lbs. From 6,165' MD to 6,708' MD. 1/14/2019 1/14/2019 1.00 INTRM2 CEMENT PULD T Attempt to makeup joint#168. Unable 6,768.0 6,708.0 01:30 02:30 to achieve proper torque after cleaning and redressing threads. Lay down joint #168 and replace with joint #206. Change out collar on joint #167. 1/14/2019 1/14/2019 0.75 INTRM2 CEMENT PUTB P Continue P/U and RIH with 7" 26# L- 6,708.0 6,992.0 02:30 03:15 80 TSH- Blue, Torque to 9,01Oft-lbs. From 6,708' MD to 6,992' MD. 1/14/2019 1/14/2019 0.50 INTRM2 CEMENT PULD T Attempt to make up joint #174. Unable 6,992.0 6,992.0 03:15 03:45 to achieve proper torque after cleaning and redressing threads. Lay down joint #174 and replace with joint #196. Change out collar on joint #173. Page 15129 Report Printed: 2119/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start Time Endnm_ Our (hr) Phase Op code Activity Code Time P-T-x Operation (ftKB) End Depth (Itl(B) 1/14/2019 1/14/2019 4.25 INTRM2 CEMENT PUTS T Continue P/U and RIH with 7" 26# L- 6,992.0 7,861.0 03:45 08:00 80 TSH- Blue, Torque to 9.010ft-lbs. From 6,992' MD to 7,861' MD. Polishing each connection to achieve proper torque. 1/14/2019 1/14/2019 1.00 INTRM2 CEMENT HOSO P Establish circulation on joint#195 with 7,861.0 7,892.0 08:00 09:00 Volant CRT @ 1 bpm, 270 psi. PU= 220k SO=185k. Wash down to locate TOL. Locate seals @ 7,872.12' via pressure increase. Shut down and bleed off, slack off to no-go @ 7,892'. (TOL=7,872.12' MD 6,444.7 TVD, Shoe 11,059.93' MD 7,902.7 TVD corrected.) 1/14/2019 1/14/2019 0.50 INTRM2 CEMENT PRTS P Rig up and pressure test seal 7,892.0 7,892.0 09:00 09:30 assembly via 9-5/8" X 7" annulus to 1000 psi for 10 minutes, with bleeder open on casing side. Good test. 1/14/2019 1/14/2019 0.25 INTRM2 CEMENT HOSO P Sting out and UD 7" singles from 7,892.0 7,820.0 09:30 09:45 7,892' MD to 7,820' MD. 1/14/2019 1/14/2019 0.75 INTRM2 CEMENT WAIT P Make up 7" space out pups (4.98' and 7,820.0 7,820.0 09:45 10:30 3.85) Observed 19' pup joint was 7 5/8". Decision made to UD pups and wait on pup joint to arrive. 1/14/2019 1/14/2019 2.25 INTRM2 CEMENT CIRC T Clean and clear rig floor, while waiting 7,820.0 7,820.0 10:30 12:45 on 7" 26 ppf L-80 TSH Blue pup joint. 1/14/2019 1/14/2019 3.00 INTRM2 CEMENT HOSO P Make up 18.15' pup, X/O from TSH 7,820.0 7,873.0 12:45 15:45 Blue to H563, M/U 1.8'space out pups. M/U hanger and landing joint. R/U lines to Volant tool to pump. Pump down casing string @ 4 bpm 480 psi (SIMOPS PJSM spot inhibitor and diesel.) 1/14/2019 1/142019 1.50 INTRM2 CEMENT CRIH P Reverse in 40 bbl Hi Vis spacer, 180.7 7,873.0 7,873.0 15:45 17:15 bbl corrosion inhibited seawater into 9.625"x 7" annulus. @3.5 bpm 650 psi. 1/142019 1/14/2019 1.00 INTRM2 CEMENT FRZP P Line up Ball mill and PT lines to 2500 7,873.0 7,873.0 17:15 18:15 psi. 40.5 bbl diesel pumped by Ball Mill into 9.625"x 7" annulus @ 3 bpm, 834 psi. 1/14/2019 1/14/2019 0.25 INTRM2 CEMENT HOSO P Shut down, strip in landing joint until 7,873.0 7,892.0 18:15 18:30 seals entered TOL, Bleed pressure to 0, open annular and continue slacking off until landed @ 7,892' seal assy depth, spaced 7.13' off fully located. 1/142019 1/142019 1.00 INTRM2 CEMENT RURD P Rig down reverse circulating 0.0 0.0 18:30 19:30 equipment, back out and lay down landing joint. RID Volant tools and equipment. 1/14/2019 1/142019 1.00 INTRM2 CEMENT WWSP P Make up packoff running tool, Install 0.0 0.0 19:30 20:30 13"x7" Packoff. Run in lock downs and packoff, torque to 450 ft-lbs. Pressure test void to 250/5000 psi, 5mmll Omin. Good test witnessed 1/14/2019 1/14/2019 1.00 INTRM2 CEMENT PRTS P Pressure test 9-5/8" x 7" annulus to 0.0 0.0 20:30 21:30 2500 psi for 30 minutes charted, good. Used Ball Mill pump and diesel for test. Bleed annulus to 0 psi, close in valves. Clear lines of diesel. Install PT sensor / gauge on annulus @ wing valve. Page 16129 ReportPrinted: 2/1912019 - Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time EM Time Dur (hr) Phase Op Code Arbvity Code Time P -T -X Operaflan (Bi(6) EM Depth (WS) 1/14/2019 1/1512019 2.50 INTRM2 CEMENT BOPE P Change out upper rams from 4-1/2" x 0.0 0.0 21:30 00:00 7" VBR to 3%" x 6" VBR. SIMOPS- Change out saver sub on top drive from NC50 to XT39. 1/15/2019 1/15/2019 0.75 INTRM2 CEMENT SEQP P Continue change out saver sub on top 0.0 0.0 00:00 00:45 drive from NC50 to XT39. 1115/2019 1/15/2019 1.25 INTRM2 CEMENT BOPE P Rig up and test upper 3.5" X 6" VBR 0.0 0.0 00:45 02:00 to 25013500 for 5/10 minutes with 4" lest joint. 7" annulus vented for leak path, Monitor same. 1115/2019 1/15/2019 0.50 INTRM2 CEMENT RURD P Pull lest plug, R/D test equipment. 0.0 U-0- 02:00 02:30 Install 6.25" ID wear bushing. 1/15/2019 1/15/2019 0.50 INTRM2 CEMENT RURD P Clean and clear rig floor and install 4" 0.0 0.0 02:30 03:00 elevators. 1/15/2019 1/1512019 2.25 INTRM2 CEMENT BHAH P PIU and RIH with BHA #6 to 294' MD. 0.0 294.0 03:00 05:15 BHA weight 12k 1/15/2019 111512019 5.25 INTRM2 CEMENT PULD P RIH with clean out BHA #6, picking up 294.0 4,279.0 05:15 10:30 4" DP singles from pipe shed to 4,279' MD. 1/15/2019 1/15/2019 9.25 INTRM2 CEMENT WAIT T Phase III weather conditions, Shut 4,279.0 4,279.0 10:30 19:45 down operations at 1030 hrs. Break circulation at 4,279' MD 100 gpm 320 psi. every 6 hrs while WOW. 1/15/2019 1115/2019 0.25 INTRM2 CEMENT SFTY P Received Phase II weather conditions 4,279.0 4,279.0 19:45 20:00 at 1945 hrs to resume operations, PJSM P/U and continue RIH with 4" singles. 1/15/2019 1/16/2019 4.00 INTRM2 CEMENT PULD P RIH with clean out BHA #6, picking up 4,279.0 4,708.0 20:00 00:00 4" DP singles from pipe shed from 4,279' MD. to 7,408' MD. 1/16/2019 1116/2019 1.00 INTRM2 CEMENT PULD P Continue to single in the hole with 6" 4,708.0 8,269.0 00:00 01:00 clean out assembly on 4" 14# Drill pipe 1/1612019 1/16/2019 1.50 INTRM2 CEMENT TRIP P RIH w/ 6" clean out assembly on 4" 8,269.0 10,740.0 01:00 02:30 14# drill pipe from the derrick. 1/16/2019 1116/2019 1.25 INTRM2 CEMENT SLPC P Slip and cut 75' of drill line. 10,740.0 10,740.0 02:30 03:45 Circulate at 2bpm 750psi while slipping and cutting. Cut MW back to a 10.2ppg 1/16/2019 1/16/2019 0.50 INTRM2 CEMENT SVRG P Service Top Drive and Drawworks. 10,740.0 10,740.0 03:45 04:15 Circulate at 2bpm 750psi while slipping and cutting. Cut MW back to a 11 0.2ppg 111612019 1/16/2019 1.25 INTRM2 CEMENT CIRC P Circulate and condition mud to a 10,740.0 10,740.0 04:15 05:30 10.2ppg 280 gpm 1580 psi. 1116/2019 1/16/2019 0.25 INTRM2 CEMENT RURD P Rig up for casing test, rig up surface 10,740.0 10,740.0 05:30 05:45 lines and establish circulation kill line. 1/1612019 1/16/2019 1.25 INTRM2 CEMENT PRTS P Test 7" casing string to 3500 psi for 30 10,740.0 10,740.0 05:45 07:00 minutes charted, good. 1116/2019 1/16/2019 0.50 INTRM2 CEMENT RURD P Rig down test equipment, blow down 10,740.0 10,740.0 07:00 07:30 kill line. 1/16/2019 1/16/2019 1.00 INTRM2 CEMENT COCF P Wash and ream down from 10,740' 10,740.0 10,991.0 07:30 08:30 MD to 10,991' MD tag up on cement / cement retainer. 200 gpm, 1060 psi, 40 rpm, 4k. 1/16/2019 1/16/2019 2.00 INTRM2 CEMENT DRLG P Continue drill cement retainer and 10,991.0 11,025.0 08:30 10:30 cement from 10,991' MD to 11,025' MD. 200-300 gpm 1150-1650 psi. 15k WOB. 1/16/2019 1116/2019 1.25 PROD1 CEMENT CIRC P Pump 29 bbls 11 ppg Hi -Vis sweep at 11,025.0 11,025.0 10:30 11:45 11,025' MD, Continue circulate sweep out at 11,025' MD @ 300 gpm 1650 psi. 50 rpm 4k torque. Page 17129 Report Printed: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth SM Time End Time our (hr) Phase op code Mviy Code Time P -T -X CpemNon dtKB) End Depth (ftKB) 1/16/2019 1/16/2019 0.50 PROD1 CEMENT OWFF P Observe well for flow @ 11,025' MD. 11,025.0 11,025.0 11:45 12:15 Static 1/16/2019 1/16/2019 4.25 PROD1 CEMENT TRIP P POOH on elevators from 11,025' MD 11,025.0 4,564.0 12:15 16:30 to 4,564' MD. 1/16/2019 1/16/2019 0.25 PROD1 CEMENT CIRC P Pump 21 bbls 11 ppg slug. Blow down 4,564.0 4,564.0 16:30 16:45 top drive. 1/16/2019 1/16/2019 1.75 PROW CEMENT TRIP P POOH on elevators from 4,564' MD to 4,564.0 112.0 16:45 18:30 1 1 1112'MD. 1/16/2019 1/16/2019 0.75 PROD1 CEMENT OWFF P Observe well for flow @116'MD. 112.0 112.0 18:30 19:15 Static (SIMOPS) RID mud bucket and air slips. P/U tools to handle BHA. 1/16/2019 1116/2019 2.00 PROD1 CEMENT BHAH P UD BHAfrom 112' MD. Clean and 112.0 0.0 19:15 21:15 clear rig floor from spare tools and equipment. '""`Recover 75lbs of metal debris from magnets**** 1/16/2019 1/16/2019 0.75 PROD1 CEMENT WWWH P Flush stack @ 9 bpm. Blow down top 0.0 0.0 21:15 22:00 1 1 ldrive. 1116/2019 1/16/2019 0.50 PROD1 WHDBOP RURD P R/U test joint and wear bushing 0.0 0.0 22:00 22:30 retrieving tool. Pull wear bushing. ( ID 6.25" No wear) 1/16/2019 1/16/2019 0.25 PROD1 WHDBOP WWWH P Flush stack @ 10 bpm 330 psi.. Blow 0.0 0.0 22:30 22:45 down top drive. 1/16/2019 1/17/2019 1.25 PROD1 WHDBOP RURD P Drain stack and set lest plug. R/U to 0.0 0.0 22:45 00:00 test BOPE. Fill stack and manifold with water, purge air from system. Shell test to 2500 psi (good test) 1/17/2019 1/17/2019 7.25 PRODt WHDBOP BOPE P Test BOPE with 3.5" and 4.5" test jts. 0.0 0.0 00:00 07:15 AOGCC rep Austin McLoud witness test. BLM rep Quinn Sawyer waived witness on 1-13-19 at 1108 hrs. With 4.5" TJ, test annular preventer to 250/2500 psi for 5/10 min, 3W' x 6" Upper VBR's, 3W' x 6" lower VBR's to 250/3500 psi for 5/10 min.Test 4" Demes Kill valve, Auto and manual IBOP valves, HCR and Manual Choke and Kill valves, floor safety valves 1- XT39 and, Dart Valves 1- XT39, Choke Valves 1-14 and Needle valve to 25013500 psi for 5110 min. Test gas alarms, Flow paddle and High level pit alarms. Perform accumulator test, System Pressure=3000 psi, Pressure after functioning all rams, annular and HCR's=1700 psi, 200 psi attained=26 sec, Full System Recovery --ill sec. 4 bottle Nitrogen average=2100 psi. Change to 3.5" test joint, lest annular to 250/2500 and lower VBR's to 250/3500 psi for 5/10 min. Test blind rams to 250/3500 5/5 min. Test Manual and Super Auto chokes to 1100 psi. 1/17/2019 1117/2019 0.50 PROD1 WHDBOP RURD P RID test equipment. Blow down choke 0.0 0.0 07:15 07:45 j j I I and kill lines. 1/17/2019 1/17/2019 0.50 PROD1 WHDBOP RURD P Pull test plug and install 6.25" wear 0.0 0.0 07:45 08:15 1 1 ring. 1/1712019 1/17/2019 0.25 PROD1 CEMENT RURD P P/U RCD bearing and R/U BPA 0.0 0.0 08:15 08:30 1 I manifold. Page 1809 ReportPrinted: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Btad Depth Bted Time End Time Dur hit Phase Op Code Activity Code Tone P.T.X Operation (WB) End Depth (WEI) 1/17/2019 1/17/2019 3.50 PROD1 CEMENT BHAH P PJSM, M/U BHA#7 to 135' MD per 0.0 135.0 08:30 12:00 Baker DD/MWD, Upload MWD/Perforn testrak function test with 200 gpm 770 psi. Blow down top drive. 1/17/2019 1/17/2019 1.00 PROD1 CEMENT BHAH P PJSM, P/U BHA#7 and load nukes 135.0 355.0 12:00 13:00 from 135' MD to 355' MD per Baker DD/MWD, Below jar 11.51k Total 14.8k. 1117/2019 1/1712019 6.25 PROD1 CEMENT TRIP P Trip in hole with BHA#7 from 355' to 355.0 10,991.0 13:00 19:15 10991' MD from derrick. Fill pipe every 20 stands. Trip displacement (Calculated: 69 bbls, ACT: 61 bbis.) 1/17/2019 1/1712019 0.50 PROD? CEMENT COCF P Wash and ream down from 10,991' 10,991.0 11,025.0 19:15 19:45 MD to 11,025' MD @ 200 gpm, 1600 psi, 60 rpm @ 5-61k Tq. Continue cutting mud weight to 10.2 ppg. 1/17/2019 1/17/2019 2.00 PROD1 CEMENT DRLG P Drill cement out shoe track from 11,025.0 11,132.0 19:45 21:45 11,025' MD to 11,059' MD. Clean out rat hole from 11,059' MD to 11,132' MD. @ 200 gpm, 1670 psi, 60 rpm @ 7-8k Tq. 1/17/2019 1/17/2019 0.50 PROD1 CEMENT DDRL P Drill new formation from 11,132' MD to 11,132.0 11,152.0 21:45 22:15 11,152' MD. @ 215 gpm @ 1630 psi, 11.05 ppg ECD. P/U=170k, S/O=145k, ROT=160k, 60 rpm. Tq onloff=7k. 1/17/2019 1/17/2019 1.25 PROW CEMENT CIRC P Back ream from 11,152' MD to 11,022' 11,152.0 11,022.0 22:15 23:30 MD @ 215 gpm, 1630 psi, 60 rpm 7.7k Tq. Work string inside the casing without rotation 4x. Rack back stand to 9,457' MD. 1/17/2019 1/18/2019 0.50 PROD1 CEMENT FIT P R/U and perform FIT to 12.5 ppg, 985 11,022.0 11,022.0 23:30 00:00 psi with 10.1 ppg mud in hole, no leak off. 1.4 bbl pumped and bled back. Shut in pressure 850 psi after ten minutes. 1/18/2019 1/18/2019 0.25 PROD1 CEMENT FIT P Finish monitor shut in pressure from 11,022.0 11,022.0 00:00 00:15 FIT & R/D testing equipment. 1/18/2019 1/18/2019 0.50 PROD1 DRILL MPDA P Remove trip nipple & install RCD 11,022.0 11,022.0 00:15 00:45 bearing. 1/18/2019 1/18/2019 0.50 PROD1 DRILL REAM P W&R f/11,022'to 11,152'w/200,1440 11,022.0 11,152.0 00:45 01:15 psi, 60 rpm, 8 k trq 1/18/2019 1/18/2019 1.75 PROD1 DRILL DISP P Pump 26 We Hi -Vis spacer and 11,152.0 11,152.0 01:15 03:00 displace 10.1 ppg mud with 8.8 ppg Repro @200 gpm 1200 gpm, 60 rpm while reaming from 11,152' MD to 11,086' MD. Take SCR's 1/18/2019 1/18/2019 0.75 PROD1 DRILL OWFF P Perform MPD draw down test with 8.8 11,152.0 11,152.0 03:00 03:45 ppg FloPro (25 psi increase) Well static 1/18/2019 1/18/2019 0.25 PROD1 DRILL REAM P Wash and ream from 11,086' MD to 11,152.0 11,152.0 03:45 04:00 11,152' MD @ 200 gpm 1010 psi 80 rpm 5k torque. 1/18/2019 1/18/2019 8.00 PROD1 DRILL DDRL P Directional drill from 11,152' MD to 11,152.0 11,805.0 04:00 12:00 11,805' MD, 7,922' TVD @ 226 gpm, - 1560 psi, 140 rpm, 8k ftlbs Tq. P/U wt 183k, SIO wt 139k, ROT wt 159k. ADT= 6.4 tins ECD: 10.03 ppg Max gas 4788 units. 1/18/2019 1/19/2019 12.00 PROD1 DRILL DDRL P Directional drill from 11,805' MD to 11,805.0 13,178.0 12:00 00:00 13,178' MD, 7,896' TVD @ 230 gpm, 1870 psi, 140 rpm, 8k ftlbs Tq. P/U wt 185k, SIO wt 140k, ROT wt 1561k ADT= 9.4 hrs ECD: 10.36 ppg Max gas 7833 units. Page 19/29 ReportPrinted: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Sten Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 1/19/2019 1/19/2019 12.00 PROD1 DRILL DDRL P Directional drill from 13,178' MD to 13,178.0 13,870.0 00:00 12:00 13,870' MD, 7,896' TVD @ 230 gpm, 2070 psi, 150 rpm, 9k - 12 f1lbs Tq. P/U wt 180k, SIO wt 130k, ROT wt 150k ADT= 9.9 hrs ECD: 10.48 ppg Max gas 6500 units @ 13,450' MD. 1/19/2019 1/20/2019 12.00 PROD1 DRILL DDRL P Directional drill from 13,870' MD to 13,870.0 14,978.0 12:00 00:00 14,978' MD, 7,896' TVD @ 230 gpm, 2110 psi, 140 rpm, 7.5k ftlbs Tq. P/U wt 185k, S/O wt 130k, ROT wt 155k ADT= 9.9 hrs ECD: 10.16 ppg Max gas 8500 units @ 14660' MD. 1/20/2019 1/20/2019 12.00 PRODI DRILL DDRL P Directional drill from 14,978' MD to 14,978.0 15,654.0 0000 12:00 15,654' MD, 7,922' TVD @ 230 gpm, 2190 psi, 140 rpm, 5 / 8.7k ftlbs Tq. P/U wt 190k, S/O wt 125k, ROT wt 155k ADT= 10.4 hrs ECD: 10.62 ppg Max gas 9000 units @ 15,150' MD. 1/20/2019 1/21/2019 12.00 PRODI DRILL DDRL P Directional drill from 15,654' MD to 15,654.0 16,615.0 12:00 00:00 16,615' MD, 7,944' TVD @ 230 gpm, 2070 psi, 140 rpm, 6.5 18.5k Ribs Tq. P/U wt 21 Ok, S/O wt 115k, ROT wt 152k ADT= 9.8 hrs ECD: 10.26 ppg Max gas 5300 units @ 16,490' MD. 1/2112019 1/2112019 12.00 PROD1 DRILL DDRL P Directional drill from 16,615' MD to 16,615.0 17,042.0 00:00 12:00 17,042' MD, 7,940' TVD @ 230 gpm, 2300 psi, 150 rpm, 916.5k ftlbs Tq. PIU wt 210k, S/O wt 115k, ROT wt 152k ADT= 10.4 hrs ECD: 10.47 ppg Max gas 9020 units @ 16,650' MD. 1/21/2019 1/22/2019 12.00 PRODI DRILL DDRL P Directional drill from 17,042' MD to 17,042.0 18,001.0 12:00 00:00 18,001' MD, 7,957' TVD @ 230 gpm, 2300 psi, 140 rpm, 11 / 7k ftlbs Tq. P/U wt 216k, S/O wt 115k, ROT wt 158k ADT= 10 hrs ECD: 10.81 ppg Max gas 9980 units @ 17,450' MD. 1/22/2019 1/22/2019 12.00 PRODI DRILL DDRL P Directional drill from 18,001' MD to 18,001.0 18,580.0 00:00 12:00 18,850' MD, 7,933' TVD @ 230 gpm, 2370 psi, 140 rpm, 11.6 / 7k ftlbs Tq. PIU wt 21 Ok, S/O wl N/Ak, ROT wt 162k ADT= 10.1 hrs ECD: 10.50 ppg Max gas 4570 units @ 18,210' MD. 1/22/2019 1/23/2019 12.00 PROD1 DRILL DDRL P Directional drill from 18,850' MD to 18,580.0 19,529.0 12:00 00:00 19,529' MD, 7907' TVD @ 230 gpm, 2370 psi, 150 rpm, 12.3/9 ftlbs Tq. P/U wt 223k, S/O wt N/Ak, ROT wt 158k ADT= 8.1 hrs ECD: 10.85 ppg Max gas 8776 units @ 18,704' MD. 1/23/2019 1/23/2019 12.00 PRODI DRILL DDRL P Directional drill from 19,529' MD to 19,529.0 20,608.0 00:00 12:00 20,608' MD, 7858' TVD @ 230 gpm, 2100 psi, 150 rpm, 14.5/10 Ribs Tq. PIU wt 245k, S/O wt N/Ak, ROT wt 160k ADT= 9.4 hrs ECD: 10.72 ppg Max gas 8086 units @ 20,570' MD. 1123/2019 1/23/2019 PROD1 DRILL DDRL P Directional drill from 20,608' MD to 20,608.0 21,704.0 12:00 12:00 21.704' MD, 7847' TVD @ 230 gpm, 2100 psi, 150 rpm, 15/10 ftlbs Tq. PIU wt 245k, SIO wt N/Ak, ROT wt 160k ADT= 9.5 hrs ECD: 10.84 ppg Max gas 8328 units @ 20,733' MD. Page 20129 ReportPrinted: 2/19/2019 Operations Summary (with Timelog Depths) Awl,% MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time Ew Tme Dur(hr) Phase Op Cede Activity Code Time P -T -x Operation (PKa) End DePlh (IIKa) 1/24/2019 1/24/2019 6.50 PRODt DRILL DDRL P Directional drill from 21,704'MD to 21,704.0 22,228.0 00:00 06:30 22,228' MD, 7834' TVD @ 230 gpm, 2670 psi, 150 rpm, 17.5/10.5 ftlbs Tq. PIU wt 250k, S/O wt N/AK ROT wt 160k ADT= 5.2 hrs ECD: 11.4 ppg Max gas 6000 units @ 21,920' MD. 1/2412019 1/24/2019 3.00 PROD1 CASING CIRC P Circ 2 B/U w/230 gpm, 2650 psi, 80 22,228.0 22,133.0 06:30 09:30 rpm, 12 k trq. Rack back 1 stand to 22,133' 1/24/2019 1/24/2019 0.50 PROD1 CASING OWFF P B/D top drive. Shut in MPD chokes. 22,133.0 22,133.0 09:30 10:00 Perform formation draw down test w/8.9 ppg mud. Build 140 psi in 10 min. Bleed off pressure. Build 130 psi in 10 min. Calculate 0.33 ppg under balance. Decision made to weight up to 9.4 ppg. 1/24/2019 1124/2019 0.50 PROD1 CASING BKRM P BROOH f/22,133'to 22,038'w/225 22,133.0 22,038.0 10:00 10:30 gpm, 2520 psi, 30 rpm, 10 k trq. Weight up on the fly to 9.4ppg 1/24/2019 1/24/2019 1.50 PROD1 CASING PMPO P Pump OOH w/225 gpm, 2050 psi. 22,038.0 21,948.0 10:30 12:00 f/22,038- to 21,948' taking Test Track pressure samples as per Baker reps. (Continue to weight up to 9.4ppg). 1/24/2019 1/24/2019 2.00 PROD1 CASING DLOG P Test station 1:21,948' MD, 3 attempts 21,946.0 21,948.0 12:00 14:00 to obtain sample no success. (continue to weight up to 9.4ppg). 1/24/2019 1124/2019 1.00 PROD1 CASING BKRM P Backream V 21948'to 21,840' 21,948.0 21,840.0 14:00 15:00 225gpm, 2230psi, 100 rpm, 12.5k ftlibs tq. (continue weighting up to 9.4ppg). Decision made to go back to bottom and finish weighting up. 1/24/2019 1/24/2019 1.50 PROD1 CASING WASH T Wash/ream 21,840'to 22,226' 21,840.0 22,226.0 15:00 16:30 225gpm, 2350psi, 80-120 rpm, 12- 12.51k fUlbs tq. (continue weighting up to 9.4ppg) 1/24/2019 1/24/2019 2.00 PROD1 CASING CIRC T Circulate and condition mud. Finish 22,226.0 22,226.0 16:30 18:30 1 1 weighting up to 9.4ppg. 1/24/2019 1/24/2019 0.50 PRODi CASING OWFF T Perform 30 minute flow check. Static. 22,226.0 22,226.0 18:30 19:00 1/24/2019 1/24/2019 1.50 PROD1 CASING BKRM T Backream it 22,226'to 21,851' 22,226.0 21,851.0 19:00 20:30 225gpm, 2400psi, 80rpm, 12k tt/Ibs tq, 1/24/2019 1/25/2019 3.50 PROD1 CASING DLOG P Log 21,851'to 21,654'for corrrelation. 21,851.0 21,654.0 20:30 00:00 Get on depth for test station #2: bit depth 21,727' sample depth 21,643.37'. 1/25/2019 1/25/2019 10.50 PROD1 CASING DLOG P Pump& BROOH while taking 21,654.0 20,028.0 00:00 10:30 formation pressure samples f/21,654 to 20,028'w/225 gpm, 2350 psi, 50 rpm, 11 k trq (Bit depths for samples; 21,646, 21,566, 21,377, 21,251, 21,163, 20,985, 20,907, 20,495, 20,291, 20,028) 1/25/2019 1/2512019 10.00 PROD1 CASING BKRM P BROOH to next sample depth 20,028.0 17,455.0 10:30 20:30 (/20,028' to 17,454 w/225 gpm, 2350 psi, 80 - 30 rpm, 11 - 14 k trq. (Had significant trouble back reaming thru Kingak f/18,385' - 18,100' hole packing off & stalling out top drive). 1/25/2019 1/25/2019 1.00 PRODt CASING DLOG P Take formation pressure sample @ 17,455.0 17,455.0 20:30 21:30 17,454' MD bit depth. 1/25/2019 1/26/2019 2.50 PROD1 CASING REAM P Wash/ Ream f/ 17,454'to 18,130'. 17,455.0 18,130.0 21:30 00:00 220k PU/ 158k Rot Wt. 200 GPM/ 1870 PSI/ 9k Ft/Lbs TQ. Losses Q10 bph slowed rate to 200gpm. Page 21129 ReportPrinted: 211912019 y, Operations Summary (with Timelog Depths) MT6-02 W Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log shah Depth BteetTyne I EnGTime Dur(hr) Phase Op Cafe Activity Cade Time P -T -X operation (ftKB) End Depth(ftKB) 1/26/2019 1/26/2019 13.50 PROD1 CASING REAM P Wash/ Ream f/18,130'to22,228' 18,130.0 22,228.0 00:00 13:30 w/200 - 220gpm, 1880 - 2000 psi, 80 rpm, 11.5 k trq, PU wt 230 k, ROT wt 159 k. No issues reaming back thru Kingak 1/26/2019 1/26/2019 0.50 PROD1 CASING SVRG P Service rig, top drive & draw works. 22,228.0 22,228.0 13:30 14:00 Circ w/200 gpm, 2000 psi 1/26/2019 1/26/2019 0.50 PROD1 CASING CIRC P Circ & cond w/200 gpm, 2000 psi, 80 22,228.0 22,228.0 14:00 14:30 rpm, 12 k trq. SIMOPS - PJSM & prep for displacemt. 1/26/2019 1/26/2019 2.50 PRODi CASING DISP P Displace well to 9.6 ppg vis brine 22,228.0 22,228.0 14:30 17:00 w/225 gpm, 2300 psi, 80 rpm, 12 k trq 1/26/2019 1/26/2019 0.50 PROD1 CASING OWFF P FIC (static) SIMOPS - line up MPD to 22,228.0 22,228.0 1700 17:30 stripOOH 1/26/2019 1/2712019 6.50 PROD1 CASING SMPD P StripOOH as per MPD schedule 22,228.0 18,080.0 17:30 00:00 f/22,228'to 18.080'. (18,874'15k drag/ 18,204'15k drag /18,174' 12k drag) 1/27/2019 1/27/2019 7.25 PROD1 CASING SMPD P StripOOH as per MPD schedule 18,080.0 11,342.0 00:00 07:15 f118,080'to 11,342' as per MPD schedule. Tock wt w/ 25 k wob 11,342' and not able to make forward process. Decision made to back ream 1127/2019 1/27/2019 1.25 PROD1 CASING BKRM T BROOH f/11,342' to 10,992' w/225 11,342.0 10,992.0 07:15 08:30 gpm, 1140 psi, 40 rpm, 6 k trq 1127/2019 1/27/2019 1.25 PROD1 CASING CIRC P Pump high vis sweep & circ casing 10,992.0 10,992.0 08:30 09:45 clean w/225 gpm, 1300 psi, 40 rpm, 5.6 k trq 1/27/2019 1/27/2019 0.25 PROD1 CASING OWFF P F/C (static) SIMOPS - B/D top drive, 10,992.0 10,992.0 09:45 10:00 function rams, PJSM on C/O RCD bearing. Mobilize tools & equipment. 1/27/2019 1/27/2019 0.50 PROD1 CASING MPDA P C/O RCD bearing 10,992.0 10,992.0 10:00 10:30 1/27/2019 1/27/2019 1.00 PROD1 CASING SLPC P Slip & cut drill line 75' drill line. 10,992.0 10,992.0 10:30 11:30 Calibrate block height. 1/27/2019 1/27/2019 0.50 PROD1 CASING SVRG P Service dg, top drive, draw works. 10,992.0 10,992.0 11:30 12:00 1/27/2019 1/27/2019 0.50 PROD1 CASING MPDA P Line up MPD equipment 10,992.0 10,992.0 12:00 12:30 1/27/2019 1/27/2019 7.50 PROD1 CASING SMPD P StripOOH as per MPD schedule 10,992.0 1,020.0 12:30 20:00 f/10,992'to 1,020'. 1/27/2019 1/27/2019 1.00 PROD1 CASING MPDA P Flow check (Static). Retrieve RCD 1,020.0 1,020.0 20:00 21:00 bearing and install trip nipple. 1/27/2019 1/27/2019 1.25 PROD1 CASING TRIP P POOH f/ 1020'to 266' 1,020.0 266.0 21:00 22:15 1/27/2019 1/27/2019 1.50 PROD1 CASING SHAH P PJSM. Remove source and UD BHA. 266.0 0.0 22:15 23:45 1/27/2019 1/28/2019 0.25 PROD1 CASING BHAH P Clean & clear floor of BHA tools & 0.0 0.0 23:45 00:00 equipment. 1/28/2019 1/28/2019 1.00 COMPZN CASING RURD P Clean rig floor from wet trip. SIMOPS - 0.0 0.0 00:00 01:00 Mobilize liner running tools & equipment. 1/28/2019 1/28/2019 2.00 COMPZN CASING PULD P PIU & rack back in derrick 17 stands 0.0 0.0 01:00 03:00 of 4" HWDP for liner run. 1/28/2019 1/28/2019 1.00 COMPZN CASING RURD P R/U to run 4-1/2" liner. Power tongs, 0.0 0.0 03:00 04:00 slips & elevators. 1/28/2019 1/28/2019 6.00 COMPZN CASING PUTB P Pick up & RIH 4-1/2" 12.6# L-80 TXP 0.0 5,983.0 04:00 10:00 liner with pert pups to 5,983' If 50 Its & 22 pert pups) Page 22129 Report Printed: 2119/2019 . Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sean 7me EM Time Dw (hr) Phase Op Cove Activity C.d. Torre PJX Operation Start Depth (ftKa) EM Depth (WEI) 1/28/2019 1/28/2019 1.00 COMPZN CASING PUTB P C/O Handle equipment & M/U HRDE 5,893.0 6,018.0 10:00 11:00 liner setting sleeve as per Baker rep. Break circ & confirm fluid path clean w/1 bpm @ 60 psi, PU wt 120 k / SO wt 110 k 1/28/2019 1/28/2019 0.75 COMPZN CASING RURD P R/D liner running tools & equipment. 6,018.0 6,018.0 11:00 11:45 Clean & clear floor. 1/28/2019 1/29/2019 12.25 COMPZN CASING RUNL P RIH wl TXP liner on DP f/6,018'to 6,018.0 16,972.0 11:45 00:00 16,972'. Parameters @ 11,047': 165k PU, 140k SO, 152k Rot, 3 bpm @ 370psi, 3.5k fUlbs TO @ 10/20/30 rpm. Parameters @ 16,972': 205k PU, 125k SO, 165k Rot, 3 bpm @ 370psi, Sk fUlbs To @ 10/20/30 rpm. 1/29/2019 1/29/2019 12.00 COMPZI CASING RUNL P RIH w/TXP liner on DP f/16,972'to 16,972.0 20,448.0 00:00 12:00 20,448'. PU wt 210 k, SO wt N/A, ROT wt 170 k, 30 rpm, 8.8 - 10 k trq. Washing down @ 1.5 bpm, 150 - 200 psi. Had to rotate liner f/17,900'. Had trouble washing & reaming 1/19,695'to 19,715'. 1/29/2019 1/29/2019 1.50 COMPZI CASING RUNL P Conl.W&R liner f/20,448'to set depth 20,448.0 20,905.0 12:00 13:30 of 20,905' w/1.5 gpm, 200 psi, 30 rpm, 9.7 k trq. Dropped ball on last stand. PU wt 215 k, SO wt N/A, ROT wt 175 k 1/29/2019 1/29/2019 0.75 COMPZ1 CASING CIRC P Circ down ball w/5 bpm, 930 psi. Slow 20,905.0 14,831.0 13:30 14:15 pumps to 2 bpm, 240 psi @ 900 stks. Ball on seat 1400 stks. Pressure up to 3000 psi & release from liner. PU with 200 k & confirm free. SO & confirm dogs are out. POOH 1 stand to 14,831' (Shoe @ 20,905'& TOL 14,896') 1/29/2019 1/29/2019 0.25 COMPZI CASING OWFF P B/D top drive. F/C (static) 14,831.0 14,831.0 14:15 14:30 1/29/2019 1/30/2019 9.50 COMPZI WELLPR TRIP P POOH f/14,831'to 1270'. 14,831.0 1,270.0 14:30 00:00 1/30/2019 1/30/2019 0.50 COMPZI WELLPR TRIP P POOH f/1270' 1p 36' 1,270.0 -§6-0- 6000:00 00:00 00:30 1/30/2019 1/30/2019 0.50 COMPZ1 WELLPR BHAH P UD Baker liner running tools. 36.0 0.0 00:30 01:00 1/30/2019 1/30/2019 0.50 COMPZI WELLPR CLEN P Clean & clear floor of BHA tools & 0.0 0.0 01:00 01:30 equip. 1/30/2019 1/30/2019 1.75 COMPZ1 WELLPR PULD P RIH 15 stands of HWDP needed for 0.0 0.0 01:30 03:15 liner run to 1,351'. POOH & UD same. 1/30/2019 1/30/2019 3.00 COMM WELLPR RGRP P C/O saver sub on top drive. 0.0 0.0 03:15 06:15 1/30/2019 1/30/2019 0.50 COMPZI WHDBOP WWWH P M/U Johnny wacker&flush stack. 0.0 0.0 06:15 06:45 1/30/2019 1/30/2019 2.75 COMPZI WHDBOP RURD P FMC pull wear ring & set test plug. 0.0 0.0 06:45 09:30 R/U to test BOPE. Fill stack with H2O & purge. Flood lines & purge air from system. Shell test BOPE. SIMOPS - C/O valve paddle & seat on 4" Demco Page 23129 ReportPrinted: 2119/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Slat Time Ent! Time our (hr) phase op Code Adiviry Cole rare p -T -X operation MKS) End Depth (ftKB) 1/30/2019 1/30/2019 5.50 COMPZ1 WHDBOP BOPE P Test BOPE w/4"&4-112"test joints. 0.0 0.0 09:30 15:00 Annular 250 psi for 5 min / 2500 psi for 5 min, Remaining test 250 psi for 5 min / 3500 psi for 5 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Uppenlower 3-1/2" X 6" VBR's & blind rams, 4" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 2950 psi, final 1450 psi, tat 200 psi recharge = 31 sec's, full recharge = 160 seconds. Nitrogen Bottles x4 = 2100 psi. Gas alarms and PVT alarms tested. Draw down on chokes V1100 psi. AOGCC Guy Cook waived witness. 1/30/2019 1/30/2019 1.00 COMPZ1 WHDBOP RURD P R/D testing equipment. Pull test plug & 0.0 0.0 15:00 16:00 set wear ring. 1/30/2019 1/30/2019 3.75 PROD2 DRILL BHAH X PJSM. MID 6"AutoTrak BHA as per 0.0 344.0 16:00 19:45 Baker reps to 344'. (Load sources) 1/30/2019 1/30/2019 2.00 PROD2 DRILL PULD X RIH w/BHA picking up 66 jts 4" DP 344.0 2,200.0 19:45 21:45 f/344' to 2200' 1/30/2019 1/30/2019 0.25 PROD2 DRILL DHEQ X Shallow Test MWD tools w/200 gpm, 2,200.0 2,200.0 21:45 22:00 650 psi 1/30/2019 1/31/2019 2.00 PROD2 DRILL TRIP X RIH w/ BHA, culling Jts w/ worn 2,200.0 2,526.0 22:00 00:00 hardbanding and UD same f/2,200' to 2,526' 1/31/2019 1/31/2019 8.00 PROD2 DRILL TRIP X RIH w/ BHA, culling As w/ worn 2,526.0 10,982.0 00:00 08:00 hardbanding and UD same f/2,526' to 10,982' 1/31/2019 1/31/2019 1.00 PROD2 DRILL SLPC X Slip & cut 60' drill line 10,982.0 10,982.0 08:00 09:00 1/31/2019 1/31/2019 0.50 PROD2 DRILL SVRG X Service dg, top drive & draw works. 10,982.0 10,982.0 09:00 09:30 1/31/2019 1131/2019 1.00 PROD2 DRILL MPDA X Pull trip nipple & install RCD bearing. 10,982.0 10,982.0 09:30 10:30 Break in bearing as per MPD rep. 1/31/2019 1/31/2019 1.00 PROD2 DRILL TRIP X Cont. to RIH f/10,982'to 11,728' 10,982.0 11,728.0 10:30 11:30 1/31/2019 2/1/2019 12.50 PROD2 DRILL DDRL X Trough, time drill & open hole side 11,728.0 11,735.0 11:30 00:00 track w/230 gpm, 1300 psi, 100 rpm, 6 k 6q. f/11,728 to 11,735' (Displace 9.6 ppg vis brine to 8.8 ppg FloPro on thre fly) 2/1/2019 2/112019 12.00 PROD2 DRILL DDRL X Time drill f/11,735'to 11,752' MD / 11,735.0 11,752.0 00:00 12:00 7,933' TVD, ADT 12.0 Hrs, ECD 9.73 ppg, 230 gpm, 1390 psi, ROT wt 167 k, 120 rpm, 3.5 k trq. 2/112019 2/1/2019 7.50 PROD2 DRILL DDRL X Drill f/11,735'to 11,837' MD / 7,229' 11,752.0 11,837.0 12:00 19:30 TVD, ECD 9.73 ppg, 230 gpm, 1390 psi, ROT wt 167 k, 120 rpm, 3.5 k trq. 2/112019 2/1/2019 2.00 PROD2 DRILL DHEQ XT MWD tools stopped working. 11,837.0 11,847.0 19:30 21:30 Troubleshoot tools. Recycle pumps, different flow rates, drilled 10' to 11,847'. Several attempts with no success. After discussion with town decision made to POOH. 2/1/2019 2/2/2019 2.50 PROD2 DRILL BKRM XT Beckman OOH f/ 11,847'to 11,361', 11,847.0 11,361.0 21:30 00:00 Simops Prep to displace to 9.6ppg vis brine. 2/2/2019 2/2/2019 2.00 PROD2 DRILL XT BROOH f/11,361'to 10,981'. No 11,361.0 10,981.0 00:00 02:00 rotation while pulling lhru shoe. FM SIMOPS - Prep to displace to 9.6ppg vis brine. 2/2/2019 2/2/2019 1.75 PROD2 DRILL DISP XT Displace to 9.6 ppg Vis Brine w/225 10,981.0 10,981.0 02:00 03:45 1 gpm, 1130 psi, 10 rpm, 32 k trq. Page 24129 Report Printed: 2119120119 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sten Depth Start Time End Time our (hr) Phase Op coca ActlNly code Tim P -T -X Operation (flKB) EM Depth (flKe) 212/2019 2/2/2019 0.50 PROD2 DRILL OWFF XT F/C(static) 10,981.0 10,981.0 03:45 04:15 2/2/2019 2/2/2019 5.75 PROD2 DRILL SMPD XT StripOOH as per MPD schedule 10,981.0 911.0 04:15 10:00 f/10,981'to 212/2019 2/2/2019 0.25 PROD2 DRILL OWFF XT F/C (static). SIMOPS - PJSM on 911.0 911.0 10:00 10:15 pulling RCD bearing. 2/2/2019 2/22019 0.50 PROD2 DRILL MPDA XT Pull RCD bearing & install trip nipple. 911.0 911.0 10:15 10:45 2/2/2019 2/22019 0.25 PROD2 DRILL TRIP XT POOH f/91 Vto 344' 911.0 344.0 10:45 11:00 2/2/2019 2/2/2019 3.50 PROD2 DRILL SHAH XT Rack back HWDP & jars. Remove 344.0 0.0 11:00 14:30 sources. Plug into tools & determine failure. Bad BCPM & AzlTrak. UD Same. 222019 2/22019 2.50 PROD2 DRILL BHAH XT M/U new BHA as per Baker reps. 0.0 344.0 14:30 17:00 Inspect bit graded 1-1. Plug into tools. Load sources. RIH Jars & HWDP. 2/212019 2/2/2019 0.75 PROD2 DRILL TRIP XT RIH to 2,243'. 344.0 2,241.0 17:00 17:45 2/212019 22/2019 0.75 PROD2 DRILL DHEQ XT Shallow hole test MWD tools @ 2,241.0 2,241.0 17:45 18:30 2,241'. 215 gpm, 775 psi, 30 rpm. 212/2019 2/3/2019 5.50 PROD2 DRILL TRIP XT RIH f/ 2,243'to 10,917' Filling pipe 2,241.0 10,917.0 18:30 00:00 every 20 skis. 2/3/2019 2/3/2019 0.50 PROD2 DRILL MPDA XT Pull trip nipple & install RCD bearing 10,917.0 10,917.0 00:00 00:30 2/3/2019 2/3/2019 0.25 PROD2 DRILL DHEA XT Pulse test MWD/LWD tools w/200 10,917.0 10,917.0 00:30 00:45 gpm, 1030 psi, 30 rpm, 4.7 k trq, 2/32019 2/3/2019 1.75 PROD2 DRILL DISP XT Displace to 8.8 ppg FloPro w/225 10,917.0 10,917.0 00:45 02:30 gpm, 1450 psi 2132019 2/312019 1.00 PROD2 DRILL TRIP XT RIH f/10,917- to 11,745 10,917.0 11,745.0 02:30 03:30 213/2019 2/312019 0.75 PROD2 DRILL REAM XT W&R f/11,745 to 11,847'w/225 gpm, 11,745.0 11,847.0 03:30 04:15 1430 psi, 120 rpm, 5.2 k trq. No issues getting into sidetrack. 2/3/2019 2/3/2019 7.75 PROD2 DRILL DDRL X Drill ahead f/11,847'to 12,428' MD 1 11,847.0 12,428.0 04:15 12:00 7,937' TVD, ADT 6.6 Hrs, ECD 10.42 ppg, 225 gpm, 1660 psi, PU w1183 k, $O wt 138 k, ROT w1161 k, 130 rpm, Trq On/Off 614 k fUlbs, 10113 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/312019 2/4/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/12,428'to 13,503' MD / 12,428.0 13,503.0 12:00 00:00 7,917' TVD, ADT 9.9 Hrs, ECD 10.75 ppg, 225 gpm, 1860 psi, PU wt 183 k, SO wt 136 k, ROT wt 161 k, 130 rpm, Trq On/Off 6/4 k ft/lbs, 10113 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/4/2019 2/4/2019 12.00 PROD2 DRILL DDRL X Drill ahead f113,503'to 14,732' MD / 13,503.0 14,732.0 00:00 12:00 7,940' TVD, ADT 9.6 Hrs, ECD 10.91 ppg, 225 gpm, 2010 psi, PU wt 200 k, SO wt 125 k, ROT wt 158 k, 130 rpm, Trq On/Off 8.515 k ft/lbs, 8/12 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/4/2019 2/5/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/14,732'to 15,710' MD / 14,732.0 15,710.0 12:00 00:00 7933' TVD, ADT 10.1 Hrs, ECD 10.69 ppg, 225 gpm, 2140 psi, PU wt 203 k, SO wt 113 k, ROT wt 157 k, 130 rpm, Trq On/Off 11/6 k ft/lbs, 5/14 k WOB. Closing MPD chokes on connections & monitoring pressure. Page 25129 Report Printed: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Our(/.) Phase Op Code A fty Code Tune P -T -X operation (flKB) End DepN(BKB) 2/5/2019 215/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/15,710'to 16,800' MD / 15,710.0 16,800.0 00:00 12:00 7926' TVD, ADT 9.3 Hrs, ECD 10.98 ppg, 230 gpm, 2270 psi, PU wt 210 k, SO wt nla, ROT wt 163 k, 130 rpm, Trq On/Off 10.7/6.2 k f albs, 8/10 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/5/2019 2/6/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/16,800' to 17,730' MD / 16,800.0 17,730.0 12:00 00:00 7910' TVD, ADT 10.3 Hrs, ECD 10.74 ppg, 230 gpm, 2270 psi, PU wt 225 k, SO wt Na, ROT wt 155 k, 130 rpm, Trq On/Off 12/8.4 k It/lbs, 9111 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/6/2019 2/6/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/17,730'to 18,796' MD / 17,730.0 18,796.0 0000 1200 7,915' TVD, ADT 9.2 Hrs, ECD 11.09 ppg, 230 gpm, 2250 psi, PU wt 240 k, SO wt n/a, ROT wt 163 k, 130 rpm, Trq On/Off 13.9/9.8 k fttlbs, 719 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/6/2019 2/6/2019 11.75 PROD2 DRILL DDRL X Drill ahead f/18,796' to 19,930' MD / 18,796.0 19,930.0 12:00 23:45 7,867' TVD, ADT 9.7 Hrs, ECD 11.2 ppg, 230 gpm, 2600 psi, PU wt 240 k, SO wt Na, ROT wt 163 k, 130 rpm, Trq On/Off 13.9/9.8 k ft/lbs, 10/12 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/6/2019 2/7/2019 0.25 PROD2 DRILL CIRC X Circulate hole clean. 230 gpm, 19,930.0 19,930.0 23:45 00:00 2600psi, 130 rpm, 13k ft/lbs tq. 217/2019 2/7/2019 4.75 PROD2 CASING CIRC X Circulate hole clean. Racking back std 19,930.0 19,740.0 00:00 04:45 after each bottoms up. 225 gpm. 2410 psi. 80 rpm. 11k ftAbs tq. 2/7/2019 2/7/2019 5.25 PROD2 CASING DISP X Displace to 9.6 ppg vis brine. 230 19,740.0 19,740.0 04:45 10:00 gpm. 2410 psi. 80 rpm. 2/7/2019 2/7/2019 1.25 PROD2 CASING OWFF X Fingerprint well. Flow check static. 19,740.0 19,740.0 10:00 11:15 Take slow pump rates. Drop 2.09 hollow drift w/ tail. 2/7/2019 2/712019 0.75 PROD2 CASING SMPD X SOOH f/ 19,740'to 19,104' per 19,740.0 19,104.0 11:15 12:00 stripping schedule. 40/80 psi in/out slips. 20k OP at 19,104' 2!7/2019 2!7/2019 3.00 PROD2 CASING BKRM X RIH to 19,263'. Backream fl 19,263'to 19,104.0 18,500.0 12:00 15:00 18,500'. 230 gpm. 1790 psi. 100 rpm. 9.7k ft/lbs tq. 2/7/2019 2/712019 1.50 PROD2 CASING CIRC X Circulate BU 230 gpm. 1800 psi. 100 18,500.0 18,500.0 15:00 16:30 rpm. 9.7k ft/lbs tq. minimal cuttings across shakers. 2/7/2019 2/7/2019 6.25 PROD2 CASING SMPD X SOOH f/ 18,500'to 10,981' per 18,500.0 10,981.0 16:30 22:45 1 1 1 stripping schedule. 217/2019 2/8/2019 1.25 PROD2 CASING CIRC X Pump 30 bbl hi vis sweep. 230 gpm. 10,981.0 10,981.0 22:45 00:00 1300 psi. 20 rpm 4.2k ftllbs tq. reciprocating std. 2/8/2019 2/812019 0.25 PROD2 CASING CIRC X Circulating BU. 10,981.0 10,981.0 00:00 00:15 2/812019 2/8/2019 0.50 PROD2 CASING OWFF X Flow check. Static 10,981.0 10,981.0 00:15 00:45 2/8/2019 2/812019 3.25 PROD2 CASING SMPD X SOOH ff 10,981' to 5,755' per 10,981.0 5,755.0 00:45 04:00 stripping schedule. 2/8/2019 2/8/2019 5.50 PROD2 CASING SMPD X SOOH f/ 5,755' to 1,007' UD DP per 5,755.0 1,007.0 04:00 09:30 stripping schedule. 2/8/2019 2/8/2019 0.25 PROW CASING OWFF X Flow check. Static 1,007.0 1,007.0 09:30 09:45 1 I Page 26/29 Report Printed: 2 /1 912 01 9 Operations Summary (with Timelog Depths) ALI 13 MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log stmt tiepin StemTme End Time our (hr) Phase Op Code AcbN*Code Tome P -T -X Operation (MS) End Depth (W13) 2/8/2019 2/8/2019 0.25 PROD2 CASING MPDA X Retrieve RCD bearing assembly. 1,007.0 1,007.0 09:45 10:00 Install trip nipple. 2/8/2019 2/8/2019 2.00 PROD2 CASING PULD X POOH f/ 1,007'to 344' UD DP 1,007.0 344.0 10:00 12:00 2/812019 2/8/2019 2.25 PROD2 CASING BHAH X POOH UD BHA 344.0 0.0 12:00 14:15 2/812019 2/8/2019 1.25 PROD2 CASING CLEN X Clean and clear rig floor. 0.0 0.0 14:15 15:30 2/8/2019 2/8/2019 2.50 COMPZN CASING PULD X P/U and rack back 15 stds HWDP. 0.0 0.0 15:30 18:00 2/8/2019 2/8/2019 1.00 COMPZN CASING RURD X RU to run 4 1/2" lower completion. 0.0 0.6- 18:00 19:00 2/8/2019 2/9/2019 5.00 COMPZN CASING PUTB X RIH w/ 4 1/2" lower completion to 0.0 3,798.0 19:00 00:00 3,798'. 2/9/2019 219/2019 7.25 COMPZN CASING PUTS X RIH w/ 4 1/2" lower completion f/ 3,798.0 8,455.0 00:00 07:15 3,798'to 8,455' 2/912019 2/9/2019 2.25 COMPZN CASING OTHR X M/U ZXP liner hanger packer 8,455.0 8,608.0 07:15 09:30 assembly. RIH to 8,608'. Break circulation. 120 gpm. 110 psi. PU 162k. DN 133k. ROT 148k. 20 rpm 4k ft/lbs tq. 2/9/2019 2/9/2019 2.00 COMPZN CASING RUNL X RIH w/ liner on DP f/ 8,608'to 10,983'. 8,608.0 10,983.0 09:30 11:30 Parameters @ shoe: UP 162k. DN 133k. ROT 148k. 10/20 rpm 3.7k/4k ft/lbs tq. 2/9/2019 2/9/2019 10.25 COMPZN CASING RUNL X RIH w/ liner on DP f/ 10,983' to set 10,983.0 19,394.0 1130 21:45 depth @19,394'. PU 225k. D 125k. 2/9/2019 2/9/2019 1.25 COMPZN CASING CIRC X Circulate BU.4 bpm. 620 psi. 19,394.0 19,394.0 21:45 23:00 2/9/2019 2/9/2019 0.25 COMPZN CASING OWFF X Flow check. Static 19,394.0 19,394.0 23:00 23:15 2/9/2019 2/10/2019 0.75 COMPZN CASING PACK X Drop 1.625" ball and pump down @ 3 19,394.0 19,394.0 23:15 00:00 bpm. Pressure up to 650 hold 1 minute. Pressure up to 2500 psi. Set down 75k and confirm hanger set. Pressure up to 3500 psi to release running tool. P/U and expose slips. Set down w/ 15 rpm and 70k. Observe shear @ 125k hookload. Shoe depth 19,394'. TOL 10,900'. 2110/2019 2/10/2019 1.00 COMPZN CASING PRTS X Test packer to 3300 psi for 10 19,394.0 19,394.0 00:00 01:00 minutes. Good test. 2/10/2019 2110/2019 0.25 COMPZN WELLPR TRIP X POOH f/ 11,051 to 10,890'. 11,051.0 10,890.0 01:00 01:15 2/10/2019 2110/2019 1.50 COMPZN WELLPR CIRC X Circulate BU.4 bpm. 440 psi. 10,890.0 10,890.0 01:15 02:45 2/1012019 2/10/2019 0.25 COMPZN WELLPR OWFF X Flow check. STatic 7,612.0 7,612.0 02:45 03:00 2/10/2019 2/10/2019 4.00 COMPZN WELLPR DEVIL X POOH f/ 10,890 to 7612' @ 1500 ft/hr 10,890.0 7,612.0 03:00 07:00 logging w/ SCMT tool. Observed 200k OP @ 7" liner top. Rotate @ 5 rpm to pull through. 2/10/2019 2/10/2019 1.00 COMPZN WELLPR SLPC X Slip/cut 80' drill line. 7,612.0 7,612.0 07:00 08:00 2/10/2019 2/10/2019 0.50 COMPZN WELLPR SVRG X Service rig. 7,612.0 7,612.0 08:00 08:30 2/10/2019 2/10/2019 8.25 COMPZN WELLPR PULD X POOH UD DP f/ 7612'to 100' 7,612.0 100.0 08:30 16:45 2/10/2019 2/10/2019 1.50 COMPZN WELLPR SHAH X UD running tool and SMT tool. 100.0 0.0 16:45 18:15 Page 27129 Report Printed: 2119/2019 Operations Summary (with Timelog Depths) MT6-02 IM t is Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depm statin" End Torre Dw(hr) Phase Op Code Activit' Code Time P -T -x Operation (KKB) End Depth(M) 2/10/2019 2110/2019 1.00 COMPZN RPCOMP W W WH X Jet stack w/ 15 bpm 60 psi. Pull wear 0.0 0.0 18:15 19:15 bushing. Jet stack again w/ 15 bpm 60 psi. 2/10/2019 2/10/2019 1.25 COMPZN RPCOMP RURD P RU to run upper completion. 0.0 0.0 19:15 20:30 2/10/2019 2/11/2019 3.50 COMPZN RPCOMP PUTS P RIH w/ 4 1/2 TSH Blue upper 0.0 2,291.0 20:30 00:00 completion to 2,291'. 2111/2019 2/11/2019 2.50 COMPZN RPCOMP PUTB P RIH w/ 4 1/2" TSH Blue upper 2,291.0 3,956.0 00:00 02:30 1 completion f12,291' to 3,956' 2111/2019 2/11/2019 0.50 COMPZN RPCOMP SVRG P Service rig 3,956.0 3,956.0 02:30 03:00 2/11/2019 2/11/2019 0.75 COMPZN RPCOMP RGRP T Troubleshoot power tongs. 3,956.0 3,956.0 03:00 03:45 2/11/2019 2/11/2019 0.75 COMPZN RPCOMP PUTS P RIH wl4 1/2" TSH Blue upper 3,956.0 4,526.0 03:45 04:30 completion f/ 3,956'to 4,526'. 2/11/2019 2/11/2019 3.25 COMPZN RPCOMP WAIT T Phase III weather. Secure well and 4,526.0 4,526.0 04:30 - 07:45 monitor on TT. 2/11/2019 2111/2019 0.75 COMPZN RPCOMP WAIT T Perform derrick inspection after 4,526.0 4,526.0 07:45 08:30 inclement weather. 2/11/2019 2111/2019 8.00 COMPZN RPCOMP PUTB P RIH w/ 4 112" TSH Blue upper 4,526.0 10,807.0 08:30 16:30 completion f/ 4,526' to 10,807'. 2/11/2019 2/11/2019 1.50 COMPZN RPCOMP HOSO P MU 3jts and pump in sub. Wash down 10,807.0 10,900.0 16:30 18:00 @ 1bpm. Locate top of liner@ 10,900'. (Observed pressure increase). SO and locate no-go @ 10,914'. POOH w/ extra joints. 2111/2019 2/11/2019 1.50 COMPZN RPCOMP THGR P MU 3 pup joints, full joint, tbg hanger, 10,900.0 10,900.0 18:00 19:30 and landing joint A. Wash down 1 bpm t/ locate TOL. (Observed pressure increase). Pull tbg tbg hanger up to trip nipple to displace. 2111/2019 2/11/2019 2.25 COMPZN RPCOMP CRIH P Pump 210 bbls 9.6 ppg Cl Cir brine, 10,900.0 10,900.0 10:30 21:45 153 bbis 9.6 ppg clear brine. 2/11/2019 2/11/2019 0.75 COMPZN RPCOMP OWFF P Flow check. Static. Blow down surface 10,900.0 10,900.0 21:45 22:30 lines. 2/11/2019 2111/2019 1.00 COMPZN RPCOMP THGR P Land tubing on hanger @ 10,912'. (3' 10,900.0 10,912.0 22:30 23:30 from fully located. 2/11/2019 2/12/2019 0.50 COMPZN RPCOMP THGR P Run in lockdown screws. RU to test. 10,912.0 10,912.0 23:30 00:00 2/12/2019 2/1212019 1.00 COMPZN RPCOMP THGR P Finish running in lockdown screws. 10,912.0 10,912.0 00:00 01:00 RU to test. Test hanger seals 250/5000 psi f/ 5/10 min. Good lest. Charted 2/1212019 2/12/2019 1.00 COMPZN RPCOMP PRTS P Drop ball and rod and let fall to seat. 10,912.0 10,912.0 01:00 02:00 2112/2019 2/12/2019 1.00 COMPZN RPCOMP PRTS T Attempt to pressure test tubing. 10,912.0 10,912.0 02:00 03:00 Surface valve leaks. Troubleshoot. 2112/2019 2112/2019 3.75 COMPZN RPCOMP PRTS P Test 4 1/2" tubing to 4200 psi f/ 30 10,912.0 10,912.0 03:00 06:45 min. good test. Bleed off tbg to 2000 psi. Line up and test 4 1/2" x 7" annulus to 3300psi f/ 30 min. good test. All charted, Bleed off annulus then tbg to 0 psi. Pressure up annulus to shear out SOV. Sheared @ 2600 psi. Break circulation @ 1 bpm/ 500psi. 2/12/2019 2/12/2019 2.25 COMPZN WHDBOP MPSP P UD landing jt A. Install HP-BPV. 10,912.0 10,912.0 06:45 09:00 Install landing jt B. test BPV to 2500 psi 1115 min in direction of flow. Good test, L/O landing jt B. 2/12/2019 2/12/2019 3.00 COMPZN WHDBOP MPDA P PJSM. LID MH, TN,. R/D MPD 10,912.0 10,912.0 09:00 12:00 package. Page 28129 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Dep h Stan Time End Time Dur (hr) Phase Op Code Aa "i Code Time P -T -X Operation (ftKB) End Depth (M) 2/12/2019 2/1212019 3.75 COMPZN WHDBOP NUND P PJSM. N/D BOPE. 10,912.0 10,912.0 12:00 15:45 2/12/2019 2/12/2019 1.50 COMPZN WHDBOP NUND P Install Smooth Bore Metal Seal, install 10,912.0 10,912.0 15:45 17:15 plug off tool in HP-BPV profile per FMC.NIU Prod tree. 2/12/2019 2/12/2019 0.25 COMPZN WHDBOP PRTS P Test adapter flange to 5000 psi. good. 10,912.0 10,912.0 17:15 17:30 2/12/2019 2/12/2019 2.50 COMPZN WHDBOP PRTS P Fill tree w/diesel & R/U to test. Test 10,912.0 10,912.0 17:30 20:00 tree to 250 psi low, 5000 psi hi for 10 minutes each charted. 2/1212019 2/1212019 1.00 COMPZN WHDBOP MPSP P FMC remove HP-BPV. SIMOPS- R/U 10,912.0 10,912.0 20:00 21:00 circulating lines to freeze protect. 2/12/2019 2/12/2019 2.25 COMPZN WHDBOP FRZP P Fill tree w/ diesel. flood lines and 10,912.0 10,912.0 21:00 23:15 pressure test to 2300psi, good test.Ball mill pump @ 1 bpm 48 bbls diesel down /Awl GIS. FCP 460 psi. Line up and let well u -tube for 1 hr, 2/12/2019 2/13/2019 0.75 COMPZN WHDBOP MPSP P RID lines to prod tree. R/U to test 10,912.0 10,912.0 23:15 00:00 BPV. Tbg pressure 0 psi. 2/13/2019 2/13/2019 0.50 COMPZN WHDBOP MPSP P Install HP-BPV. 0.0 0.0 00:00 00:30 2/13/2019 2/13/2019 0.50 COMPZN WHDBOP PRTS P Test BPV to 2500psi (in direction of 0.0 0.0 00:30 01:00 flow) good test. Bleed off to 100psi. Secure well. 2/13/2019 2113/2019 1.75 COMPZN WHDBOP RURD P Clear lines. Clean cellar area. Install 0.0 0.0 01:00 02:45 flanges on tree. Secure cellar area. final pressures I/A100psi.0A Opsi.Tbg 100psi. 2113/2019 2/13/2019 5.25 DEMOB MOVE RURD P PJSM. Swap out T transducer on 0.0 0.0 02:45 08:00 gooseneck.SimOps: prep cellar/Metz area f/ rig move. 2/1312019 2113/2019 14.00 DEMOB MOVE PULD P PJSM. Install MH. UD DP from 0.0 0.0 08:00 22:00 1 1 I I derrick. 2/13/2019 2114/2019 2.00 DEMOB MOVE KURD P RID lines and wiring. Prep f/ move. 0.0 0.0 22:00 00:00 1 I I I Release dg @ 00:00 hrs 2/14/19 Page 29/29 Report Printed: 2/19/2019 ConocoPhillips ConocoPhillips Alaska Inc_WNS Western North Slope GMT1 Lookout Pad MT6.02 50-103-20792-00 Baker Hughes INTEQ Definitive Survey Report 08 March, 2019 Conocolahiliips %^ � 0 ConocAP' fillips Definitive Survey Report Ci mp sve ConocoPnisps Alaska Inc MS Project: Weskm Nodh Slope SM: GMT1 Lookout Pad Wag: MTfi-02 Wetlgme: MT6-02 Design: MT6-02 Project M.1tem NOM Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Weg M16-02 Local Coordinate Reference: Well MT6-02 TVD Reference: Plan MT6-02®69.30ush(Doyanl9 Planned) MD Ruthenia.: Plan MTS-02®89.30us0(Deyon19 Planned) North Rekronce: True Survey calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Well Position .WS 0.00 ..it Northing: Longitude; .FJ -W 0.00 use Exxon, Position Uncertainty Declination E00 usfi Wellhead Elevation: Wegboro MT"2 W) 16.25 Manned. Metal Name Seattle Date EGGM2018 1=212018 Design MT6-02 Audit Notes: Version: 1.0 Phase: ACTUAL vertical Section: Depth From (TVO) than) 37.10 Mean Sea Level Using Well Refinance Point Using geodetic scale factor 5,945,564 31 let8utle: 70° 15' 23.180 N 317,11636usb Longitude; 151°28'41.304W us0 Ground Level: 37.20 awn Declination Olp Anglo Fleld Strength (1) fl W) 16.25 80,68 57,384 T. On Depth: 37.10 .W4 .EIAs Dim"On (ug) luau) M 0.00 0.00 333.00 . 019 It 12:4S5M Page 2 COMPASS 5000.14 Build 850 Conocolthillips 4 ConocoPhillips Definitive Survey Report Company ConocePhlllipa Alaska lms%NWS Local Co-ordinate Reference. Well MT&02 Project: Mahma North Slope T.M Rebmnce. Plan MT642®59.30ua6(Dayonl9 Planned) Vertical MD She: GMT1 Lookout Ped MG Rettimmm Plan MT642®09.30uah(Doyonl9 Planned) +NIS aEl4M Well: MT642 North Reference: Due (-am P) Wellbore: MT6-02 Survey Calculation Method: Minimumeu"tum (..to rtl (R) Design: MT6-02 Data3aem, EDT 14 Alaska Production 1 O.W survey Program Dab O.W 0.00 5,90.5,561.39 317, P.fl6.39 Finite TO 75.53 0.21 Suteey Survey Way) Nam Surely (Wall".) Tool Name OefcHPtlen Span Dem EM Dab 75 53 356.00 1. Gymdffia GymSS 16-(MT642) GYD-CT-DMS Gymdata cooLddllpipe Ms 121192010 12/192018 39346 2,027.27 2. BHGE MWD+IFR+MSA 16"(MT6-02) MWDAFR-AK-C C MWD+IFR AK CAZ BGG 12232010 122302018 2,115.67 8.972.41 3. BHGE MWD ATK+IFR+MSA 121/4"(M MWD+IFR-AK-0 ZSC MWD+IFRAKCAZSCC 1212601010 1229!2018 9.065.23 11,105.67 4. BHGE MWD+IFR+MSA6SM" (MT6-0 MWD+IFR-AK-CAZSC MWD+IFRAKCA SGC 111001019 11172019 11.152.00 22,198.77 S. BHGE MNND+IFR+MSA 41/8"(MTM MWD+IPRAK-CA2SC MWD+IFR AK CAZ BCC 1/102019 1124/2019 Survey 3/82019 11 12 45AM Page 3 COMPASS 5000.14 8udd85O Bl Map Vertical MD 1. AN TVD TVDSS +NIS aEl4M Neth ang EiIN) 131-5 serSurvey 7481 Name Anralatien (-am P) (1 ("M (uaM (uart) (..to rtl (R) (,11w) ret o) 1,0 3]01 1 O.W 3].1,0 42.20 O.W 0.00 5,90.5,561.39 317, P.fl6.39 0.00 G UNDEFINED 75.53 0.21 259A2 75.53 -13.]] -0Dl -0.07 5945,56139 317, li6.M 0.55 0.02 GYMT-0M5(1) Inco 0.44 232211 1,02.01 W.70 -09 45a 5.945,5..13 317,11585 128 0.W GYMT-01,15(1) 259.22 128 M1.87 259.22 mem 4.51 -1.01 5,945,5 91 317,115.37 0.28 101 GYD-0T-0235(1) .6.00 140 291 35599 266.69 0.71 -1.18 5,945585.2 317,115.23 1.61 117 GYD-CT-0M611) 393.46 2.36 i1.. od. 304A2 1.0 -1.. 5946588.37 317,115.40 yon 221 MND.11ill-CAZSC(2) 402.67 4.11 1197 411149 393.19 6.91 -016 5,945,5]1,30 317,11640 1.97 6.23 MJu➢+IFR-AK-C ZSC (2) 5]6.84 545 11.01 57133 437.03 1461 234 5945576.56 ulTll W 1.42 1241 MMD+IFR-AK-CAZSG (2) 668.30 629 11.89 667,31 57801 n.7. 321 5,945,523 1,8 317,120.10 102 19.73 MWDAFR-AK-CAZSC (2) 762.. 7.48 10.65 ]8,79 67149 34.55 540 5,90.5.593.. 317,1M.M 1.27 28.60 MWDAFR- -CALSC (2) We 78 053 939 am.te 7..89 47.n ]]3 5945611.96 317,1MM 1.12 39.06 WADAFR-AKCAZSC (2) 230.44 9.4a 852 Wee &5].39 62.2] 10.18 5,945.62335 31712308 102 0.82 MMD+IFRAK-CAZSC (2) 1,044.41 1150 0.n 1029.24 949.94 78.32 12.77 5945.64237 317131.06 1.09 63.98 MND+IFR-AK-0.4250121 113SR8 H64 8.65 1.13191 1,.2.61 98.41 1554 5,94568 .39 31],134.2] 142 78.35 MNDNFR-P ,iZ.4 0(2) 1.TJ A 1358 1167 t22147 1,1351] 116,07 19.10 5.945.680 IS 317,1XM 1.90 95.55 MJNAFR-MCA C(2) 1,323.85 15.13 1162 1]13. 1,224.33 139.23 23% 5,945)0313 317143.33 1.70 113,411 MNDAFR- -CP (2) 1.419.41 16.52 11.10 1,401.69 1.314.39 1..38 2868 5.945]23.41 317,14896 149 1]3.49 MWDAFR-N4CPZSC (2) 1512.]] 17.2 1D.b 14@.94 1403.64 191.32 3362 5,.5,7..82 317,151.64 1,22 155.20 MNDAFR-AN-0AZSC (2) 1.60740 15.92 10.20 1,56292 149352 22044 30.03 5,945,733.81 31718.53 1.2T 17578 MNDAFRAH-CAZSC (2) 3/82019 11 12 45AM Page 3 COMPASS 5000.14 8udd85O Survey Con000Phillips GUhUC(3Phlfflps Definitive Survey Report Mep Compny. COnocoPhl91PS Alaska Inc_ MS Local Coo7maete Reteren.e: Wall MT6-D2 Project Weirem North Slope TVD Peters...: Plan MT6-02®8931C)i(Di 9 Planned) She: GMTI Lookout Pad MD Reference: Plan MT8-02 @ 8930us11(Doi Planned) Well: MT6402 North Reference: True Wellbore: MT6-02 Survey Cal.ulation seemed: Minimum CurveWre Design: MT602 Database: EDT 14 Ali PmducBon Survey Annotation 33201911: 1245AM Page 4 COMPASS 5)0014 Budd 850 Map Mep Vertical MD ledAal TVD TVDSS +373 +EI.W NOMInp Eaatln9 OLS SeSurvey tool Name (i (7 M (aalp (-am (aanl IDaDI m Int 1.1100.1 ("1 m 1,]02.63 20.47 1D5t 1672.37 1503.14 251.83 4059 5,945,01545 ]1,].1,6708 174 ZMY3 MWDHFR-N(-Ch2SC(2) 1,79710 21.55 902 1.761 1.671,39 20539 SOA" 594584835 317.1]3]5 112 Z11.30 MND+IFR-MH AZSC(2) 1,89164 23.14 9.37 1.84843 1]58.83 320.74 5535 5,94588365 317,180.51 1.68 36030 MND+IFRM-0AZSC (2) 1885]0 24.52 930 1,93434 1,614.94 35836 8259 5,945921,00 317437.50 107 290.80 MWDOFP-P AZSC(2) 202727 24.59 toll 1,97198 1.882,66 375.25 65.51 5,945,931.92 317493.99 0.75 3 ,61 MWDHFR-AK-0AZSC(2) 2115,67 25.16 10.57 205219 1.06209 411.83 R18 5,945,974,31 317.198.55 069 33417 MWUNFR✓J(-CAZSC(3) 2,181.31 X.12 11.04 2,111.36 2,M 06 439,72 77,51 5,94500207 317,2()4.55 tA9 35661 MWpHFRJJ(-CA25L(3) 2.275.41 27.48 10.92 218536 2,106.06 481,36 05.59 5,9"80"3.37 317,21364 103 39004 MW()+IFR- sZ41C(3) 2.370.51 29.07 10.81 227942 2,189.82 5X.59 94.07 59"6,081 317=19 1.69 42559 1uW0+IFR-A1(CAZSC(3) 2.464.83 3020 10.65 2,351.10 2271.80 571,41 10275 5,94643340 317,23299 13O 462.48 vNI) FR -AK -00250(3) 2559.44 31.70 1117 2,44220 2,352.90 619.24 11196 5,916"5069 31724337 169 500.91 MM1D+IFRAK-00250(3) 2651]8 3256 10.62 2,520.35 2,431.05 68152 121,27 5,946R28R 31725383 0.90 53971 MND+1FRiK{,7250(3) 274627 3253 to.R 260002 251073 717A7 131160 59,16,27843 317,26445 007 5799" MNOHFRAKCPLSC(3) 2.841.33 32,49 9.40 2680.10 259068 767.77 139.60 5946,328.50 317.274.59 1 fiN]1 MND+IFR-N4C]SSC(3) 2,93535 3236 8.95 2.78032 2670.92 81014 14774 5,946,370.55 317303.94 O.X X190 MWD+IFRrV(CPZSC(3) 303002 32% 921 2,80,36 2)49.95 86]96 155.70 5,946428.36 317.293.11 045 TR.67 MWDNFR-N(-0PZSC(3) 3,12247 32.51 BW 2,916.95 Z82765 916.85 163.80 5,946,41`894 317,3V1A0 0.36 742.56 MNDNFR.ix AZSC(3) 3,215]8 3261 Boo 2996.69 2.907,39 067,16 171,61 5946.52704 317.311,42 008 70304 MND+IFR✓J(-CA -SC(3) 3.311,58 32.56 802 3,07657 3,91 1,09,12 17874 5,94557700 317,31,9.7. 005 025.5 MWD+IFR-M{ C(3) 3,405,14 32.59 890 3,155A1 337511 1,061 186A7 5,906.627.03 317,3MAt 0.53 06867 MWD+IFR-PH-CA,SC(3) 309,93 3253 1007 323531 3448.01 1117.65 191.59 5.M.677.12 31],336.05 064 907.67 MWD+IFR.K sZSC(3) 359269 31.0 10.91 3,31384 3,22434 1,137.07 X1ID 5,9M.R6]0 317,396.36 OSo 847.39 MWD+IFR-AK-0AZSC(3) 3637.46 32.47 1165 3393,35 3304.05 1,21697 213,615 5.946,775.74 317359,52 0.45 987.33 MND+IFRAKLAZSC(3) 3780.96 34.13 12.04 3,47150 3,302.20 1M721 22419 5,937,8X50 317,3736 1,79 1,02731 MND+IFR-0KC -SC (3) 3.074.2 35.80 12.45 3.548.50 3,45920 131882 YS62 5,937,07802 317.383.97 1]8 1,05900 1sNO+IFRAKCPZ-6C(3) 3,969.47 3737 12.89 362435 3,535.05 1,374.09 24800 5946,932.76 317.397.69 1.82 1,112." MNDHFR-AKLPZSC(3) 4371,05 3931 13.50 3]37.36 3,61496 1,43656 262.47 5,948.994.68 317.413.5 1.81 1,160.83 MNDHFRN4CPZSC(3) 0.164]1 41,71 1391 3.775.16 3,68588 1,49541 276.62 5,947052M 317,429.43 2.59 1.2..74 MND+IFR-MH AZSC(3) 4X892 43.55 14.09 3,a4"A7 3,755,17 1.557,32 29226 5,947,11405 317,4"535 195 1,25490 MWD+IFR-MH AZSC(3l 4351.85 44.02 1453 3.91155 382236 1619,62 308.16 5,947 ,1,7595 317.463.76 060 1.300 20 MWD.lFRJ A2!EC(3) 444565 44.07 1505 397s 11, 388983 168275 325.06 594723864 317,48220 0.50 1,351.76 MWD+IFR-MH AZSC(3) Annotation 33201911: 1245AM Page 4 COMPASS 5)0014 Budd 850 Conocopwillips Conocolthillips Definitive Survey Report CompanyCDnac.litub aAlaace lnc_WNS Local Coordinate Reference: N 11 MT6-02 Protect Western North Shape TVD Reference: Plain MT6-02@ 89J0usR(Doyonl9 Planned) Site: GM71 Lookout Pad MD Reference: Plan MT642@ 8980usft(Dayon19 Planned) Well: MT6-02 North Reference: True Wallach, MT6-02 Survey Calculation Method: Minimum Curvatura Design. MT642 Database: EDT 14 Alaska Pmduction Survey Annotation 1- a 3768019 11: 12.45AM Page 5 COMPASS 5000.14 Budd 85D Map Map 'emlical MO Ix Aid(I 109 T( 4095 aPJ.W NoMing Eaetng DLS Secwn Survey Tool Name IwRI 1'1 1°1 IusM -am usery lusnl Well) (t) IRI Nagar) IN) 4,540.88 4011 1595 404739 3,958.09 1,745.40 34296 5.WrW'.M 31750164 036 140035 MA➢HFR-A ALbC(3) 4,63582 44D5 16]0 4115.59 4,02629 1809)8 361,53 5,947,36V5 317,521]3 0.55 1,440.40 MrY➢HFRJJ AZ -SC 13) 4730.27 44.02 1695 4,183.49 4,094]9 1872.62 383.53 5,91,47.11 31754225 019 1,495]6 MWD+IFR-MH AZSC(3) 482425 43.93 low 4,25112 4,161.82 1,93505 309.52 5,9174119.09 317,%275 0.11 1.542.77 MND+IFR-Pl(-CAZSC(3l 4,92009 44.06 1591 43.4.04 4=74 1,Po&BB 41831 591,55240 317583D8 0,72 1,591.11 MWD+IFR-AK-CAZSC(31 5,01421 HW 1572 4,38771 4,29&41 2,WIN 43615 5,947614.95 39,60245 014 1,09.15 MNDNFR-AK-CAZSC(3) 5,1011,36 44.13 toes 4,456,32 48%02 2,12499 40.01 5,947,677,59 39.62163 0.15 1,68734 MWDNFR--CAZSC(3) 5.20277 43.97 1676 4.52348 4433.08 210.9-03 12J07 5,947,740.17 39,641.42 0.91 1,735.23 MWDAFRAK-CPZSC(3, 5.21761 4385 1729 4,591.50 450220 2250.92 481,33 5,947,802.58 39,66220 040 1 782S MWD+IFR-AK-GP C(3) 5,390.16 4392 1720 465820 4,568,90 231220 am 35 591.85337 317.682,70 009 1,82849 MWD+IFR-AK-0PZSC(3) 5,484.40 4385 18.62 4726.12 4,635.82 2,374.36 53344 591,92502 31].704.28 1.05 1,874.76 MrVD+IFR-PH-CAZSC(3) 5.578.93 4378 1762 4,794.33 4.705,03 2438.56 55029 5.94T9,36 71 31772815 074 1.92094 MND+1FR-AK-0MZ C(3) 5,672,88 4388 16.95 486211 477231 2.49868 570.13 5,94SM834 39 ]4690 0,51 1,96751 MND+IFRJ-CAZSC(3) 6757.61) 43,02 1629 4.93042 4041.12 256156 585,88 5,94&11074 31776727 0.49 3,01501 MWDHFR-PI(-C C(3) 5.850.78 44.12 14.50 4,997.48 4,909.18 2,623,93 60&06 5.MlTZ67 317.785.95 1.37 2,662.79 MWO+IFRAK-0AZSC(3) 5,N&M 4415 15.06 5.065]1 49TSAt 2,68793 622.95 584823524 317804311 0.41 2.112.15 MND+ffRJJ(CAL6C(3) 6,05053 44.03 16.615 5,133.74 5,04444 2,751.28 640.96 5948,29813 317,623.93 120 2,16042 MWDOFR-AK-CMSC(3) 6.14465 44.10 1725 5,ZI139 5,11209 2,813.88 660.06 5,848361,24 317,844.53 043 2207.52 MWDOMAK-CPZSC(3) 6,23822 44,0) I&M 5.26864 5,9934 287605 679.9 5948,422.& 317,865.15 027 225425 MWD+IFRAKCAL C(3) 633265 44.03 16.79 5,33657 5,24727 2838.83 69830 5,90.48527 317,05.T0 0,10 230158 MVND+IFRAK-0MSC(3) 6,4279 MW 15.82 5,40.52 5.315.22 SWISS 716.63 5,849.547.51 39,905.88 0.71 234938 MWD+IFRAK-GMSC 13) 6,521.83 4012 16,07 5,11.83 5,38253 3,05452 734.53 5.94B.FA3.99 31752 88 023 239794 MAD+IFRAK-CPZSC(3) 8,61632 449 16.57 6,54035 5.451.00 3,91132 75321 5,94&673.33 399459. 036 2.445.40 MWD+IFR-AK-0AZSC(3) 8,710.63 4487 ISM 5,608.11 5,518.81 3.191.19 772.03 Sgaar7ISog 317,985.2 015 2.492.87 MWD+IFR-AKLKSC(3) 8,805.30 4489 17.15 5,676.12 5,588.2 325478 79123 5,940,7%211 317he35 029 2540.28 MND+lFR--CA?-SC (3) ono`9 44.13 17.44 5,743.53 5.65423 3,316.56 81088 5948,860.10 31000729 022 3,587.09 MWDNFRAK-CAZSC(3) 6,99393 44,13 16D 5.811.53 5,722 23 3,7936 830.09 5,94892237 318,029,04 0332 2,03.01 MWDNFR-W(-CAZ C(3) 7,00663 43M 18,22 5,87823 5,78593 3,44050 851.06 5,94&9&100 alSon.66 032 2879.13 MWD+IF&FK-0.4750(3) 7,181,62 4379 1704 5.94615 535748 3,50303 871,42 5,948045.02 318,072.55 0.28 2,72561 MWDNFR-N AZSC(3) 7,276.21 43.92 9.76 6,01499 5,93560 See. 891,45 5,949.196.90 318,094.09 0.15 277211 MWD,IFRJ IAZSC(3) 7359.73 43.94 1&40 600234 599104 367.11 911,59 5949.168.07 318.115.72 048 281793 MWD+IFR- -CAZ-SC(3) Annotation 1- a 3768019 11: 12.45AM Page 5 COMPASS 5000.14 Budd 85D `. Conmofahillips ConocoPlllllps Definitive Survey Report Company. ConowPhi0ips Alaska Inc_ AM Local Coordinate Refemnce: W0ll MT6-02 F.Ie4O Wasters NOM Slope TVD Reference: Plan MTS52 ® 891 (Goyonl9 Planned) She: GMTt Lookout Pad MD Reference: Plan MT6-02@ 8930us0(Doyonl9 Planned) Well: MT642 None Reference: Toon Wellbore: MTS -02 Survey Calculation Method: Minimum Curvature Design. MT6-02 Dabbase: EDT 14 Alaska Production Survey Annotation �^,�,I65 • L x,719 11: 12:454M Pag0 6 COMPASS 500014 Sued e5D Map Ill withad MD Na Aai TVD TVDSS Ni+ aEd4M NorDli Saa0ng OLS Satiation 9urvry Tool Name lull) P) P) lass) (u50) (men) 1.1t) (III IA) (9100') IRI 7.464.13 43.89 1955 6.15034 006104 3iiks. 932.07 5,949.229.45 318.138.W 0.85 ZM343 MWOHFRrixLPZSC(3) 7.55029 43.03 20,01 6.21&M 6.12930 3]5&74 955.07 5.9493NI61 318.16219 034 290034 MWOHFR-PH -SC(3) 7,653.28 4387 MM &28514 6,197.44 3,01220 line) 5949,351.50 318,186.21 0.19 295266 MNOHFR-AK-CAZAC(3) 7,746.53 4389 2023 6,353% 6,264.86 3.87284 999.97 5349,411.57 318,210.04 OD2 2.996]5 MJN+IFR-P14LALSL(3) 7.810.86 43.4 2035 642199 6.33299 3.93418 1,02204 5.949.472.32 318,23419 0.10 3,041.09 MND+IFR-AKAAZSO(3) 7.05,38 "M 19.97 6,48006 6,44(1.76 3,99569 1,.523 5.849,533.28 310,256.26 033 3.95.66 MNDNFR-AH-0AZSC(3) 0.0211,45 43.94 18.58 6.552. 6.46714 4,086.69 1.06596 5949,59373 310,201ID 1.04 3.130.33 M C+IFR-AK-0AZSC(3) 81,2331 41M 10.35 6,625.37 6,53007 4,118.09 1,097,40 5,868,65561 310303.41 016 3,17647 MWDAFRAKLAZS (3) 8217.17 4393 18.57 6.693.5 &X0375 4,18018 1,107.99 6,949116]8 310,32550 0.17 3,22209 MWD+IFRAK-0AL (3) Si 4156 19.01 6.26C1.44 0,671.14 4,242.6 1,128.04 5,949,777.52 310,347,83 0.34 3,267.21 MW0HFRAK-0PZSC(3) BAW..26 43.84 21,32 6,M,37 6,740.07 4.304.30 1,151.71 6,919,82.19 3183820 1.67 3,31230 MWD+IFRAKCALSC(3) 8,500.4 43.81 21.0 6,086.62 6,808.32 4.36539 1,175.69 5,949.899.67 318.397.86 0.22 3,355.83 MWD+11i'R-AK-0PZSC(3) 8.598.94 44.20 19.92 6,96667 687737 442776 1,186.30 5,948%145 318.42277 125 3,400.69 MWC+I RAKL7SS0(3) 0686,86 4453 1829 7.3218 6,943.10 4.4118.57 1M36 5850.0113 318.44530 129 3,445.31 MW3+IFRrWCA28C(3) 0,783.86 411.07 16.41 7.86.27 7,009.97 4,52.80 1,240A4 5,950085.53 318.466.93 207 3,48350 MWDHFRJJ4CA2LC(3) 887708 47. 1500 716;62 7,07432 461&86 125&90 5,950,151.03 318.407.07 209 3,513.87 MWD+IFR.As-CAZSL(3) 0,9n.41 48.37 14.05 7226.25 7,12,$ 4,607.27 12n21 5,950,218.98 310,586.96 in 3.59555 MWDHFR-Ai(3) 9.29.X1 49.0 ISM 7,286,37 7,19707 4,755.55 1,28566 5.950,28818 3101 0.72 3,649.01 ~+IFRAK-CAZSC(4) 9,15915 52.92 13.12 7.344.95 7,2595 4.826.68 131369 5,9M..35746 310546,81 312 3704.21 MWD+1FRAK-0AZSC(4) 9.25389 55.25 1D.34 7AMAI 7,31141 4,901.65 1,X823 5,e5g43201 M.S..1. 3,43 3,M394 MWDHFRAKLQSC(4) 9,34030 56,86 7.2 7.45333 7.32.93 4.92.23 1,341.05 6,986.62.28 310.5n86 3.30 382770 MWD+IFRAK-0AZSC(4) 9,44338 59-03 5.63 7.86309 741439 5,059.30 1,350.2 6.950.59.11 318,68&81 229 3,lease MWD+IFR-AK-CAZSC(4) 9.537.37 6114 436 7,586.57 7,461.27 5,140.44 1,357.20 5,986.670.4 318598.00 2.63 3,2397 MWOHFRAKCAZSC(4) 9631.10 63.X 329 7,594.23 75..93 5,223.16 1362.60 5,986.75262 318,605,53 2.55 4,035.19 MWO+1FR4,K-0AZSC(4) 9125.90 Mite 0.81 72514 7,545.84 6,308.63 138525 5,9M.837,97 318,6106a 3X 4,10995 MWD+IFR-AK- AZ4SC(4) 992137 67.61 359.. 7,6412 7,58319 6,39623 13X572 5,986,92553 310,6126a 276 4,48086 MWDHFRAK-CPZ56(4) 9,91486 69.73 350.X 7,706,97 7,617.67 6,41 1.3272 5,951,01227 318.61215 239 4266.23 1AWD+IFR-AWCPZSC(4) 1029.82 71,29 3503a 7,73005 7,648.75 5,571.89 1,359.56 5951.ID1.29 318,61015 295 4,31737 MWD+IFR-AK-CAZSC(4) 1D.103A7 73.32 3%W 770642 7677.12 555202 1,3542 5,951,191.51 310,60730 184 4430.19 MJN+IFR-AK-LAZSL(4) 1019740 75.40 35559 718168 7,702.38 5,75227 1,34784 5.951,201 n6 316,603.41 252 4513.40 MNDHFRAK-CAZSC(4) 10.291 W nA7 354.02 7813.8 7703.42 5,843.56 134018 5.. 13]3.X 31859797 2. 486022 MJ)DHFRAKLAZSC(4) Annotation �^,�,I65 • L x,719 11: 12:454M Pag0 6 COMPASS 500014 Sued e5D .. COf10CAPllll�lF15 Con000Phillips Definitive Survey Report Company: ConomPhilips Alaska Inc_WNS Local CoorglnaOe Reference: 64411 MT6-02 Pm)ecC Milken North Slope WD Reference: Plan MT6432®89.30usfl(Doyonl9 Planned) Sam: GMTt Lookout Pad MD Reference: Plan MTB -02@ 89.30uaX(Dayanl9 Planned) Well: MTB52 None Reference: Tma Welled.: MT6-02 Survey Calculation Method: Minimum Curvature Design: MTs -02 Dambace: EDT 14 Alaska Pmtlu0ion Survey Annotation 64,69 • 3/8201911: 12454M Paget COMPASSfi1.14Bvdd8W Map Map Map withal MD Inc Aal TVD MSS 'NIS ♦EI -W Noneing OLS 9ecgon Survrytool Name (ung) 1') P) liken) (-ft) (Balt) (9aR) Ig) (h) ('11017) ml 10385.11 ]901 350.11 2,832.13 714283 6,930.]] 1,33134 5951464.72 316,59135 2.61 4,683.51 MWDNFRAK-0 -SC(4) 10.480.02 81.93 35350 2,04J.19 ],25]89 6,022.93 1,32132 5,9515511.09 318,583.50 232 4.72V0 MWDrIFRN-CMSC(4) 10.523.01 03.85 36294 2,850.20 2,26940 6,119.55 1310.33 5,951649.94 318.524.83 215 4852.60 MSMNFRA-CM0(4) 10666.02 84.92 35142 2.W288 2728.58 6,21210 1,29266 5961.242.26 318,564.41 1.93 4 945 89 MW9'IFRJJ -SC(4) 1o'Ae5 9 0504 388.80 7,026.9 2,282.23 6,30.36 1,282.49 59511840.36 310.551.61 one 503944 MWII+IFR-M-CMSC(4) 10,&54.81 84.92 35016 2,884.33 2,29503 6,396.91 1.262.81 5,951,92924 310,53806 0]3 5,124.12 MW➢NFR-g-CAZSC(4) 10,949.88 84.09 349.50 2,892.25 2.003.45 6.40906 1,251.13 5952,021.50 318,524.65 0.69 5,214.49 MPoDdFR.-C-0 4C (4) 11644.11 0426 348.92 7.93132 2,611.82 650231 1233.55 5,952,114.40 318,50.32 0.58 5304.06 MWDNFR-PK 4C(4) 1110552 0426 340.46 2.906.09 2,012.59 6,64243 1221.56 599,174.29 318,498]9 0.82 5.363.02 MyNDAFR-PK-0AZSC(4) 11152.00 0528 348.10 2,910.92 2,821.62 6,602.63 1,21231 5,95222020 318.493.9 1.22 5,40839 MJNHFR--CAZSC(5) 11,242.24 W.91 348.00 2,917.40 2,828.10 6)80.61 I.I.A2 5,95e.313.0 318.42322 1]1 5.50011 MAD.IFR- -CL E (5) 11.34212 8693 348.9 2.9252.50 2,83320 6,823.44 1123,45 5962,405.88 310,488.32 0.46 5,01.54 MNDNFR-AK-CP (5) 11.432.25 8845 34860 2,925.34 2,03204 6,988.55 1,154.60 5.952.503.42 318,4W,n LW 6,68306 MWDNFRAK-CAZSC(5) 11.91.99 0869 342.48 2.92850 2.839,40 2,059.20 1.134.88 5952593.52 310422.36 1.21 5,224.53 MJ4DHFR-AK-0 C(5) 1162261 8892 346.15 2,930.65 7,04135 2,1938 1,11312 5.952.882.0 3111 1.42 5,86236 MWDNFRAK-CAZSC(5) 11 Zone 89.12 346.92 2,932.24 2,642.94 2,244.93 1,093.13 5.952.28825 310.38204 029 5,96032 MWDNFRAK-CAZSC(6) 11,812.61 9212 34G.w 2,931.18 2.84188 2,339.68 1,02.50 5,952022.9 3193fii64 3.26 6,M2.39 MWDNFRAK-CAZSC(6) 11,912.28 91.92 344.94 2,922.24 2.030.44 2,426.81 1043.92 5,952,69.21 318340.31 151 6.145.19 NOVD'6R4K-CT C(5) 1200088 93.0 34195 2.923.59 2.864.72 2,520.55 1016.66 5,953052.52 310,315.20 3.30 6.23930 MWDNFR4K-Cr1 C(5) 12,10324 ot.88 339.42 7,91852 7,029.22 2,60926 98843 5,953.142.51 310,2W.M 2.62 6.=.92 MWDNFRAK-0AZSC(6) 12.19&25 91.20 335.51 2,915.02 2.825.22 2.692.45 949.0 SW3.2 05 318.252.W 461 6.422.W MNf) FR-AWCPZSC(5) 1239325 90.0 331.M 2.913.25 2,023.95 2,28232 90.59 5.963321.92 310,211.61 442 6,522.56 MWD+KR-AK-0PZSC(6) 12W2.W 91.33 325.63 2,911.30 2,ai 2,86343 852& 5.99.40419 318.16484 4.92 6.616.92 MWDNFRAK-CP-SC(5) 124030 9129 J25.18 2,9M79 2,01949 7.042.16 itui 5,99.484.18 310,113.48 160 6.21126 MWDNFRAK-0 C(5) 1252856 9136 325.9 290.12 2,01602 8,020.28 288.20 5953,58409 310.061.14 062 6,00 .94 MWDNFRAWCPLSC(5) 12623.45 9164 325.88 290388 2,81430 8,00.16 OWN 5953.643.24 31800.65 )A1 6,90.04 MWD'1FR- A25C(5) 12.26188 9139 325.48 2,901.19 2.81189 8,12251 64435 5,907A.34 317,959.06 021 6,99360 MWDNFRAKHCA45C(5) 12.W3.24 9145 32540 2,89802 2,00.52 0.25202 591.61 59989509 317.908.26 010 2.08842 M IFRAK ZZC(5) 12.M2.W 93.28 3250 2,89240 20010 8'3 &. 53919 599,883.62 312.852.22 1.31 2,1020 MWDrIFR-Al({' C(5) 1302]4 no. 32559 7.895.94 280264 8,414.12 40562 5,953,993]1 312.8012 045 222&55 MVD+IFR-M-CAZSC(5) 13.14902 R0.44 324.25 269633 2602.03 &493.19 43965 5,9`04.04499 312253.10 9.69 232192 MWDNFR MKCAZSC 01 Annotation 64,69 • 3/8201911: 12454M Paget COMPASSfi1.14Bvdd8W survey ConocoPhillips SR 4 WNFS ConocoPhilliI Ix Definitive Survey Report Map Company ConocoPblllips Alaska lnc WNS Local Do-erdlnate Reference: WaRMTe-02 Project: Western North Slope TVD Reference: Plan MT642@ 89.00usfl(Myonl9 Planned) ND Sime: GMTI Lookout Pad MD Reference: Plan MT642®89.30usX(Dayonl9 Planned) Northing Well: MTB52 North Reference: True Annotation Wellborn,: MT6-02 Survey Calculation Method: Minimum Curvature (-an) Design MT652 Database: EDT 14 Alaska ProEuclien survey Map Map Vertical MD Inc Art ND NDSS +WS 4F! -V1 Northing Eestln9 DLS SeSumYT0ol Nama Annotation total r) I7 (-an) (uau) (uartl (-ft)n) (•1100'1 (ft) (ft) 132433 2 90.11 326. 00 ],895.63 7,80633 11,5]0]] 0]].15 55622 ,9,195 31]17 ,]01.50 1A0 ],86539 MWO+IFR-AKLAZSL(5) 1334000 .,. 326.15 7,1193"3 3,80013 0.051.00 32325 5,954204.5 31],649.5] 1.85 7.561,35 MWDWRN4 -eC(5) 1343531 9213 32628 7,08903 7,000.53 0,730.16 270.29 5,954204.83 317,598.5 0.15 7,65592 MWDnFR-M ..(5) 13,53063 9205 35,00 THIN 7,707,04 Saimaa 217,64 5954355,63 317.540.05 0.65 7,750.50 MWD -IFR- -CA C(5) 13,82550 9034 324.4 7,08436 7,79500 60560 16436 5,954,445.2 317,495.40 3.16 7,844.65 MWD+IFR-M-CA 1.(5) 13,.2004 0681 32287 7.885.[8 ],795.]6 8,96418 107.86 5,95452635 317.41.07 2.30 7,938.71 MND+IFR-M-CASC(5) 13,815.04 07,90 37217 7.887.73 T7M.43 9.06030 49.58 5,954.60025 317,385.2 1.14 8"0229 MrWNFR-M-CMSL(6) 13,911.91 Bad 32419 7,091.% 7,801.76 9.11699 -0.48 5.954.678.1 317,33029 211 8,126.69 MJJDNFR✓J(LKEC(5) 14.%5.90 87.85 325.15 7.894.46 7.05,16 9.194.44 5235 5,954.357.07 3172P30 L" 0220.62 MMD+IFR-M4 MSC(5) 10.101.87 88.10 16.53 7,a93.81 7,809.51 9,2.2.52 11632 5,951,846,42 317.1524 046 8 3141 MJr11NFR-M M-0 C(5) 1,tA97.19 8632 325.48 7.900.711 7,811.48 9,351.03 -170.28 5,954,91622 317,1.120 024 0,40914 MNDr-FR- -CAZSL (5) 142M.W 91.5 325.93 7.900.89 7.81159 9,429.65 -.13.93 5.95499611 317,121AB 3.43 0,50354 MNDr-FR- -C-0 SL(5) 1430709 91.70 326.19 7.89821 78),15,.91 9,508.19 -078.79 5,9$075.91 317,07155 0.32 0.597,52 MWDNFRAKSPZSL(5) 14,48270 9090 M,27 7,65601 7,8%]1 9,587,66 529.92 5651565 31701937 081 0.692.44 MWDHFR11(-0AZSC(5) 14,5P.76 POA" .4.. 7,094.5 700550 95592 503.5 5,9523010 316,85736 1.3 0,785.66 MWDOFRAK MA C(5) 146.278 90.8 326.07 7.0091 7,804.61 6744.05 4RS 5,95315.59 316.91525 1.50 Bitumen! WAANWRA-CAZSC(5) 14)07]3 9037 32835 7.09301 7Short 6021.98 -090t% 5955,395.78 316.86439 0.48 8,97511 MWD+IFR- -C-0 SC (S) 14,85641 5.5 327A1 7,093.83 7,004.53 9,95.11 542% 5,955,477.15 316814.07 211 9,07023 MWDNFR- -CMSC(5) 14,958.5 8644 32]17 Teri 78%95 9.9564 594% 5,955,55.89 316.8,, 0.44 9.16520 MWD+IFR-N(LAZSC(5) is OK09 06.50 321.4 790046 7611.16 10,%470 5"3.. 5,955.641.13 316.717011 243 9.260.05 MrVDHFR-AK-0"250(5) 15,14877 0657 3".61 7904.5 7,815,23 10,146,05 59219 5,955.]2362 316,670]9 227 8.354,4 MvW+IFR-AKCALSC(5) 1534499 0776 329% 74907.61 7,818.31 10,220.7] -74124 5,955807.51 316.62317 102 9,450.42 MVC+IFR] .CA SC (5) 15,33980 0746 326]0 7.911.56 7,11.236 10.309.90 -790.14 5955.8fen 318,516.85 043 9,544.90 MND+IFR-AK-LAZSL(5) 1543428 8764 32940 7.5560 T,5630 1039009 53883 595.971.23 316.53035 060 9,839.08 MNDdFR.-CoZ51.(5) 1559.73 88.67 331,59 7,916.60 7,829.38 10.473.91 585.61 5.95.056.% 316,485A0 253 9]34.38 MAD+1FRAK-CAZSC(5) 1562425 can 332% 7,92113 7,515 10,57,55 929.57 S las 140.74 316,44149 149 96265 ~+IFR -AK -SC(5) 15119." 59fi 333.5 7,92563 7,61513 10,642.51 -en,, 5,856,22.70 31640282 162 9,92396 MM+1FR-AKCAZSC(5) 15814.75 B7,10 333.93 79"90 7.040.. 10,M7.89 -101438 5'83,31300 316362. 0.40 1001914 MWD+lFR-AK-CAZSL(5) 1590022 87.59 333.90 7.934.1 7,04/92 10,812.65 AM.01 5.95,39682 316,323,42 0542 10.113.50 MWD+IFR-AWCPZSL(5) 1.0051] 89.60 3.,.3 793634 7..7,. 10,.a. -1,09797 5955.4%% 31628643 241 1020941 MW0HFR-A1L 5C(5) 1.090.89 90.13 334.12 793632 764702 10,96403 -1,13936 6,9565816 3161244.10 027 10.334.11 MWD+lFRAKCA2SC(51 . 2019 11;12;45404 Patina COMPASS SOW, f48ped 85D Survey ConocoPhillips ConocoPhillips DefinRive Survey Report Company: ConacoPhilips Alaska Inc_ MS Local Coondlitah Pehnres: Vrbll MT6-02 Project. Mellon North Slope WD Reference: Plan MT6-02 @ 09.30us6 (DDyon19 Planned) Site: GMT1 Walnut Pad MO Reference. Plan MT"2 @ 89.30usg (Wyonl9 Planned) Well: MT"2 None Reference'. Tme Wellbore: MT602 Surrey Calculation Method: Mnimum Curvature Dol9n'. MT"2 Database: EDT 14 Alaska PmEumon Survey Annotation 988201911: 1245AM Page 9 COMMSS 5000.14 Badd 050 p Wheal MD Mc AL TVD WD55 11,11-5-0-W Nothing Eatng DG9 section survey cool Name (RM7 N (1) (usn) (..ft) loan) luanl (III III) (°1100•) (II) 16 pliant WAS 33338 793600 7846.78 11,069.97 -1,18177 5.956,659.10 316203.82 077 lot,S)93 MWD+IFR-AK-CAZSCSj 16 290.83 09.58 33310 7.935.29 7,84&99 1115494 -1,224.61 5958]45.08 316.163.05 060 10,495.09 MWD+IFR-AK-CAZ4tC(5, 1,6.386.03 W.n 33273 7.937.70 7,80,40 11.239.62 -1,267.92 5,958.833.78 316.121.82 098 10,59020 MWD+IFRAKCAZSC(6) 1640126 8743 33126 7.940.90 7,05160 11,323.67 -1,31262 5,95,91598 318.079.17 205 10,605.30 M .IFR -AK AZ3C(5) 16575.25 IS" 332.03 7,944.05 7,854.75 11,4W..H -1.357.23 5.958.933.61 316036.50 1.61 10.77929 MWOAFRAK-CAZSO(5) 1667191 9088 331,94 7,944.30 7,85500 11,49167 -1002,63 5957,01s01 315,99327 223 1007593 "CAFR- AZSC(5) 16766.44 90.62 33182 7,943.14 286304 11,574.80 8448.00 5,957,17072 315.949.91 121 10,970. MJvDH0FR-AKL .C(5) 16082.8 91.18 332.27 2941.64 285234 11,09.10 -1,493.60 5957 ,25.59 315,9032 1.02 11,036.46 MND+IFR- -CL C(5) 16958.79 9053 331.78 7,94033 7.850.93 11,74234 -1,537.89 5,957,33988 315861.14 0.5 11,160.44 N%DHFR-AH-0AZSC(5) 17,0140 09.65 333.28 7,939.92 765062 11,02518 -1,503]6 595242380 315.82d31 Ll4 11.255.32 MWD+lFR-AK-C ZSC(6) 12148.18 B&M 33111 7,W,13 2853.03 1404.44 -163105 5,9525010 315.27507 3.73 11.35180 MWD+lFRA-CA2SC(5) 12243.19 85.18 332.26 7,950.15 7.81 11992..5 -067544 5,957,59366 315,73217 172 11,44&60 MWDHFR-AK-CASC(5) 17,33862 BB.M 332.111 7,957.28 7.86288 12027.24 -1,71998 5,957,679.08 315,68025 121 11541.76 MWD+lFRAWOAZSC(5) 1743405 88.42 33360 7.9110 2072.40 12,16235 -1,762.0 5957]65.20 315,64942 See 11447.07 1040+1FR-AK-CAZSC(5) 17,52925 89.43 33449 7,98349 7,074.19 12247.90 -0,801.63 5,957.051.73 315,609.78 1.14 ii.M24 MW0+1FRAK-CAZSC(6) 1262479 9023 33440 296371 7,07447 12,33401 -1,01601 5,951"938.02 31557050 0.89 11,827.75 MWUHFRAN-CPZSC(6) 17 n0e. 9'. 334.29 7,963,40 767410 12419.94 -1,80220 5,998.025.71 315,531.41 020 11,923.02 MWD+lFRAKLAZ-SC(5) 17,81493 91.18 33447 20224 28894 1250545 -1,928.21 5858.112.19 315,49249 1.03 12,01283 M 1FRAK-CAZSC(5) 17,91054 915 333.81 7,959.90 287086 1259146 -1,969.90 595,199.19 315,452.0 079 12113.39 MADNFR-AoCAZSC(5) 10.0530 90.71 334.15 7.95.10 7,86&80 12876.58 4,01146 5,958.285.29 315,413.43 095 12,208.10 MND+IFRAKCAZSC(5) 18.101.15 90.50 33.00 7,957.00 7,06278 12762,00 1.053.37 5,950,372,19 315,373.0 027 12,30.95 MJJD+IFR-A AZSC(6) 18.196.61 ... 333.99 7,954.40 7,80518 1?048.5 1.05.20 5,950,45923 315.333.98 223 12,399.35 MNO+IFRrVtLAZSC(6) 18,291.49 9268 33249 7.950.00 2860.70 120318 8,137,88 6 all, Was 315,29329 150 1249413 MND+lFRJ AZSC(5) 18.398.11 9299 330.95 7.91540 7,858.10 13,01641 $182.65 5,95&82414 315,250.5 1.0 12588.80 MNDNFRAoCAZSC(5) 1&102.. 9398 330.72 L939.55 7.850.25 13,10.28 -2,22946 5,958714 12 315.20.44 10 12,684.5 MWD+JFRJ -C-0 SC (5) 10.576.39 9394 331 7.933.0 7,8,13.76 13,101.95 -237564 5.950)9808 315,181.61 0.45 12,778,32 MWD+1FR--CAZSC(5) 1&6RM 9308 32981 7,926.53 7,037.23 13,201.69 -ZacMA9 5.958000.75 315116.09 0.30 12.073.63 MNDHFRAK-CPZSC(5) IS 767.52 94.50 330.15 7,81958 2830.26 133232 337062 5958.984.50 31507078 001 12,0074 MWDNFRAK-CAZSC(5) 18 44294 91.5 33L69 7,91L95 7,8II5 13,430.56 -241&53 5.09,048.03 315.026.01 130 13,0300 MWD+IFR- -CAZ-SC(5) 1095200 93.57 33249 7,90.16 7,01506 13,513.00 -246034 5.959.133.20 314984.44 126 13.150.20 MWD+IFRAK-CAZSC(5) 1905343 9061 1.. 7901.67 7.01237 13,59850 -250561 5.959.210.95 31494184 309 13253.95 MJVDHFRAKGAZSC(6) Annotation 988201911: 1245AM Page 9 COMMSS 5000.14 Badd 050 Survey ConocoPhillips COnocoPhillips Definitive Survey Report Company: ConPcoPhilipa Meek. lnc WNS Local Co-andmace Reference: Well MT6-D2 Project Metal, North Slope TVD Reference: Plan MTB-0289.30ustl(Dayonl9 Planned) she GMT1 Lookout Pad MD Reference: Plan MT6-0289.30usft(Dayonl9 Planned) Well: MT6412 North Reference: Tme Wellbore: MT64)2 Survey Calculation MetboB: Minimum Curvature Design: MT&D2 Wbbaec: EDT 14 Alaska Prod.Mn Survey Annotation �r ifc�V o 3/8/1019 11: 12:454M Page 10 COMPASS 5000.14 n W 85D aRlsal MD 1. AM TVD TVDSS aW4 +EIAV NPMaP as EtinB DLS Section 3 (1401- (1) (') (41 -11)( -am (-am (�) (•1100') Survey Tool Name rt(111 (4) (ft) 19, 14986 900] 332.51 T7.901.10ZBt1.50 13,88.29 1.54994 5959,304.70 3114899.59 OW 13,39955 MWOaIFRAK-0.7.50(5) 19,244]7 0951 33.25 9,901.37 7,81207 13 M797 4,59329 5.959.39041 31485331 0.89 13.444.86 MWD+IFRJJ(LALSC(5) 19,33939 00.53 3M,97 7,902.91 7.813.61 1305361 -0,634.86 5959.477.03 314,81383 213 13,539.06 MWDAFR-P<C C(5) 19,43570 88.75 334W 7,a020 7,01590 13,94209 -2,672.80 5,959.Y,se 314,MM 377 1363592 MWDHFR-PI(-CALbC(5) 19531B7 9111 MI. T86Al 7815.51 14,032M 4.705.81 5959.857,58 31475225 415 13,731.16 MWDNFR-PH-0.42.0(5) 1932731 9312 34298 7.900.79 7.81149 14,123.16 -2735.03 5959,74&91 314 7 24 231 13,825.50 MWDNFR-N(-0AZSC(5) 197274 95.15 343M 7 MM 7.00458 14,21336 -2762.09 5,5H59,83914 31470037 225 13.910.16 MD -IFR -M-0 C(5) 19617,68 9430 34204 7,88(k01 7,M,71 14,30411 -2,79032 5,95993114 314.67438 1.03 14,01236 MWD+IFR-PK-C C(5) 1991167 91.86 343,8 7881.19 7,791.89 1439440 281791 5,9W.W2.07 31464&94 3.55 14,10483 MWD+IFR-PKCA24C(5) 20,00304 9,54 3442) 7,07664 7786.34 14,48699 -2,844.1 5.986.11528 31462460 0,53 1419940 MWD+IFR-P14CAZSC(5) 2010330 91.63 343.86 707600 7.78670 14,57836 -2,87135 6,BW.20726 31460002 123 1429298 MWD+IFR-N(-CA24C(5) 2019859 91.33 343A2 7,87351 7.78424 14.869.57 -2,898.82 5,960,29911 314574.71 0.49 143868 MD+IFR-N(-CAZ (6) 20,8291 9247 3M23 7,Mal 7,781.11 14750,11 8,925.08 5,980,]X125 314,55072 108 14.47931 MWD+WR-AK-0.25[(5) 20,389.06 82.93 34542 7865. 7)76.59 14,852.80 -2,95022 5,960.483.52 314,52704 133 1457331 MWD+IFRAK-CR (5) 20,48359 92.86 34710 7861,77 7M47 14,944.53 -2,9]7.65 5.95057576 314,507.64 200 14.W523 lMDOFR-AK-0292.[(5) .578]8 9151 34443 7858.. 7.769.50 15.038]5 -2,9%M 5,060.5.51 314,4116.50 2.. 14,75302 MWD+IFR-AK-0.42.[(5) 20673.90 91.45 341.88 7,BY34 7787.04 15,127.82 -3,023.02 5.96076023 314461/4 2.68 11.85169 MOD+IFR-AK-0.42.[(5) 876920 .,fl 330.94 7855.8 7,70.58 15.217.52 -3.055.54 5,860,8%65 314.431.41 3.95 14946.. MDAFRAK-0-25[(5) 20864A5 8924 Me 7,05725 776795 15,38631 -3,0.,90 5,95D94026 314399.14 0.32 15,040,85 MVD+IFRAK-0P C(5) 20.56048 91,12 33392 78156.95 7,M7.65 15,39581 -,12472 5,961=57 314350,59 198 15.13936 oMDNFRAK-07 ZC(5) 21655.82 90.0 33&09 7.855.63 7,M33 15,484.53 4159.65 5,961,12(1.11 31433392 ,11 15,M127 MND+IFRAK-0P24C(5) 21150.83 .53 337.40 7.854.80 7,765.50 15,.42.48 419564 5,9612080 3142.98 013 15,325.95 MWD+IFR-A 4iC(6) 21245.. 90.47 337.05 7.453.97 7,M4.67 15.86002 32.A0 596129730 31429653/7 0.37 15.420.88 MND+IFRAK-0PZ-C(5) 21.Ml.M 89.61 338.55 7,853.88 7)64.50 15.74822 .,27019 5961,3.39 314,229.2 1.0 15,516.41 MWDAFR+ix-0.42.[(5) 21,43796 90.29 3M30 7,053.90 7,M4.63 15,&75.. -,30&24 5961AT486 3141%81 071 15,6115) MAMAFRN(-0A25C(5) 21,5.2&4 9195 3.24 7.052.07 7,762.77 15,923.10 .34363 5,961,563.06 314,157.55 L74 15,706,93 MWDAFRAKLAZSC(5) 2165.. 9,54 33606 7.849.20 7,759.90 76,[0928 43M72 5,961.6%, 31412,57 0.48 15 eve MWD -IFR -ML C(5) 21,MM 9038 334.90 7,847.59 7,7W29 16,09627 ..42441 596173805 31408901 111 15,89653 MWD+IFR-01 QL C(5) 21918.17 8918 334.71 7.80.96 7.7N,66 16,182.80 3465.12 5,%1,025.5 3t4D45A1 127 15,992.12 MND+IFR-PA-0 C0) 21,913.31 0&S 335.4 7,849.02 7,759.72 1659,11 y505,14 5,961912.86 314,007.50 0'. 16,08710 IMDAFR✓J4CA2£C(5) wos,29 92.01 336.90 7,80]2 7.768.42 16,3564o 41,543.60 5,962.000.93 313,971.17 295 15.10243 MWD+IFR-PH{ C(5) Annotation �r ifc�V o 3/8/1019 11: 12:454M Page 10 COMPASS 5000.14 n W 85D �6R o i ucRns 3 a()19 11 12: 454M Page 11 COMPASS SOW 14 Bugd 660 Conmolohillips v ConocoPhIllIps Definitive Survey Report Company: LonocoPhillps Aha" Inc -MS local Coordinate Reference: Noll MT6-02 Project: Minem North Slope TVD Reference: Plan MT642®39.30usn(Doyanl 9 Planned) Site: GMT1 Lookout Pad MD Referent: Plan MT6-02 ® 69.30usp (Doyanl9 Planned) Well: MT642 North Reference: True Wellbore: MT642 Survey Calculation Method: Minimum Curvature Design: MT6-02 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Ad TVD NDSB iWS -E1-W Northing EaaNng OLS SeGlon survey Tool Name Annotation (usnl fl (1) loath luaRl lural (uaR) IRI MI 0e00'1 (ft) 22.103]7 9450 33732 1A42.32 7,75302 16,44302 .5W.51 5.95308927 313938.40 266 16277V MWDrIFRJ CAZS (5) 22.19077 93.08 338.42 7.836.04 ].746]4 1553099 4.617,75 5,962,97.32 313.901.E 177 16,371.64 MWD+1FR-W-CAZS0(6) 2222BW 9300 3842 7,834A7 7,745.17 16,557.74 4,629.42 5,962,204.34 313,890.P n00 16,400.E PROJECTED to TO �6R o i ucRns 3 a()19 11 12: 454M Page 11 COMPASS SOW 14 Bugd 660 aA111101111L Cement Detail Report MT6-02 String: Conductor Cement Job: DRILLING ORIGINAL, 12/22/2018 00:00 Cement Details Description Conductor Cement Cementing Start Date 2/5!2018 08:00 Cementing End Date 2/5/2018 10:00 Wellbore Name MT6-02 Comment Cement Stages Stage # 1 Description Conductor Cement ObjectsTop Depth (ftKB) Cement Conductor 36.8 Bottom Depth (ftKB) 115.0 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (blift... Q Pump Final (bbll... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip7 No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids 6 Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bon (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft /sack) Mix H2O Ratio (ga9sa... Free Water (%) Density (iblgal) Plastic Viscosity (0) Thickening Time (hr) CmprStr t (psi) Additives Additive Type Concentration Conc Unit label Page 1/t ReportPrinted: 3118/2019 Cement Detail Report a MT6-02 String: Surface Casing Cement Job: DRILLING ORIGINAL, 12/221201800:00 Cement Details Description Cementing Start Dale Cementing End Date Wellbore Name Surface Casing Cement 12/2412018 22:30 12/2572018 01:30 MT6-02 Comment Dowell pump 2.1 bbls H2O & PT to 3500 psi (good). Dowell pump 100.1 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 382.5 bbls 11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement and 72.7 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 279.6 bbis/ 2,798 stks 10 ppg DrillPlex with 8 bpm / 700 psi. Reduce pumps to 3 bpm/400 psi. last 10 bbls. Bump plug, pressure 500 psi over to 900 psi for 5 min. Check floats. F/C good. CIP @ 1:29 Hrs. Calculate 150 bbls good cement to surface. Full returns & reciprocated pipe during cement job. Cement Stages Stage # 1 Description jObjective Top Depth (ftKB) Bottom Depth (ftKB) Full Return?Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement Surface Casing 37.0 2,080.4 Yes 150.0 Yes Yes Q Pump Init (bbl/m... Q Pump Final (bbll... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (R) Ratatetl? Pipe RPM (rpm) 8 3 5 400.0 900.0 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Dowell pump 2.1 bbis H2O & PT to 3500 psi (good). Dowell pump 100.1 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 382.5 bbls 11.0 ppg 1.95 Max yield LiteCRETE lead cement and 72.7 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 279.6 bbls / 2,798 stks 10 ppg DriIlPlex with 8 bpm 1700 psi. Reduce pumps to 3 bpm 1400 psi. last 10 bbis. Bump plug, pressure 500 psi over to 900 -psi for 5 min. Check floats. F/C good. CIP @ 1:29 Hrs. Calculate 150 We good cement to surface. Full returns & reciprocated pipe during cement job. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Surface Cement 37.0 I 1,580.0 1,101 B 382.5 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) 14.80 Cmprstr 7 (psi) 1.95 7.03 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,580.0 2,080.4 352 G 72.7 Yield (RYsack) Mix H2O Ratio (gal/"... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.0 1 15.80 5.00 Additives - Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 31181201! a Cement Detail Report MT6-02 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 12/22/2018 00:00 Cement Details Description Intermediate Casing Cement Cementing Stag Data 1/1/201916:00 Cementing End Date 111/20192300 Wellbore Name MT6-02 Comment SLB pumped 60 bbl Mud Push, 98 bbl 12.2 ppg Lead cement, 48.8 bbl 15.8 ppg Tail cement. Kicked out with 20 bbl water. Rig displaced with 638 bbl LSND. Bottom plug landed on time, @ 490 bbl into displacement, pressure built up to 3000 psi, packed off and lost returns. 110 bbl lost to formation. Cement Stages Stage all 1 Description Intermediate Casing Cement Objective Top Depth (ftKB) 1000 feet of cement for 8,504.0 drilling ahead Bottom Depth (ftKB) 8,742.5 Full Return. No Vol Cement... Top Plug. Yes Btm Plug? Yes Q Pump [nit (bbllm... 4 3 Q Pump Final (b4T—.gMetthod Q PumAvg (bbil... 3 P Pump Final (psi) 3,080.0 P Plug Bump (psi) 3,060.0 Redp? No Stroke IN) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Lost returns at 490 bbl into displacement, packoff and pressure up to 3100 psi. Lost 110 bbl cement to formation. Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top IRKS) 7,742.5 I EstBtm (ftKB) 8,115.0 Amount (sacks) 239 Class G Volume Pumped (bbl) 98.0 Yield (R'/sack) 2.30 Mix H2O Ratio (gal/es... 13.23 Free Water (%) Density (lb/gal) 12.20 Plastic Viscosity (cP) 12.0 Thickening Time (hr) 5.00 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 8,115.0 Est Boo (ftKB) 8,742.5 Amount (sacks) 236 Class G Volume Pumped (bbl) 48.8 Yield (ft'/sack) 1.16 Mix H2O Ratio ignites... 5.06 Free Water (%) Density (lb(gal) 15.80 Plastic Viscosity (CF) 124.0 Thickening Time (hr) 5.50 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 311812019 Cement MT6-02 Liner Cernei it Cement Details Description Liner Cement Cementing Start Date 1/12/201912:00 Cementing End Date 1/121201913:30 Wellbore Name Pill, Comment Test lines to 3,000 psi. Pump 38.4 bbls 11.5 ppg mud push 11, Mix and pump 55.1 bbls 15.8 ppg cement, Pump 20 bbls water. Sting in and displace with 142 bbls 10.9 ppg LSND mud. Final circulation pressure at 2 bpm 720 psi. Cement in place at 13:30 hrs. Observed no mud losses. Cement Stages Stage 9 1 Description Objective Top Depth (RKB) Bottom Depth (ftKB) Full Return? Liner Cement Cement 7" SDL Liner 9,551.0 11,051.0 Yes Vol Cement... Top Plug? elm Plug? 0.0 No No Pump Init (bbllm... Q2 O Pump Final (bbg... D Pump Avg (bbil... 2 P Pump Final (psi) 730.0 P Plug Bump (psi) R-ip? No Stroke (it) Rotated? No Pipe RPM (rpm) Tagged Depth (RKB) Tag Method Depth Plug Drilled Out To (RKB) Drill Out Diameter (In) Comment Pumped via cement retainer @ 10,988' Cement Fluids & Additives Fluid flultl Type Tail Cement Fluid Description Estimetatl Top (ttKB) 9,551.0 Est Burt (ttKB) 11,051.0 Amoum (sacks) 263 lasa CG' G Volume Pumped (bbl) 55.3 Yield (rP/sack) 1.16 Mix H2O Ratio (gal/sack) 5.02 Free Water Iv) Density (Iblgal) 15.80 Plasllc Viscosity (CP) 115.0 Thickening Time (hr) 5.56 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 111412019 MEMORANDUM To: Jim Regg 7'11312,0/1C, P.1. Supervisor FROM: Guy Cook Petroleum Inspector Well Name GMTU MT6-02 Insp Num: mitGDC190315153331 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 19, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. MT6-02 GMTU MT6-02 Src: Inspector Reviewed By: P.I.SuprvJ �. NON -CONFIDENTIAL Comm API Well Number 50-103-20792-00-00 Inspector Name: Guy Cook Permit Number: 218-160-0 - Inspection Date: 3/12/2019 Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min 'a Well MT6-02 ']Type Inj %V ITVD 2888 'Tubing 'o3 2403 >-Im ]40: PTD 2181600 Type Test', SPT Test psi 1972 IA - '00 3130 3090 3080 - -- — -- BBL Pumped. 2 -1BBL Returned 2 OA 3s4 - 418 a - iIs Interval 1NITAL �p/F P ✓ Notes: Initial MIT -IA for new injector. Testing was performed with a Little Red Services pump truck and currently calibrated gauges from DHD. OOA 106/106/106/106 Tuesday, March 19, 2019 Page I of I BA ER F UGHES a GE company Abby Bell Date: March 8, 2019 AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 ( 21 8160 30 41, 0 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94`h Avenue Anchorage, Alaska 99515 lease find enclosed the directional survey data forth e following welI(s): MT6-02 MT6-02L1 RECEovF'D MAR 13 2019 A®GCC (2) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper(aBakerHughes.com ConocoPhillips ConocoPhillips Alaska Inc_WNS Western North Slope GMT1 Lookout Pad MT6-02 50-103-20792-00 Baker Hughes INTEQ Definitive Survey Report 08 March, 2019 21 81 60 30440 BAT(ER UGHES 01 a GE company ConocoPhillips ConocoPhillips Definitive Survey Report B! UGq FS 0 Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Well: MTB -02 North Reference: True Wellbore: MI -6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02 Database: EDT 14 Alaska Production Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MT6-02 Well Position +NI -S 0.00 usft Northing: 5,945,564.39usft Latitude: +E/ -W 0.00 usft Easting: 317,116.39usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: Wellbore MT6-02 Magnetics Model Name Sample Date Declination Dip Angle BGGM2018 12/22/2018 16.25 80.68 Design MT6-02 Audit Notes: Version: TO Vertical Section: Phase: ACTUAL Depth From (TVD) (usft) 37.10 Tie On Depth: 37.10 +NI -S +E/ -W Direction (usft) (usft) (I 0.00 0.00 333.00 70" 15' 23.180 N 151'28'41.304 W 37.20 usft Field Strength (nT) 57,384 3/8/2019 11: 12: 45AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips tN 0 ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: ;Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMTi Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02 Database: EDT 14 Alaska Production Survey Program Date From TO Survey Survey (us") (usft) Survey (Wellbore) Tool Name Description Start Date End Date 75.53 35600 1, Gyrodata GyroSS 16" (MT6-02) GYD-CT-DMS Gyrodata cont drillpipe m/s 12/19/2018 12/19/2018 393.46 2,027.27 2. BHGE MWD+IFR+MSA 16°(MT6-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/232018 12/23/2018 2,115.67 8,972.41 3. BHGE MWD ATK+IFR+MSA 121/4"(M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/262018 12/29/2018 9,065.23 11,105.67 4. BHGE MWD+IFR+MSA6 3/4" (MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/102019 1/17/2019 i 11,152.00 i 22,198.77 5. BHGE MWD+IFR+MSA41/8"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/18/2019 1/24/2019 11 Survey 4 Map Map Vertical MD Inc An TVD TVDSS +N/ -S +E/ -W Northing DLS Fasting Section ' (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name Annotation 1N) (N) (N) 37.10 0.00 0.00 37.10 -52.20 0.00 0.00 5,945,564.39 317,116.39 0.00 0.00 UNDEFINED 75.53 0.21 259.42 75.53 -13.77 -001 -0.07 5,945,564.38 317,116.33 0.55 0.02 GYD-CT-DMS(1) I 172.00 0.44 232.20 172.00 82.70 -0.27 -0.54 5,945,564.13 317,115.85 0.28 0.00 GYD-CT-DMS(1) 259.22 0.28 261.87 259.22 169.92 -0.51 -1.01 5,945,563.91 317,115.37 0.28 0.01 GYD-CT-DMS(1) ) 356.00 _. 1.48 2.91 355.99 266.69 0.71 -1.18 5,945,565.12 317,115.23 1.61 1.17 GYD-CT-DMS (1) 393.46 2.36 8.49 393.42 304.12 1.95 -1.04 5.945.566.37 317,115.40 2.40 2.21 MWD+IFR-AK-CAZSC 12) 482.67 4.11 10.97 482.49 393.19 6.91 -0.16 5,945,571.30 317,116.40 1.97 6.23 MWD-IFR-AK-CAZ-SC 12) 1 576.84 5.45 11.09 576.33 487.03 14.61 1.34 5,945,578.96 317,118.09 1.42 12.41 MWD+IFR-AK-CAZSC (2) j 668.30 629 11.89 667.31 578.01 23.78 3.21 5,945,588.08 317,120.18 0.92 19.73 MWD+IFR-AK-CAZ-SC(2) 762.46 7.48 10.65 760.79 671.49 34.85 5.40 5,945,599.09 317,122.64 1.27 28.50 MWD+IFR-AK-CAZ-SC(2) 856.78 8.53 9.79 854.19 764.89 47.77 7.73 5,945511.96 317,125.28 1.12 39.06 MWD+IFR-AK-CAZ-SC (2) 950.44 9.48 9.52 946.69 857.39 62.23 10.18 5,945,626.35 317,128.08 1.02 50.82 MWD+IFR-AK-CAZ-SC(2) 1,094.41 10.50 8.77 1,039.24 949.94 78.32 12.77 5,945,642.37 317,131.06 1.09 63.99 MWD+IFR.AK-CAZ-SC(2) 1,138.88 11.84 8.65 1,131.91 1,042.61 96.41 15.54 5,945,660.39 317,134.27 1.42 78.85 MWD+IFR-AK-CAZ.SC(2) 1,233.76 13.58 10.87 1,224.47 1,135.17 116.97 19.10 5,945,680.86 317,138.33 1.90 95.55 MWD+IFR-AK-CAZ-SC(2) 1,325.85 15.13 11.62 1,313.68 1,224.38 139.36 23.56 5,945,703.13 317,143.33 1.70 113.48 MWD+IFR-AK-CAZ-SC(2) i 1,419.41 16.52 11.10 1,403.69 1,314.39 164.38 28.58 5,945,728.01 317,148.96 1.49 133.49 MWD+IFR-AK-CAZ-SC(2) I 1,512.77 1762 10.10 1.492.94 1.403.64 191.32 33.62 5,945,754.82 317,154.64 1.22 155.20 MWD+IFR-AK-CAZ-SC(2) ' 1,607.40 18.82 10.20 1,582.82 1,493.52 220.44 3883 5,945,783.81 317,160.56 1.27 178.78 MWD+IFR-AK-CAZ-SC(2) ) 3WO19 11.:12:45AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips RACER a F�UGHFS ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: .Plan MT6-02 Q 89.30usft (Doyon19 Planned) Site: GMT1 Lookout Pad MD Reference: -Plan MT6-02 Q 89.30usft (Doyonl9 Planned) Well: MTB -02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02 Database: EDT 14 Alaska Production Survey 1 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Easting DLS Section c (usft) (°) (°) instill (usft) (usft) (us") (°/1000 Survey Tool Name Annotation ,_4 (ft) (ft) (ft) (ft) .... 1,70263 2047 10.51 1,672.50 1,583.20 251.93 44.59 5,945,815.15 317,167.09 1.74 204.23 MWD+IFR-AK-CAZ-SC(2) I 1,797.10 21.55 9.42 1,760.69 1,671.39 285.29 50.44 5,945,848.35 317,173.75 1.22 231.30 MWD+IFR-AK-CAZ-SC(2) 1,891.64 23.14 9.50 1,848.13 1,758.83 320.74 56.35 5,945.883.65 317,180.51 1.68 260.20 MWD+IFR-AK-CAZ-SC(2) 1,985.78 24.52 9.38 1,934.24 1,844.94 358.26 62.59 5,945,921.00 317,187.66 1.47 290.80 MWD+IFR-AK-CAZ-SC(2) 2,027.27 24.58 10.11 1,971.98 1,882.68 375.25 65.51 5,945,937.92 317,190.99 0.75 304.61 MWD+IFR-AK-CAZ-SC(2) 2,115.67 25.16 10.57 2,052.19 1,962.89 411.83 72.18 5,945,974.31 317,198.55 0.69 334.17 MWD+IFR-AK-CAZ-SC(3) 2,181.31 26.12 11.04 2,111.36 2,022.06 439.72 77.51 5.946,002.07 317,204.55 1.49 356.61 MWD+IFR-AK-CAZ-SC(3) 2,275.41 27.46 10.92 2,195.36 2,106.06 481.36 85.58 5,946,043.50 317,213.64 1.43 390.04 MWD+IFR-AK-CAZ-SC(3) 2,370.51 29.07 10.81 2,279.12 2,189.82 525.59 94.07 5,946,087.50 317,223.19 1.69 425.59 MWD+IFR-AK-CAZ-SC(3) j 2,464.83 30.20 10.65 2,361.10 2,271.80 571.41 102.75 5,946,133.10 317,232.98 1.20 462.48 MWD+IFR-AK-CAZ-SC(3) Vi 2,559.44 31.78 11.17 2,442.20 2,352.90 619.24 111.98 5.946.180.69 317,243.37 1.69 500.91 MWD+IFR-AK-CAZ-SC(3) 2,651.78 32.56 10.62 2,520.36 2,431.06 667.52 121.27 5,946,228.72 317,253.83 0.90 539.71 MWD+IFR-AK-CAZ-SC(3) I 2,746.27 32.53 10.72 2,600.02 2,510.72 717.47 130.68- 5,946,278.43 317,264.45 0.07 579.94 MWD+IFR-AK-CAZ-SC(3) 2,841.33 32.49 9.40 2,680.18 2,590.88 767.77 139.60 5,946,328.50 317,274.59 0.75 620.71 MWD+IFR-AK-CAZ-SC(3) 2,936.25 32.54 8.95 2,760.22 2.670.92 818.14 147.74 5.946.378.65 317,283.94 0.26 661.90 MWD+IFR-AK-CAZ-SC(3) 3,030.02 32.56 9.21 2,839.26 2,749.96 867.96 155.70 5,946,428.26 317,293.11 0.15 702.67 MWD+IFR-AK-CAZ-SC(3) - 3,122.17 32.51 9.60 2,916.95 2,827.65 916.85 163.80 5,946,476.94 317,302.40 0.23 742.56 MWD+IFR-AK-CAZ-SC(3) 3,216.78 32.61 8.04 2,996.69 2,907.39 967.16 171+61 5,946,527.04 317,311.42 0.89 783.84 MWD+IFR-AK-CAZ-SC(3) 3,311.58 32.56 8.02 3,076.57 2,987.27 1,017.72 178.74 5,946,577.40 317,319.78 0.05 825.65 MWD+IFR-AK-CAZ-SC(3) 3,405.14 32.59 8.94 3,155.41 3,066.11 1,067.54 186.17 5,946.627.03 317,328.41 0.53 866.67 MWD+IFR-AK-CAZ-SC(3) 3,499.93 32.53 10.07 3,235.31 3,146.01 1,117.85 194.59 5,946,677.12 317,338.05 0.64 907.67 MWD+IFR-AK-CAZ-SC(3) 3,592.89 32.63 10.91 3,313.64 3,224.34 1,167.07 203.70 5,946,726.10 317,348.36 0.50 947.39 MWD+IFR-AK-CAZ-SC(3) 3,687.46 32.47 11.65 3,393.35 3,304.05 1,216.97 213.65 5,946,775.74 317,359.52 0.45 987.33 MWD+IFR-AK-CAZ-SC(3) 3 3,780.96 34.13 12.04 3,471.50 3,382.20 1,267.21 224.19 5,946,825.70 317,371.28 1.79 1,027.31 MWD+IFR-AK-CAZ-SC(3) (f 3,874.92 35.80 12.45 3,548.50 3,459.20 1,319.82 235.62 5,946,878.02 317,383.97 1.79 1,069.00 MWD+IFR-AK-CAZ-SC(3) 3,969.47 37.50 12.89 3,624.35 3,535.05 1,374.89 248.00 5,946,932.76 317,397.69 1.82 1,112.44 MWD+IFR-AK-CAZ-SC(3) 4,071.45 39.31 13.50 3,704.26 3.614.96 1,436.56 262.47 5,946,994.06 317,413.65 1.81 1,160.83 MWD+IFR-AK-CAZ-SC(3) 4,164.71 41.71 13.91 3,775.16 3,685.86 1,495.41 276.82 5,947,052.54 317,429.43 2.59 1,206.74 MWD+IFR-AK-CAZ-SC(3) { 4,258.92 43.55 14.09 3,844.47 3,755.17 1,557.32 292.26 5,947,114.05 317,446.36 1.96 1,254.90 MWD+IFR-AK-CAZ-SC(3) 4,351.85 44.02 14.53 3,911.56 3,822.26 1,619.62 308.16 5,947,175.95 317,463.76 0.60 1,303.20 MWD+IFR-AK-CAZ-SC(3) 4,445.85 44.07 15.46 3,979.13 3,889.83 1.682.75 325.06 5,947,238.64 317,482.20 069 1,351.76 MWD+IFR-AK-CAZ-SC(3) 3/812019 11 12 45A Page 4 COMPASS 5000.14 Build 850 ConocoPhillips0 t u FRw+Es ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 -. Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) { Well: NF -6-02 North Reference: True i Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature - Design: MT6-02 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc An TVD TVDSS +N/ -S +E/ -W Northing Easting Section Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°�oo) (ft) 4,540.88 44.11 15.95 4,047.39 3,95809 1,74640 342.96 5,947,301.84 317,501.64 0.36 1,400.35 MWD+IFR-AK-CAZ-SC(3) 4,635.82 44.05 16.70 4,115.59 4,026.29 1,809.78 361.53 5,947,364.75 317,521.73 0.55 1,448.40 MWD+IFR-AK-CAZSC (3) 4,730.27 44.02 16.95 4,183.49 4,094.19 1,872.62 380.53 5,947,427.11 317,542.25 0.19 1,495.76 MWD+IFR-AK-CAZ-SC (3) 4,824.25 43.93 16.89 4,251.12 4,161.82 1,935.05 399.52 5,947,489.05 317,562.75 0.11 1,542.77 MWD+IFR-AK-CAZ-SC (3) 4,920.04 44.06 15.91 4,320.04 4,230.74 1,998.88 418.31 5,947,552.40 317,583.08 0.72 1,591.11 MWD+IFR-AK-CAZ-SC(3) 5,014.21 44.06 15.72 4,387.71 4,298.41 2,061.89 436.15 5,947,614.95 317,602.45 0.14 1.639.15 MWD+IFR-AK-CAZ-SC(3) j 5,108.36 44.13 15.55 4,455.32 4,366.02 2,124.98 453.81 5,947,677.59 317,621.63 0.15 1.687.34 MWD+IFR-AK-CAZ-SC(3) 5,202.77 43.97 16.76 4,523.18 4,433.88 2,188.03 472.07 5,947,740.17 317,641.42 0.91 1,735.23 MWD+IFR-AK-CAZ-SC(3) i 5,297.61 43.86 17.29 4,591.50 4,502.20 2,250.92 491.33 5,947,802.58 317,662.20 0.40 1,782.53 MWD+IFR-AK-CAZ-SC(3) I 5,390.16 43.92 17.20 4,658.20 4,568.90 2,312.20 510.35 5,947,863.37 317,682.70 009 1,828.49 MWD+IFR-AK-CAZ-SC(3) 5,484.40 43.85 18.62 4,726.12 4,636.82 2,374.36 530.44 5,947,925.02 317,704.29 1.05 1,874.76 MWD+IFR-AK-CAZ-SC(3) 5,578.93 43.78 17.62 4,794.33 4,705.03 2,436.56 550.79 5,947,986.71 317,726.15 0.74 1,920.94 MWD+IFR-AK-CAZ-SC(3) 5,672.88 43.88 16.95 4,862.11 4,772.81 2,498.68 570.13 5,948,048.34 317,746.98 0.51 1,967.51 MWD+IFR-AK-CAZ-SC(3) 5,767.60 43.82 16.29 4,930.42 4,841.12 2,561.56 $88.89 5,948,110.74 317,767.27 0.49 2,015.01 MWD+IFR-AK-CAZ-SC(3) i 5,860.78 44.12 14.50 4,997.48 4,908.18 2,623.93 606.06 5,948,172.67 317,785.95 1.37 2,062.79 MWD+IFR-AK-CAZ-SC(3) 5,955.84 44.15 15.06 5,065.71 4,976.41 2,687.93 622.95 5,948,236.24 317,804.38 0.41 2,112.15 MWD+IFR-AK-CAZ-SC(3) 6,050.53 44.00 16.68 5,133.74 5,044.44 2,751.28 640.96 - 5,948,299.13 317,823.93 1.20 2,160.42 MWD+IFR-AK-CAZ-SC(3) 6,144.65 44.10 17.25 5,201.39 5,112.09 2,813.88 660.06 5,948,361.24 317,844.53 0.43 2,207.52 MWD+IFR-AK-CAZ-SC 13) 6,238.22 44.00 16.92 5,268.64 5,179.34 2,876.06 679.17 5,948,422.94 317,665.15 0.27 2,254.25 MWD+IFR-AK-CAZ-SC (3) 6,332fi8 44.03 16.79 5,336.57 5,247.27 2,938.88 698.20 5,948,485.27 317,885.70 0.10 2,301.58 MWD+IFR-AK-CAZ-SC(3) 6,427.17 44,00 15.82 5,404.52 5,315.22 3,001.89 716.63 5,948,547.81 317,905.65 0.71 2,349.36 MWD+IFR-AK-CAZ-SC (3) 6,520.83 44.12 16.07 5,471.83 5,382.53 3,064.52 734.53 5,948,609.96 317,925.06 0.23 2,397.04 MWD+IFR-AK-CAZ-SC (3) 6,616.32 44.12 16.57 5,540.38 5,451.08 3,128.32 753.21 5,948,673.30 317,945.28 0.36 2,445.40 MWD+IFR-AK-CAZ-SC(3) 6,710.63 44.07 16.76 5,608.11 5,518.81 3,191.19 772.03 5,948.735,69 317,965.62 0.15 2,492.87 MWD+IFR-AK-CAZ-SC(3) 6,805.30 44.09 17.15 5,676.12 5,586.82 3,254.18 791.23 5,948,798.20 317,986.35 0.29 2,540.28 MWD+IFR-AK-CAZ-SC(3) 6,899.19 44.13 17.44 5,743.53 5,654.23 3,316.58 810.66 5,948,860.10 318,007.29 0.22 2,587.06 MWD+IFR-AK-CAZ-SC(3) 6,993.93 44.13 18.29 5,811.53 5,722.23 3,379.36 830.90 5,948,922.37 318,029.04 0.62 2,633.81 MWD+IFR-AK-CAZ-SC(3) 7,086.63 43.84 18.22 5,878.23 5,788.93 3,440.50 851.06 5,948,983.00 318,050.68 0.32 2,679.13 MWD+IFR-AK-CAZ-SC(3) 7,181.62 43.79 17.84 5,946.78 5,857.48 3,503.03 871.42 5,949,045.02 318,072.55 028 2,725.61 MWD+IFR-AK-CAZ-SC(3) 7,276.21 43.92 17.76 6,014.99 5,925.69 3,565.43 891.45 5,949,106.90 318,094.09 0.15 2772.11 MWD+IFR-AK-CAZ-SC 13) 7,369.73 43.94 18.40 6,082.34 5,993.04 3,627.11 911.59 5,949,168.07 318,115.72 0.48 2,817.93 MWD+IFR-AK-CAZ-SC(3) 318/2019 11: 12:45AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips0 NES ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS - Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: .Plan MT6-02 @ 89.30usft (Doyon19 Planned) Site: GMT7 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02 Database: EDT 14 Alaska Production Survey Map Map Vertical # MD Inc An TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I P) (usft) (usft) (usft) (usft) (-/100') Survey Tool Name Annotation (ft) (ft) (ft) 7,464.13 43.89 19.55 6,150.34 6,061.04 3,689.02 932.87 5,949,229.45 318,138.50 0.85 2,863.43 MWD+IFR-AK-CAZ-SC(3) 7,558.79 43.83 20.01 6,218.60 6,129.30 3,750.74 955.07 5,949,290.61 318,162.19 0.34 2,908.34 MWD+IFR-AK-CAZ-SC(3) 7,653.28 43.87 20.26 6,286.74 6,197.44 3,812.20 977.60 5,949,351.50 318,186.21 0.19 2,952.88 MWD+IFR-AK-CAZ-SC(3) y 7,746.53 43.88 20.23 6,353.96 6,264.66 3,872.84 999.97 5,949,411.57 318,210.04 0.02 2,996.75 MWD+IFR-AK-CAZ-SC(3) 7,840.88 43.84 20.35 6,421.99 6,33269 3,934.16 1,022.64 5,949,472.32 318,234.19 0.10 3,041.09 MWD+IFR-AK-CAZ-SC(3) f 7,935.38 44.00 19.97 6,490.06 6,400.76 3,99569 1,045.23 5,949,533.28 318,258.26 0.33 3.085.66 MWD+IFR-AK-CAZ-SC(3) 8,028.45 43.94 18.58 6,557.04 6,467.74 4,056.69 1,066.56 5,949,593.73 318,281.07 1.04 3,130.33 MWD+IFR-AK-CAZ-SC(3) 8,123.31 43.89 18.35 6,625.37 6,536.07 4,119.09 1,087.40 5,949,655.61 318,303,41 0.18 3,176.47 MWD+IFR-AK-CAZ-SC(3) 8,217.17 43.83 18.57 6,693.05 6,603.75 4,180.78 1,107.99 5,949,716.78 318,325.50 0.17 3,222.09 MWD+IFR-AK-CAZ-SC(3) 8,310.61 43.86 19.02 6,76044 6,671.14 4,242.06 1,128.84 5,949,777.52 318,347.83 0.34 3,267.21 MWD+IFR-AK-CAZ-SC(3) i 8,406.26 43.94 21.32 6,829.37 6,740.07 4,304.30 1,151.71 5,949,839.19 318,372.20 1.67 3,312.30 MWD+IFR-AK-CAZ-SC(3) 8,500.94 43.81 21.55 6,897.62 6,808.32 4,365.39 1,175.69 5,949,899.67 318.397.66 0.22 3,355.83 MWD+IFR-AK-CAZ-SC(3) 8,596.94 44.20 19.92 6.966.67 6,877.37 4,427.76 1,199.30 5,949,961.45 318,422.77 1.25 3,400.69 MWD+IFR-AK-CAZ-SC(3) 8,688.99 44.53 18.29 7,032.48 6.943.18 4,488.57 1,220.36 5,950,021.73 318,445.30 1.29 3,445.31 MWD+IFR-AK-CAZ-SC(3) 8,783.86 45.97 16.41 7,099.27 7,009.97 4,552.88 1,240.44 5,950,085.53 318,466.93 2.07 3,493.50 MWD+IFR-AK-CAZ-SC(3) 8,877.88 47.64 15.00 7,163.62 7,074.32 4,618.86 1,258.98 5,950,151.03 318,487.07 2.09 3,543.87 MWD+IFR-AK-CAZSC(3) 8,972.41 49.37 14.85 7,226.25 7,136.95 4,687.27 1,277.21 5,950,218.98 318,506.96 1.83 3,596.55 MWD+IFR-AK-CAZSC(3) 9,065.23 49.90 15.38 7,286.37 7,197.07 4,755.55 1,295.66 5,950,286.78 318,527.05 0.72 3,649.01 MWD+IFR-AK-CAZSC(4) 9,159.15 52.92 13.12 7,344.95 7,255.65 4,826.69 1,313.69 5,950,357.46 318,546.81 3.72 3,704.21 MWD+IFR-AK-CAZSC(4) } EI 9,253+69 55.25 10.34 7,400.41 7,311.11 4,901.65 1,329.23_ 5,950.432.01 318,564.16 3.43 3,763.94 MWD+IFR-AK-CAZSC(4) 9,348.30 56.88 7.02 7,453.23 7,363.93 4,979.23 1,341.05 5,950,509.28 318.577.86 3.38 3,827.70 MWD+IFR-AK-CAZ-SC (4) % 9,443.38 59.02 5.83 7,503.69 7,414.39 5,059.30 1,350.06 5,950,589.11 318,588.81 2.49 3,894.96 MWD+IFR-AK-CAZ-SC (4) 9,537.37 61.14 4.36 7,550.57 7,461.27 5,140.44 1,357.28 5,950,670.04 318,598.00 2.63 3,963.97 MWD+IFR-AK-CAZ-SC(4) 9,631.10 63.33 3.29 7,594.23 7,504.93 5,223.18 1,362.60 5.950.752a2 318,605.53 2.55 4,035.19 MWD+IFR-AK-CAZ-SC (4) 9,725.90 65.54 0.81 7,635.14 7,545.84 5,308.63 1,365.85 5,950,837.97 318,610.64 3.32 4,109.95 MWD+IFR-AK-CAZ-SC(4) 9,821.37 67.61 359.04 7,673.09 7,583.79 5,396.23 1,365.72 5,950,925.53 318.612.64 216 4,188.05 MWD+IFR-AK-CAZ-SC(4) 9,914.50 69.73 358.32 7,706.97 7.617.67 5,482.95 1,363.72 5,951,012.27 318,612.75 2.39 4,266.23 MWD+IFR-AK-CAZ-SC(4) 10,008.82 71.79 356.34 7,738.05 7,648.75 5,571.89 1,359.56 5,951,101.29 318,610+75 2.95 4,347.37 MWD+IFR-AK-CAZ-SC(4) 10,103.47 73.32 356.60 7,766.42 7677.12 5,662.02 1,354.00 5,951,191.51 318,607.38 1.64 4,430.19 MWD+IFR-AK-CAZ-SC(4) 10 19740 7548 355.59 7,791.68 7,702.38 5,752.27 1,347.84 5,951,281.88 318,603.41 2.52 4,513.40 MWD+IFR-AK-CAZ-SC (4) 10 291 63 7747 354.82 7,81372 7]24.42 5,843.56 1,340.18 5,951,373.32 318,597.97 2.26 4,598.22 MWD+IFR-AK-CAZ-SC (4) 3/8/2019 11: 12:45AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips eA ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT7 Lookout Pad Well: MT6-02 Wellbore: MT6-02 Design: MT6-02 Survey Local Coordinale Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Plan MT6-02 @ 89.30usft (Doyonl9 Planned) True Minimum Curvature EDT 14 Alaska Production Annotation 3WO19 11:12:45AM Page 7 COMPASS 5000.14 Build 85D Map Map MD Inc Azi TVD NDSS +N/ -S +E1 -W Northing Easting DLSVertical Section (usff) (°) (°) (usff) (usff) (usff) (usff) ('A00') Survey Tool Name (ft) (ft) (ft) 10,385.11 79.81 354.11 7,832.13 7,742.83 5,934.77 1,331.34 5,951,464.72 318,591.35 261 4,683.51 MWD+IFR-AK-CAZ-SC(4) 10,480.02 81.93 353.50 7,847.19 7,757.89 6,027.93 1,321.22 5,951,558.09 318,583.50 2.32 4,771.10 MWD+IFR-AK-CAZ-SC(4) I 10,573.01 83.85 352.94 7,858.70 7,76940 6,119.55 1,310.33 5,951,649.94 318,574.83 2.15 4,857.68 MWD+IFR-AK-CAZ-SC(4) 9 10,666.87 84.92 351.47 7,867.88 7,778.58 6,212.10 1,297.66 5,951,742.76 318,564,41 1.93 4,945.89 MWD+IFR-AK-CAZ-SC(4) 10,765.69 85.04 350.80 7,876.53 7,787.23 6.309.36 1,28249 5,951,840.36 318.551.61 0.69 5,039.44 MWD+IFR-AK-CAZ-SC(4) 10,854.61 84.92 350.16 7.884.33 7,795.03 6,396.91 126].81 5,951,928.24 318,539.06 0.73 5,124.12 MWD+IFR-AK-CAZ-SC(4) i 10,949.60 84.89 349.50 7,892.75 7,803.45 6A89.85 1,251.13 5,952,021.54 318.524.65 0.69 5,214.49 MWD+IFR-AK-CAZ-SC(4) Bi 11,044.11 84.76 348.97 7,901.27 7,8%97 6,582.31 1,233.55 5,952,114.40 318,509.32 0.58 5,304.86 MWD+IFR-AK-CAZ-SC(4) 11,105.67 84.76 348.46 7,906.89 7,817.59 6.642.43 1,221.56 5,952,174.79 318,498.79 0.82 5,363.87 MWD+IFR-AK-CAZ-SC(4) 11,152.00 85.28 348.18 7,910.92 7,821.62 6,687.63 1,212.21 5,952,220.20 318,490.55 1.27 5,408.39 MWD+IFR-AK-CAZ-SC(5) 9 11,247.24 86.91 348.08 7,917.40 7,828.10 6,780.61 1,192.67 5,952,313.63 318,473.27 1.71 5,500.11 MWD+IFR-AK-CAZ-SC(5) 11,342.17 86.93 348.52 7,922.50 7,833.20 6,873.44 1,173.45 5,952,406.88 318,456.30 046 5,591.54 MWD+IFR-AK-CAZ-SC(5) 11,437.25 88.45 348.60 7,926.34 7,837.04 6,966.55 1,154.60 5,952,500.42 318,439.73 1.60 5,683.06 MWD+IFR-AK-CAZ-SC(5) I 11,531.99 88.69 347.48 7,928.70 7,839.40 7,059.20 1,134.98 5,952,593.52 318,422.36 121 5,774.53 MWD+IFR-AK-CAZ-SC(5) 11,627.61 88.97 346.15 7,930.65 7,841.35 7,152.28 1,113.17 5,952,687.09 318,402.82 142 5,867.36 MWD+IFR-AK-CAZ-SC(5) 11,723.09 89.12 345.92 7,932.24 7,842.94 7,244.93 1,090.13 5,952,780.26 318,382.04 029 5,960.37 MWD+IFR-AK-CAZ-SC(5) 11,817.61 92.17 346.36 7,931.18 7,841.88 7,33&68 1,067.50 5,952,872.53 318,361.64 3.26 6,052.39 MWD+IFR-AK-CAZ-SC(5) 11,912.78 91.97 344.94 7,927.74 7,838.44 7,428.81 1,043.92 5,952,965.21 318,340.31 1.51 6,145.19 MWD+IFR-AK-CAZ-SC(5) 12,008.58 93.00 341.95 7,923.59 7,834.29 7,520.55 1,016.66 5,953,057.57 318,315.28 3.30 6,239.30 MWD+IFR-AK-CAZ-SC(5) 12,103.24 93.08 339.47 7,918.57 7,829.27 7,609.76 985.43 5,953,147.51 318,286.23 2.62 6,332.97 MWD+IFR-AK-CAZ-SC(5) 12,198.25 91.20 335.51 7,915.02 7,825.72 7,697.45 949.09 5,953,236.05 318,252.03 4.61 6,427.60 MWD+IFR-AK-CAZ-SC(5) 12,293.25 90.93 331.32 7,913.25 7,823.95 7,782.37 906.59 5,953,321.97 318,211.61 4.42 6,522.56 MWDAFR-AK-CAZ-SC(5) I 12,387.89 91.33 326.63 7,911.38 7,822.08 7,863.43 857.84 5,953,404.19 318,164.84 4.97 6,616.92 MWD+IFR-AK-CAZ-SC(5) 12,483.00 91.79 325.18 7,908.79 7,819.49 7,942.16 804.54_ 5,953,484.18 318,113.48 1.60 6,711.26 MWD+IFR-AK-CAZ-SC(5) 12,578.56 91.36 325.59 7,906.17 7,816.87 8,020.78 750.28 5,953,564.09 318,061.14 0.62 6,805.94 MWD+IFR-AK-CAZ-SC(5) 12,673.45 91.64 325.86 7,903.68 7,814.38 8,099.16 696.86 5,953,643.74 318,009.65 0.41 6,900.04 MWD+IFR-AK-CAZ-SC(5) !� 12,767.80 91.39 326.48 7,901.19 7,811.89 8,177.51 644.35 5,953,723.34 317,959.06 0.71 6,993.68 MWD+IFR-AK-CAZ-SC(5) g 12,863.24 91.45 326.40 7,898.82 7,809.52 8,257.02 591.61 5,953,804.09 317,908.26 0.10 7,088.47 MWD+IFR-AK-CAZ-SC(5) 12,957.50 90.28 326.02 7,897.40 7,808.10 8,335.34 539.19 5,953,883.67 317,857.77 1.31 7,182.06 MWD+IFR-AK-CAZ-SC(5) i 13,052.74 90.28 325.59 7,896.94 7,807.64 8,414.12 485fi7 5,953,963.71 317,806.17 0.45 7,276.55 MWD+IFR-AK-CAZ-SC(5) 13,149.0] 90.44 324.75 ],896.33 7,807.03 8,093.19 43065 5,959,044.09 317,753.10 0.89 7,371.97 MWD+IFR-AK-CAZ-SC (5) Annotation 3WO19 11:12:45AM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips BA ER f�UGHFS ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc_WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-02 Wellbore: MT6-02 Design: MT6-02 Survey Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyon19 Planned) Plan MT6-02 @ 89.30usft (Doyon19 Planned) True Minimum Curvature EDT 14 Alaska Production 31WO19 11: 12:45AM Page 8 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi ND 7VDSS +N/ -S +E1_yy Northing Easting DLS Section (usft) (`) (,1 (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 13,243.32 90.41 326.07 7,895.63 7,806.33 8,570.77 377.15 5,954,122.95 317,701.50 1.40 7,465.39 MWD+IFR-AK-CAZ-SC (5) i 13,340.00 92.20 326.15 7,893.43 7,809.13 8,651.00 323.25 5,954,204.46 317,649.57 1.85 7,561,35 MWD+IFR-AK-CAZ-SC (5) i 13,435,31 92.13 326.28 7,889.83 7,800.53 8,730.16 270.29 5,954,284,87 317,598.55 0.15 7,655,92 MWD+IFR-AK-CAZ-SC (5) 13,530.63 92.06 326.90 7,886.34 7,797.04 8,809.68 217.84 _ 5.954.365,63 317,548.05 0.65 7,750.58 MWD+IFR-AK-CAZ-SC (5) 13,625.50 90.34 324.44 7,884.36 7,795.06 8,888.00 164.36 5,954,445.22 317,496.48 3.16 7,844,65 MWD+IFR-AK-CAZ-SC (5) 13,720.84 88.81 322,87 7,885.06 7,795.76 8,964.78 107.86 5,954,523.35 317,441.87 2.30 7,938,71 MWD+IFR-AK-CAZ-SC (5) 13,816.04 87.98 322.17 7,887.73 7,798.43 9,040.30 49,96 5,954,600.25 317,385.82 1.14 8,032.29 MWD+IFR-AK-CAZ-SC (5) 13,911.91 88.04 324,19 7,891.06 7,801.76 9.116.99 -7.46 5,954,678,31 317,330.29 2.11 8,126,69 MWD+IFR-AK-CAZ-SC (5) 14,006.90 87.86 325.16 7,894.46 7,805.16 9,194.44 -62.35 5,954,757.07 317,277.30 1.04 8,220.62 MWD+IFR-AK-CAZ-SC(5) 14,101.87 88.10 325.53 7,897.81 7,808.51 9,272.52 -116.32 5.954,836.42 317,225.24 0.46 8,314.68 MWD+IFR-AK-CAZ-SC (5) 14,197,19 88.32 325.46 7,900.78 7,811.48 9,351.03 -170.29 5,954,916.22 317,173.20 0.24 8,409.14 MWD+IFR-AK-CAZ-SC(5) 14,292.38 91.55 325.93 7,900.89 7,811.59 9,429.65 -223.93 5,954,996.11 317,121.48 3.43 8,503.54 MWD+IFR-AK-CAZ-SC(5) 14,387.09 91.70 326.19 7,898.21 7,808.91 9,508.19 -276.79 5,955,075.91 317,070.55 0.32 8,597.52 MWD+IFR-AK-CAZ-SC(5) 14,482.70 90.93 326.27 7,896.01 7,806.71 9,587.65 -329.92 5,955,156.63 317,019.37 0.81 8,692.4 MWD+IFR-AK-CAZ-SC(5) 14,577.76 90.44 324.60 7,894.88 7,805.58 9,665.92 -383.85 5,955,236.18 316,967.36 1.83 8,786.66 MWD+IFR-AK-CAZ-SC(5) 14,672,76 90.72 326.07 7,893.91 7,804.61 9,744.05 -437.88 5,955,315.59 316,915.25 1.58 8,880.81 MWD+IFR-AK-CAZ-SC(5) 14,767.73 90.37 326.36 7,893.01 7,803.71 9,822.98 -490.68 5,955,395.78 316.864.38 0.48 8,975.11 MWD+IFR-AK-CAZ-SC(5) 14,863.41 88.65 327.41 7,893.83 7,804.53 9,903.11 -542.95 5,955,477.15 316,814.07 2.11 9,070.23 MWD+IFR-AK-CAZ-SC(5) 14,958.83 88.44 327.77 7,896.25 7,806.95 9,983.64 -594.08 5,955,558.89 316,764.92 0.44 9,165.20 MWD+IFR-AK-CAZ-SC(5) 15,054.09 86.50 329.04 7,900.46 7,811.16 10,064.70 -643.93 5,955,641.13 316,717.05 2.43 9,260.05 MWD+IFR-AK-CAZ-SC(5) 15,148.77 88.57 329.61 7,904.53 7,815.23 10,146.05 .692.19 5,955,723.62 316,670.79 2.27 9,354.4 MWD+IFR-AK-CAZ-SC(5) 15,244.99 87.76 329.06 7.907.61 7,818.31 10,228.77 -741.24 5,955,807.51 316,623.77 1.02 9,450.42 MWD+IFR-AK-CAZ-SC(5) 15,339.80 87.46 328.78 7,911.56 7,822.26 10,309.90 -790.14 5,955,889.79 316,576.85 0.43 9,544.90 MWD+IFR-AK-CAZ-SC(5) 15,434,28 87.64 329.40 7,915.60 7,826.30 10,390.89 -838.63 5,955,971.93 316,530.35 0.68 9,639.08 MWD+IFR-AK-CAZ-SC(5) 15,529.73 88.67 331.59 7,918.68 7,829.38 10,473.91 -885.61 5.956.056.06 316,485.40 2.53 9,734.38 MWD+IFR-AK-CAZ-SC 15) 15,624.25 88.35 332.96 7,921.13 7,831.83 10,557.55 -929.57 5,956,140.74 316,443.49 1.49 9,828,86 MWD+IFR-AK-CAZ-SC (5) 15,719.44 86.96 333.62 7,925.03 7,835.73 10,642.51 -972.31 5,956,226.70 316,402.82 1.62 9,923,96 MWD+IFR-AK-CAZ-SC(5) 15,814.75 87.18 333.93 7,929.90 7,84060 10,727.89 -1,014.38 - 5,956,313.08 316,362.84 0.40 10,019.14 MWD+IFR-AK-CAZ-SC(5) 15,909.22 87.58 333.90 7,934.22 7,844,92 10,812.65 -1,055.87 5,956,398.82 316,323.42 0.42 10,113.50 MWD+IFR-AK-CAZ-SC(5) 16,005.17 89.89 334.03 7,936.34 7,847.04 10,898.84 -1,097.97 5,956,486.00 316,283,43 2.41 10,209.41 MWD+IFR-AK-CAZ-SC(5) 16,099.89 90.13 334.12 7,936.32 TUTU 10,984.03 -1,139.38 5,956,572.16 316,244.10 0.27 10,304.11 MWD+IFR-AK-CAZ-SC(5) 31WO19 11: 12:45AM Page 8 COMPASS 5000.14 Build 85D ConocoPhillipst1GNFS „w,,. ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Local Coordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MTB -02 @ 89.30usft (Doyonl9 Planned) Site: GMTt Lookout Pad MD Reference: Plan MT6-02 Q 89.30usft (Doyonl9 Planned) well MT6-02 North Reference: True , Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NAS +E/ -W Northing Easting DLS Section Survey Tool Name Annotation (usk) (°) (°) (usk) (usk) (usk) (usk) (k) (k) (°/100') (ft) 16,195.72 90.16 333.38 7,936.08 7,846.78 11.069.97 -1,181.77 5,956,659.10 316,203.82 0.77 10,399.93 MWD+IFR-AK-CAZ-SC(5) 16,290.88 89.58 333.10 7,936.29 7,846.99 11,154.94 -1,224.61 5,956,745.08 316,163.05 0.68 10,495.09 MWD+IFR-AK-CAZ-SC(5) Y 16,386.00 88.72 332.73 7,937.70 7,848.40 11,23962 -1,267.92 5,956,630.78 316,121.82 098 10,590.20 MWD+IFR-AK-CAZ-SC(5) f 16,481.26 87.43 331.26 7,940.90 7,851.60 11,323.67 .1,312.62 5,956,915.89 316,079.17 2.05 10,685.38 MWD+IFR.AK-CAZ.SC(5) I 16,575.25 88.73 332.03 7,944.05 7,854.75 11,406.34 -1,357.23 5,956,999.61 316,036.58 1.61 10,779.29 MWD+IFR-AK-CAZ.SC(5) 16,671.91 90.88 331.94 7,944.38 7,855.08 11,491.67 -1,402.63 5,957,086.01 315,993.27 2.23 10,875.93 MWD+IFR-AK-CAZ-SC(5) 16,766.63 90.62 330.82 7,943.14 7,853.84 11,574.80 -1,448.00 5,957,170.22 315,949.94 1.21 10,970.60 MWD+IFR-AK-CAZ.SC(5) 16,862.52 91.18 332.27 7,941.64 7,852.34 11,659.10 -1,493.68 - 5,957,255.59 315,906.32 1.62 11,066.45 MWD+IFR-AK-CAZ-SC(5) 16,956.79 90.53 331.78 7,940.23 7,850.93 11,742.34 -1,537.89 5,957,339.88 315,864.14 0.86 11,160.69 MWD+IFR-AK-CAZ.SC(5) 17,051.48 89.85 330.28 7,939.92 7,850.62 11,825.18 -1,583.76 5,957,423.80 315,820.31 1.74 11,255.32 MWD+IFR-AK-CAZ.SC(5) 17,148.18 86.34 331.11 7,943.13 7,853.83 11,909.44 -1,631.05 5,957,509.18 315,775.07 3.73 11,351.88 MWD+IFR-AK-CAZ-SC (5) 17,243.19 85.18 332.26 7,950.15 7,860.85 11,992.85 -1,675.99 5,957,593.66 315,732.17 1.72 11,446.60 MWD+IFR-AK-CAZ-SC (5) 17,338.62 86.26 332.68 7,957.28 7,867.98 12,077.24 .1,719.98 5,957,679.08 315,690.25 1.21 11,541.76 MWD+IFR-AK-CAZ-SC (5) 17,434.05 88.42 333.80 7,961.70 7,872.40 12,162.35 -1,762.90 5,957,765.20 315,849.42 2.55 11,637.07 MWD+IFR-AK-CAZ-SC(5) e 17,529.25 89.43 334.19 7,963.49 7,874.19 12,247.90 .1,804.63 5,957,851.73 315,609.78 1.14 11,732.24 MWD+IFR-AK-CAZ-SC (5) 17,624.79 90.23 334.48 7,963.77 7,874.47 12,334.01 -1,846.01 5,957,938.82 315,570.50 0.89 11,827.75 MWD+IFR.AK-CAZ-SC(5) 17,720.08 90.22 334.29 7,963.40 7,874.10 12,419.94 -1,887.20 5,958,025.71 315,531.41 0.20 11,923.02 MWD+IFR.AK-CAZ-SC(5) 17,814.93 91.18 334.47 7,962.24 7,872.94 12,505.45 -1,928.21 5,958,112.19 315,492.49 1.03 12,017.83 MWD+IFR.AK-CAZ-SC(5) 17,910.54 91.55 333.81 7,959.96 7,870.66 12,591.46 .1,969.90 5,958,199.19 315,452.90 0.79 12,113.39 MWD+IFR-AK-CAZ-SC(5) 18,005.28 90.71 334.15 7,958.10 7,868.80 12.676.58 -2,011.46 5,958,285.29 315,413.43 0.96 12,208.10 MWD+IFR-AK-CAZ-SC(5) 18,101.15 90.50 334.00 7,957.08 7,867.78 12,762.80 -2,053.37 5,958,372.49 315,373.63 0.27 12,303.95 MWD+IFR.AK-CAZ-SC(5) 18,196.61 92.63 333.99 7,954.48 7,865.18 12,848.56 .2,095.20 5,958,459.23 315,333.89 2.23 12,399.35 MWD+IFR-AK-CAZ-SC(5) 4 18,291.49 92.68 332.49 7,950.08 7,860.78 12,933.18 -2,137.88 5,958,544.86 315,293.29 1.58 12,494.13 MWD+IFR.AK-CAZ.SC(5) 18,386.11 92.99 330.95 7,945.40 7,856.10 13,016.41 -2,182.65 5,958,629.14 315250.55 1.66 12,588.60 MWD+IFR-AK-CAZ-SC (5) 18,482.34 93.98 330.72 7,939.55 7,850.25 13,100.28 -2,229.46 5,958,714.12 315,205.80 1.06 12,684.59 MWD+IFR.AK-CAZ.SC(5) 18,576.39 93.94 330.30 7,933.06 7,843.76 13,181.95 -2,27564 5,958,796.88 315.161.61 0.45 12,778.32 MWD+IFR-AK-CAZ-SC(5) 18,672.04 93.88 329.94 7,926.53 7,837.23 13,264.69 -2,323.18 5,958,880.75 315,116.09 0.38 12,873.63 MWD+IFR-AK-CAZ.SC(5) 18,767.52 94.50 330.45 7,919.56 7,830.26 13,347.32 -2,370.52 5,958,964.50 315,070.78 0.84 12,968.74 MWD+IFR-AK-CAZ-SC(5) 18,862.94 94.65 331.69 7,911.95 7,822.65 13,430.56 -2,416.53 5,959,048.83 315,026.81 1.30 13,063.80 MWD+IFR-AK-CAZSC(5) 18,957.60 93.57 332.19 7,905.16 7,815.86 13,513.88 -2,460.94 5,959,133.20 314,984.44 1.26 13,158.20 MWD+IFR-AK-CAZSC(5) 19,053.43 90.61 332.20 7,901.67 7,812.37 13,598.58 -2,505.61 5,959,218.95 314,941.84 3.09 13,253.95 MWD+IFR-AK-CAZ-SC (5) 3/8/2019 11:12:45AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report BA ER l UGHFS Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope ND Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MTB -02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02 Database: EDT 14 Alaska Production Survey (ft) (ft) (°/100') MD (usft) 19,149.04 19,244.17 19,339.39 19,435.70 19,531.97 19,627.31 19,721.74 19,817.68 19,911.67 20,008.04 20,103.30 20,198.59 20,292.91 20,389.06 20,483.59 20,578.78 20.673.98 20,769.20 20,864.45 20,960.46 21,055.82 21,150.83 21,245.80 21,341.76 21,437.06 Inc 90.37 89.61 88.53 88.75 91.71 93.12 95.15 94.38 91.50 91.54 91.63 91.33 92.47 92.93 92.06 91.51 91.45 89.11 89.24 91.12 90.47 90.53 90.47 89.64 90.29 21,532.64 91.95 21,626.88 91.54 21,722.53 90.38 21,818.17 89.18 21,913.31 89.55 22,008.72 92.01 3/8/2019 11: 12: 45AM Page 10 COMPASS 5000.14 Build 85D Map Map Vertical Azi ND NOSS +N/ -S +E/ -W Northing Easting DLS Section Survey Tool Name Annotation (°) (usft) (usk) (usk) (usk) (ft) (ft) (°/100') (ft) 332.54 7.901.10 7,811.80 13,683.29 -2,549.94 5,959,304.70 314,899.58 067 13,349.55 MWD+IFR-AK-CAZ-SC(5) 333.25 7,901.37 7,812.07 13,767.97 -2,593.29 5,959,390.41 314,858.31 0.89 13,444.68 MWD+IFR-AK-CAZ-SC(5) 334.97 7,902.91 7,813.61 13,853.61 -2,634.86 5,959,477.03 314,818.83 2.13 13,539.86 MWD+IFR-AK-CAZ-SC(5) 338.60 7,905.20 7,815.90 13,942.09 -2,672.80 5,959,566.39 314,783.05 3.77 13,635.92 MWD+IFR-AK-CAZ-SC(5) 341.29 7,904.81 7,815.51 14,032.50 -2,705.81 5,959,657.58 314,752.25 4.15 13,731.46 MWD+IFR-AK-CAZ-SC(5) 342.98 7,900.79 7,811.49 14,123.16 -2,735.03 5,959,748.91 314,725.24 2.31 13,825.50 MWD+IFR-AK-CAZ-SC(5) 343.62 7,893.98 7,804.68 14,213.36 -2,762.09 5,959,839.74 314,700.37 2.25 13.918.16 MWD+IFR-AK-CAZ-SC(5) 342.04 7,886.01 7,796.71 14,304.71 -2,790.32 5,959,931.74 314,674.38 1.83 14,012.36 MWD+IFR-AK-CAZ-SC(5) 343.72 7,881.19 7,791.89 14,394.40 -2,817.94 5,960,022.07 314,648.94 3.55 14,104.83 MWD+IFR-AK-CAZ-SC(5) 344.23 7,878.64 7,789.34 14,486.99 -2,844.54 5,960,115.28 314,62460 0.53 14,199.40 MWD+IFR-AK-CAZ-SC(5) 343.06 7,876.00 7,786.70 14,578.36 -2,871.35 5,960,207.26 314,600.02 1.23 14,292.98 MWD+IFR-AK-CAZ-SC(5) 343.42 7,873.54 7,784.24 14,669.57 -2,898.82- 5,960,299.11 314,574.77 0.49 14,386.72 MWD+IFR-AK-CAZ-SC(5) 344.23 7,870.41 7,781.11 14,760.11 -2,925.08 5,960,390.25 314,550.72 1.48 14,479.31 MWD+IFR-AK-CAZ-SC (5) 345.42 7,865.89 7,776.59 14,852.80 -2,950.22 5,960,483.52 314,527.84 1.33 14,573.31 MWD+IFR-AK-CAZ-SC (5) 347.10 7,861.77 7,772.47 14,944.53 -2,972.65 5,960,575.76 314.507.64 2.00 14,665.23 MWD+IFR-AK-CA7-SC (5) 344.43 7,858.80 7,769.50 15,036.75 -2,996.05 5,960,668.51 314,486.50 2.86 14,758.02 MWD+IFR-AK-CAZ-SC (5) 341.88 7,856.34 7,767.04 15,127.82 -3,023.62 5,960,760.23 314,461.14 2.68 14,851.69 MWD+IFR-AK-CAZ-SC (5) 338.94 7,855.88 7,766.58 15,217.52 -3,055.54 5,960,850.66 314,431.41 3.95 14,946.09 MWD+IFR-AK-CAZ-SC (5) 338.66 7,857.25 7,767.95 15,306.31 -3,089.98 5,960,940.26 314,399.14 0.32 15,040.85 MWD+IFR-AK-CAZ-SC (5) 338.92 7,856.95 7,767.65 15,395.81 -3,124.72 5,961,030.57 314,366.59 1.98 15,136.36 MWD+IFR-AK-CAZ-SC (5) 338.09 7,855.63 7,766.33 15,484.53 -3,159.65 5,961,120.11 314,333.82 1.11 15,231.27 MWD+IFR-AK-CAZ-SC(5) 337.40 7,854.80 7,765.50 15,572.46 -3,195.64 5,961,208.88 314,299.98 0.73 15,325.95 MWD+IFR-AK-CAZ-SC(5) 337.05 7,853.97 7,764.67 15,660.02 -3,232.40 5,961,297.30 314,265.36 0.37 15,420.66 MWD+IFR-AK-CAZ-SC(5) 336.56 7,853.88 7,764.58 15,748.22 -3,270.19 5,961,386.39 314,229.72 1.00 15,516.41 MWD+IFR-AK-CAZ-SC(5) 336.38 7,853.93 7,764.63 15,835.60 -3,308.24 5,961,474.66 314,193.81 0.71 15,611.53 MWD+IFR-AK-CAZ-SC(5) 336.24 7,852.07 7,762.77 15,923.10 -3,346.63 5,961,563.06 314,157.55 1.74 15,706.93 MWD+IFR-AK-CAZ-SC(5) 336.06 7,849.20 7,759.90 16,009.26 -3,384.72 5,961,650.11 314,121.57 0.48 15,800.98 MWD+IFR-AK-CAZ-SC(5) 334.90 7,847.59 7,758.29 16,096.27 -3,424.41 5,961,738.05 314,084.01 1.71 15,896.53 MWD+IFR-AK-CAZ-SC(5) 334.71 7,847.96 7,758.66 16,182.80 -3,465.12 5,961,825.55 314,045.41 1.27 15,992.12 MWD+IFR-AK-CAZ-SC(5) 335.54 7,849.02 7,759.72 16269.11 -3,505.14 5,961,912.80 314,007.50 0.96 16,087.18 MWD+IFR-AK-CAZ-SC(5) 336.90 7,847.72 7,758.42 16,35640 -3.54360 5,962,000.99 313.971.17 2.95 16.182.43 MWD+1FR-AK-CAZ-SC(5) 3/8/2019 11: 12: 45AM Page 10 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips Alaska lnc_WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-02 Wellbore: MTS -02 Design: MT6-02 Survey MD Inc Azi (usft) (°I (°) 22,103.77 94.50 337.32 22,198.77 93.08 336.42 22,228.00 9308 336.42 ConocoPhillips Definitive Survey Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyon19 Planned) Plan MT6-02 @ 89.30usft (Doyon 19 Planned) True Minimum Curvature EDT 14 Alaska Production 31WO19 11:12:45AM Page 11 COMPASS 5000.14 Build 65D Map Map Vertical ND NDSS +N/ -S +N/ -S +E/ -W Northing Easting DLS Section Survey Tool Name Annotation (us") (usftVDD (usR) (°/100 ) (ft) (ft) (ft) 7,842.32 7,753.02 16,443.82 -3,580.51 5,962,089.27 313,936.40 266 16,27707 MWD+IFR-AK-CAZ-SC(5) 7.83604 7,746.74 16,530.99 -3,617.75 5,962 177 32 313,901.29 1.77 16,37164 MWD+IFR-AK-CAZ-SC(5) 7834.47 7.745.17 16,557.74 -3,629.42 5,962,204.34 313,890.27 000 16,400.78 PROJECTED to TD 31WO19 11:12:45AM Page 11 COMPASS 5000.14 Build 65D 21 81 6() Originated: Schlumberger PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax WELL NAME .. # CD3 -123 50-103-20677-00 CD3 .198 50-103-20637-00 MT6-02 50.103-20792-00 ORDERSERVICE E540.00058 E540.00059 E57Z-00024 Delivered to: tea" AOGCC v ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision • 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 FIELDto NAME DESCRIPTIONDELIVERABLE DESCRIPTION COLVILLE RIVER WL Cutting COLVILLE RIVER WL Cutting Greater Mooses Tooth Memory C8L-SCMT DATA FINAL FIELD FINAL FIELD FINAL FIELD •• r, • r 31 -Jan -19 1 -Feb -19 10 -Feb -19 19 -Feb -19 t9Feb19-JW01 Prints CD -saw 1 1 1 3 A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The Print ame Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please retu is courier or sign/scan and email a copy o chlumberger and CPAL point. Weekly Progress Report for BLM p Text Area 2 Weekly Progress Report 2/4/19 Well: MT6-02 FINer Setllege Curve - Well Nem..(MT6-02) M DailyRep -asl24 - Well Name: (MT6-02) Weekly Progress Report for BLM Hole Depth vs. Day 0 2.000 4.000 6.000 8.000 10.000 L n d a 12.000 0 Z 14.000 16.000 16.000 20.000 22.000 Fitter Settings Cu'. - Well Name'. (MTF02) WV_DalNRem,r UsQ4 - Well Name'.(MT602) 0 5 10 15 20 25 30 35 40 45 Day Weekly Progress Report for BLM 4 columns from WV_ DailyReport_Last24 Report Start Report End Date Date General Remarks _ AM 12:OOAM power. 129201912:00 1 /302019 AM 12:OOAM 1=12019 12.00 1131/2019 AM 12:00AM 1/31201912:00 2/1201912:00 AM ALI 2/1201912:00 22201912:00 ALI AAI 22201912:00 2WO1912:OD AM AM 2131201912:00 2/4201912:00 Aht APA Fear evil Curve - Well Name: (MT6-02) WV_DailyReport last24 - Well Name,(MT"2) BOPETested 147-19. Rams functioned 1-27-19 No AIS. Rig and camp on highline power. ROPE Tested 1-17-19. Rams functioned 1-27-19 No AIS. Rig and camp on highline power. DOPE Tested 1-3419. No AIS. Rig and camp on highline power. ROPE Tested 1-3419. No AM Rig and camp on highline power. BOPE Tested 1-3419. No AIS. Rig and camp on highline power. ROPE Tested 1-3419. No AIS. Rig and camp on highline power BOPE Tested 1-3419. Last 24 Hour Summary on DP to 16.972'. RIH liner on DP washing 8 POOH to 1.2701. Cont. POOH 8 LID liner run Flush stack. Test BOPE. W 2.526 RIH f2.526'l0 10.982'. Slip to 11,735' Time drill & open hole side 11.361'. Backream OOH to shoe. DI 10.91T. Install RCD bearing. Distill, f/11.84T to 13.503' Loepp, Victoria T (DOA) From: Marushack, Andy J <Andy.J.Marushack@conocophillips.com> Sent: Monday, February 4, 2019 10:44 AM To: BLM_AK_AKSO_EnergySection_Notifications@blm.gov; Loepp, Victoria T (DOA) Subject: MT6-02 Update 2/4/19 Attachments: Weekly Progress Report for BLM.pptx Follow Up Flag: Follow up Flag Status: Flagged Hello, Over the weekend MT6-02 successfully time drilled and achieved separation from the first latera. Once drilling ahead, we lost communication with the tools and had to POOH to P/U a new BCPM and AziTrak. We are now back on bottom and drilling ahead. 0 2,000 4.000 6.000 8,000 10.000 L d d 12.000 d O 14.000 16.000 18.000 20,000 22.000 0 5 10 15 20 25 30 35 40 45 Day 1 Report Start Report End Date Date AM 12:00 AM 129201912:00 1/302019 AM 1200 AM 1/302019 12:00 11312019 AM 12:00 AM General Remarks power. BOPE Tested 1-17-19. Rams functioned 1-27-19 No AIS. Rig and camp on highline power. BOPE Tested 1-17-19. Rams functioned 1-27-19 No AIS. Rig and camp on highline power. ROPE Tested 1-30.19. 1/31201912:00 211201912:00 No AIS. Rig and camp on highline AM AM power. BOPE Tested 1-30-19. 2/12019 12:00 AM 22201912:00 AM 222019 12:00 No AIS. Rig and camp on highline AM power. BOPE Tested 1-30-19. 2(32019 12:00 AM 2!3201912:00 2/4201912:00 AM AM Sincerely, Andy No AIS. Rig and camp on highline power. BOPE Tested 1-30-19. No AIS. Rig and camp on highline power. BOPE Tested 1-30.19. 2 Last 24 Hour Summry on DP to 16,972'. RIH liner on DP washing & POOH to 1,270'. Cont. POOH & L/D liner run Flush stack. Test ROPE. M/ 2,526' RIH f2,526to 10,982'. Slip to 11,735' Time drill & open hole side 11,361'. Backream OOH to shoe. DI 10,91T. Install RCD bearing. Displa f/11,84T to 13,503' Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Monday, January 21, 2019 9:53 AM To: Mutasim Elganzoory; Loepp, Victoria T (DOA) Subject: Operations Update for MT6-02 Attachments: Well Weekly Progress Report01212019.pdf Follow Up Flag: Follow up Flag Status: Flagged Good morning, Attached is the operations update for MT6-02. Let me know if you have any questions. Thanks, Andrew (303)378-8881 Weekly Progress Report for BLM Weekly Progress Report 1/21/19 Well: MT6-02 Field: Lookout API: 5010320792 Hole Depth vs. Day Report Start Report End Date - Date General Remarks Last 24 HPur summry 1/11/2019 1/12/2019 No AIS, Rig and camp on highline annulate and condition mud, SOON to T' liner bp. Flow check well, Continue 900H to 0 12:00 AM 12:00 AM power, 5" drill pipe, Remove RW bearing and install top nipple. Continue POON and LID liner ROPE Tested l-3-19. Rams functioned running tools.P/U and run K-1 cement airy and UP packer hangerassV ale AN. 1/11/19 RIM Quinn Sawyer performed rig ... 2.000 1/12/2019 1/13/2019 No AIS, Rig and umpon highline Continue RIH with Wl cement Pr, and UPpcker assy. Circulate and drop 1.75" 12:00 AM 12:00AM power. bronco release ball, set cement seiner, Cement T' liner and set packer. Pull out UP ROPE Tested 1-3-39. Rams functioned packer and circulate. Few check and POOH LID 5- drill pipe. 1/11/19 4,000 BIM Quinn Sawyer Performed rig ... 1/13/2019 1/14/2019 No AIS, Rig and camp on highline PQOHL/135"drillpipe,rackback4"drill pipe and L/D running tools. Tent T' liner and 12:00 AM 12:OOAM power packer to IWO psi 10min.P/U and run 7 b back string. ROPE Tested 1-3-19. Rams functioned 6,000 1/11/19 RLM Quinn Sawyer performed rig ... 1/14/2019 1/15/2019 No AIS, Rg and came con hghlble Continue run 7" fie back string, space out and dirpixe annulus to 83 Ppg lnhibtted 12:00 AM 12:00 AM power. brine. bMT'tb back and set pack oR ale test Test AS/8" X T' annulus to 2,500 psi ROPE Tested 1-349. Rams functioned 30 min. Change out UPR W 3.5"X6". 8,000 1/11/19 ebelycoteefects7"Tleback ... 1/15/2019 1/16/2019 No AIS, Rig and amp on highline Finish change out topdnve saver sub, est upper pipe dams 250/3500psi, R/D test 12:00AM 12:MAM powerr assembly and set 61/4'9to mar bushing,P/U and run 6" clean out assembly. P/U 4" 10,000 BOPE Tested l-3-19. Rams functioned doll pipe singles. Shut down operations for phase 111 weather conditions. Phase 11 1/11/19 weathercondidonsat1915hrs.renume,dat.m. P/1,14" drill pipesingles and ... Continue RIH with 6" clean out assembly. 1/16/2019 1/17/2019 No AIS, Rig and ramp on highline RIH wOh 6"them, osrt airy P/U4"dtlll pipe singles W 10,739', Cut and slip drill line, y 12,000 12:00 AM 12:OOAM power. Circulate and cut mud might to10.2 N. Test using to 3500 P5130 min. Wash and t° BORE Tested 1-3-19. Rams fludicned ream to cement rubber at 10,991'MD. Drill neeiner and cement to 11.025' MD. 1/11/19 Circulate and condition mud, Flow check and POOH L/D clean out assy 751ls of model recovered. Pull wear bushing and test WP's, 14,000 1/17/2019 1/18/2019 No AIS, Rig and camp on highline Continue est ROP's, set wear bushing and P/U6"RSS drilling dew.. RlN with R55 1200 AM 12:00 AM Power, drilling ratty. Wash and ream to TOC at 11,025' MD. Drill shoe tack and Clean out at ROPE Tested 1.17-19. Rams hole to 11,132'MD. Drill 20'newformation from 11,132'MD to 11, 152' MD. Circulate functioned 1/17/19 and condition mud 10.2 Rise Perform FR to 12.5 ppg. Wash and ream to 11,152' MD 16,000 and displace well with 8.8 poll Flow Pro, Monitor well, Drill 6" production C sand ... 1/18/2019 1/19/2019 No AIS, Rig and camp on highllne Perform FFFto12.5 pM Displace well with 8.8 ppg Few Pro, Install RCD bearing. 12:00 AM 12:00AM power. Monhorwell,Drill 6" ploductlon C sand section 1/11,152' to 13,178' MD, ROPE Tested 1.17-19. Rams 18,000 Functioned! 1/17/19 1/19/2019 1/20/2019 No AIS, Rig mW camp on highline Dnll 6" production C sand section f/ 13,178' MO to 14,978'MD. 12:00 AM 12:00 AM power. ROPE Tested 1-17-19. Rams 20,000 functioned 1/17/19 1/20/2019 1/21/2019 No AS, Rlgand damp on highline DHII 6"productionCund sedlon f/ 14,978' MD to 16,615' MO. 12:00AM 12:00AM power. 22,000 ROPE Tested 1-17-19. Rams runctioned 1/17/19 0 5 30 15 20 25 30 35 40 Day Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Monday, January 14, 2019 3:17 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]Re: MT6-02 Operations Update Attachments: MT6-02 WV Cement Report_]nt2.pdf,, MT6-02 71NCH liner.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, See attached. Let me know if you need anything else. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Monday, January 14, 2019 12:22 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]Re: MT6-02 Operations Update Andrew, Please send the cement job summary as well as the cement job graphs. Thanx, Victoria Sent from my iPhone On Jan 14, 2019, at 9:40 AM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, We successfully cemented our Intermediate 2 liner over the weekend without any issues. We will log the job as originally planned during the liner run. Thanks, Andrew (303)378-8881 Schlumberger i Cementing Job ._sport CemCAT v1.7 Wall MT6-02 Rate Client ConocoPhillips Fleur MOoses Tooth SIR No. 82837 Engineer John Morrison 11:36:00 Sob Type Intermediate liner Country United States Sob Date 01-12-2019 Time Pressure Rate -- Density WHP Messages 11:26:00 11:36:00 pump water ahead mums seen. shubd m low pressure stall high Pr W 3000 psi 11:46:00 Reset Total, Vol = 1.39 bbl Blead Off Pressure batch up mud push Reset Total, Vol = 0.00 bbl rig sees mums 115600 12:06:00 cement wet Reset Total, Vol = 38.39 boll 12:16:00 pump cement sample taken scale 15.8 12:26:00 Reset Tatal, Vol = 55.28 bbl water 12:36:00 Reset TOW, Val = 19.95 bbl swap to rig 12:4600 I i 12:56:00 I 13:06:00 13:15:04 hh:mm:ss om cam moo cam cam smo om :o +a sa +a wa sa raa ,sa ma :za o woo yam cam +soo saoo u �• PSI e/M UVG PSI 01/12/201915:38:29 Schlumberger Cementing Service Report Page 10 14 CYstdMr co.womlllips ,ab NPM6Cr-- -... 82837 Wall MT6-02 Lounsn(lep.) Drill Site MT6 SM0. never lnunm Prudhoe Other lab alert ]an/12/2019 Fl.ld MocePs Tooth I MneNon NMM/Type Clean -Sandstone peylatbn 83 deg BN She 8.8 in Wall ND 11132.0 ft WeITVD 7909.0 ft County North Shope Mude/DroNns Alaska IMP ON am ST 179 t(e9F BNCT 152 de9F Pare P.. Gradient Ib/gal Wall MMw 0631803869 ADI/Um 50103207920000 M9 Name Doyon 19 Drilled Fa 011 Servls Wa and D.Ms/t,ner Dep@R she. in Welght. Ib/R 0reis Ttlrasd 0111Merc Sen. Wall Ossa New Well Type Development 8742.09.6 47.0 L80 HYD563 11051.0 7.0 26.0 LBO HYD563 Drilling Ruid Type Mex. Den," Ib/gal Plastic WsMft CP TL "/DAn Mpe T/D Opb.R she. In WeftK lb/ft Grad. Ttrhd SerA. Line Cemenbng lob Type Intermediate liner D 7858.0 5.0 19.5 D 10997.0 4.0 14.0 Max. All.wed Top Rw psi Max. AllewN Ann. Phe PM WM OMMA. 2" 1502 PSMeradas/opee Mal. Ts. ft BaRMry R allet/R Me. oeshoto Te w Interval Serd. 1.0thhhhans ft It ft ft ft Diamela In k ft Treat Down Ohl] pipe OMDiMMeld Packer Typo 142.0 bbl liner top Peraer D.pb 7863.0 ft Tuaing Val. 166.6 bbl CaMrlp Vol. Annular Vol. 73.2 bbl 455.8 bbl openbPM VW. bbl QmIn9/Tubl.g Secured ❑ 1 Noce Va. O.I.Dw prior b Cement ❑% CeehIM Taws squeeze lea Lift Prewra psi M. TV" Other S9ueeze TVs PIs Sotebd ❑ Ms Nad'Mated ❑ MIs Depth 11051.0R Teel Tys No, C.nb.N. 75 TS Plugs BWbrn Pk*. SLS Tool type Tei D.pm ft Cement Meed Type Mas TIM Darm ft Tall Mae is" In lob Scheduled iw 3an/12/2019 AnlTod on Locrtlen 3an/12/2019 lava Iarallon ]an/12/2019 Collar Tys ONler Tall Ms Depth ft Coyer Dapb 10997.6 ft sqz. Tafel VW. bbl Dab Time 3Mhr dxk T Unq Flaw Prenura HAD, DID SIM Denalty W/o WNPCIR lOT SLUR CMTjTG�VOL Nssgs Ps BBL BBL 01/12/2019 07:55:29 178 0.0 0.00 300 O.D 0.0 Sorted AWUNkion 01/12/2019 07:55:40 55 0.0 0.01 306 0.0 0.0 On k.Ow 0 0700 01/12/2019 07:55:59 59 0.0 0.00 308 0.0 0.0 01/12/2019 07:56:29 63 0.0 0.00 300 0.0 0.0 01/12/2019 07:56:59 64 0.0 0.01 306 0.0 0.0 01/12/2019 07:57:29 66 0.0 0.01 310 0.0 0.0 01/12/2019 07:57:59 83 0.0 0.00 310 0.0 0.0 01/12/2019 07:58:29 54 0.0 0.01 304 0.0 0.0 01/12/2019 1 07:58:59 57 1 0.0 0.01 283 0.0 0.0 01/12/2019 07:59:29 59 0.0 0.01 305 0.0 0.0 01/12/2019 07:59:59 59 0.0 0.00 308 0.0 0.0 01/12/2019 08:00:29 138 0.0 0.00 308 0.0 0.0 01/12/2019 08:00:59 64 0.0 0.01 305 0.0 0.0 01/12/2019 08:01:29 67 0.0 0.00 306 0.0 0.0 01/12/2019 08:01:59 69 0.0 0.01 305 0.0 0.0 01/12/2019 08:02:29 67 0.0 0.01 309 0.0 0.0 01/12/2019 08:02:59 67 0.0 0.00 381 D.0 0.0 01/12/2019 08:03:29 66' 0.1 -0.00 365 0.0 0.0 01/12/2019 08:03:59 69 0.0 0.00 365 0.0 0.0 01/12/2019 08:04:29 66 0.0 -0.00 371 0.0 0.0 01/12/2019 08:04:59 67 0.0 -0.00 361 Page 10 14 Well MT6-02 I{H4 Mooser Tooth ]ab Sort Sen/12/2019 Duelemerlab ConxoMilliDs Number 82837 Date 24Ar McOt naaula P53 Nob !/M I Den WV is/O "P PS[ CMt_tO _AL CW-STO_VOL Mesaaga VL !NL 01/12/2019 08:05:59 69 0.0 0.00 346 0.0 0.0 01/12/2019 08:06:29 69 0.0 0.00 367 0.0 0.0 01/12/2019 08:06:59 66 O.D 0.01 357 0.0 0.0 01/12/2019 08:07:29 66 0.0 0.01 371 0.0 0.0 01/12/2019 08:07:59 65 0.0 -0.00 357 0.0 0.0 01/12/2019 08:08:29 67 0.0 0.00 367 0.0 D.0 01/12/2019 08:08:59 66 0.0 0.01 360 0.0 0.0 01/12/2019 08:09:29 68 0.0 0.00 359 0.0 0.0 01/12/2019 08:09:59 67 0.0 0.00 363 0.0 0.0 01/12/2019 08:10:29 69 0.0 0.01 364 0.0 0.0 01/12/2019 08:10:59 71 0.0 0.00 373 0.0 0.0 01/12/2019 08:11:29 65 0.0 0.00 372 0.0 0.0 01/12/2019 08:11:59 68 0.0 0.01 378 0.0 0.0 01/12/2019 08:12:29 68 0.0 0.01 367 0.0 0.0 01/12/2019 08:12:59 68 0.0 0.01 359 0.0 0.0 01/12/2019 08:13:29 67 0.0 0.01 364 0.0 0.0 01/12/2019 08:13:59 fib 0.0 0.00 377 0.0 0.0 01/12/2019 08:14:29 73 0.0 0.01 363 0.0 0.0 01/12/2019 08:14:59 71 0.0 0.01 357 0.0 0.0 01/12/2019 08:15:29 71 0.0 0.00 367 0.0 0.0 01/12/2019 08:15:59 70 0.0 0.01 355 0.0 0.0 01/12/2019 08:16:29 65 0.0 0.00 380 0.0 0.0 01/12/2019 08:16:59 67 0.0 0.00 371 0.0 0.0 01/12/2019 08:17:29 69 0.0 0.01 365 0.0 0.0 01/12/2019 08:17:59 65 0.0 0.00 370 0.0 0.0 01/12/2019 08:18:29 66 0.0 0.01 385 0.0 0.0 01/12/2019 08:18:59 67 0.0 0.00 386 0.0 0.0 01/12/2019 08:19:29 fib 0.0 0.00 389 0.0 0.0 01/12/2019 08:19:59 66 0.0 0.00 379 0.0 0.0 01/12/2019 08:20:29 69 0.0 1 0.01 466 0.0 0.0 01/12/2019 08:20:59 66 0.0 0.00 453 0.0 0.0 01/12/2019 08:21:29 67 0.0 0.01 447 0.0 0.0 01/12/2019 08:21:59 69 0.0 0.00 439 0.0 0.0 01/12/2019 08:22:29 69 0.0 0.00 453 0.0 0.0 01/12/2019 08:22:59 69 0.0 0.01 457 0.0 0.0 01/12/2019 08:23:29 67 0.0 0.00 433 0.0 0.0 01/12/2019 08:23:59 66 0.0 0.00 409 0.0 D.0 01/12/2019 08:24:29 66 0.0 0.01 391 0.0 0.0 01/12/2019 08:24:59 65 0.0 0.01 398 0.0 0.0 01/12/2019 08:25:29 66 0.0 0.01 392 O.D 0.0 01/12/2019 08:25:59 64 0.0 0.00 390 0.0 0.0 01/12/2019 08:26:29 65 0.0 0.00 404 0.0 0.0 01/12/2019 08:26:59 65 0.0 0.01 408 0.0 D.0 01/12/2019 08:27:29 66 0.0 0.00 393 0.0 0.0 01/12/2019 D8:27:59 65 0.0 0.00 393 0.0 0.0 01/12/2019 08:28:29 67 0.0 0.01 389 0.0 0.0 01/12/2019 08:28:59 67 0.0 0.01 396 0.0 0.0 01/12/2019 08:29:29 64 0.0 0.01 411 0.0 0.0 01/12/2019 08:29:59 65 0.0 0.00 H2 0.0 0.0 01/12/2019 08:30:29 64 0.0 0.00 453 0.0 0.0 01/12/2019 08:30:59 68 0.0 0.00 435 0.0 0.0 01/12/2019 08:31:29 65 0.0 0.00 451 0.0 0.0 01/12/2019 08:31:59 66 0.0 0.00 450 0.0 0.0 01/12/2019 08:32:29 fi] 0.0 0.00 426 0.0 0.0 P,2M14 WMI MT6-02 - Moosm Tooth ]an/12/2019 C n=Milllp Mr 82837 Oso TImY 24.N tlOC4 TH m rewun Pp Noir NatY B/M B4YMly 4/O "PLNT oea TOT SLUR CNT 5T -VO` Mu BBL BBL 01/12/2019 08:33:29 66 0.0 0.00 4200.0 0.0 01/12/2019 08:33:59 65 0.0 0.01 435 0.0 0.0 01/12/2019 08:34:29 65 0.0 0.01 431 0.0 0.0 01/12/2019 08:34:59 63 0.0 0.01 419 0.0 0.0 01/12/2019 08:35:29 66 0.0 -0.00 434 0.0 0.0 01/12/2019 08:35:59 67 0.0 0.00 421 0.0 0.0 01/12/2019 08:36:29 66 0.0 0.00 427 0.0 0.0 01/12/2019 08:36:59 66 0.0 0.00 439 0.0 0.0 01/12/2019 08:37:29 66 0.0 0.00 427 0.0 0.0 01/12/2019 08:37:59 65 0.0 0.00 416 0.0 0.0 01/12/2019 08:38:29 64 0.0 0.00 437 0.0 0.0 01/12/2019 08:38:59 67 0.0 0.00 422 0.0 0.0 01/12/2019 08:39:29 65 0.0 0.00 421 0.0 0.0 01/12/2019 08:39:59 67 0.0 0.00 413 0.0 0.0 01/12/2019 08:40:29 66 0.0 0.00 437 0.0 0.0 01/12/2019 08:40:59 66 0.0 0.01 424 0.0 0.0 01/12/2019 08:41:29 62 0.0 0.01 423 0.0 0.0 01/12/2019 08:41:59 65 0.0 0.01 422 0.0 0.0 01/12/2019 08:42:29 67 0.0 0.00 443 0.0 0.0 01/12/2019 08:42:59 fib 0.0 0.00 425 0.0 0.0 01/12/2019 08:43:29 67 0.0 0.00 420 0.0 0.0 01/12/2019 08:43:59 67 0.0 0.00 412 0.0 0.0 01/12/2019 08:44:29 67 0.0 0.00 431 0.0 0.0 OI/I2/2019 08:44:59 65 0.0 0.00 419 0.0 0.0 01/12/2019 08:45:29 66 0.0 0.01 422 0.0 0.0 01/12/2019 08:45:59 68 0.0 0.00 414 0.0 0.0 01/12/2019 08:46:29 66 0.0 0.00 430 0.0 0.0 01/12/2019 08:46:59 66 0.0 0.00 440 0.0 0.0 01/12/2019 08:47:29 69 0.0 0.01 419 0.0 0.0 01/12/2019 08:47:59 66 0.0 0.01 418 0.0 0.0 01/12/2019 08:48:29 66 0.0 0.00 407 0.0 0.0 01/12/2019 08:48:59 fib 0.0 0.00 428 0.0 0.0 - 01/12/2019 08:49:29 69 0.0 0.00 436 0.0 0.0 01/12/2019 08:49:59 65 0.0 0.00 417 0.0 0.0 01/12/2019 08:50:29 66 0.0 0.00 423 0.0 0.0 01/12/2019 08:50:59 66 0.0 0.01 418 0.0 0.0 01/12/2019 08:51:29 66 0.0 0.00 424 0.0 0.0 01/12/2019 08:51:59 65 0.0 0.00 433 0.0 0.0 01/12/2019 08:52:29 66 0.0 0.00 423 0.0 0.0 01/12/2019 08:52:59 68 0.0 0.01 410 0.0 0.0 01/12/2019 08:53:29 152 0.0 0.00 428 0.0 0.0 01/12/2019 08:53:59 I80 0.0 0.00 436 0.0 0.0 01/12/2019 08:54:26 64 0.0 0.00 235 0.0 0.0 Un Pf 01/12/2019 08:54:29 65 0.0 0.00 226 0.0 0.0 01/12/2019 08:54:59 2930 0.0 0.00 90 0.0 0.0 01/12/2019 08:55:29 2927 0.0 0.00 64 0.0 0.0 01/12/2019 08:55:59 5083 0.0 0.00 61 0.0 0.0 01/12/2019 08:56:29 4962 0.0 0.00 60 0.0 0.0 01/12/2019 08:56:59 4982 0.0 0.00 59 0.0 0.0 01/12/2019 08:57:29 169 0.0 0.01 66 0.0 0.0 01/12/2019 08:57:59 63 0.0 0.00 56 0.0 0.0 01/12/2019 08:58:29 63 0.0 0.01 75 0.0 0.0 01/12/2019 08:58:35 63 0.0 0.01 70 0.0 0.0 Pr lnq ONt 01/12/2019 08:58:59 64 0.0 0.00 -138 0.0 0.0 WB43014 Wea W6-02 Fie14 Nooses TO h 1e6 A Jan/12/2019 Cuar4mer Con=Phllllp5 lob Mumher 82837 C4M 1 TMm 24-M dotlt h4>tynp Pr4rBYn PSI NTrr Bata BIN Banally 1B/G WNP PSI C1R lOT}W0. BBL <MT SIQVOS BBL Mawga 01/12/2019 08:59:59 59 0.0 0.01 1 0.0 0.0 01/12/2019 09:00:29 49 0.0 0.01 19 0.0 0.0 01/12/2019 09:00:59 68 0.0 0.01 20 0.0 0.0 01/12/2019 09:01:29 85 0.0 0.00 12 0.0 0.0 01/12/2019 09:01:59 82 0.0 0.00 -130 0.0 0.0 01/12/2019 09:02:29 110 0.0 0.00 25 0.0 0.0 01/12/2019 09:02:59 186 0.0 0.00 22 0.0 0.0 01/12/2019 09:03:29 64 0.0 0.01 57 0.0 0.0 01/12/2019 09:03:59 67 0.0 0.00 42 0.0 0.0 01/12/2019 09:04:29 62 0.0 0.00 48 0.0 0.0 01/12/2019 09:04:59 136 0.0 0.00 60 0.0 0.0 01/12/2019 09:05:29 66 0.0 0.00 58 0.0 0.0 01/12/2019 09:05:59 67 0.0 0.00 67 0.0 0.0 01/12/2019 09:06:29 65 0.0 0.00 37 0.0 0.0 01/12/2019 1 09:06:59 65 1 0.0 0.00 15 0.0 0.0 01/12/2019 09:07:29 69 0.0 0.00 202 0.0 0.0 01/12/2019 09:07:59 69 0.0 0.00 246 0.0 0.0 01/12/2019 09:08:29 68 0.0 0.01 316 0.0 0.0 01/12/2019 09:08:59 69 0.0 0.00 394 0.0 0.0 01/12/2019 09:09:29 70 0.0 0.00 367 0.0 0.0 01/12/2019 09:09:59 67 0.0 -0.00 367 0.0 0.0 01/12/2019 09:10:29 68 0.0 0.00 364 0.0 0.0 01/12/2019 09:10:59 69 0.0 0.01 365 0.0 0.0 01/12/2019 09:11:29 68 0.0 0.00 388 0.0 0.0 01/12/2019 09:11:59 69 0.0 0.01 371 0.0 0.0 01/12/2019 09:12:29 69 0.0 0.01 380 0.0 0.0 01/12/2019 09:12:59 114 0.0 8.25 368 0.0 0.0 01/12/2019 09:13:29 79 0.0 4.69 360 0.0 0.0 01/12/2019 09:13:59 241 0.0 3.59 385 0.0 0.0 01/12/2019 09:14:29 238 0.0 8.12 358 0.0 0.0 01/12/2019 09:14:59 233 0.0 8.28 377 0.0 0.0 01/12/2019 09:15:29 116 0.0 8.11 365 0.0 0.0 01/12/2019 09:15:59 77 0.0 8.00 356 0.0 0.0 01/12/2019 09:16:29 71 0.0 7.95 388 0.0 0.0 01/12/2019 09:16:59 69 0.0 7.92 367 0.0 0.0 01/12/2019 09:17:29 67 0.0 7.90 376 0.0 0.0 01/12/2019 09:17:38 67 1.1 7.89 381 0.0 0.0 h head rate GNck 01/12/2019 09:17:59 71 3.1 7.87 368 1.1 1.1 01/12/2019 09:18:29 65 0.0 7.86 377 1.5 1.5 01/12/2019 09:18:59 66 3.1 7.84 366 1.8 1.8 01/12/2019 09:19:29 66 0.1 7.83 366 2.7 2.7 01/12/2019 09:19:59 67 0.1 7.81 385 2.7 2.7 01/12/2019 09:20:29 70 0.1 7.81 365 2.8 2.8 01/12/2019 09:20:59 129 3.5 7.79 387 2.9 2.9 01/12/2019 09:21:29 80 1.5 7.79 371 4.2 4.2 01/12/2019 09:21:55 116 3.2 7.78 379 5.3 5.3 h head rate Gm& 01/12/2019 09:21:59 114 0.0 7.78 379 5.3 5.3 01/12/2019 09:22:11 115 3.1 7.78 822 5.9 5.9 PB Toral, Val = 5.92 hhl 01/12/2019 09:22:29 114 3.1 7.77 1321 6.9 0.9 01/17/2019 09:22:59 115 3.1 7.76 2194 8.4 2.5 01/12/2019 09:23:29 80 0.0 7.76 3508 9.0 3.0 01/12/2019 09:23:59 104 0.0 7.75 4146 9.0 3.0 01/12/2019 09:24:06 102 3.1 7.75 4130 9.0 3.1 9 head rate Gnirk 01/12/2019 09:24:29 107 3.1 7.75 4105 10.2 4.3 PNp4au Wen MT6-02 Nel4 Mooser Tooth Jeb adR Ian/12/2019 Cuetomer Con=Millips ]46 NUMB 82837 paleTime 24-nr doa Tibtln9 OMYe1� vat NOYI RaN a/N D o" Y/6 "PCNT-,TOT,$UR Pa1 NL CMT SlfyWll. Mapa9e OK 01/12/2019 09:25:29 64 0.0 7.74 4079 12.0 6.0 01/12/2019 09:25:59 64 0.0 7.73 3670 12.0 6.0 01/12/2019 09:26:29 65 0.0 7.74 2775 12.0 6.0 01/12/2019 09:26:59 64 0.0 7.74 1816 12.0 6.0 01/12/2019 09:27:29 66 0.0 7.73 1067 12.0 6.0 01/12/2019 09:27:59 63 0.0 7.73 613 12.0 6.0 01/12/2019 09:28:29 64 0.0 7.72 568 12.0 6.0 01/12/2019 09:28:59 62 0.0 7.72 564 12.0 6.0 01/12/2019 09:29:29 64 0.0 7.72 574 12.0 6.0 01/12/2019 09:29:59 64 0.0 7.72 84 12.0 6.0 01/12/2019 09:30:29 68 0.0 7.72 277 12.0 6.0 01/12/2019 09:30:59 65 0.0 7.71 358 12.0 6.0 01/12/2019 09:31:29 68 0.0 7.72 394 12.0 6.0 01/12/2019 09:31:59 67 0.0 7.71 379 12.0 6.0 01/12/2019 09:32:29 68 0.0 7.71 361 12.0 6.0 01/12/2019 09:32:59 67 0.0 7.71 379 12.0 6.0 01/12/2019 09:33:29 67 O.D 7.71 403 12.0 6.0 01/12/2019 09:33:59 67 0.0 7.71 169 12.0 6.0 01/12/2019 09:34:29 69 0.0 7.71 141 12.0 6.0 01/12/2019 09:34:59 67 0.0 7.71 127 12.0 6.0 01/12/2019 09:35:29 66 0.0 7.71 90 12.0 6.0 01/12/2019 09:35:59 64 0.0 7.71 75 12.0 6.0 01/12/2019 09:36:29 67 0.0 7.71 74 12.0 6.0 01/12/2019 09:36:59 64 O.D 7.70 84 12.0 6.0 01/12/2019 09:37:29 63 0.0 7.70 92 12.0 6.0 01/12/2019 09:37:59 66 0.0 7.70 49 12.0 6.0 01/12/2019 09:38:29 64 0.0 7.70 95 12.0 6.0 01/12/2019 09:38:59 65 0.0 7.70 86 12.0 6.0 01/12/2019 09:39:29 65 0.0 7.70 57 12.0 6.0 01/12/2019 09:39:59 63 0.0 7.70 65 12.0 6.0 01/12/2019 09:40:29 70 0.0 7.70 -380 12.0 6.0 01/12/2019 09:40:59 70 0.0 7.70 -378 12.0 6.0 01/12/2019 09:41:29 70 0.0 7.69 -375 12.0 6.0 01/12/2019 09:41:59 70 0.0 7.69 -359 12.0 6.0 01/12/2019 09:42:29 68 0.0 7.69 -11 12.0 6.0 01/12/2019 09:42:59 65 0.0 7.69 5 12.0 6.0 01/12/2019 09:43:29 65 0.0 7.69 5 12.0 6.0 01/12/2019 09:43:59 66 0.0 7.69 21 12.0 6.0 01/12/2019 09:44:29 68 0.0 7.69 23 12.0 6.0 01/12/2019 09:44:59 67 0.0 7.69 7 12.0 6.0 01/12/2019 09:45:29 65 0.0 7.69 9 12.0 6.0 01/12/2019 09:45:59 66 0.0 7.69 1 12.0 6.0 01/12/2019 09:46:29 66 O.D 7.68 21 12.0 6.0 01/12/2019 09:46:59 67 0.0 7.68 1 -17 12.0 6.0 01/12/2019 09:47:29 67 0.0 7.68 8 12.0 6.0 01/12/2019 09:47:59 66 0.0 7.68 28 12.0 6.0 01/12/2019 09:48:29 67 0.0 7.68 -277 12.0 6.0 01/12/2019 09:48:59 69 0.0 7.68 -364 12.0 6.0 01/12/2019 09:49:29 69 0.0 7.68 -369 12.0 6.0 01/12/2019 09:49:59 68 0.0 7.67 7 12.0 6.0 01/12/2019 09:50:29 67 0.0 7.67 7 12.0 6.0 01/12/2019 09:50:59 68 0.0 7.68 30 12.0 6.0 01/12/2019 09:51:29 66 0.0 7.68 19 12.0 6.0 01/12/2019 09:51:59 67 0.0 7.67 9 12.0 6.0 P4a4 5014 MIYB MT6-02 FNitl Mooser Tmh 1Y651prtCuftanrer 3aN12/2019 Co.-Mllips ]46 Number 82837 perp nm. 24Ae COCk T flap F um F51 Fbw Bate B/N p .ft LB/B NMF OICTGT3]]]a CNT}TQNOL NYewpO PS] YL BBL 01/12/2019 09:52:59 66 0.0 7.67 15 12.0 6.0 01/12/2019 09:53:29 65 0.0 7.67 14 12.0 6.0 01/12/2019 09:53:59 64 0.0 7.67 15 12.0 6.0 01/12/2019 09:54:29 66 0.0 7.67 -29 12.0 6.0 01/12/2019 09:54:59 66 0.0 7.67 -23 12.0 6.0 01/12/2019 09:55:29 67 0.0 7.67 -29 12.0 6.0 01/1212019 09:55:59 68 0.0 7.67 260 12.0 6.0 01/12/2019 09:56:29 67 0.0 7.67 231 12.0 6.0 01/12/2019 09:56:59 66 0.0 7.67 248 12.0 6.0 01/12/2019 09:57:29 65 0.0 7.67 232 12.0 6.0 01/12/2019 09:57:59 68 0.0 7.67 297 12.0 6.0 01/12/2019 09:58:29 65 0.0 7.66 455 12.0 6.0 01/12/2019 09:58:59 65 0.0 7.66 494 12.0 6.0 01/12/2019 09:59:29 66 0.0 7.66 497 12.0 6.0 01/12/2019 09:59:59 68 0.0 7.66 501 12.0 6.0 01/12/2019 10:00:29 71 0.0 7.66 503 12.0 6.0 01/12/2019 10:00:59 69 0.0 7.66 499 12.0 6.0 01/12/2019 10:01:29 67 0.0 7.66 582 12.0 6.0 01/12/2019 10:01:59 66 0.0 7.66 582 12.0 6.0 01/12/2019 10:02:29 70 0.0 7.66 595 12.0 6.0 01/12/2019 10:02:59 69 0.0 7.66 592 12.0 6.0 01/12/2019 10:03:29 69 0.0 7.66 591 12.0 6.0 01/12/2019 10:03:59 67 0.0 7.66 601 12.0 6.0 01/12/2019 10:04:29 65 0.0 7.65 747 12.0 6.0 01/12/2019 10:04:59 65 0.0 7.65 739 12.0 6.0 01/12/2019 10:05:29 66 0.0 7.65 7N 12.0 6.0 01/12/2019 10:05:59 67 0.0 7.65 751 12.0 6.0 01/12/2019 10:06:29 66 0.0 7.66 886 12.0 6.0 01/12/2019 10:06:59 67 0.0 7.66 930 12.0 6.0 01/12/2019 10:07:29 68 0.0 7.65 927 12.0 6.0 01/12/2019 10:07:59 65 0.0 7.65 933 12.0 6.0 01/12/2019 10:08:29 65 0.0 7.65 1079 12.0 6.0 01/12/2019 10:08:59 67 0.0 7.65 1096 12.0 6.0 01/12/2019 10:09:29 67 0.0 7.65 1106 12.0 6.0 01/12/2019 10:09:59 68 0.0 7.65 1102 12.0 6.0 01/12/2019 10:10:29 64 0.0 7.65 1094 12.0 6.0 01/12/2019 10:10:59 68 0.0 7.65 1102 12.0 6.0 01/12/2019 10:11:29 66 0.0 7.65 1112 12.0 6.0 01/12/2019 10:11:59 67 0.0 7.64 1109 12.0 6.0 01/12/2019 10:12:29 64 0.0 7.64 1107 12.0 6.0 01/12/2019 10:12:59 69 0.0 7.65 1106 12.0 6.0 01/12/2019 10:13:29 64 0.0 7.64 1104 12.0 6.0 01/12/2019 10:13:59 67 0.0 7.64 1099 12.0 6.0 01/12/2019 10:14:29 65 0.0 7.65 1105 12.0 6.0 01/12/2019 10:14:59 66 0.0 7.64 1102 12.0 6.0 01/12/2019 10:15:29 66 0.0 7.64 1106 12.0 6.0 01/12/2019 10:15:59 66 0.0 7.64 1106 12.0 6.0 01/12/2019 10:16:29 66 0.0 7.64 1104 12.0 1 6.0 01/12/2019 10:16:59 67 0.0 7.64 1109 12.0 6.0 01/12/2019 10:17:29 64 0.0 7.64 1119 12.0 6.0 01/12/2019 10:17:59 66 0.0 7.63 1115 12.0 6.0 01/12/2019 10:18:29 69 0.0 7.63 1111 12.0 6.0 01/12/2019 10:18:59 66 0.0 7.64 1110 12.0 6.0 01/12/2019 10:19:29 66 0.0 7.63 1094 12.0 6.0 FYBe 6 x114 wen MT6-02 FlNe Mooser Tooth lap SbR 3eN1212019 Cpefamar con=Philllpl lep Number 8283] peep n. 24 appy Tro n Pwfun PBt PyBe Rao B/M B4BMlV Ls/O IBBP OMT_T0T_A111B CMT_AffyVOL M4sYBe M BBL BBL 01/12/2019 10:20:29 66 0.0 7.64 1105 12.0 6.0 01/12/2019 10:20:59 66 0.0 7.64 1103 12.0 6.0 01/12/2019 10:21:29 68 O.D 7.63 1102 12.0 6.0 01/12/2019 10:21:59 68 0.0 7.63 1106 12.0 6.0 01/12/2019 10:22:29 63 0.0 7.63 1109 12.0 6.0 01/12/2019 10:22:59 66 0.0 7.63 1108 12.0 6.0 01/12/2019 10:23:29 67 0.0 7.63 1104 12.0 6.0 01/12/2019 10:23:59 66 0.0 7.63 1106 12.0 6.0 01/12/2019 10:24:29 65 0.0 7.63 1100 12.0 6.0 01/12/2019 10:24:59 66 0.0 7.63 1112 12.0 6.0 01/12/2019 10:25:29 67 0.0 7.63 1117 12.0 6.0 01/12/201910:25:59 64 0.0 7.63 1123 12.0 6.0 01/12/2019 10:26:29 65 0.0 7.63 1123 12.0 6.0 01/12/2019 10:26:59 67 0.0 7.63 1116 12A 6.0 Be50t ToW,Vol=6.04 bbl 10:27:29 67 0.0 7.63 1110 0.0 0.0 2L19 12/2019 10:27:59 65 0.0 7.62 1112 0.0 0.0 01/12/2019 10:28:29 660.0 7.63 1111 O.D 0.0 01/12/2019 10:28:59 66 0.0 7.62 1116 0.0 0.0 01/1](2019 10:29:29 66 0.0 7.62 1119 0.0 0.0 01/12/2019 10:29:59 65 0.0 7.62 1122 0.0 0.0 01/12/2019 10:30:29 64 0.0 7.62 1112 0.0 0.0 01/12/2019 10:30:59 65 O.D 7.62 1117 0.0 0.0 01/12/2019 10:31:29 66 0.0 7.62 1113 0.0 0.0 01/12/2019 10:31:59 67 0.0 7.62 1118 0.0 0.0 01/12/2019 10:32:29 67 0.0 7.62 1114 1 0.0 0.0 01/12/2019 10:32:59 65 0.0 7.62 1106 0.0 0.0 01/12/2019 10:33:29 67 0.0 7.62 1114 0.0 0.0 01/12/2019 10:33:59 66 0.0 7.62 1119 0.0 0.0 01/12/2019 10:34:29 67 0.0 7.61 1118 0.0 0.0 01/12/2019 10:34:59 64 0.0 7.62 1116 0.0 0.0 01/12/2019 10:35:29 66 0.0 7.62 1123 0.0 0.0 01/12/2019 10:35:59 65 0.0 7.62 1120 0.0 0.0 01/12/2019 10:36:29 67 0.0 7.62 1150 0.0 0.0 01/12/2019 10:36:59 66 0.0 7.62 1139 0.0 0.0 01/12/2019 10:37:29 65 0.0 7.62 1143 0.0 0.0 01/12/2019 10:37:59 67 0.0 7.61 1140 0.0 0.0 01/12/2019 10:38:29 66 0.0 7.61 1141 0.0 0.0 01/12/2019 10:38:59 64 O.D 7.61 1141 0.0 0.0 01/17(2019 10:39:29 65 0.0 7.61 1134 0.0 0.0 01/12/2019 10:39:59 67 0.0 7.61 1136 0.0 0.0 01/12/2019 10:40:29 66 O.D 7.61 1136 0.0 D.0 01/12/2019 10:40:59 67 0.0 7.61 1140 0.0 0.0 01/12/2019 10:41:29 fi5 0.0 7.61 1134 0.0 0.0 01/12/2019 10:41:59 64 0.0 7.61 1137 0.0 0.0 01/12/2019 10:42:29 66 0.0 7.61 1138 0.0 0.0 01/12/2019 10:42:59 65 0.0 7.61 1134 0.0 0.0 01/12/2019 10:43:29 65 0.0 7.61 1139 D.0 0.0 01/12/2019 10:43:59 65 0.0 7.61 1142 0.0 0.0 01/12/2019 10:44:29 66 0.0 7.61 1143 0.0 0.0 01/12/2019 10:44:59 63 0.0 7.61 1131 0.0 0.0 01/12/2019 10:45:29 64 0.0 7.61 1132 0.0 0.0 01/12/2019 10:45059 62 0.0 7.61 1133 0.0 0.0 01/12/2019 10:46:29 650.0 7.61 1140 0.0 0.0 01/12/2019 10:46:59 65 0.0 7.60 1133 0.0 0.0 Pe9e 7 014 WWI W6-02 MN4 Mooser Toots lab SUK 1an/12/2019 CUKamer ConamPh0lips 306 Number 82837 Cala TeMB 24-hr tl0d1 TMBeg gwuro PBI Mew xab B/M D Wtv MI/6 MMP CMT_TOT AYM CMT SlB_YOL Massage PB1 BB1 BBL 01/12/2019 10:47:59 66 0.0 7.61 1135 0.0 0.0 01/12/2019 10:48:29 64 0.0 7.60 1148 D.0 0.0 01/12/2019 10:48:59 64 0.0 7.60 1139 0.0 0.0 01/12/2019 10:49:29 63 0.0 7.60 1135 0.0 0.0 01/12/2019 10:49:59 66 0.0 7.61 1128 0.0 0.0 01/12/2019 10:50:29 64 0.0 1.61 1127 0.0 0.0 01/12/2019 10:50:59 67 0.0 7.60 1134 0.0 0.0 01/12/2019 10:51:29 65 0.0 7.60 1139 0.0 0.0 01/12/201910:51:59 66 0.0 7.60 1138 0.0 0.0 01/12/2019 10:52:29 65 0.0 7.60 1130 0.0 0.0 01/12/2019 10:52:59 65 0.0 7.60 1133 0.0 0.0 01/12/2019 10:53:29 65 0.0 7.60 1137 0.0 0.0 01/12/2019 10:53:59 64 0.0 7.60 1137 D.0 0.0 01/12/2019 10:54:29 65 0.0 7.60 1144 0.0 0.0 01/12/2019 10:54:59 68 0.0 7.60 1135 0.0 0.0 01/12/2019 10:55:29 66 0.0 7.60 1135 0.0 0.0 01/12/2019 10:55159 66 0.0 7.60 1136 0.0 0.0 01/12/2019 10:56:29 66 0.0 7.fi0 1132 0.0 0.0 01/12/2019 10:56:59 65 0.0 7.60 1135 0.0 0.0 01/12/2019 10:57:29 65 0.0 7.60 1123 D.0 0.0 01/12/2019 10:57:59 64 0.0 7.60 1128 0.0 0.0 01/12/2019 10:58:29 66 0.0 7.60 1114 0.0 0.0 01/12/2019 10:58:59 65 0.0 7.60 1118 D.0 0.0 01/12/2019 10:59:29 fib 0.0 7.60 1106 0.0 D.0 01/12/2019 10:59:59 68 0.0 7.60 1110 0.0 0.0 01/12/2019 1 11:00:29 67 0.0 ].59 111] 0.0 0.0 01/12/2019 11:00:59 66 0.0 7.60 1120 0.0 0.0 01/12/2019 11:01:29 66 0.0 ].60 1122 0.0 0.0 01/12/2019 11:01:59 65 0.0 7.59 1113 0.0 0.0 01/12/2019 11:02:29 67 0.0 7.59 1114 0.0 0.0 01/12/2019 11:02:59 66 0.0 7.59 316 0.0 0.0 01/12/2019 11:03:29 68 0.0 7.59 76 0.0 0.0 01/12/2019 11:03:59 65 O.D 7.59 60 0.0 0.0 01/12/2019 11:04:29 68 0.0 7.59 31 0.0 D.0 01/12/2019 11:04:59 66 0.0 7.59 41 0.0 0.0 01/12/2019 11:05:29 69 0.0 7.59 33 0.0 0.0 01/12/2019 11:05:59 65 0.0 7.59 46 0.0 0.0 01/12/2019 11:06:29 65 0.0 7.59 60 0.0 0.0 01/12/2019 11:06:59 67 0.07.59 68 0.0 0.0 01/12/2019 11:07:29 64 0.0 7.59 56 0.0 0.0 01/12/2019 11:07:59 143 0.0 7.59 88 0.0 0.0 01/12/2019 11:08:29 137 0.0 7.59 -2 0.0 0.0 01/12/2019 11:08:59 137 0.0 7.59 296 0.0 0.0 01/12/2019 11:09:29 140 0.0 7.58 307 0.0 0.0 01/12/2019 11:09:59 137 0.0 7.59 304 0.0 0.0 01/12/2019 11:10:29 138 0.0 7.59 306 0.0 0.0 01/12/2019 11:10:59 137 0.0 7.59 356 0.0 0.0 01/12/2019 11:11:29 138 0.0 7.58 369 0.0 0.0 01/12/2019 11:11:59 138 0.0 7.59 362 0.0 0.0 01/12/2019 11:12:29 139 0.0 7.58 352 0.0 0.0 01/12/2019 11:12:59 196 0.0 7.58 363 0.0 0.0 01/12/2019 11:13:29 194 0.0 7.59 360 0.0 0-0 01/12/2019 11:13:31 197 0.0 7.58 361 0.0 0.0 P35M 01/12/2019 11:13:59 193 0.0 7.58 359 0.0 0.0 Papa B 0114 Page 9 of 14 Weld Moos65 Toots 3e6 SmR ]aN12/2019 Watomet Con=Millips 346 Hum6W 82837 Weli MT6-02 Date Tlme 29 -hr C4du Testln9 9rewrre P91 Tlew OWN, !7M De"M Ill/D WN9 CIT NT}W0. QTTfT4�VOl M0vsa9� ME eK MR. 01/12/2019 11:14:59 190 0.0 7.58 417 0.0 0.0 01/12/2019 11:15:29 190 0.0 7.58 411 0.0 0.0 01/12/2019 11:15:59 186 0.0 7.58 418 0.0 0.0 01/12/2019 11:16:29 189 0.0 7.58 402 0.0 0.0 01/12/2019 11:16:59 101 0.0 7.58 401 0.0 0.0 01/12/2019 11:17:29 72 0.0 7.58 472 0.0 0.0 01/12/2019 11:17:59 69 0.0 7.58 460 0.0 0.0 01/12/2019 11:18:29 68 0.0 7.58 432 0.0 0.0 01/12/2019 11:18:59 67 0.0 7.58 452 D.0 0.0 01/12/2019 11:19:29 67 0.0 7.58 461 0.0 0.0 01/12/2019 11:19:59 65 0.0 7.58 484 0.0 0.0 01/12/2019 11:20:29 67 0.0 7.57 495 0.0 0.0 01/12/2019 11:20:59 64 0.0 7.58 494 0.0 0.0 01/12/2019 11:21:29 67 0.0 7.58 535 0.0 0.0 01/12/2019 11:21:59 67 0.0 7.58 513 0.0 0.0 01/12/2019 11:22:29 67 0.0 7.58 526 0.0 0.0 01/12/2019 11:22:32 68 O.D 7.58 508 0.0 0.0 hard 8rle blown Down 01/12/2019 11:22:59 69 0.0 7.58 518 0.0 0.0 01/12/2019 11:23:29 68 0.0 7.58 540 0.0 0.0 01/12/2019 11:23:59 70 0.0 7.58 511 0.0 0.0 01/12/2019 11:24:29 69 0.0 7.57 526 0.0 0.0 01/12/2019 11:24:59 69 0.0 7.57 516 0.0 0.0 01/12/2019 11:25:29 69 0.0 7.57 506 0.0 0.0 01/12/2019 11:25:59 660.0 7.57 544 0.0 0.0 01/12/2019 11:26:29 70 0.0 7.5] 525 0.0 0.0 01/12/2019 11:26:59 680.0 ].57 526 0.0 0.0 01/12/2019 11:27:29 70 0.0 ].57 509 0.0 0.0 01/12/2019 11:27:59 69 0.0 7.57 51310.0 0.0 01/12/2019 11:28:29 69 0.0 7.57 514 D.001/12/2019 11:28:59 68 0.0 ].57 509 0.001/12/2019 11:29:29 71 0.0 7.57 532 0.001/12/2019 11:29:59 68 0.0 7.57 500 0.001/12/2019 11:30:29 67 0.0 7.56 523 0.001/12/2019 11:30:59 68 0.0 7.56 500 0.0 01/12/2019 11:31:29 66 0.0 7.57 504 0.0 0.0 01/12/2019 11:31:59 69 0.0 7.56 504 0.0 0.0 01/12/2019 11:32:29 66 0.0 7.56 512 0.0 0.0 01/12/2019 11:32:59 69 0.0 7.57 496 0.0 0.0 01/12/2019 11:33:29 67 0.0 7.56 528 0.0 0.0 01/12/2019 11:33:59 67 0.0 7.57 495 0.0 0.0 01/12/2019 11:34:29 68 0.D 526 0.0 0.0 01/12/2019 11:34:59 66 0.0 501 0.0 0.0 01/12/2019 11:35:29 68 0.0 518 0.0 0.0 01/12/2019 11:35:59 67 0.0 :7.56 491 0.0 0.0 01/12/2019 11:36:29 69 0.0 504 0.0 0.0 01/12/2019 11:36:59 7D 0.0 501 0.0 0.0 01/12/2019 11:3]:29 68 0.0 7.56 520 0.0 0.0 01/12/2019 11:3]:59 68 0.0 7.56 253 0.0 0.0 01/12/2019 11:38:29 68 0.0 7.56 el 0.0 0.0 01/12/2019 11:38:59 69 0.0 7.56 90 0.0 0.0 01/12/2019 11:39:29 67 0.0 7.56 98 01/12/2019 11:39:59 69 0.0 7.55 96 0.0 D.0 01/12/2019 11:40:29 67 0.0 7.55 87 0.0 0.0 01/12/2019 11:40:49 1 68 0.2 7.55 78 0.0 0.0 i pump wall~ Page 9 of 14 WON W6-02 Flel4 MOoses Toots Joe S ft 1aiV12/2019 OuaJemer Co.o Mil llp: Jot Numbm 82837 Dob Thee x4a. slow Tr4iwlp er4vun vs1 Mew Nwe N/N Oamft u/s WNV M M _M-OwN o T}a v L eNL NL Ntl 01/12/2019 11:41:29 485 2.4 7.56 430 0.5 0.5 01/12/2019 11:41:59 226 0.0 7.55 225 1.3 1.3 01/12/2019 11:42:12 214 0.0 7.56 205 1.3 1.3 reU seen, shutdown 01/12/2019 11:42:29 206 0.0 7.55 1% 1.3 1.3 01/12/2019 11:42:59 199 0.0 7.55 197 1.3 1.3 01/12/2019 11:43:22 733 0.1 7.55 717 1.4 1.4 low pessum stall 01/12/2019 11:43:29 725 0.0 7.56 733 1.4 1.4 01/12/2019 11:43:59 2271 0.0 7.55 2302 1.4 1.4 01/12/2019 11:44:00 2262 0.0 7.55 2299 1.4 1.4 ho fT to 3000 MI 01/12/2019 11:44:07 2672 0.1 7.55 2726 1.4 1.4 NeNetTOW, VOI - 1.39 01/12/2019 11:44:29 3144 0.0 7.55 3360 1.4 0.0 01/12/2019 31:44:59 3126 0.0 7.55 3125 1.4 0.0 01/12/2019 11:45:12 3122 0.0 7.55 3119 1.4 0.0 Mtbl Meed OffN um 01/12/2019 11:45:29 124 0.1 7.55 80 1.4 0.0 01/12/2019 11:45:59 106 0.0 7.55 93 1.4 0-0 01/12/2019 11:46:29 110 0.3 7.54 108 1.5 0.1 01/12/2019 11:46:59 122 0.3 7.55 112 1.6 0.2 01/12/2019 11:47:29 122 0.3 ].54 107 1.8 0.4 01/12/2019 11:47:59 129 0.3 7.55 123 1.9 0.5 01/12/2019 11:48:29 136 0.3 8.32 122 2.1 0.7 01/12/2019 11:48:59 130 0.3 8.30 96 2.2 0.8 01/12/2019 11:49:29 127 0.3 8.27 59 2.3 1.0 01/12/2019 11:49:41 132 0.3 8.28 68 2.4 1.0 battle u0 mud psh 01/12/2019 11:49:59 136 0.3 8.40 77 2.5 1.1 01/12/2019 11:50:29 135 0.3 10.00 62 2.6 1.2 01/12/2019 11:50:59 134 0.3 12.57 73 2.8 1.4 01/12/2019 31:51:29 137 0.3 11.78 66 2.9 1.5 01/12/2019 11:51:59 136 0.3 11.68 73 3.0 1.6 01/12/2019 11:52:29 137 0.3 11.64 75 3.2 1.8 01/12/2019 11:52:59 143 0.3 11.55 82 3.3 1.9 01/12/2019 11:53:07 137 1 0.3 11.54 78 3.3 1.9 Rae[TOtal, Vol 0.00 WI 01/12/2019 11:53:29 157 0.3 11.46 74 3.4 0.1 01/12/2019 11:53:59 720 2.7 11.48 570 4.1 0.8 01/12/2019 11:54:29 733 2.8 12.69 520 5.5 2.2 01/12/2019 11:54:50 744 2.8. 12.41 510 6.5 3.2 rl9 sees nYums 01/12/2019 11:54:59 718 2.8 12.4 502 6.9 3.6 01/12/2019 31:55:29 722 2.9 11.94 507 8.3 5.0 01/12/2019 11:55:59 724 2.9 11.63 497 9.8 6.4 01/12/2019 11:56:29 722 2.9 12.64 493 11.2 7.9 01/12/2019 11:56:59 736 2.9 12.78 484 12.7 9.3 01/12/2019 11:57:29 694 3.0 11.72 490 14.1 10.8 01/12/2019 11:57:59 710 3.0 12.22 468 15.6 12.3 01/12/2019 11:58:29 694 3.0 11.46 485 17.1 13.8 01/12/2019 11:58:59 870 3.9 11.33 550 18.8 15.4 01/12/2019 11:59:29 898 3.9 11.33 538 20.7 17.4 01/12/2019 11:59:59 865 3.9 11.30 538 22.7 19.3 01/12/201912:00:29 856 3.9 11.23 545 24.6 21.3 01/12/2019 12:00:59 864 4.0 11.27 530 26.6 23.3 01/12/2019 12:01:29 663 3.0 11.30 450 28.3 25.0 01/12/2019 12:01:59 675 3.0 11.27 447 29.8 26.5 01/12/2019 12:02:29 659 3.0 11.23 441 31.3 28.0 01/12/2019 12:02:59 653 3.0 11.07 445 32.8 29.5 01/12/2019 12:03:29 659 3.0 10.91 423 34.3 31.0 01/12/2019 1 203:59 643 3.0 10.92 445 1 35.8 32.5 Opa 10 0 14 Well W6-02 Fe14 Moses Tooth Sob9tast ]an/12/2019 Customer CO caPhillIp5 77 Sob Numb" 82837 Bute Tme 24-6r cock T,eabeg Pweure P5[ Wow M.A. a/N OeeeN1 LB/B CNT TBT�W0. CNT_BT6,�VOL BR BBL Naw90 01/12/2019 12:04:59 341 0.8 12.05 E467 37.3 34.0 01/12/2019 12:05:29 364 0.8 11.70 37.8 34.4 01/12/7019 12:05:59 657 3.0 11.54 38.7 35.4 01/12/2019 12:06:29 658 3.0 11.54 40.2 36.9 01/12/2019 12:06:59 366 1.8 11.55 41.7 38.4 01/12/2019 12:07:29 130 0.0 11.49 63 41.7 38.4 01/12/2019 12:07:59 124 0.0 11.49 75 41.7 38.4 01/12/2019 12:08:29 117 0.0 11.49 52 41.7 38.4 01/12/2019 12:08:59 116 0.0 11.48 58 41.7 38.4 01/12/2019 12:09:29 112 0.0 11.48 56 41.7 38.4 01/12/2019 12:09:59 113 0.0 11.48 75 41.7 38.4 01/12/2019 12:10:29 121 0.0 11.20 76 41.7 38.4 01/12/2019 12110:59 131 0.0 8.45 87 41.7 38.4 01/12/2019 12:11:29 132 0.0 8.66 88 41.7 38.4 01/12/2019 .12:11:37 134 0.0 8.84 84 41.7 38.4 ®meat Wet 01/12/2019 12:11:40 139 0.0 9.24 89 41.7 38.4 Reset Total, Vol = 38.39 bbl 01/12/2019 12:11:59 154 0.0 11.07 112 41,7 0.0 01/12/2019 12:12:29 169 0.0 13.55 128 41.7 0.0 01/12/2019 12:12:59 182 0.0 15.37 140 41.7 0.0 01/12/2019 12:13:29 186 0.0 15.53 140 41.7 0.0 01/12/2019 12:13:59 189 0.0 16.09 141 41.7 0.0 01/12/2019 12:14:29 189 0.0 16.14 139 41.7 0.0 01/12/2019 12:14:59 190 0.0 15.97 136 41.7 0.0 01/12/2019 12:15:28 377 1.5 15.91 263 41.8 0.1 pump Bement 01/12/2019 12:15:29 447 1.7 15.90 321R48.8 0.1 01/12/2019 12:15:59 1014 3.5 16.09 577 1.7 01/12/2019 12:16:29 1028 3.5 15.72 556 3.5 01/12/2019 12:16:59 959 3.6 15.78 514 5.3 01/12/2019 12:17:29 953 3.6 15.81 505 7.1 01/12/2019 12:17:59 962 3.7 15.69 469 8.9 01/12/2019 12:18:29 1078 4.0 15.75 485 10.7 01/12/2019 12:18:59 1069 4.0 15.84 480 54.5 12.8 01/12/2019 12:19:29 1053 4.0 15.84 445 56.5 14.8 01/12/2019 12:19:59 845 3.6 15.75 349 58.4 16.7 01/12/2019 12:20:29 844 3.7 15.75 360 60.2 18.5 01/12/2019 12:20:59 823 3.7 15.83 308 62.1 20.4 01/12/2019 12:21:20 805 3.8 15.82 294 63.4 21,6 sample talwn 01/12/2019 12:21:25 823 3.7 15.81 294 63.7 21.9 Scale 15.8 01/12/2019 12:21:29 761 3.7 15.79 269 63.9 22.2 01/12/2019 12:21:59 769 3.7 15.72 275 65.8 24.0 01/12/2019 12:22:29 796 3.8 15.68 257 67.6 25.9 01/12/2019 12:22:59 772 3.8 15.83 238 69.5 27.8 01/12/2019 12:23:29 756 3.8 15.94 218 71.4 29.7 01/12/2019 12:23:59 774 3.8 15.90 199 73.3 31.6 01/12/2019 12:24:29 750 3.8 15.84 187 75.2 33.5 01/12/2019 12:24:59 727 3.9 15.82 161 77.1 35.4 01/12/2019 12:25:29 785 4.1 15.82 172 79.1 37.4 01/12/2019 12:25:59 772 4.1 15.79 160 81.1 39.4 01/12/2019 12:26:29 772 4.1 15.80 154 83.2 41.5 01/12/2019 12:26:59 867 4.4 15.80 200 85.3 43.6 01/12/2019 12:27:29 847 4.4 15.75 188 87.5 45.8 01/12/2019 12:27:59 858 4.4 15.74 192 89.7 48.0 01/12/2019 12:28:29 830 4.3 15.77 248 91.9 50.2 01/12/2019 12:28:59 835 4.4 15.81 190 94.1 52.4 Page 11 of 14 wa MT6-02 wa4 Mooser Tooth am>na.e San/12/2019 asaner ConoroPhilli0s 146 nnneer 82837 Drte T6ne 246r tlxN Tr""m Preenn PSI Plow Rab 6/M OensltY LB/6 WRP P9 cMTTOTSLUR CMT_Sf0_VOL fieL SSI. MeuPSa 01/12/2019 12:29:39 845 4.4 15.77 204 97.0 55.3 Reset Total, Vol = 55.28 obl 01/12/2019 12:29:59 218 2.2 15.77 110 98.2 1.2 01/12/2019 12:30:12 200 2.2 15.76 93 98.7 1.7 water 01/12/2019 12:30:29 193 2.1 15.75 74 99.3 2.3 01/12/2019 12:30:59 294 2.6 15.75 100 100.4 3.4 01/12/2019 12:31:29 291 3.3 15.49 105 102.0 5.0 01/12/2019 12:31:59 297 3.3 15.14 83 103.7 6.7 01/12/2019 12:32:29 284 3.3 14.95 96 105.4 8.4 01/12/2019 12:32:59 282 3.3 14.82 60 107.0 10.0 01/12/2019 12:33:29 265 3.3 14.70 46 108.7 11.7 01/12/2019 12:33:59 694 5.7 14.47 115 110.4 13.4 01/12/2019 12:34:29 877 7.0 13.54 152 113.9 16.9 01/12/2019 12:34:59 97 0.8 12.68 42 116.9 19.9 01/12/2019 12:35:29 87 0.0 12.12 13 116.9 19.9 01/12/2019 12:35:59 61 0.0 12.05 64 116.9 19.9 01/12/2019 12:36:29 58 0.0 12.00 79 116.9 19.9 01/12/2019 12:36:39 59 0.0 11.99 72 116.9 19.9 Pest Total, Vol = 19.95 otl 01/12/2019 12:36:46 59 0.0 11.99 243 116.9 0.0 swan W ng 01/12/2019 12:36:5961 0.0 11.97 360 116.9 0.0 01/12/2019 12:37:29 158 0.0 11.95 366 116.9 0.0 01/12/2019 12:37:59 165 0.0 11.93 379 116.9 0.0 01/12/2019 12:38:29 66 0.011.91 376 116.9 0.0 01/12/2019 12:38:59 61 0.0 11.90 379 116.9 0.0 01/12/2019 12:39:29 61 0.0 11.88 377 116.9 0.0 01/12/2019 12:39:59 173 0.0 12.05 381 116.9 0.0 01/12/2019 12:40:29 171 0.0 8.92 372 116.9 0.0 01/12/2019 12:40:59 167 0.0 9.89 366 116.9 0.0 01/12/2019 12:41:29 168 0.0 12.19 374 116.9 0.0 01/12/2019 12:41:59 172 0.0 12.93 370 116.9 0.0 01/12/2019 12:42:29 176 0.0 13.29 204 116.9 0.0 01/12/2019 12:42:59 177 0.0 13.28 0 116.9 0.0 01/12/2019 12:43:29 188 0.0 13.32 -2 116.9 0.0 01/12/2019 12:43:59 188 0.0 13.32 2 116.9 0.0 01/12/2019 12:44:29 190 0.0 13.33 2 116.9 0.0 01/12/2019 12:44:59 185 0.0 13.33 3 116.9 0.0 01/12/2019 12:45:29 190 0.0 9.74 1 116.9 0.0 01/12/2019 12:45:59 190 0.0 9.77 -1 116.9 0.0 01/12/2019 12:46:29 188 0.0 9.75 1 116.9 0.0 01/12/2019 124659 190 0.0 9.70 0 116.9 0.0 01/12/2019 12:47:29 191 0.0 9.62 -1 116.9 0.0 01/12/2019 12:47:59 188 0.0 9.29 5 116.9 0.0 01/12/2019 12:48:29 189 0.0 9.14 -2 116.9 0.0 01/12/2019 12:48:59 187 0.0 9.03 -3 116.9 0.0 01/32/2019 12:49:29 188 0.0 8.94 -1 116.9 0.0 01/12/2019 12:49:59 185 0.0 8.86 -7 116.9 0.0 01/12/2019 12:50:29 189 0.0 8.75 -2 116.9 0.0 01/12/2019 12:50:59 188 0.0 6.48 -1 116.9 0.0 01/12/2019 12:51:29 186 0.0 8.45 •2 116.9 0.0 01/12/2019 12:51:59 188 0.0 8.45 -5 116.9 0.0 01/12/2019 12:52:29 189 0.0 8.45 -4 116.9 0.0 01/12/2019 12:52:59 177 0.0 8.45 -6 116.9 0.0 01/12/2019 12:53:29 63 0.0 8.43 -3 116.9 0.0 01/12/2019 12:53:59 64 0.0 8.41 -19 116.9 0.0 01/12/2019 12:54:29 66 0.0 8.40 -10 116.9 0.0 H9e 12014 Pa 13 of 14 Fle14 lab Slant CUIaaRT lab t1111abN Wall W6-02 Mooser Tooth Jw/12/2019 Co.=PNIUM 82837 MM T6M Tre." Rcw Da -.ft WRa CRT TOT}WR cw-S ,YOL R l4Ar a um Rata LB/B PBI BBL BBL dOfll PBI B/R 01/12/2019 12:55:29 228 4.8 8.38 -7 119.7 2.8 01/12/2019 12:55:59 228 4.8 8.37 -3 121.1 5.2 01/12/2019 12:56:29 223 4.6 6.37 -6 124.5 7.6 01/12/2019 12:56:59 223 4.8 8.36 -e 126.9 30.0 01/12/2019 12:5]:29 83 0.0 8.37 -12 127.3 10.4 01/12/2019 12:57:59 197 4.7 8.36 -12 128.9 12.0 01/12/2019 12:58:29 247 5.5 8.36 -16 131.6 14.6 01/12/2019 12:58:59 248 5.5 8.34 -17 134.3 1].4 01/12/2019 12:59:29 72 0.0 8.33 -14 136.6 19.7 01/12/2019 12:59:59 69 0.0 8.31 -11 136.6 19.] 01/12/2019 13:OD:29 64 0.0 8.31 -15 136.6 19.7 01/12/2019 13:00:59 64 0.0 8.31 0 136.6 19.7 01/12/2019 13:01:29 63 0.0 8.32 22 136.6 19.7 01/12/2019 13:01:59 65 0.0 8.27 30 136.6 19.7 01/12/2019 13:02:29 65 0.0 8.08 65 136.6 19.7 01/12/2019 13:02:59 82 2.7 8.00 68 136.7 19.7 01/12/2019 13:03:29 233 5.2 7.97 81 138.] 21.8 01/12/2019 13:03:59 83 1.9 7.93 98 139.8 22.9 01/12/2019 13:04:29 155 3.6 7.92 95 141.2 24.3 01/12/2019 13:04:59 223 4.8 7.90 105 143.4 26.5 01/12/2019 13:05:29 77 0.0 7.89 106 144.7 27.7 01/12/2019 13:05:59 111 3.4 7.89 100 145.6 28.6 01/12/2019 13:06:29 73 1.3 7.49 95 147.5 30.6 01/12/201913:06:59 72 0.0 0.01 116 349.0 32.1 01/32/2019 13:07:29 67 0.0 0.01 121 149.0 32.1 01/12/2019 13:07:59 67 0.0 0.00 138 149.0 32.1 01/12/2019 13:08:29 67 0.0 0.01 151 149.0 32.1 01/12/2019 13:08:59 69 0.0 0.01 381 149.0 32.1 01/12/2019 13:09:29 69 0.0 0.00 198 149.0 32.1 01/12/2019 13:09:59 69 0.0 0.00 212 149.0 32.1 01/12/2019 13:10:29 68 0.0 0.00 221 199.0 32.1 01/12/2019 13:10:59 ]0 0.0 0.00 231 149.0 32.1 01/12/2039 13:11:29 68 0.0 0.01 261 149.0 32.1 01/12/2019 13:11:59 70 0.0 0.00 264 149.0 32.1 01/12/2019 13:12:29 69 0.0 0.01 287 149.0 32.1 01/12/2019 13:12:59 71 0.0 0.00 332 149.0 32.1 01/32/2019 13:13:29 71 0.0 0.01 330 149.0 32.1 01/12/2019 13:13:59 69 0.0 0.00 354 149.0 32.1 01/12/2019 13:14:29 69 0.0 0.00 3T/ 149.0 32.1 Pa 13 of 14 W." Field lob SM1u Cudtemar Job Number MT6-02 Mooses Tooth Jan/12/2019 ConocomiMps 82837 Post Job summary ppe 14 010 aveTege pump Bales. bW/min Vaiume W Fhad 1.1e bbl SlurryN2 Mud Maximum Reb Tebi 000 Mud Spacer N2 2.9 ].1 55.2 0.0 38.3 haaMM preuun Summary. pal Bwkdywn Flub MauMum Flea) average Bump NuOb BmakdoWn Type Volume Dm -Ry 5297 69 201 bbl lb/gal An. M2 fta Iff Dlspmn ix Weber Temp .1UWd W SUd.W Vuyme bblSybm Wm T.- pert' ❑ To k % 51.6 19.9 bbl80 degF Qlalmeerer AuMUlaedBepmaeMauve wd.mbUnw Suparylwr CiIWleMea lou ❑ 1ob CpmPlebd Y❑ Nick SJOH us John Morrison ppe 14 010 Cement Liner Came it MT6-02 Cement Details Description Cementing Start Data Cementing End Date Wellbore Name Liner Cement 1/12/201912:00 11121201913:30 MT6-02 Comment Test lines to 3,000 psi. Pump 38A bbls 11.5 ppg mud push II, Mbc and pump 55.1 bbls 15.8 ppg cement, Pump 20 bbls water. Sting in and dispiace with 142 bbls 10.9 ppg LSND mud. Final circulation pressure at 2 bpm 720 psi. Cement in place at 13:30 hm. Observed no mud losses. Cement Stages Stage # 1 DescriptionObjective Top Depth (ftKB) Bottom Depth (ftKB) Full Retum? Vol Cement... Top Plug? Bim Plug? Liner Cement Cement T' SDL Liner 9,551.0 11,051.0 Yes 10.0 No No Q Pump Inst (bbllm... Q Pump Final (bbll... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No 3 2 2 730.0 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Dml Out Diameter (in) Comment Pumped via cement retainer @ 10,988, Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Eat Bun. (ftKB) Amount (aacka) Claes Volume Pumped (bbl) 55.3 Tail Cement 9,551.0 11,05151.0 263 G Yield (ft'Isaak) Mix M20 Ratio (gailsack) Free Water (%) Density gblgal) Plastic Viscosity (CP) Thickening Tlme (hr) CmprStr 1 (psi) 1.16 5.02 15.80 115.0 5.56 Additives Concentration Cone Unit label AdditiveTypo Page 111 Report Printed: 111 412 01 9 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: �j AOGCC a ATTN: Natural Resources Technician II 1 Alaska Oil &Gas Conservation Commision 333 W. 7th Ave, Suite 100 ..,y Anchorage, AK 99501 TRANSMITTALDATE TRANSMITTAL# 2 18 160 P7 -L) 2/g — /6 D Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, January 3, 2019 8:54 PM To: Beat, Andrew T Subject: Re: [EXTERNAL]Re: MT6-02 Operations Update (218-159) Andrew, Approval is granted to drill out the shoe track and obtain an FIT prior to running the CBL if required. A CBL will then be obtained. Thanx, Victoria Sent from my Phone On Jan 3, 2019, at 4:06 PM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, In case the incoming replacement part does not fix the E -Line unit, we would like to get your approval to drill out the 9-5/8" shoe track and get an FIT before obtaining a CBL. We will not drill additional footage beyond what is needed for an FIT and will still get the CBL. It will just be a change in order of operations. If the unit gets fixed as hoped we will perform the CBL first. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <yictoria.loepp@alaska.aov> Sent: Thursday, January 03, 2019 11:53 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]Re: MT6-02 Operations Update (218-159) Thank you; good game plan. Sent from my iPhone On Jan 3, 2019, at 11:40 AM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, We lost returns while pumping our Intermediate 1 cement job on MT6-02 (Doyon 19). We were battling unstable shales and had to set about 300' off bottom. We are currently rigging up E -Line to run a CBL so we can determine our top of cement. We expect the data between 4-5 PM this evening, maybe earlier if we are lucky. I will send you another email with that information and our requested plan forward for your approval. Let me know if you have any questions in the meantime. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Thursday, January 3, 2019 4:06 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]Re: MT6-02 Operations Update (218-159) Follow Up Flag: Follow up Flag Status: Flagged Victoria, In case the incoming replacement part does not fix the E -Line unit, we would like to get your approval to drill out the 9- 5/8" shoe track and get an FIT before obtaining a CBL. We will not drill additional footage beyond what is needed for an FIT and will still get the CBL. It will just be a change in order of operations. If the unit gets fixed as hoped we will perform the CBL first. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, January 03, 2019 11:53 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]Re: MT6-02 Operations Update (218-159) Thank you; good game plan. Sent from myiPhone On Jan 3, 2019, at 11:40 AM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, We lost returns while pumping our Intermediate 1 cement job on MT6-02 (Doyon 19). We were battling unstable shales and had to set about 300' off bottom. We are currently rigging up E -Line to run a CBL so we can determine our top of cement. We expect the data between 4-5 PM this evening, maybe earlier if we are lucky. I will send you another email with that information and our requested plan forward for your approval. Let me know if you have any questions in the meantime. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 8:49 AM To: Beat, Andrew T (Andrew.T.Beat@conocophillips.com) Subject: RE: MT6-02 CBL and Plan Forward Thanx for the cement job information. It is not necessary to meet at this time. More interested in the FIT and plans forward. From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 8:45 AM To: Beat, Andrew T (Andrew.T.Beat@conocophillips.com) <Andrew.T.Beat@conocophiIlips.com> Subject: RE: M76-02 CBL and Plan Forward Another question: Is there 300' of hole below the shoe? What if the FIT doesn't pass? Could you place cement in the hole versus a squeeze? Let me know your plans. From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 8:23 AM To: Beat, Andrew (Andrew.T.Beat (@conocophillips.com) <Andrew.T.Beat@conocophiIlips. com> Subject: FW: MT6-02 CBL and Plan Forward Andrew, Please forward the information below, however, you may move forward with the FIT which must pass to drill ahead. We will likely grant a waiver from the 250' TVD cement required. Will a CBL be run on the 7" right after the cement job? Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 7:54 AM To:'Beat, Andrew T' <Andrew.T.Beat@conocophillips.com> Subject: RE: MT6-02 CBL and Plan Forward Andrew, Please forward the cement job summary, log and cement job plots. Where is the free pipe indication on the log? Please have your log analyst interpret quality of cement, feet of cement and show the ^'170' TVD of good cement. Are you in town? Can someone come over and review? We are available anytime. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 7:33 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.aov> Cc: Hobbs, Greg S <Gree.S.Hobbs@conocophillips.com>; Marushack, Andy J <Andy.J.Marushack conocophilllps.com>; Njoku, Johnson <Johnson.Nioku@conocophi IIips.com>; Alexa, Kurt J <Kurt.J.Alexa@conocophi IIips.com>; Alvord, Chip <Chip.Alvord @conocophi IIips.com> Subject: MT6-02 CBL and Plan Forward Importance: High Victoria, Last night we logged the top of cement at 8,504' MD (6,899' TVD). Our casing shoe is at 8,742' MD (7,070' TVD) so we have 238' MD (171' TVD) of cement coverage on the backside of our Intermediate 1 casing. We would like to request a waiver from the 500' MD/250' TVD casing cement requirement (20 AAC 25.030 (d) (5)) to allow us to continue with planned operations without any remediation. Our Intermediate 2 casing will cover from the Alpine C reservoir to surface providing additional isolation to the zones exposed in Intermediate 1 and the cement job will be logged. We believe that with this additional barrier along with the 238' MD of cement placed behind the Intl casing that all requirements in 20 AAC 25.030 (a) are met. Please let me know if you have any questions or would like to discuss further. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office Schlumberger Cementing Job sport CernCAT v1.7 Well MT6-02 Client ConomPhillips Feld Alpine SIR No. Engineer Lance Kalivas Job Type 9 5/8" Intermediate Country United States lob Date 01-01-2019 Time Pressure Rate -- –Density — WHP Messages 16:08:25 16:38:00 17:08:00 PISM Dare - Blow Air Down Hard Un¢ Fluid Pads Hard line Low Pr 17:38:00 Trips tripped! High Pr High Pr Good MudPush Scaled 11.5 Pecet TOW, Vol - 1.23 boll Start MuciPush Down Hole 16:08:00 Shut Down Drop Bottom Plug Start Batdang Lead Cement Reset Total, Vol = 60.03 bbl Cement Scaled 12.5 pW 18:38:00 End lead Slum Start Satchim Tail Reset Total, Vol - 98.09 bbl Tail Scaled 15.6 Shut Down Drop 2 top plugs Reset Total, Vol = 48.82 bbl 19:08:00 Fresh water behind Swap to rig to drolace Reset Total, vol2bbl fire Rewe air down hard We 19:38:00 —' 20:08:00 20:38:00 21:08:00 21:38:00 22:08:00 22:38:00 23:08:00 23:30:54 hh:mm:ss °O° sa° mm am° '°°° smo °°° 'a ,a m ea s°a w yea rsn ma ua cam moo mm am° um v -n r.v PSI B/M le/G —PSI 01/02/2019 00:59:55 Schlumberger Cementing Service Report PaW 1 a 5 C Mcuaer Con=ftillips Jeb Number Wall MT6-02 lautlDn(lepM) 1476 Ik lumberearr Ifta PRUDHOE OTHER Jab Start Jan/01/2019 FleM Alpine FmmaMon Mama/Type DeHetlon deg DR SMa 12.3 in Wall MD 9016.0 ft WW WD 7218.0 ft County Stell/P Ixax Alaska MIF psi ON ST 163 degF BXCT 100 ftF pore Press. DraOMnt Ib/gal Wall llaatW AM/OWI III, Nama DOyan 19 OHNed Far SW Woe Via 1 -and CHkM/UPar Depth, R Slzb in We19K Ib/ft Rinow "KaMi 011akwe Z. WeN a. Neal Weu Typo Development 8506.0 9.6 40.0 N80 BUTT 0.0 0.0 0.0 O6141n9 Maid TypeMar, DenaIty lb/gal Mxtx, Vlara m, CP TuMnq/OrM pipe T/D M^ ft 9ka,ln Weight, lb/ft Wad. Tbresd Sarvics U..Job Cementing Type 9 5/8" Intermediate Max. A„awed Tub. PMaa psi N. Mlmvall MM. PMw P9 WH Copnaxtlan 2" 1502 Mrrarst101N/Open Nola Topp ft Bottom, ft WxA/ft Mo. atMmta Total IMaml service insnumona ft ft It ft R W. It it in Traet Down Casing DMWacanw nt vadat Typa 658.4 bbl Packer Depu R Tow" Val. bat Cairo Vol. Annular VOL 664.6 bbl bbl Openkale Val. bbl Casing/WNn9 eacurad ❑ S MSM VM.(N.WaMD prior M Cement Casing Tools 59ueev3ob UR Pre . MI Mata TYaa nD Squeese TyW PIP, Rotated I Pipe Recipar Md El a. DapU 8506.0 It Taxi Typo Nx. Centralizers Tax Muy 2 Bottom muga 1 MW Tao, Typo T.1 DeRA It Daman Head Typo Stpa Tool DlaM k Tall Pipe SMa In Job SNa l.w Por Jan/01/2019 brived an tacatlon Jan/0112019 have t atlon Jan/01/2019 faNar Type Floe[ TSD Pipe DepM ft DAM, DepM 8422.0 it SW. total yW- bbl Data Thai g4-br tlotlt Treating Maw P.. Rall PSI B/N Dewily Valu. rbTG_,YDL LB/D eel BSL WIN MMeape PSI 01/01/2019 16:08:25 67 0.0 6.80 0.0 0.0 1 Started AWuisi[bn 01/01/2019 16:10:55 65 0.0 6.80 0.0 0.0 4 01/01/2019 16:13:25 67 0.0 6.80 0.0 0.0 3 01/01/2019 16:15:55 68 0.0 6.80 0.0 0.0 1 01/01/2019 16:18:25 69 0.0 6.79 0.0 0.0 120 01/01/2019 16:20:55 66 0.0 6.79 0.0 0.0 123 01/01/2019 16:23:25 65 0.0 6.78 0.0 0.0 127 01/01/2019 16:25:55 65 0.0 6.78 0.0 0.0 110 01/01/2019 16:28:25 67 0.0 6.78 0.0 0.0 109 01/01/2019 16:30:55 68 0.0 6.78 0.0 0.0 110 01/01/2019 16:33:25 fib 0.0 6.78 0.0 0.0 109 01/01/2019 16:35:55 65 0.0 6.77 0.0 0.0 118 01/01/2019 1 16:38:25 67 1 0.0 6.77 0.0 0.0 116 01/01/2019 16:40:55 71 0.0 6.77 0.0 0.0 -178 01/01/2019 16:43:25 67 0.0 6.77 0.0 0.0 241 01/01/2019 16:45:55 68 0.0 6.77 0.0 0.0 201 01/01/2019 16:48:25 68 0.0 6.77 0.0 0.0 224 01/01/2019 16:50:55 65 0.0 6.76 0.0 0.0 245 01/01/2019 16:53:25 66 0.0 6.76 0.0 0.0 299 01/01/2019 16:55:55 68 0.0 6.76 0.0 0.0 344 01/01/2019 16:58:25 69 0.0 6.76 0.0 0.0 383 PaW 1 a 5 Wei MT6-02 fleltl Alpine 1e651MA, )an/01/2019 Cu4 r Conocomillipa .lab MunbT Cate Time 24 -hr dod T.." PHumare P51 Wow Mete a/M Cen4tT 18/G Volume MT STQ_ O NL BBL MMP PSI He.." 01/01/2019 17:03:25 68 0.0 6.76 0.0 0.0 379 01/01/2019 17:05:55 69 0.0 6.75 0.0 0.0 375 01/01/2019 17:08:25 68 0.0 6.76 0.0 0.0 381 01/01/2019 17:10:55 68 0.0 6.75 0.0 0.0 388 01/01/2019 17:13:25 67 0.0 6.75 0.0 0.0 391 01/01/2019 17:15:37 68 0.0 6.75 0.0 0.0 384 P9SM Cone 01/01/2019 17:15:55 68 0.0 6.75 0.0 0.0 385 01/01/2019 17:16:52 68 0.0 6.74 0.0 0.0 386 Blow Air Down Had We 01/01/2019 17:18:25 68 0.0 6.74 0.0 0.0 396 01/01/2019 17:20:23 87 0.0 6.75 0.0 0.0 172 Fluid Pack Held lYle 01/01/2019 17:20:55 85 0.9 6.75 0.1 0.1 170 01/01/2019 17:22:40 174 0.0 6.74 1.2 1.2 241 Low m 01/01/2019 17:23:08 14001 0.0 6.74 1 1.2 1.2 1511 Tripe tripped 01/01/2019 17:23:25 1388 0.0 6.74 1.2 1.2 1471 High Pf 01/01/2019 17:25:33 3996 0.0 6.74 1.2 1.2 4057 High PT Good 01/01/2019 17:25:55 159 0.0 6.74 1.2 1.2 218 01/01/2019 17:28:25 67 0.0 6.74 1.2 1.2 61 01/01/2019 17:30:55 67 0.0 6.74 1.2 1.2 62 01/01/2019 17:33:25 130 0.0 6.74 1.2 1.2 57 01/01/2019 17:35:55 143 0.0 6.75 1.2 1.2 72 01/01/2019 17:38:25 134 0.0 11.37 1.2 1.2 62 01/01/2019 17:39:02 135 0.0 11.76 1.2 1.2 66 MudP sh Sled 11.5 01/01/2019 17:39:18 134 0.0 11.67 1.2 1.2 71 Peet Total, Vol m 1.23 t01 01/01/2019 17:40:09 155 0.0 11.43 1.2 0.0 93 Start MudPuah Down Hole 01/01/2019 17:40:55 417 2.5 11.76 3.3 2.1 248 01/01/2019 17:43:25 499 3.2 11.38 9.9 8.7 278 01/01/2019 17:45:55 481 3.2 11.38 17.9 16.7 276 01/01/2019 17:48:25 612 4.0 11.44 26.2 25.0 321 01/01/2019 17:50:55 577 4.1 11.47 36.3 35.1 278 01/01/2019 17:53:25 594 4.1 11.34 46.4 45.2 298 01/01/2019 17:55:55 429 3.0 11.41 55.8 54.6 249 01/01/2019 17:58:09 157 0.0 11.86 61.3 60.0 103 Shut Down Drop Bottom Plug 01/01/2019 17:58:25 158 0.0 11.86 61.3 60.0 104 01/01/2019 18:00:55 158 0.0 8.83 61.3 60.0 64 01/01/2019 18:03:21 154 OA 8.67 61.3 60.0 54 Start Batdgng load Cement 01/01/2019 18:03:25 158 0.0 9.32 61.3 60.0 61 01/01/2019 18:05:55 160 0.0 12.55 61.3 60.0 80 01/01/2019 18:06:09 163 0.0 12.54 61.3 60.0 87 Peat Total, Vol =60.03 bbl 01/01/2019 18:06:29 163 0.0 12.54 61.3 0.0 87 Cement Sled 12.5 ppg 01/01/2019 18:08:25 503 3.1 11.99 66.8 5.5 216 01/01/2019 18:10:55 525 3.2 12.20 75.2 13.9 210 01/01/2019 18:13:25 465 2.9 12.31 83.1 21.8 188 01/01/2019 18:15:55 459 2.9 12.21 90.4 29.1 195 01/01/2019 18:18:25 557 3.6 12.22 99.6 38.4 186 01/01/2019 18:20:55 545 3.5 12.42 108.4 47.1 210 01/01/2019 18:23:25 526 3.5 12.21 117.1 55.8 182 01/01/2019 18:25:55 508 3.4 12.22 125.7 64.5 195 01/01/2019 18:28:25 502 3.4 12.08 134.4 73.2 147 01/01/2019 18:30:55 459 3.2 12.22 143.1 81.8 176 01/01/2019 18:33:25 467 2.7 12.27 150.2 88.9 221 01/01/2019 18:35:55 428 2.4 11.94 156.4 95.1 224 01/01/2019 18:37:52 150 0.0 12.02 159.3 98.1 64 End lead Slurry 01/01/2019 18:38:25 145 0.0 12.02 159.3 98.1 83 01/01/2019 18:40:55 128 0.0 8.47 159.3 98.1 66 Page 245 wen MT6-02 weld Algne ase Stan 3an/01/2019 C.A. Gori=Phillps 1o6 MeeAer wta nma 2 r Clack Tread" Praswro PSI Mew nate B/M nen WT u/a volume BN. MT Sfal_v BBL VMIP M51 Maa. 01/01/2019 18:42:56 129 0.0 7.22 159.3 98.1 58 Peet Total, Vol = 98.09 bbl 01/01/2019 18:43:25 127 0.0 8.38 159.3 0.0 59 01/01/2019 18:45:55 120 0.0 15.71 159.3 0.0 58 01/01/2019 18:47:08 199 0.0 15.58 159.3 0.0 56 Tall Seed 15.6 01/01/2019 18:48:25 828 3.6 15.46 163.2 3.8 368 01/01/2019 18:50:55 887 3.7 15.78 172.2 12.9 323 01/01/2019 18:53:25 950 4.0 15.80 181.9 22.6 346 01/01/2019 18:55:55 1000 4.0 15.77 191.9 32.5 342 01/01/2019 18:58:25 924 4.0 15.49 201.8 42.4 330 01/01/2019 19:00:47 132 0.0 15.38 208.2 48.8 7 Shut Down Drop 2 top plugs 01/01/2019 19:00:55 112 0.0 15.38 208.2 48.8 -7 01/01/2019 19:02:50 104 0.0 10.01 208.2 48.8 -29 Peet Total, Vol = 48.82 bbl 01/01/2019 19:03:25 104 0.0 9.66 208.2 0.0 0 01/01/2019 19:05:55 99 0.0 8.98 208.2 0.0 3 01/01/2019 19:07:46 100 0.0 8.80 208.2 0.0 25 Fresh ware behind 01/01/2019 19:08:25 553 4.0 8.77 210.0 1.8 246 01/01/2019 19:10:55 557 4.0 8.69 219.9 11.8 216 01/01/2019 19:13:13 92 0.0 8.64 228.3 20.1 -1 Swap W rig to displace 01/01/2019 19:13:25 88 0.0 8.63 228.3 20.1 14 01/01/2019 19:13:28 87 0.0 8.63 228.3 20.1 12 Peset Tobi, Vol - 20.09 bbl 01/01/2019 19:14:48 145 0.0 8.60 228.3 0.0 240 Mw Mr down hand line 01/01/2019 19:15:55 65 0.0 8.58 228.3 0.0 242 01/01/2019 19:18:25 66 0.0 9.35 228.3 0.0 246 01/01/2019 19:20:55 67 0.0 9.91 228.3 0.0 233 01/01/2019 19:23:25 70 0.0 8.97 228.3 0.0 199 01/01/2019 19:25:55 128 0.0 7.93 231.7 3.4 201 01/01/2019 19:28:25 106 0.0 7.49 231.7 3.4 179 01/01/2019 19:30:55 65 0.0 8.43 231.7 3.4 187 01/01/2019 19:33:25 67 0.0 8.42 231.7 3.4 170 01/01/2019 19:35:55 68 0.0 8.43 231.7 3.4 182 01/01/2019 19:38:25 65 0.0 8.41 231.7 3.4 172 01/01/2019 19:40:55 67 0.0 1 8.38 231.7 3.4 170 01/01/2019 19:43:25 65 0.0 7.34 231.7 3.4 1 173 01/01/2019 19:45:55 65 0.0 0.01 231.7 3.4 167 01/01/2019 19:48:25 66 0.0 0.00 231.7 3.4 174 01/01/2019 19:50:55 67 0.0 0.01 231.7 3.4 161 01/01/2019 19:53:25 85 0.0 5.68 231.7 3.4 180 01/01/2019 19:55:55 64 0.0 5.32 231.7 3.4 167 01/01/2019 19:58:25 67 0.0 0.00 231.7 3.4 175 01/01/2019 20:00:55 65 0.0 0.00 231.7 3.4 208 01/01/2019 20:03:25 66 0.0 0.00 231.7 3.4 200 01/01/2019 20:05:55 66 0.0 0.00 231.7 3.4 190 01/01/2019 20:08:25 66 0.0 0.00 231.7 3.4 195 01/01/2019 20:10:55 64 0.0 0.00 231.7 3.4 192 01/01/2019 20:13:25 67 0.0 0.00 231.7 3.4 194 01/01/2019 20:15:55 64 0.0 0.00 231.7 3.4 185 01/01/2019 20:18:25 65 0.0 0.01 231.7 3.4 186 01/01/2019 20:20:55 65 0.0 0.01 231.7 3.4 198 01/01/2019 20:23:25 63 0.0 0.00 231.7 3.4 188 01/01/2019 20:25:55 65 0.0 -0.00 231.7 3.4 204 01/01/2019 20:28:25 62 0.0 0.00 231.7 3.4 195 01/01/2019 20:30:55 62 0.0 0.01 231.7 3.4 210 01/01/2019 20:33:25 63 0.0 0.01 231.7 3.4 216 01/01/2019 20:35:55 63 0.0 0.00 231.7 3.4 215 sage 3 of 5 Well MT6-02 Fle14 Np m 1069teR Jan/01/2019 COrtamar commPo19iD5 1e6 M61P64r Date 71.4 2"r Uo4k TrOetlnP PlacwN P9i flew Data G/M 1//G YWm6 JWG-WM. B4 Gk "P MO"". m 01/01/2019 20:40:55 fit 0.0 0.01 231.7 3.4 211 01/01/2019 20:43:25 61 0.0 0.00 231.7 3.4 232 01/01/2019 20:45:55 64 0.0 0.00 231.7 3.4 206 01/01/2019 20:48:25 65 0.0 -0.00 231.7 3.4 215 01/01/2019 20:50:55 63 0.0 0.00 231.7 3.4 214 01/01/2019 20:53:25 62 0.0 0.01 231.7 3.4 222 01/01/2019 20:55:55 62 0.0 0.00 231.7 3.4 206 01/01/2019 20:58:25 63 0.0 0.01 231.7 3.4 208 01/01/2019 21:00:55 64 0.0 0.01 231.7 3.4 211 01/01/2019 21:03:25 64 0.0 0.00 231.7 3.4 212 01/01/2019 21:05:55 63 0.0 0.01 231.7 3.4 165 01/01/2019 21:08:25 64 0.0 0.00 231.7 3.4 168 01/01/2019 21:10:55 63 0.0 0.01 231.7 3.4 155 01/01/2019 21:13:25 64 0.0 0.01 231.7 3.4 197 01/01/2019 21:15:55 63 0.0 0.01 231.7 3.4 541 01/01/2019 21:18:25 64 0.0 0.01 231.7 3.4 1446 01/01/2019 21:20:55 65 0.0 0.00 231.7 3.4 2037 01/01/2019 21:23:25 64 0.0 0.00 231.7 3.4 1765 01/01/2019 21:25:55 63 0.0 0.00 231.7 3.4 2010 01/01/2019 21:28:25 63 0.0 0.00 231.7 3.4 2303 01/01/2019 21:30:55 63 0.0 0.00 231.7 3.4 2395 01/01/2019 21:33:25 62 0.0 0.01 231.7 3.4 2497 01/01/2019 21:35:55 63 0.0 0.01 231.7 3.4 2536 01/01/2019 21:38:25 63 0.0 0.00 231.7 3.4 2469 01/01/2019 21:40:55 64 0.0 0.00 231.7 3.4 2701 01/01/2019 21:43:25 63 0.0 0.00 231.7 3.4 2852 01/01/2019 21:45:55 64 0.0 0.00 231.7 3.4 2883 01/01/2019 21:48:25 64 0.0 0.00 231.7 3.4 2954 01/01/2019 21:50:55 63 0.0 0.01 231.7 3.4 3011 01/01/2019 21:53:25 62 0.0 0.01 231.7 3.4 2978 01/01/2019 21:55:55 65 0.0 0.01 231.7 3.4 2935 01/01/2019 21:58:25 65 0.0 0.00 231.7 3.4 2664 01/01/2019 22:00:55 63 0.0 0.00 231.7 3.4 2427 01/01/2019 22:03:25 62 0.0 0.00 231.7 3.4 2240 01/01/2019 22:05:55 61 0.0 0.00 231.7 3.4 2065 01/01/2019 22:08:25 63 0.0 0.01 231.7 3.4 2045 01/01/2019 22:10:55 64 0.0 0.00 231.7 3.4 2064 01/01/2019 22:13:25 63 0.0 0.01 231.7 3.4 2321 01/01/2019 22:15:55 63 0.0 0.00 231.7 3.4 2329 01/01/2019 22:18:25 63 0.0 0.00 231.7 3.4 2326 01/01/2019 22:20:55 62 0.0 0.00 231.7 3.4 2323 01/01/2019 22:23:25 63 0.0 0.00 231.7 3.4 2321 01/01/2019 22:25:55 62 0.0 0.00 231.7 3.4 2385 01/01/2019 22:28:25 61 0.0 0.00 231.7 3.4 2493 01/01/2019 22:30:55 65 0.0 0.00 231.7 3.4 2533 01/01/2019 22:33:25 61 0.0 0.00 231.7 3.4 2592 01/01/2019 22:35:55 64 0.0 0.00 231.7 3.4 2571 01/01/2019 22:38:25 60 0.0 0.01 231.7 3.4 2624 01/01/2019 22:40:55 62 0.0 0.00 231.7 3.4 2618 01/01/2019 22:43:25 61 0.0 0.00 231.7 3.4 2638 01/01/2019 22:45:55 630.0 0.00 231.7 3.4 2731 01/01/2019 22:48:25 62 0.0 0.00 231.7 3.4 2488 01/01/2019 22:50:55 62 0.0 0.00 231.7 3.4 2567 01/01/2019 22:53:25 62 0.0 0.00 231.7 3.4 2822 P."403 well MT6-02 fleltl Alpine Sal, Sae )an/01/2039 CYmemer Conixomillix ]al, NYlrll,el Data Time 24hr ela9[ Treagng Prassura Pal Now Nota BIN Cannily ID/D Vallrllla NNL W-sm_VDL !K "I' Massage Kl 01/01/2019 22:58:25 63 0.0 0.00 231.7 3.4 3284 01/01/2019 23:00:55 61 0.0 0.00 231.7 3.4 3490 01/01/2019 23:03:25 61 0.0 0.00 231.7 3.4 3480 01/01/2019 23:05:55 60 0.0 0.01 231.7 3.4 3477 01/01/2019 23:08:25 61 0.0 0.01 231.7 3.4 2721 01/01/2019 23:10:55 62 0.0 0.00 231.7 3.4 -3 01/01/2019 23:13:25 61 0.0 0.00 231.7 3.4 1 01/01/2019 23:15:55 60 0.0 0.01 231.7 3.4 1 01/01/2019 23:18:25 61 0.0 -0.00 231.7 3.4 10 01/01/2019 23:20:55 61 0.0 0.00 231.7 3.4 7 01/01/2019 23:23:25 63 0.0 0.00 231.7 3.4 6 01/01/2019 23:25:55 60 0.0 0.00 231.7 3.4 7 Post lob Summary lags S ar s Average FmrP Rsteep l,hl/mla Valume M Rule IMee+ae, hM Gunry 3.3 NS Nue Mmclmum Rata 4.2 Tebl&arty 146.8 Mud 0.0 sparer 60.0 N2 Treating Pressure Summary, Pi scesaeuwn Pluie Maximum 4031 Mnal 58 AverageBump 168 muga -lallewn TyPa ValmYe bbl Degalq Ib/gal Avg. M2 Permnt % Designee Slung Volume 145.4 bbl Displarament 0.0 bbl Mh watm Temp AegF Dement arnratee b Surface) Ej Velume bbl washes Tnru Pats Te It Customer ar Authorized Representative Kenny Harding SChlu abe supervisor Lance Kallva5 arcuiWan Lam ❑% l4l, Canpletag - lags S ar s Cement MT6-02 intermediate Casing Cetne Cement Details Description Intermediate Casing Cement Cementlng Start Date 1/1/2019 16:00 Cementlng End Date 1/112019 23:00 Wellbore Name MT6A2 Comment SLB pumped 60 bbl Mud Push, 98 bbl 12.2 ppg Lead cement, 48.8 bbl 15.8 ppg Tail cement. Kicked out with 20 bbl water. Rig displaced with 638 bbl LSND. Bottom plug landed on time, @ 490 bbl into displacement, pressure built up to 3000 psi, packed off and lost returns. 110 bbl lost to formation. Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Top Depth (ftKS) 1000 feet of cement for 7,742.5 I drilling ahead Bottom Depth (ttKB) 8,742.5 full Return? No V01 Cement... Top PWg7 Yes Btm Plug? Yes O Pump Init (bblim... 4 O Pump Final (bbll... 3 D Pump Avg (bbb... 3 P Pump Final (psl) 3,080.D P Plug Bump (psi) 3.080.0 Recip? No Stroke (n) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (fWB) Drill Out Diameter (in) Comment Lost returns at 490 bbl into displacement, packoff and pressure up to 3100 psi. Lost 110 bbl cement to formation. Cement Fluids & Additives Fluid Fluid TypeFluid Intermediate Cement Description Estimated Top (nKB) 7,742.5 Est Bum (nKB) 8,115.0 Amoum (sacks) 239 Class Volume G 98.0 Pumped (bbl) Yield (ft'/sack) 2.30 Mix H2O Ratio (gailsack) 13.23 Free Water (%) Dansiry (Ib/gat) 1220 Plastic Viscosity [cP) 12.0 Thickening Tlma (hr) CmprStr 5.00 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftK81 8,175.0 Est 82" (nKB) 8,742.5 Amount (sacks) 236 Ciass Volume G 48.8 Pumped (bbl) Yield (ft /sack) 1.16 Mix H2O Ratio (gallsack) 5.06 Free Water I %) Density (Iblgal) 15.80 Plastic Viscoslry (cP) 124.0 Thickening Time (hr) 5.50 CmprStr t (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 114/2019 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 9:26 AM To: 'Beat, Andrew T' Subject: RE: [EXTERNAL)RE: M76-02 CBL and Plan Forward Approval is granted to drill out the shoe track and 20' of new formation and obtain an FIT. Would like to see the FIT results before approval is granted to drill ahead. I will be available. Just give me a heads up. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 9:21 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: (EXTERNAL)RE: MT6-02 CBL and Plan Forward Victoria, Will do. To make sure I understand correctly, we have approval to at least drill out the shoe track and 20' of new formation to take an FIT. If that FIT passes, do we have approval to continue on with the remaining well operations? Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, January 04, 2019 9:17 AM To: Beat, Andrew <Andrew.T.Beat @conocophiI ips.com> Subject: RE: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Andrew, Please forward the results of the FIT including plot as soon as available. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 9:00 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: RE: [EXTERNAL)RE: MT6-02 CBL and Plan Forward Victoria, Regarding the CBL of the Int2 cement job, as long as the execution goes per plan we would log it with a sonic tool in the liner running BHA as we have done in the past. So it would not be immediately after pumping. However, if we suspected that there were issues with the execution then we would log before drilling ahead. There is —300' of hole below the shoe. If the FIT did not pass then we would squeeze cement below the shoe allowing it to push into wherever was leaking. We feel confident that the shoe is competent but we did lose circulation so that fracture may be below us and could cause a low LOT. In either case, our first play would be to squeeze the shoe. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, January 04, 2019 8:45 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Another question: Is there 300' of hole below the shoe? What if the FIT doesn't pass? Could you place cement in the hole versus a squeeze? Let me know your plans. From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 8:23 AM To: Beat, Andrew T (And rew.T.Beat@conocophillips.com) <Andrew.T.Beat@conocophillips.com> Subject: FW: MT6-02 CBL and Plan Forward Andrew, Please forward the information below, however, you may move forward with the FIT which must pass to drill ahead. We will likely grant a waiver from the 250' TVD cement required. Will a CBL be run on the 7" right after the cement job? Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 7:54 AM To: 'Beat, Andrew T' <Andrew.T.Beat@conocophillips.com> Subject: RE: MT6-02 CBL and Plan Forward Andrew, Please forward the cement job summary, log and cement job plots. Where is the free pipe indication on the log? Please have your log analyst interpret quality of cement, feet of cement and show the ^'170' TVD of good cement. Are you in town? Can someone come over and review? We are available anytime. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocoPhil Iips.com> Sent: Friday, January 4, 2019 7:33 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Hobbs, Greg 5 <Greg.S.Hobbs@conocophillips.com>; Marushack, Andy 1 <Andy.J.Marushack@conocophillips.com>; _ Njoku, Johnson <Johnson.Nioku@conocophilIips.com>; Alexa, Kurt J <Kurt.J.Alexa@conocophiIIips.com>; Alvord, Chip <Chip.Alvord @conocophi IIips.com> Subject: MT6-02 CBL and Plan Forward Importance: High Victoria, Last night we logged the top of cement at 8,504' MD (6,899' TVD). Our casing shoe is at 8,742' MD (7,070' TVD) so we have 238' MD (171' TVD) of cement coverage on the backside of our Intermediate 1 casing. We would like to request a waiver from the 500' MD/250' TVD casing cement requirement (20 AAC 25.030 (d) (5)) to allow us to continue with planned operations without any remediation. Our Intermediate 2 casing will cover from the Alpine C reservoir to surface providing additional isolation to the zones exposed in Intermediate 1 and the cement job will be logged. We believe that with this additional barrier along with the 238' MD of cement placed behind the Intl casing that all requirements in 20 AAC 25.030 (a) are met. Please let me know if you have any questions or would like to discuss further. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 9:27 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL)RE: MT6-02 CBL and Plan Forward Follow Up Flag: Follow up Flag Status: Flagged Roger that. Results will probably come sometime this evening. I'll touch base with you tonight if it's going to be later. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, January 04, 2019 9:26 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: RE: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Approval is granted to drill out the shoe track and 20' of new formation and obtain an FIT. Would like to see the FIT results before approval is granted to drill ahead. I will be available. Just give me a heads up. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 9:21 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: RE: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Victoria, Will do. To make sure I understand correctly, we have approval to at least drill out the shoe track and 20' of new formation to take an FIT. If that FIT passes, do we have approval to continue on with the remaining well operations? Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Friday, January 04, 2019 9:17 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: RE: [EXTERNAL]RE: M76-02 CBL and Plan Forward Andrew, Please forward the results of the FIT including plot as soon as available. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 9:00 AM To: Loepp, Victoria T (DOA) <victoria loepp@alaska.eov> Subject: RE: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Victoria, Regarding the CBL of the Intl cement job, as long as the execution goes per plan we would log it with a sonic tool in the liner running BHA as we have done in the past. So it would not be immediately after pumping. However, if we suspected that there were issues with the execution then we would log before drilling ahead. There is —300' of hole below the shoe. If the FIT did not pass then we would squeeze cement below the shoe allowing it to push into wherever was leaking. We feel confident that the shoe is competent but we did lose circulation so that fracture may be below us and could cause a low LOT. In either case, our first play would be to squeeze the shoe. Thanks, Andrew 1303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Sent: Friday, January 04, 2019 8:45 AM To: Beat, Andrew T <Andrew.T.Beat @conocophi Ili ps.com> Subject: [EXTERNAL]RE: MT6-02 CBL and Plan Forward Another question: Is there 300' of hole below the shoe? What if the FIT doesn't pass? Could you place cement in the hole versus a squeeze? Let me know your plans. From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 8:23 AM To: Beat, Andrew T (And rew.T.Beat@conocophillips.com) <Andrew.T Beat @conocophi Ilips.com> Subject: FW: MT6-02 CBL and Plan Forward Andrew, Please forward the information below, however, you may move forward with the FIT which must pass to drill ahead. We will likely grant a waiver from the 250' TVD cement required. Will a CBL be run on the 7" right after the cement job? Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Friday, January 4, 2019 7:54 AM To:'Beat, Andrew T' <Andrew T Beat@conocophillips.com> Subject: RE: MT6-02 CBL and Plan Forward Andrew, Please forward the cement job summary, log and cement job plots. Where is the free pipe indication on the log? Please have your log analyst interpret quality of cement, feet of cement and show the —170' TVD of good cement. Are you in town? Can someone come over and review? We are available anytime. Thanx, Victoria From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 4, 2019 7:33 AM To: Loepp, Victoria T (DOA) <victoria.loePP@alaska.eov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.eov> Cc: Hobbs, Greg S <Gree.S.Hobbs@conocophillips.com>; Marushack, Andy J <Andy.J Marushack@conocophillips.com>; Njoku, Johnson <Johnson.Nioku@conocophill ips.com>; Alexa, Kurt 1 <Kurt.J.Alexa@conocophillips.com>; Alvord, Chip <Chip.Alvord conocophillips.com> Subject: MT6-02 CBL and Plan Forward Importance: High Victoria, Last night we logged the top of cement at 8,504' MD (6,899' TVD). Our casing shoe is at 8,742' MD (7,070' TVD) so we have 238' MD (171' TVD) of cement coverage on the backside of our Intermediate 1 casing. We would like to request a waiver from the 500' MD/250' TVD casing cement requirement (20 AAC 25.030 (d) (5)) to allow us to continue with planned operations without any remediation. Our Intermediate 2 casing will cover from the Alpine C reservoir to surface providing additional isolation to the zones exposed in Intermediate 1 and the cement job will be logged. We believe that with this additional barrier along with the 238' MD of cement placed behind the Intl casing that all requirements in 20 AAC 25.030 (a) are met. Please let me know if you have any questions or would like to discuss further. Thank you, Andrew Beat Senior Drilling Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office Loepp Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Saturday, January 5, 2019 8:51 AM To: Beat, Andrew T Subject: Re: MT6-02 Intl FIT Follow Up Flag: Follow up Flag Status: Completed Andrew, Approval is granted to proceed with the approved well plan. Victoria Sent from my Whone On Jan 5, 2019, at 8:31 AM, Beat, Andrew T <Andrew T Beat(a)conocophillips.com> wrote: Victoria, Attached are the results of the FIT taken below the Intl shoe. Are we approved to proceed as planned with the remainder of the well? Thanks, Andrew (303)378-8881 <MT6-02 Int 1 Casing Test - 8.75 FIT- 9046.pdf> 1 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Graham Alvord 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 �.a ogcc.a laska.gov Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-02 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-160 Surface Location: 239' FNL, 3115' FEL, SEC. 6, TION, R3E, UM Bottomhole Location: 4490' FNL, 2286' FEL, SEC. 13, TI IN, R2E, 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, Hollis S. French Chair DATED this day of December, 2018. STATE OF ALASKA ALJ .A OIL AND GAS CONSERVATION COMMP ON PERMIT TO DRILL 90 AAc 96 nnF RECEIVED NOV L 8 2018 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service- WAG 21 Service - Disp ❑ 1c. Specify I�'�yw-�)-�,'�,�, r: Drill ❑✓ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service- Winj ❑ Single Zone ❑� Coalbed G)S L7" Gds Rydra es ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. cij MT6-02 3. Address: 6. Proposed Depth: 1211r/ M 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 22669 TVD: 7809 Greater Mooses Tooth Unit Lookout Pool 4a. Location of Well (Governmental Section): 7. PropertyDesig dation: Surface: 239' FNL, 3115' FEL, Sec. 6, T10N, R3E, UM • r r (AA)81818, 92346, 81798, 92345, 81743 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 4079' FNL, 1861' FEL, Sec. 30, T11 N, R3E, UM 932553, 340761, 932533, 340760 12/25/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4490' FNL, 2286' FEL, Sec. 13, T11 N, R2E, UM 1208, 600, 607, 3837, 640 2289' to AA092340 t 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 89. 15. Distance to Nearest Well Open Surface: x- 317115 y- 5945564 Zone -4 GL / BF Elevation above MSL to Same Pool: 2187' to MT6-03 16. Deviated wells: Kickoff depth: 1 318 feet 17. Maximum Potential Pressures in psig (see ) Maximum Hole Angle: 91.Q gree Downhole: 3810 Surface: 3015 18. Casing Program: Specifications (IF Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD MD TVD (including stage data) 42" 20" 94 H-40 Welded 80 34 115 115 10 yds 16" 13.375" 68 L-80 BTC -M 2066 34 2100 2036 � sx 11.0 ppg DeepCmte,330 sx 15.8 ppg G 12.25" 9.625" 40 L-80 TXP 8430 34 8464 6868 218 sx 15.8 ppg tail M7877 8.75" 7.0" 26 L-80 Blue 11145 34 11179 7905 230 sx 15.8 ppg tail 6" 4.5" 12.6 L-80 Blue 11690 10979 22669 7809 uncemented pert pup liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes❑ No 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch e Drilling Program Seabed Report B Time v. Depth Plot Shallow Hazard Analysis Drilling Fluid Program B 20 AAC 25.050 requirementse 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. -15 Contact Name: Andrew Beat Al Authorized Name: Graham Alvord (265-6120) Contact Email: andrew1beat CO .Com Authorized Title: Drilling Manager Contact Phone: 907 265-6341 Authorized Signature: �. l/^�" Date: Z -O fe Commission Use Only Permit to DrillAPI Number: Permit Approval See cover letter for other Number: I — A 50- �D3� �' '0� —OO Date: I requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coa Rbetl methane, gas hydrates, or gas contained in shales: Other:l3 oP a Samples req'd: Yes E]No[T Mud log req'd: Yes❑ Noy s4j /� H2S�6ob measures: Yes No ❑ y� ❑ [� Directional svy req'd: Yes [�]' NoE] l� etc eption req'd: Yes ❑ Noy Inclination -only svy req'd: Yes E] NoEq� ;e Clic �Z � J'ht Post initial injection MIT req'd:Yes�No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I Z t I I Form 10- (f �/ /��f/ l' 401 Revised 5/2 17 This permit is valid for 2 o r*/����� Submit Form and rovat per 20 AAC 25.005 g) /Attachments in Duplicate ILIX" a / y ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 28th, 2018 Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT6-02 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the MT6 drilling pad. The intended spud date for this well is December 25, 2018. It is intended that Doyon Rig 19 be used to drill the well. MT6-02 is planned to be a horizontal Alpine C sand injector. The 16" surface hole will TD above the C-30 sand and then 13- 3/8" casing will be set and cemented to surface. The intermediate hole will be drilled in two sections to mitigate issues with shale instability over the long interval. The 12-1/4" intermediate #1 section will be drilled into the top of the HRZ. A 9-5/8" casing string will be set and cemented from TD to secure the shoe and cover 500' above any hydrocarbon -bearing zones. The second intermediate will be drilled with one of two options, ultimately landing in the Alpine sand. Option 1, a 7" steerable liner drilling assembly consisting of a 6" pilot BHA ahead of the casing shoe and incorporate a 8-3/4" underreamer for increased annular clearance. The drilling assembly inner string will then be tripped and a cement assembly run into the hole to cement the 7" drilling liner annulus. Option 2, will use an 8-3/4" drilling assembly and under reamed to 10 ''/d'. The section will then be lined with a 7" Liner. Managed Pressure Drilling technology will also be utilized to assist with providing stability through the HRZ, Kalubik, and Miluveach formations. The drilling assembly inner string will then be tripped and a cement assembly run into the hole to cement the 7" drilling liner annulus. The production interval will be a 6" horizontal that will be geo-steered in the Alpine sand. The well will be completed as an injector with a 4.5" pre -perforated liner and tied back to surface with a 4.5" tubing string. It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) 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 Andrew Beat at 265-6341 (andrew.t.beat@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, i�, h cc: JoT6-02hnson Well File /Ann Haggerty -Sherrod ATO 1530 \ Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Andrew Beat John Cookson ATO 1750 Drilling Engineer Applica or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 MT6-02 Application for Permit to Drill Document ConomPhilfips Table of Contents 1. Well Name (Requirements of 20 AAC25.005 (f))............................................................ 3 2. Location Summary (Requirements of20AAC 25.005(c)(2)) ............................................ 3 Requirements o170 AAC 25.050(b)....................................._...................................................................... 3 3. Blowout Prevention Equipment Information (Requirements of20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of20 AAC 25.005 (c)(4)) ........................ 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005 (c')(5))......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) .......... 5 7. Diverter System Information (Requirementsof20AAC25.005(c)(7)).........................5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of20AAC 25.005 (c)(10)) .........................................7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ........................ 7 12. Evidence of Bonding (Requirements gf20AAC 25.005 (c)(12)) ...................................7 13. Proposed Drilling Program (Requirements of'20AAC 25.005 (c)(13)) .........................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 (Requirements of 20 AAC 25.005(c)(14))............................................................................. 7 15. Attachments............................................................................................................... 8 Attachment I Cement Sumrnary................................................................................................................. 8 MT6-02 PTD Page 1 of 14 Printed. 28 -Nov -18 Attachment 2 Drilling Hazards Summary Attachment Completion Schematic....... Attachment 4 Area of Review .................. Attachment 5 Directional Plan .................. MT6-02 PTD Page 2 of 14 Printed: 28 -Nov -18 Applicai or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 1. Well Name (Requirements of20AAC25.005 (n) The well for which this application is submitted will be designated as MTU MT6-02. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 239' FNL, 3115' FEL, Sec. 6, TION, R3E, UM NAD 1927 Northings: 5,945,564 Eastings: 317,115 RKB Elevation I 89.3' AMSL Pad Elevation 52.1'AMSL To of Productive Horizon eel 4079' FNL 1861' FEL, Sec. 30, T11N, R3E, UM NAD 1927 Northings: 5,952,252 Eastings: 318,505 Measured Depth, RKB: 11,159' Total Vertical Depth, RKB: 7,847' Total Vertical Depth, SS: 7,758' Total Depth Toe 4490' FNL 2286' FEL, Sec. 13, T11N, R2E, UM NAD 1927 Northings: 5,962,529 Eastings: 313,343 Measured Depth, RKB. E,669' Total Vertical Depth, RKB: 7,809' Total Vertical Depth, SS: 7,720' Requirements of 20 AAC 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. MT6-02 PTD Page 3 of 14 Printed. 28 -Nov -18 Applird 4. Drilling Hazards Information(Requirementsof20AAC25.005(c)(4)) or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD(ft) Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 115 / 115 10.9 52 54 13.375 2100/2036 14.5 918 1332 9.625 8464/6868 13.5 3356 2835 7 11179/7905 12.5 3625 2825 4.5 22669/7809 12.5 3605 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP = Anticipated Surface pressure in psi \ FG = Fracture gradient at the casing seat in lb/gal 3110 0.052 = Conversion from Ib/gal to psi/ft 0.1 -Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling below conductor casing (2011) ASP = [(FG x 0.052) - 0.1] D = [(10.9 x 0.052) - 0. 1 ] x 115=54 psi OR ASP = FPP - (0.1 x D) = 918 - (0.1 x 2036) = 714 psi 2. Drilling below surface casing (13-3/811) ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1 ] x 2036' = 1332 psi OR ASP = FPP - (0.1 x D) = 3356 - (0.1 x 6868') = 2670 psi 3. Drilling below intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.1 ] D = [(13.5 x 0.052) - 0.1 ] x 6868 = 4135 psi OR ASP = FPP - (0.1 x D) = 3625- (0.1 x 7905') = 2835 psi MT6-02 PTD Page 4 of 14 Printed.., 28 -Nov -18 Applica( or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 4. Drilling below production liner (7) M10 ASP = [(FG x 0.052) — 0.11 D = [(12.5 x 0.052) — 0.1 ] x 7905 = 4350 psi ASP = FPP — (0.1 x D) = 3605 — (0.1 x 7809) = 2825 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC 25.005 (c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Csg/Tbg Hole Size Weight Grade Conn. Length Top MD/TVD Btm MD?VD Cement Program OD (in) (167ft) (ft) (h) (ft) 20 42 94 H-40 Welded 80 Surf 115/115 Cemented to surface with 10 yds slurry H563/ Cement to Surface with 13-3/8 16 68 L-80 Up Surf 2,100 / 2,036 964 sx DeepCrete Lead at 11.0 ppg, 330 330 sx Class G Tail Slurry at 15.8 ppg TXP/ 9-5/8 12-1/4 40 L-80 TN -80 8,449 Surf 8,464 / 6,868 218 sx Class G Tail at 15.8 ppg HC 7 63/4 26 L-80 Blue 11,142 Surf 11,179 / 7,905 230 sx Class G Tail at 15.8 ppg 4-1/2 n/a 12.6 EL -80 Surf 10,979 / 7,877 n/a 41/2 6 12.6 jBlue10,942 11,690 10,979 / 7,877 22,669 / 7,809 Uncemeneted open hole liner w/ pre - perforated pup joints 7. Dlverter System Information (Requirements of20AAC25.005(c)(7)) It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. MT6-02 PTD Page 5 of 14 Printed: 28 -Nov -18 Applical or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 8. Drilling Fluid Program(Requiremenrsof20AAC25.005(e)(8)) Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight <I0.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid FloPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-02 PTD Page 6 of 14 Printed: 28 -Nov -18 Surface Intermediate Intermediate Production #1 #2 Hole Size in. 16 12.25 6.0 x 8.75 6.0 Casing Size in. 13.375 9.625 7 4.5 Density PPG 9.0-10.0 9.4-10.0 10.0-11.0 8.8 PV cP13 10 10 15 YP Ib./lftz 35-50 20-28 20-28 15-20 Funnel Viscosity s/qt. 200 40-50 40-50 60-80 Initial Gels Ib./100 50 10 10 10 10 Minute Ib./100 Gels ftz 60 15 20 15 API Fluid cc/30 Loss min. N.C. —15.0 5.0 5.0 4.0 HPHT Fluid cc/30 Loss min. n/a 8.0-12.0 8.0-12.0 10.0 PH 1 11.0 1 9.5-10.0 9.5-10.0 9.0-9—.5 Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight <I0.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid FloPro weighted to 8.8-9.5 ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. MT6-02 PTD Page 6 of 14 Printed: 28 -Nov -18 Applica or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 9. Abnormally Pressured Formation Information (Requirements of20AAC25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis(Requirements of20AAC25.005(c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding(Requirements of20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program(Requirements of20 AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. End MT6-02PH PTD and begin MT6-02 PTD. 2. Perform either an open hole sidetrack or cemented sidetrack from MT6-02PH. 3. Drill 6" horizontal hole to section TD (LWD Program: GR/ Azimuthal RES). 4. Circulate the hole clean and POOH with drilling BHA. 5. Run in hole with 4.5" liner with pre -perforated pup joints on 4" drill pipe (CBL 7" Liner on way out of hole) 6. Set liner top packer and release from liner. 7. Displace well to kill weight brine. 8. Run 4.5" upper completion. Space out and land hanger. 9. Install HP back pressure valve and pressure test hanger seals to 5000 psi. Nipple down BOP. 10. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove back pressure valve. 11. Test tubing to 3500 psi/ 30 min and chart. Test tubing -casing annulus separately to 3300 psi / 30 mins and chart. 12. Shear circulation valve in GLM. Circulate tubing to diesel and install freeze protection in the annulus. 13. Set BPV and secure well. RDMO. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT6-02 will be injected into a permitted surface casing x production casing annulus on MT6/CDI. The MT6-02 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1200' TVD. Significant hydrocarbon zones include only the Alpine sand based on pre -drill interpretations. There will be 500' MD, or 250' TVD, whichever is greater, of cement placed above the top of the Alpine reservoir. Once MT6-02 has been drilled and completed, consideration may be given to permit this well for annular injection. MT6-02 PTD Page 7 of 14 Printed: 28 -Nov -18 Applicaf or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bb] without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) * (2,033') + 1,500 psi = 2767 psi Pore Pressure = 910 psi Therefore Differential = 2767 — 910 = 1857 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85% of Burst 85% of (ppf) Type Collapse Burst 13-3/8" 68 L-80 3 BTC -M 2260 psi 1921 psi 5020 psi 4267 psi 9-5/8 40 L-80 3 BTC -M 3090 psi 2626 psi 5750 psi 4887 psi 15. Attachments Attachment I Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan MT6-02 PTD Page 8 of 14 Printed: 28 -Nov -18 GMTV MT6-02 wp07 Schemabe Applica Attachment 1 — Cement Summary Hd ember 27 v air e'YAtl.tl aa„wm� n4 or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 r• scan tf u.. r.. Alst A-. TOO-?} Y 04. MD 112 p.p 11 Ow.c Yum/ M� T J ns 41FNMrlI fi,?A B,tN' 1NJ 1-910 hr bl IVV OV-lal. sNCM. LiCTNin Tlr Lis. 5�K1m M ♦Y IRAWeYd Mw�m lOi A,pltr YO i r,leln }b lfippy tlm Ctiry n•a 6%"Ops NeM 9•bY Lao T5®Ir lmr ertir4l�vT,50!'LiO 5Y 02.Y 3nP al AY IDrw Fbai }yr liMLffil"R BIu 'SP.BSM LOIr,nty 140 .____. AYr wIn MRyv MT6-02 PTD Page 9 of 14 Printed. 28 -Nov -18 Applica( or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 13-3/8" Surface Casing run to 2.100' MD 12,0361 TVD. Cement from 2,100' MD to 1,600'(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1,600' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1,106' MD), zero excess in 20" conductor. Lead slurry from 1,600' MD to surface with DeepCrete @ 11.0 ppg Conductor (115'— 37') X 1.0190 ft3/ft X 1.0 (0% excess) = 79 ft' Permafrost to Conductor (1,106'— 115 X 0.4206 ft3/ft X 3.5 (250% excess) = 1,459 ft' Top of Tail to Permafrost (1,600'— 1,106) X 0.4206 ft3/ft X 1.5 (50% excess) = 312 ft3 Total Volume = 79 + 1,459 + 312 = 1850 ft3 => 964 sx of 11.0 ppg DeepCrete @ 1.92 ft3 /sk Tail slurry from 2,100' MD to 1,600' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,100'-1,600 X 0.4206 ft3/ft X 1.50 (50% excess) = 315 ft3 Shoe Joint (80) X 0.8407 ft3/ft X 1.0 (0% excess) = 68 ft3 Total Volume = 315 + 68 = 383 ft3 => 330 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk 9-5/8" Intermediate casing to 8.464' MD / 6,868' TVD Cement 500' up from 9-5/8" casing shoe from 8,464' MD to 7,964' MD. Assume 40% excess annular volume. Tail slurry from 8,464' MD to 7,964' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (8,464'— 7,964) X 0.3132 ft3/ft X 1.40 (40% excess) = 219 ft3 Shoe Joint (80� X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft3 Total Volume = 219 + 34 = 253 ft3 => 218 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk 7" Intermediate liner run to 11.179' MD / 7.905' TVD Top of slurry is designed to be — 250' TVD up from the 7" liner shoe. Assume 30% excess annular volume. 6" x 8-3/4" underreamer to be 100ft behind the drill bit. Tail slurry from 11,179' MD to 9,896' MD with 15.8 ppg Class G + additives (250' tvd) 8-3/4" Hole to Top of Tail (11,179'-9,896) X 0.1503 ft3/ft X 1.30 (30% excess) = 251 ft3 Shoe Joint (80) X 0.2148 ft3/ft X 1.0 (0% excess) = 17 ft3 Total Volume = 250 + 17 = 267 11:3 => 230 sx of 15.8 ppg Class G + additives 0 1.16 ft3/sk MT6-02 PTD Page 10 of 14 Printed: 28 -Nov -18 Applicat or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole / 13-3/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed — control drill, reduce pump rates and Hole swabbing on trips Medium circulating time reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Lost circulation Low Increase mud weight, use weighted sweeps, Abnormal Pressure in Low reduce fluid viscosity, control ROP Abnormal Pressure in Low Diverter drills, increased mud weight. Shallow Surface Formations Medium hazard stud noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement Abnormal Reservoir Low slurries port collar, control pipe running seeds 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time hole ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD Lost circulation Low monitoring,MPD stripping ractices Abnormal Pressure in Low Well control drills, check for flow during Overburden Formations connections, increase mud weight. Shallow hazard Hole swabbing on trips Medium study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices 6" x 8-3/4" Hole 7" Liner - C ina Interval Event Risk Level Miti ation rategy Sloughing shale, Tight High MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring,Liner will be in place at TD Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increase mud weight Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control practices, mud scavengers MT6-02 PTD Page 11 of 14 Printed: 28 -Nov -18 Applica, or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 6" Hole / 4-1/2" Pre -Perforated Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Low Well control drills, check for Flow during Pressure connections increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT6-02PH will be the seventh well drilled on the pad. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in the pilot and intermediate #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Steerable Drilling Liner and Managed Pressure Drilling will be used in conjunction with a 4 -string casing design to mitigate shale instability. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT6-02 PTD Page 12 of 14 Printed.. 28 -Nov -18 Applica or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 Attachment 3 —Completion Schematic MT6-02, Proposed Completion Schematic WP07 U TOC at least 30P MD O above Piker 8500' 4-V 12-69 L$0 TS Blue MID above Alpine C. With PerFPupa Planned to Laney Tap. Top Alpine 6 0 0 0 0 0 0 11.159' MID 17,903' TVD 7" 26 ppf L-80 TS Blue Liner 6" Hole, TD at to 11,179' MD t 7.906' TVD 6 85 deg at 22,669' MD / 7,809' TVD Nauember 2019 - ATB MT6-02 PTD Page 13 of 14 Printed: 28 -Nov -18 20" 79 ppi HAD Insulated Conductor Tuning d Liner Completion: 80 feet, cemented in surface I1 444" Landing Nipple (3.8I T ID) 2)4±r; x GLM 0 3) 4-Y,' x 1' GLM 4) Liner Top Packer l Hanger ud Tie Bark sleani 6.1 733P8" 69 pp1 L4M TXPIBTCM 59 4-'J, ' Lending NippleNipple[3.725 Norco} Surface Casing deg gat -74 @ 2t0df' MID l203fi'TUD D M Ocemented m surface 6) 4 W TS Blue Blank Pipe 7) 4 5S" TS Blue Liner with Part Pups 44P2" 126 Piet L80 Tennis Sim W 10,1179' MO T" 26 ppf L -W TS Blue Tie Back 9 5111" 40 ppF L -W TXP (to 4,A64' MD) 9 5111" 40 ppt TWOO HS TXP (to To) @ 8.464" MD i 6,8W TVD U TOC at least 30P MD O above Piker 8500' 4-V 12-69 L$0 TS Blue MID above Alpine C. With PerFPupa Planned to Laney Tap. Top Alpine 6 0 0 0 0 0 0 11.159' MID 17,903' TVD 7" 26 ppf L-80 TS Blue Liner 6" Hole, TD at to 11,179' MD t 7.906' TVD 6 85 deg at 22,669' MD / 7,809' TVD Nauember 2019 - ATB MT6-02 PTD Page 13 of 14 Printed: 28 -Nov -18 Applicaf or Permit to Drill, Well MTU MT6-02 Saved: 28 -Nov -18 Attachment 4 —Area of Review MT6-02 Area of Review: This Area of Review is required as MT6-02 is being permitted as an Alpine C Sand Injector. There are currently not any wells or planned wells that fall within '% mile of the well's entry point into the Alpine C sand. MT6-02 Quarter Mile Plot MT6-02 Quarter Mile Plot a,:r amm�e "ma: "vrso, rfi,..a+veme / 22500 'unao `'urce� 20000 \ 5000 ureas \ 10000 \ urea. �` 1500 }I 2500 Attachment 5 — Directional Plan MT6-02 MT6-02 PTD Page 14 of 14 Printed: 28 -Nov -18 ConocoPhillips _ConocoPhillips Export Company Western North Slope GMT1 Lookout Pad MT6-02 Mtffl a Plan: MT6-02_wp07 Drilling Summary Report 14 November, 2018 BT�a GHES GE company Well Positron +N/ -S 0.00 usft ConocoPhillips 5,945,564.39 usft BAT ConocoPhillips Drilling Summary 0.00 usft Easting: 317,116.39 usft Longitude: 151° 28'41.304 W Report 0.00 usft Wellhead Elevation: UGHES Ground Level: k6ij Hf- 37.20 usft (usft) (usft) (°) a GEmrnpany Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02_wp07 Database: EDT 14 Alaska Production Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site GMT7 Lookout Pad Site Position: Northing: 5,945,571.14 usft Latitude; 70' 15'23.251 N From: Map Easting: 317,134.52 usft Longitude: 151° 28'40.782 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -1.39 ° Well MT6-02 Well Positron +N/ -S 0.00 usft Northing: 5,945,564.39 usft Latitude: 70° 15'23.180 N +E/ -W 0.00 usft Easting: 317,116.39 usft Longitude: 151° 28'41.304 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: k6ij Hf- 37.20 usft Wellbore MT6-02 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (6) n (nn BGGM2018 1/1/2019 16.24 80.68 57,383 Design MT6-02_wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,620.00 Vertical Section: Depth From (TVD) -NI-S +El -W Direction (usft) (usft) (usft) (°) 37.20 0.00 0.00 346.86 11114/2018 5:33:11PM Page 2 COMPASS 5000.14 Build 850 �- ConocoPhillips BAT COnOCOPh1111p5 Drilling Summary Report UHES a GE company Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Well: MT602 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02 wp07 Database: EDT 14 Alaska Production Survey Tool Program Date 11/14/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 89.30 1,100.00 MT6-02PH_wp07 (MT6-02 Pilot Hole) GYD-GC-SS Gyrodsta gyro single shots 1,100.00 2,100.00 MT6-02PH_wp07 (MT6-02 Pilot Hole) MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC 2,100.00 8,464.00 MT6-02PH_wp07(MT6-02 Pilot Hole) MWD-IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8,464.00 10,820.00 MT6-02PH_wp07(MT6-02 Pilot Hole) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,820.00 11,179.00 MT6-02_wp07(MT6-02) MWD MWD -Standard 10,820.00 11,179.00 MT6-02_wp07(MT6-02) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 11,179.00 22,669.66 MT6-02_wP07(MT6-02) MWD MWD -Standard 11,179.00 22,669.66 MT6-02_wp07(MT6-02) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°NOOusft) V) (usft) (usft) (usft) 10,820.00 79.92 353.50 7,851.01 7,761.71 0.00 0.00 5,931.32 5,951,921.30 318,554.30 TIP/KOP 10,840.00 79.92 353.50 7,864.51 7,765.21 0.00 0.00 5,950.88 5.951,940.91 318,552.55 Start DLS 4.00 TFO.66.42 10,900.00 80.89 351.27 7,864.51 7,775.21 4.00 -66.44 6,009.76 5,951,999.72 318,546.14 11,000.00 82.53 347.58 7,878.94 7,789.64 4.00 -66.07 6,108.59 5,952,097.37 318,530.35 11,100.00 84.20 343.93 7,890.51 7,801.21 4.00 -65.54 6,207.88 5,952,194.19 318,508.25 11,179.00 85.53 341.05 7,897.58 7,808.28 4.00 -65.11 6,286.32 5,952,269.76 318,486.41 7" z 8.3/4" 11,200.00 85.89 340.29 7,899.15 7,809.85 4.00 -64.86 6,307.14 5,952,289.68 318,479.96 11,216.57 86.17 339.69 7,900.30 7,811.00 4.00 -64.80 6,323.55 5,952,305.34 318,474.68 Alpine C 11,300.00 87.60 336.67 7,904.83 7,815.53 4.00 -64.76 6,405.89 5,952,383.39 318,445.60 11,389.59 89.14 333.43 7,907.38 7,818.08 4.00 -64.59 6,493.54 5,952,465.46 318,409.81 Start 2110.41 hold at 11389.59 MD 11,389.90 89.15 333.42 7,907.39 7,818.09 4.00 -64.50 6,493.84 5,952,465.75 318,409.68 11,400.00 89.15 333.42 7,907.54 7,818.24 0.00 0.00 6,503.66 5,952,474.88 318,405.38 11,500.00 89.15 333.42 7,909.03 7,819.73 0.00 0.00 6,600.91 5,952,565.36 318,362.82 111142018 5:33:11PM Page 3 COMPASS 5000.14 Build 85D W, ConocoPhillips BA. I(ER ConocoPhillips Drilling Summary Report �jUGHES a GE company Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMTI Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02_wp07 Database: EDT 14 Alaska Production Planned Survey MD Inc AN (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Fasting Wait) (°) (°) (usft) (usft) (°/190usft) (°) (usft) (usft) (usft) 11,600.00 89.15 333.42 7,910.52 7,821.22 0.00 0.00 6,698.16 5,952.655.83 318,320.27 11,700.00 89.15 333.42 7,912.01 7,822.71 0.00 0.00 6,795.41 5,952,746.30 318,277.71 11,800.00 89.15 333.42 7,913.50 7,824.20 0.00 0.00 6,892.66 5,952,836.78 318,235.16 11,900.00 89.15 333.42 7,914.99 7,825.69 0.00 0.00 6,989.91 5,952,927.25 318,192.60 12,000.00 89.15 333.42 7,916.48 7,827.18 0.00 0.00 7,087.16 5,953,017.73 318,150.04 12,100.00 89.15 333.42 7,917.97 7,828.67 0.00 0.00 7,184.41 5,953,108.20 318,107.49 12,200.00 89.15 333.42 7,919.46 7,830.16 0.00 0.00 7,281.66 5,953,198.67 318,064.93 12,300.00 89.15 333.42 7,920.96 7,831.66 0.00 0.00 7,378.91 5,953,289.15 318,022.37 12,400.00 89.15 333.42 7,922.45 7,833.15 0.00 0.00 7,476.16 5,953,379.62 317,979.82 12,500.00 89.15 333.42 7,923.94 7,834.64 0.00 0.00 7,573.41 5,953,470.09 317,937.26 12,600.00 89.15 333.42 7,925.43 7,836.13 0.00 0.00 7,670.66 5,953,560.57 317,894.71 12,700.00 89.15 333.42 7,926.92 7,837.62 0.00 0.00 7,767.91 5,953,651.04 317,852.15 12,800.00 89.15 333.42 7,928.41 7,839.11 0.00 0.00 7,865.16 5,953,741.52 317,809.59 12,900.00 89.15 333.42 7,929.90 7,840.60 0.00 0.00 7,962.41 5,953,831.99 317,767.04 13,000.00 89.15 333.42 7,931.39 7,842.09 0.00 0.00 8,059.66 5,953,922.46 317,724.48 13.100.00 89.15 333.42 7,932.88 7,843.58 0.00 0.00 8,156.91 5,954,012.94 317,681.93 13,200.00 89.15 333.42 7,934.37 7,845.07 0.00 0.00 8,254.15 5,954,103.41 317,639.37 13,300.00 89.15 333.42 7,935.86 7,846.56 0.00 0.00 8,351.40 5,954,193.88 317,596.81 13,400.00 89.15 333.42 7,937.36 7,848.06 0.00 0.00 8,448.65 5,954,284.36 317,554.26 13,500.00 89.15 333.42 7,938.85 7,849.55 0.00 D.00 8,545.90 5,954,374.83 317,511.70 Start DLS 1.50 TFO -84.84 13,500.27 89.15 333.42 7,938.85 7,849.55 0.00 0.00 8,546.16 5,954,375.07 317,511.59 13,600.00 89.28 331.93 7,940.22 7,850.92 1.50 -84.79 8,642.84 5,954,464.75 317,467.98 13,700.00 89.42 330.43 7,941.35 7,852.05 1.50 -84.77 8,739.11 5,954,553.49 317,421.92 13,800.00 89.56 328.94 7,942.25 7,852.95 1.50 -84.75 8,834.65 5,954,641.01 317,373.57 13,900.00 89.69 327.45 7,942.90 7,853.60 1.50 -84.74 8,929.38 5,954,727.24 317,322.94 14,000.00 89.83 325.95 7,943.31 7,854.01 1.50 -84.73 9,023.25 5,954,812.12 317,270.09 1111412018 5:33:11PM Page 4 COMPASS 5000.14 Build 850 `- ConocoPhillips BAER ConocoPhillip5 Drilling Summary Report UGHES a GEmmpany Company: _ConocoPhillips Export Company Local Coordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 Q 89.30usft (Doyon19 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02 Wp07 Database: EDT 14 Alaska Production Planned Sumey - MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (o) (o) (usft) (usft) (%1(Y0us111t) (% (usft) (usft) (usft) 14,091.56 89.96 324.59 7,943.48 7,854.18 1.50 -84.72 9,108.38 5,954,888.60 317,219.78 14.097.37 89.96 324.59 7,943.49 7,854.19 0.00 0.00 9,113.77 5,954,893.42 317,216.52 Start 745.53 hold at 14097.37 MD 14,100.00 89.96 324.59 7,943.49 7,854.19 0.00 0.00 9,116.20 5,954,895.60 317,215.05 14,200.00 89.96 324.59 7,943.56 7,85426 0.00 0.00 9,208.73 5,954,978.47 317,159.10 14,300.00 89.96 324.59 7,943.63 7,854.33 0.00 0.00 9,301.27 5,955,061.35 317,103.16 14,400.00 89.96 324.59 7,943.71 7,854.41 0.00 0.00 9,393.81 5,955,144.22 317,047.21 14,500.00 89.96 324.59 7,943.78 7,854.48 0.00 0.00 9,486.35 5,955,227.10 316,991.26 14,600.00 89.96 324.59 7,943.85 7,854.55 0.00 0.00 9,578.89 5,955,309.98 316,935.31 14,700.00 89.96 324.59 7,943.93 7,854.63 0.00 0.00 9,671.42 5,955,392.85 316,879.36 14,800.00 89.96 324.59 7,944.00 7,854.70 0.00 0.00 9,763.96 5,955,475.73 316,823.41 14,842.90 89.96 324.59 7,944.03 7,854.73 0.00 0.00 9,803.66 5,955,511.28 316,799.41 Start DLS 1.50 TFO 82.98 14,847.76 89.96 324.59 7,944.03 7,854.73 0.00 0.00 9,808.16 5,955,515.31 316,796.68 14,900.00 90.05 325.36 7,944.03 7,854.73 1.50 82.92 9,856.63 5,955,558.80 316,767.75 15,000.00 90.24 326.85 7,943.77 7,854.47 1.50 82.92 9,950.14 5,955,643.13 316,714.03 15,100.00 90.42 328.34 7,943.19 7,853.89 1.50 82.92 10,044.54 5,955,728.83 316,662.51 15,200.00 90.61 329.83 7,942.29 7,852.99 1.50 82.93 10,139.76 5,955,815.83 316,613.24 15,300.00 90.79 331.32 7,941.07 7,851.77 1.50 82.95 10,235.73 5,955,904.08 316,566.24 15,400.00 90.98 332.81 7,939.52 7,850.22 1.50 82.96 10,332.40 5,955,993.52 316,521.56 15,412.99 91.00 333.00 7,939.30 7,850.00 1.50 82.99 10,345.01 5,956,005.22 316,515.93 MT6-02 wp07_T05 (copy) 15,413.17 91.00 333.00 7,939.30 7,850.00 0.00 0.00 10,345.18 5,956,005.38 316,515.85 Start DLS 0.02 TFO -86.05 15,500.00 91.00 332.98 7,937.78 7,848.48 0.02 -86.00 10,429.47 5,956,083.66 316,478.31 15,600.00 91.00 332.96 7,936.03 7,846.73 0.02 -86.00 10,526.53 5,956,173.79 316,435.05 15,700.00 91.00 332.93 7,934.28 7,844.98 0.02 -86.00 10,623.58 5,956,263.91 316,391.74 1111412018 5:33:11PM Pages COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips Drilling Summary Report BA ER F�UGI�ES a GEmmpaN Company: _ConocoPhillips Export Company Local Cc -ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02_wp07 Database: EDT 14 Alaska Production Planned Survey MD Inc AN (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°1100usft) (% (usft) (usft) (usft) 15,800.00 91.01 332.91 7,932.52 7,843.22 0.02 -86.00 10,720.62 5,956,354.00 316,348.40 15,900.00 91.01 332.88 7,930.77 7,841.47 0.02 -86.00 10,817.65 5,956,444.08 316,305.03 16,000.00 91.01 332.86 7,929.00 7,839.70 0.02 -86.00 10,914.66 5,956,534.14 316,261.61 16,100.00 91.01 332.83 7,927.24 7,837.94 0.02 -86.01 11,011.67 5,956,624.18 316,218.16 16,200.00 91.01 332.81 7,925.47 7,836.17 0.02 -86.01 11,108.67 5,956,714.21 316,174.67 16,300.00 91.01 332.79 7,923.70 7,834.40 0.02 -86.01 11,205.66 5,956,804.21 316,131.14 16,400.00 91.02 332.76 7,921.93 7,832.63 0.02 -86.01 11,302.64 5,956,894.20 316,087.57 16,500.00 91.02 332.74 7,920.16 7,830.86 0.02 -86.01 11,399.61 5,956,984.16 316,043.97 16,600.00 91.02 332.71 7,918.38 7,829.08 0.02 -86.01 11,496.56 5,957,074.11 316,000.32 16,700.00 91.02 332.69 7,916.60 7,827.30 0.02 -86.01 11,593.51 5,957,164.05 315,956.64 16,800.00 91.02 332.67 7,914.81 7,825.51 0.02 -86.01 11,690.45 5,957,253.96 315,912.93 16,900.00 91.02 332.64 7,913.02 7,823.72 0.02 -86.01 11,787.38 5,957,343.85 315,869.17 17,000.00 91.03 332.62 7,911.23 7,821.93 0.02 -86.01 11,884.29 5,957,433.73 315,825.38 17,100.00 91.03 332.59 7,909.44 7,820.14 0.02 -86.01 11,981.20 5,957,523.59 315,781.55 17,200.00 91.03 332.57 7,907.64 7,818.34 0.02 -86.01 12,078.09 5,957,613.43 315,737.68 17,300.00 91.03 332,55 7,905.85 7,816.55 0.02 -86.01 12,174.98 5.957,703.25 315,693.77 17,400.00 91.03 332.52 7,904.04 7,814.74 0.02 -86.01 12,271.85 5,957,793.05 315,649.83 17,500.00 91.04 332.50 7,902.24 7,812.94 0.02 -86.01 12,368.72 5,957,882.83 315,605.85 17,600.00 91.04 332.47 7,900.43 7,811.13 0.02 -86.01 12,465.57 5,957,972.60 315,561.83 17,700.00 91.04 332.45 7,898.62 7,809.32 0.02 -86.01 12,562.42 5,958,062.35 315,517.77 17,800.00 91.04 332.43 7,896.81 7,807.51 0.02 -86.01 12,659.25 5,958,152.07 315,473.68 17,900.00 91.04 332.40 7,894.99 7,805.69 0.02 -86.01 12,756.07 5,958,241.78 315,429.54 18,000.00 91.04 332.38 7,893.17 7,803.87 0.02 -86.01 12,852.88 5,958,331.47 315,385.38 18,100.00 91.05 332.35 7,891.35 7,802.05 0.02 -86.01 12,949.68 5,958,421.15 315,341.17 18,103.88 91.05 332.35 7,891.28 7,801.98 0.02 -86.01 12,953.44 5,958,424.62 315,339.45 18,200.00 91.05 332.35 7,889.52 7,800.22 0.00 0.00 13,046.48 5,958,510.81 315,296.94 1111412018 5:33:11PM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips BA <ER COnOCOPilllllp5 Drilling Summary Report FIUGHES a GE c=pa, Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Site: GMTi Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02_wp07 Database: EDT 14 Alaska Production Planned Survey MD Inc Azl (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (I (craft) (usft) r1l00usft) (°) (usft) (usft) (usft) 18,288.50 91.05 332.35 7,887.91 7,798.61 0.00 0.00 13,132.14 5,958,590.16 315,257.80 Start 505.83 hold at 18288.50 MD 18,300.00 91.05 332.35 7,867.70 7,798.40 0.00 0.00 13,143.28 5,958,600.47 315,252.71 18,400.00 91.05 332.35 7,885.88 7,796.58 0.00 0.00 13,240.07 5,958,690.14 315,208.49 18,500.00 91.05 332.35 7,884.05 7,794.75 0.00 0.00 13,336.87 5,958,779.80 315,164.26 18,600.00 91.05 332.35 7,882.23 7,792.93 0.00 0.00 13,433.66 5.958,869.46 315,120.03 18,700.00 91.05 332.35 7,880.40 7,791.10 0.00 0.00 13,530.46 5,958,959.12 315,075.80 18,794.33 91.05 332.35 7,878.68 7,789.38 0.00 0.00 13,621.77 5,959,043.70 315,034.09 Start DLS 0.02 TFO 93.93 18,800.00 91.05 332.35 7,878.58 7,789.28 0.00 0.00 13,627.25 5,959,048.79 315,031.58 18,900.00 91.05 332.35 7,876.76 7,787.46 0.00 0.00 13,724.05 5,959,138.45 314,987.35 18,978.63 91.05 33235 7,875.32 7,766.02 0.00 0.00 13,800.16 5,959,208.95 314,952.58 19,000.00 91.04 332.36 7,874.93 7,785.63 0.02 93.99 13,820.85 5,959,228.11 314,943.12 19,100.00 91.04 332.38 7,873.11 7,783.81 0.02 93.99 13,917.65 5,959,317.79 314,898.92 19,200.00 91.04 332.41 7,871.29 7,781.99 0.02 93.99 14,014.46 5,959,407.48 314,854.76 19,300.00 91.04 332.43 7,869.48 7,780.18 0.02 93.99 14,111.29 5,959,497.19 314,810.64 19,400.00 91.04 332.45 7,867.66 7,778.36 0.02 93.99 14,208.12 5,959,586.93 314,766.55 19,500.00 91.04 332.48 7,865.85 7,776.55 0.02 93.99 14,304.97 5,959,676.68 314,722.50 19,600.00 91.03 332.50 7,864.05 7,774.75 0.02 93.99 14,401.82 5,959,766.44 314,678.49 19,700.00 91.03 332.53 7,862.24 7,772.94 0.02 93.99 14,498.69 5,959,856.23 314,634.51 19,800.00 91.03 332.55 7,860.44 7,771.14 0.02 93.99 14,595.57 5,959,946.04 314,590.57 19,900.00 91.03 332.57 7,858.64 7,769.34 0.02 93.99 14,692.45 5,960,035.66 314,546.67 20.000.00 91.03 332.60 7,856.85 7,767.55 0.02 93.99 14,789.35 5,960,125.70 314,502.81 20,100.00 91.03 332.62 7,855.05 7,765.75 0.02 93.99 14,886.26 5,960,215.56 314,458.99 20,200.00 91.02 332.65 7,853.26 7,763.96 0.02 93.99 14,983.18 5,960,305.44 314,415.20 20,300.00 91.02 332.67 7,851.48 7,762.18 0.02 93.99 15,080.11 5,960,395.34 314,371.45 20,400.00 91.02 332.69 7,849.69 7,760.39 0.02 93.99 15,177.04 5,960,485.26 314,327.74 1111412018 5:33.11PM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips BAT Drilling Summary Report �j IGHES a GE company Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planed) Well: MT6-02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02_wp07 Database: EDT 14 Alaska Production Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (I (•) (usft) (usft) (•/100usft) (°) (usft) (usRj (usft) 20,500.00 91.02 332.72 7,847.91 7.756.61 0.02 93.99 15,273.99 5,960,575.19 314,284.07 20,600.00 91.02 332.74 7,846.13 7,756.83 0.02 93.99 15,370.95 5,960,665.15 314,240.43 20,700.00 91.02 332.77 7,844.36 7,755.06 0.02 93.99 15,467.92 5,960,755.12 314,196.83 20,800.00 91.01 332.79 7,842.59 7,753.29 0.02 93.99 15,564.90 5,960,845.11 314,153.27 20,900.00 91.01 332.82 7,840.82 7,751.52 0.02 93.99 15,661.89 5,960,935.11 314,109.75 21,000.00 91.01 332.84 7,839.05 7,749.75 0.02 93.99 15,758.89 5,961,025.14 314,066.27 21,100.00 91.01 332.86 7,837.29 7,747.99 0.02 93.99 15,855.90 5,961,115.19 314,022.82 21,200.00 91.01 332.89 7,835.53 7,746.23 0.02 93.99 15.952.93 5,961,205.25 313,979.41 21,300.00 91.01 332.91 7,833.77 7,744.47 0.02 94.00 16,049.96 5,961,295.33 313,936.04 21,400.00 91.00 332.94 7,832.01 7,742.71 0.02 94.00 16,147.00 5,961,385.43 313,892.71 21,500.00 91.00 332.96 7,830.26 7,740.96 0.02 94.00 16,244.05 5,961,475.55 313,849.41 21,600.00 91.00 332.98 7,828.51 7,739.21 0.02 94.00 16,341.11 5,961,565.68 313,806.15 21,669.51 91.00 333.00 7,827.30 7,738.00 0.02 94.00 16,408.59 5,961,628.35 313,776.10 MT6-02 wp07 T07 (copy) 21,669.66 91.00 333.00 7,827.30 7,738.00 0.00 0.00 16,408.73 5,961,628.48 313,776.04 Start 1000.00 hold at 21669.66 MD 21,700.00 91.00 333.00 7,826.77 7,737.47 0.00 0.00 16,438.18 5,961,655.83 313,762.93 21,800.00 91.00 333.00 7,825.02 7,735.72 0.00 0.00 16,535.26 5,961,745.99 313,719.72 21,900.00 91.00 333.00 7,823.28 7,733.98 0.00 0.00 16,632.33 5,961,836.15 313,676.50 22,000.00 91.00 333.DD 7,821.53 7,732.23 0.00 0.00 16,729.40 5,961,926.31 313,633.29 22,100.00 91.00 333.00 7,819.79 7,730.49 0.00 0.00 16,826.48 5,962,016.46 313,590.08 22,200.00 91.00 333.00 7,818.04 7,728.74 0.00 0.00 16,923.55 5,962,106.62 313,546.86 22,300.00 91.00 333.00 7,816.30 7,727.00 0.00 0.00 17,020.62 5,962,196.78 313,503.65 22,400.00 91.00 333.00 7,814.55 7,725.25 0.00 0.00 17,117.70 5,962,286.94 313,460.44 22,500.00 91.00 333.00 7,812.81 7,723.51 0.00 0.00 17,214.77 5,962,377.09 313,417.23 22,600.00 91.00 333.00 7,811.06 7,721.76 0.00 0.00 17,311.84 5,962,467.25 313,374.01 11/14/2018 5:33:11PM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips Company: _ConocoPhillips Export Company Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-02 Wellbore: MT6-02 Design: MT6-02_wp07 Planned Survey MD Inc Azl (azimuth) (usft) (1) (1) 22,669.51 91.00 333.00 Planned TD at 22669.66 Casing Points Formations Measured Vertical Depth Depth (usft) (usft) 11,179.00 7,897.58 7'x8-3/4" 22,669.66 4-1/2" x 6-1/8" Measured Vertical Depth Depth (usft) (usft) 11,216.57 7,900.30 Alpine C ConocoPhillips BA, ICER Drilling Summary Report �j IGHES aGEwmpany Local Co-ordinate Reference: Well MT6-02 TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) MD Reference: Plan MT6-02 @) 89.30usft (Doyon19 Planned) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production TVD TVDBS DLeg TFace V. Sec Northing Easting (usft) (usft) (°1100usft) (usft) (usft) (usft) 7,809.85 7,720.55 0.00 0.00 17,379.32 5,962,529.92 313,343.97 Name Casing Hole Diameter Diameter Name (in) (in) 7.000 8.750 4.500 6.125 Dip Dip Direction Lfthology 11/1412018 5:33:11PM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips BA_ ICER COnoc Phillips Drilling Summary Report IGHES aGEcompany Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Site: GMT7 Lookout Pad MD Reference: Plan MT6-02 ® 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-02 Survey Calculation Method: Minimum Curvature Design: MT6-02_wp07 Database: EDT 14 Alaska Production Plan Annotations Measured Vertical Depth Depth (usft) (usft) 10,820.00 7,851.01 10,840.00 7,854.51 11,389.59 7,907.38 13,500.00 7,938.85 14,097.37 7,943.49 14,842.90 7,944.03 15,413.17 7,939.30 18,288.50 7,887.91 18,794.33 7,878.68 21,669.66 7,827.30 22,669.51 7,809.85 Local Coordinates +N/ -S +FJ -W (usft) (usft) 6,390.35 1,283.22 6,409.91 1,280.99 6,930.88 1,125.54 8,817.99 181.28 9,329.29 -126.42 9,936.88 -558.45 10.423.98 -853.93 12,977.61 -2,174.45 13,425.61 -2,409.13 15,979.24 -3,729.64 16,869.98 -4,183.50 Comment TIP/KOP Start DLS 4.00 TFO -66.42 Start 2110.41 hold at 11389.59 MD Start DLS 1.50 TFO -84.84 Start 745.53 hold at 14097.37 MD Start DLS 1.50 TFO 82.98 Start DLS 0.02 TFO -86.05 Start 505.83 hold at 18288.50 MD Start DLS 0.02 TFO 93.93 Start 1000.00 hold at 21669.66 MD Planned TD at 22669.66 Checked By: Approved By: Date: 11114/2018 5:33:11PM Page 10 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-02 MT6-02 MT6-O2_wp07 Anticollision Summary Report 14 November, 2018 BA ER BAT GE companv 110� ConocoPhillips BAT ConocoPhillips Antioollision Summary Report �j IGHES a GEmmpany Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Reference Site: GMT1 Lookout Pad Site Error: 0.00 usft Reference Well: MT6-02 Well Error: 0.00 usft Reference Wellbore MT6-02 Reference Design: MT6-02_wp07 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyon19 Planned) Plan MT6-02 @ 89.30usft (Doyon19 Planned) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Survey Tool Program Date 11/14/2018 From To Reference (usft) (usft) Survey (Wellbore) Tool Name Description 37.20 1,100.00 MT6-02PH_wp07 (MT6-02 Pilot Hole) GYD-GC-SS Gyrodata gyro single shots 1,100.00 2,100.00 MT6-02PH_wp07(MT6-02 Pilot Hole) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,100.00 8,464.00 MT6-02PH wp07(MT6-02 Pilot Hole) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8,464.00 10,820.00 MT6-02PH_wp07(MT6-02 Pilot Hole) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,820.00 11,179.00 MT6-02 wp07(MT6-02) MWD MWD -Standard 10,820.00 11,179.00 MT6-02_wp07(MT6-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,179.00 22,669.66 MT6-02_wp07(MT6-02) MWD MWD - Standard 11,179.00 22,669.66 MT6-02_wp07(MT6-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usRl (usft) GMT1 Lookout Pad MT6-02 - MT6-02 Pilot Hole -MT6-02PH_wp07 11,197.67 11,200.00 19.95 1047 2.105 No Errors, CC, ES, SF MT6-03 - MT6-03 - MT6-03 37.20 37.20 20.06 18.56 13.365 CC MT6-03 - MT6-03 - MTS -03 299.68 300.00 21.28 15.72 3.829 ES, SF MT6-03 - MT6-03PH - MT6-03PH 37.20 37.20 20.06 18.56 13.366 CC MT6-03 - MT6-03PH - MT6-03PH 299.88 300.00 21.28 15.72 3.829 ES, SF MT6-04-MT6-04-MT6-04 37.20 36.52 40.09 38.75 30.053 CC MT6-04 - MT6-04 - MT6-04 300.57 300.00 42.01 35.55 6.508 ES, SF MT6-04 - MT6-04 - MTS -04 wpl0 299.90 300.00 40.09 34.51 7.184 CC MTB -04 - MT6-04 - MT&04 wp10 399.45 400.00 40.54 33.22 5.538 ES, SF MT&05 - MT6-05 - MT6-05 37.20 36.50 60.06 58.83 49.048 CC MT6-05 - MT6-05 - MT6-05 300.59 300.00 61.62 55.23 9.640 ES, SF MT6-05 - MT6-0511 - MT6-051-1 37.20 36.50 60.06 58.83 49.048 CC MT6-05 - MT6-0511 - MT6-0511 300.59 300.00 61.62 55.23 9.640 ES, SF MT6-05 - MT6-05PB1 - MT6-05PBl 37.20 36.50 60.06 58.83 49.048 CC MT6-05 - MT6-05PB1 - MT6-OSPB7 300.59 300.00 61.62 55.23 9.640 ES, SF MT6-05-MT6-05PB2-MT6-05PB2 37.20 36.50 60.06 58.83 49.048 CC MT6-05 - MT6-05PB2 - MT6-05PB2 300.59 300.00 61.62 55.23 9.640 ES, SF MT6-06 - MT6-06 - MT6-06 37.20 36.94 80.07 78.84 65.388 CC MT6-06-MT6-06-MT6-06 399.18 400.00 82.44 74.07 9.850 ES,SF MT6-06 - MT6-06PB1 - MT6-06 Pat 37.20 36.94 80.07 78.84 65.388 CC MT6-06 - MT&06PB7 - MT6-06 PB1 399.18 400.00 82.44 74.07 9.850 ES, SF MT6-06 - MT6-06PB2 - MT6-06PB2 37.20 36.94 80.07 78.84 65.388 CC MT6-06 - MT6-06PB2 - MT6-06PB2 399.18 400.00 82.44 74.07 9.850 ES, SF MT6-07 - MT6-07 - MT6-07 wp05 300.30 300.00 100.05 93.66 15.649 CC MT6-07 - MT6-07 - MT6-07 wp05 399.19 400.00 100.50 92.03 11.860 ES, SF MT6-08 - MT&08 Lower Let- MT6-08 399.12 400.00 116.55 109.42 16.353 CC, ES, SF M1-6-08-MT6-08PS1 Lower Let - MT6-08PBl 399.12 400.00 116.55 109.42 16.353 CC, ES, SF MT6-09 - MT6-09 - MT6-09 wpl3 299.80 300.00 140.01 134.43 25.099 CC MT6-09 - MT6-09 - MT&09 wpl3 398.27 400.00 140.76 133.48 19.339 ES, SF Plan: MT6-01 - MT6-01 - F-wp02 619.50 600.00 17.05 5.96 1.537 No Errors, CC, ES, SF Plan: MT6-02 - MT6-02 - E-wp02 219.30 200.00 0.00 -3.04 0.000 Major Risk, CC Plan: MT6-02 - MT6-02 - E-wp02 15,026.26 15,100.00 54.25 -281.02 0.162 No Errors, ES, SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 111142018 4:56:13PM Page 2 COMPASS 5000.14 f3ufld 851) - ConocoPhillips BA. ICER ConocoPhillips Anticollision Summary Report IGHES BAT GE.rnp ny Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Reference Site: GMT1 Lookout Pad Site Error: 0.00 usR Reference Well: MT6-02 Well Error: 0.00 usft Reference Wellbore MT6-02 Reference Design: MT6-02_wp07 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyon19 Planned) Plan MT6-02 @ 89.30usft (Doyonl9 Planned) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference Depths are relative to Plan MTG-02 @ 89.30usft (Doyon19 P Coordinates are relative to: MT6-02 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 Central Meridian is 150° 0'0.000 W Grid Convergence at Surface is: -1.39' CC -Min centre to center distance or covergent point, SF -min separation factor, ES - min ellipse separation 11/142078 4:56:13PM Page 3 COMPASS 5000.14 Ladder Plot I I 2400 I I I I I I I I I I I I I I I I I I _J I I �J I I --------- I I --------- --------- I I I 1800 I I I I I i 1 I I I I I I I I I I I I I I I I I I I 1 1 I I I I I I I 1 1 _J I I I I I I _J I I I I I I I _J I I I I I I _J I I I I I 1 I _J I I 1 1 0 m m i? N d m 1200 U 0 C N U 600 0 4000 8000 12000 16000 20000 24000 Measured Depth LEGEND Woo:w CC -Min centre to center distance or covergent point, SF -min separation factor, ES - min ellipse separation 11/142078 4:56:13PM Page 3 COMPASS 5000.14 I I I 1 I I I I I I I I I I I I I I I I I 1 I I I I I 1 I I I I 1 I I I I I I I I I I I I I 1 1 I I I I 1 I I I I I 1 I I I I I I 1 I I I I I 1 I I I I I i 1 I I I I I I I I I I I I I I I I I I I 1 1 I I I I I I I 1 1 _J I I I I I I _J I I I I I I I _J I I I I I I _J I I I I I 1 I _J I I 1 1 Build 85D - ConocoPhillips BATER ConocoPililiips Anticollision Summary Report UGMES aGEcompany Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Reference Site: GMTI Lookout Pad MD Reference: Site Error: 0.00 usft North Reference: Reference Well: MT6-02 Survey Calculation Method: Well Error: 0.00 usft Output errors are at Reference Wellbore M76-02 Database: Reference Design: MT"2—wp07 Offset TVD Reference: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Plan MT6-02 @ 89.30usft (Doyonl9 Planned) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference Depths are relative to Plan MT6-02 @ 89.30usft (Doyonl9 P Coordinates are relative to: MT6-02 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 Central Meridian is 150' 0'0.000 W Grid Convergence at Surface is: -1.39° CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/142018 4:56.13PM Page 4 COMPASS 5000.14 Build 85D Separation Factor Plot 9.00 I1 I I I I I I I I I I I 1 I I I I I I I 1 I I I I I I 1 I I I I I I I I I p I I I I I I I I I I I I I I I I I I I I LL6.00 I I 1 1 1 I I I I I I I C O I I I 1 m— 1,11 I I 1 � I I to I I 1 I 1 I I 1 I I I I 3.00 I I I I I I 1 I I I I I I I 1 I I I 1 1 1 I I I I 1 1 1 I 1 1 _____ I I ____1__________L__ I I 1 I I I I I 0.00 I 14 I I 0 4000 8000 12660 16000 20000 Mieasu lad Depth LEGEND s'..�Pmv Ewe CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/142018 4:56.13PM Page 4 COMPASS 5000.14 Build 85D Loepp, Victoria T (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Thursday, November 29, 2018 6:07 AM To: Loepp, Victoria T (DOA) Cc: Rixse, Melvin G (DOA) Subject: RE: [EXTERNAL]Re: MT6-02 PTD Submission Follow Up Flag: Follow up Flag Status: Flagged 3-4 weeks. We are anticipating sometime around Christmas right now. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, November 28, 2018 4:19 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: [EXTERNAL]Re: MT6-02 PTD Submission How soon to spud? Sent from my Phone On Nov 28, 2018, at 3:30 PM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com> wrote: Victoria, We've had a last minute schedule change for Doyon 19 and MT6-07 will no longer follow MT6-09 (current well). Instead, MT6-02 will follow. I will be dropping off the permits later this afternoon for your review. I have also attached the directional text files for you to load. We are drilling a pilot on this well that is a bit different than what we've done in the past so please let me know if you have any questions. I can come by and discuss the submission as well. Thanks, Andrew (303)378-8881 <MT6-02_wp07 Canvas - NAD27.txt> <MT6-02PH_wp07 Canvas - NAD27.txt> From: Beat, Andrew T To: Boyer. David L (DOA) Cc: Loeoo. Victoria T (DOA); Davies. Steohen F (DOA) Subject: Re: [EXTERNAL]Confirmation of KB and GL Elevations for MT -6-06 Date: Wednesday, December 5, 2018 12:53:57 PM David, That is correct. The Baker plans have a couple issues that we are working on now. In addition to the elevation, the casing and formation depths aren't all accurate. The numbers in the PTD are correct. I thought I caught all of the GL mistakes but it looks like I missed one! Thanks for reviewing closely. Andrew From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Wednesday, December 5, 2018 12:45 PM To: Beat, Andrew T Cc: Loepp, Victoria T (DOA); Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]Confirmation of KB and GL Elevations for MT -6-06 Andrew, I am currently reviewing the PTD for MT6-02PH & MT6-02. It appears that on BakerHughes directional plan that thy are still using 37.2' for ground level instead of for the rig height with a correct KB=89.3'. On the PTD cover page, the Pad Elevation (GL) is 55' but on P.3, the pad elevation is 52.1', consistent with other wells on the pad. So I am assuming we should run with KB=89.3', GL (pad)=52.1', and rig height (constant)=37.2'. Please confirm. Thankyou, Dave Boyer AOGCC From: Beat, Andrew T <And rew.T. Beat@conocophill ips.com> Sent: Thursday, August 2, 2018 6:30 AM To: Boyer, David L (DOA) <david.boyer2@alaska.gov> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]Confirmation of KB and GL Elevations for MT -6-06 Dave, TRANSMITTAL LETTER CHECKLIST WELL NAME: M T 6— 0 PTD: '�' is -16th Development ✓Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: MnoeecT 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 ofthe_- Production should continue to be reported as a function 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. (Companv Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company- Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field 8 Pool GRTR MOOSES TOOTH, LOOKOUT OIL - 2821 PTD#: 2181600 Company C,_ONOCOPHILLIPS ALASKA, INC. Initial Class/Type SER/PEND Well Name: MOOSES TOOTH 6-02 Program SER Well bore seg GeoArea 890 Unit 10750 On/Off Shore Dn. Annular Dispo Administration '17 Nonoonven, gas conforms to AS31,05,030(j.1.A).0.2.A-D) _ _ _ _ .... _ _ _ _ _ _ NA -'Z%-.yI 1 Permit fee attached ------------------------------------------ NA -—--------------...........--------------------... 2 Lease number appropriate- _ _ . . . . . . . . . . . .......... Yes 3 Unique well name and number _ _ _ _ _ _ _ _ _ Yes 4 .Well located in a. 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 _ _ _ _ _ _ _ _ _ No. _ _ Area of Review provided with directional plan.. 9 Operator only affected party _ _ _ _ _ _ _ _ _ _ _ _ Yes 10 Operator has. appropriate bond in force _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 11 Permitcan be issued without conservation order . ............. . . . . _ _ _ Yes DLB 12/6/2018 12 Permit can be issued without administrative. approval __________ Yes 13 Can permit be approved before 15 -Slay. wait_ _ _ _ _ _ _ _ _ _ _ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ Yes 14 Well located within area and strata authorized by Injection Order # (put. 10# in.comments) (For. Yes _ _ _ _ _ AIO. No. 40 dated 05/29/18. . 15 All wells within 114 -mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ Yes 16 Pre -produced injector; duration of pro -production less than 3 months _(For service well only) _ . Yes 18 Conductor string provided ..... _ _ _ _ _ _ . NA_ _ _ _ _ _ .. Conductor set forMT6-02PH _ Engineering 19 Surface casing protects all known USDWs _ NA ...... ....... Surfers casing will be set forMT6-02PH 20 CMT_vol adequate to circulate on conductor R surf. csg .......... . . . . . . . . . . . NA... _ _ _ _ _ Surface casing will be fully cemented 21 CMT. vol. adequate to tie-in long string to surf osg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ...... NA. 22 CMT will cover all known productive horizons _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ .. Productive interval will be completed with. uncemented perforated liner 23 Casing designs adequate for C, T, B$_permafrost ............. _ _ _ _ _ _ . _ Yes 24 Adequate tankage. or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . Rig has steel tanks; all wasteto approved disposal wells..... 25 if a re -drill, has_a 10-403 for abandonment been approved ..... . . . . . . . ........ NA 26 Adequate wellbore separation proposed. . . . . . . . . . . . . . . . ................ Yes _ Anti-coflision analysis complete; no major risk failures 27 if diverter required, does it meet regulations _ _ _ _ _ _____ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA Appr Date 28 Drilling fluid, program schematic & equip list adequate_ _ _ _ _ _ _ _ _ ... Yes _ _ _ Max reservoir pressure is 3810_psig(g,4 ppg EMW); will drill w/ 9.4-11.0 ppg EMW VTL 12/17/2018 29 BOPEs,.do they meet regulation .. Yes 30 _ BORE press rating appropriate; test to.(put psig in comments) . . . . . . .......... _ Yes _ _ _ _ _ MPSP is 3015 psig; will test BOPS to 3500.psig 31 Choke manifold complies w/API. RP -53 (May 84)_ _ _ _ _ _ _ _ _ _ ___ _ _ _ _ Yes 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ Jr'--�""- - ✓TL- - - - - - - - - - - 33 Is presence of H2S gas probable . . . . ....... . . . . . . . .. . . ..... Ye< Kv_ _ _ H2S measpre?1equired ---- __34 34 Mechanical condition of wells within AOR verified (Forservice well only) _ .. .... Yes _ _ _ _ _ No wells within the 1/4.mile.radius_ _ _ _ ______ 35 Permit can be issued w!o hydrogen.sulfide measures . . . . . . ........... . . . Yes _ _ _ ... - Only MT6-03 has been flowed back to date but no H2S was encountered in that well.. Geology '.36 Data presented on potential overpressure zones _ _ _ _ _ _ Yes ....... Drilling fluid program appears adequate to control_ operator's forecast pressures_ Production interval will Appr Date 37 Seismic analysis of shallow gas zones.... ... ..... . . . . . . ......... NA _ _ _ _ be drilled with 8,8-9.5 ppg mud. using Managed Pressure Drilling Technique. DLB 12/6/2018 138 Seabed .condition survey (if off -shore) _ _ _ _ _ _ _ ___ _ _____ _ _ _ _ _ _ _ _ _ _ _ _____ NA....... 1139 Contact name/phone for weekly.progress reports [exploratory only] . . . . . . . ......... NA. ❑■ Geologic Commissioner: Date: Engineering Commissions Date Publi Date -'Z%-.yI C2! Z I* 1
