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218-108
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. MT6-04 GMTU MT6-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/23/2024 MT6-04 50-103-20775-00-00 218-108-0 W SPT 7984 2181080 1996 2150 2150 2150 2150 340 710 690 690 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 MT6-04 Inspection Date: Tubing OA Packer Depth 500 3000 2890 2880IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240930151536 BBL Pumped:2.9 BBL Returned:2.8 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 09:57:26 -08'00' 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 PTD �lq—lo8 Loepp, Victoria T (CED) From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod @contractor.conocoph i I I i ps.com> Sent: Tuesday, December 31, 2019 11:16 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]Re: Extension of time for CDS-26 and CD5-261-1 Follow Up Flag: Follow up Flag Status: Flagged Thank you and have a safe and Happy New Year! ft 9 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, December 31, 2019 10:53 AM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: [EXTERNAL]Re: Extension of time for CD5-26 and CD5-26L1 Ann, Extension is granted for 1 week to Jan 10,2020. Happy New Year Ann! Victoria Sent from my Whone On Dec 31, 2019, at 10:39 AM, Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haegerty Sherrod@contractor.conocophillips.com> wrote: Good morning, I am writing to ask for an extension of time on the due date for CD5-26 and CD5-261-1 which is currently due on Friday, January 3, 2020. Many of the engineers involved in supplying data for the 10- 407 are out on vacation and not due to return until 1/6/20. 1 just returned from vacation on 2/30 but the person filling in for me did ask for the data we needed but I think people were already gone for vacation — taking that time off that could not be carried over to the new year. Any extension you can give us would be greatly appreciated. Thanks, Ann DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181080 Well Name/No. GMTU MT6-04 �f I—' Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20775-00-00 MD 14790 TVD 8001 Completion Date 11/19/2018 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No V/ DATA INFORMATION List of Logs Obtained: GR/RES/DEN/NEU Well Log Information: Log/ Electronic File: MT6-04 EOW - NAD27.txt Electr Data Digital Dataset Type Med/Frmt Number Name ED C 30075 Log Header Scans ED C 30075 Digital Data ED C 30075 Digital Data ED C 30075 Digital Data ED C 30075 Digital Data ED C 30076 Digital Data ED C 30076 Digital Data ED C 30076 Digital Data ED C 30076 Digital Data ED C 30076 Log Header Scans ED C 30096 Digital Data ED C 30096 Digital Data ED C 30096 Digital Data ED C 30096 Log Header Scans ED C 30120 Digital Data ED C 30120 Digital Data Samples No Z Log Log Run Scale Media No Interval OH/ Start Stop CH 0 0 0 0 9176 7400 0 0 47 14790 28 14790 Received UIC Yes Directional Survey Yes (from Master Well Data/Logs) AOGCC Pagel of 5 Monday, February 25, 2019 I 101 u0V UM I U M I0 -U4 LV U HtAUt K5 12/7/2018 Electronic File: MT6-04 EOW - NAD27.pdf 12/7/2018 Electronic File: MT6-04 EOW - NAD27.txt 12/7/2018 Electronic File: MT6-04 EOW - NAD83.pdf 12/7/2018 Electronic File: MT6-04 EOW - NAD83.txt 12/7/2018 Electronic File: MT6-04PB1 EOW - NAD27.pdf 12/7/2018 Electronic File: MT6-04PB1 EOW - NAD27.txt 12/7/2018 Electronic File: MT6-04PB1 EOW - NAD83.pdf 12/7/2018 Electronic File: MT6-04PB1 EOW - NAD83.bd 2181080 GMTU MT6-04 PB1 LOG HEADERS 12/11/2018 Electronic Data Set, Filename: CPAI MT6- 04_SCMT_ 0F 16NOV2018_PASSUP3PM_018PU C.las 12/11/2018 Electronic File: CPA]_MT6- 04_SCMT_16NOV2018_PASSUP30FPM_018PU C.DLIS 12/11/2018 Electronic File: CPAI_MT6- 04_SCMT_16Nov18_ FI NAL. PDF 2181080 GMTU MT6-04 LOG HEADERS 12/17/2018 Electronic Data Set, Filename: MT6-04 Drilling Mechanics Depth Data.las 12/17/2018 Electronic Data Set, Filename: MT6-04 LTK Memory Drilling Data.las AOGCC Pagel of 5 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181080 Well NamelNo. GMTU MT6-04 MD 14790 TVD 8001 Completion Date 11/19/2018 [ED—C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data ED C 30120 Digital Data Operator CONOCOPHILLIPS ALASKA, INC. API No. 50.103-20775-00.00 Completion Status WAGIN Current Status WAGIN UIC Yes 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Depth Log.cgm 12/17/2018 Electronic File: MT6-04 LTK 2MD Memory Drilling Log.cgm 12/17/2018 Electronic File: MT6-04 LTK 5MD Memory Drilling Log.cgm 12/17/2018 Electronic File: MT6-04 LTK 5TVD Memory Drilling Log.cgm 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Runl.cgm 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Run2.cgm 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Run3.cgm 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Run4.cgm 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Run5.cgm 12/17/2018 Electronic File: MT6-04 LTK Memory Drilling Data.dls 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Depth Log.pdf 12/17/2018 Electronic File: MT6-04 LTK 2MD Memory Drilling Log.pdf 12/17/2018 Electronic File: MT6-04 LTK 5MD Memory Drilling Log.pdf 12/17/2018 Electronic File: MT6-04 LTK 5TVD Memory Drilling Log.pdf 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Runl.pdf 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Run2.pdf 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Run3.pdf 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Run4.pdf AOGCC Page 2 of 5 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2 /2 512 01 9 Permit to Drill MD 14790. 2181080. Well Name/No. GMTU MT6-04 TVD 8001 Completion Date 11/19/2018 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20775-00-00 Completion Status. WAGIN Current Status WAGIN UIC Yes ED C 30120 Digital Data 12/17/2018 Electronic File: MT6-04 Drilling Mechanics Time Log Run5.pdf ED C 30120 Digital Data 12/17/2018 Electronic File: MT6-04 EOW - NAD27.pdf ED C 30120 Digital Data 12/17/2018 Electronic File: MT6-04 EOW - NAD27.bd ED C 30120 Digital Data 12/17/2018 Electronic File: MT6-04 EOW - NAD83.pdf ED C 30120 Digital Data 12/17/2018 Electronic File: MT6-04 EOW - NAD83.txt ED C 30120 Digital Data 12/17/2018 Electronic File: MT6-04 Field Survey.xlsx Log C 30120 Log Header Scans 0 0 2181080 GMTU MT6-04 LOG HEADERS Log C 30121 Log Header Scans 0 0 2181080 GMTU MT6-04 PB1 LOG HEADERS ED C 30121 Digital Data 50 12481 12/17/2018 Electronic Data Set, Filename: MT6-04 Drilling Mechanics Depth Data.las ED C 30121 Digital Data 28 12481 12/17/2018 Electronic Data Set, Filename: MT6-04PB1 LTK Memory Drilling Data.las ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 Drilling Mechanics Depth Log.cgm ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 LTK 2MD Memory Drilling Log.cgm ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-041381 LTK 5MD Memory Drilling Log.cgm ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 LTK 5TVD Memory Drilling Log.cgm ED C 30121 Digital Data 12/17/2018 Electronic File: MT6.04PB1 Drilling Mechanics Time Log Runl.cgm ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04P81 Drilling Mechanics Time Log Run2.cgm ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 Drilling Mechanics Time Log Run3.cgm ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 Drilling Mechanics Time Log Run4.cgm ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 LTK Memory Drilling Data.dls ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 Drilling Mechanics Depth Log.pdf ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 LTK 2MD Memory Drilling Log.pdf AOGCC Page 3 of 5 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permitto Drill 2181080 Well Name/No. GMTU MT6-04 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20775-00-00 MD 14790 TVD 8001 Completion Date 11/19/2018 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 LTK 5MD Memory Drilling Log.pdf ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 LTK STVD Memory Drilling Log.pdf ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 Drilling Mechanics Time Log Runl.pdf ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 Drilling Mechanics Time Log Run2.pdf ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-041381 Drilling Mechanics Time Log Run3.pdf ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 Drilling Mechanics Time Log Run4.pdf ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 EOW - NAD27.pdf ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 EOW - NAD27.bd ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 EOW - NAD83.pdf ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1 EOW - NAD83.txt ED C 30121 Digital Data 12/17/2018 Electronic File: MT6-04PB1_Final Surveys.xlsx Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Y Directional / Inclination Data Mud Logs, Image Files, Digital Data Y /� Core Chips Y / Production Test Information rY^/ NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files (9 Core Photographs Y Geologic Markers/Tops V Daily Operations Summary OY Cuttings Samples Y / lR Laboratory Analyses Y N COMPLIANCE HISTORY Completion Date: 11/19/2018 Release Date: 9/27/2018 Description Date Comments AOGCC Page 4 of 5 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181080 Well Name/No. GMTU MT6-04 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20775-00-00 MD 14790 TVD 8001 Completion Date 11/19/2018 Completion Status WAGIN Current Status WAGIN UIC Yes Comments: 1� y 1/ ?9 Compliance Reviewed By: ME 4a FE520 AOGCC Page 5 of 5 Monday, February 25, 2019 MEMORANDUM To: Jim Regg K� q 1/111 P.I. Supervisor ( m FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, January 11, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. MT6-04 GMTU MT6-04 Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name GMTV MT6-04 API Well Number 50-103-20775-00-00 Inspector Name: Guy cook Insp Num: mitGDC1812210655I2 Permit Number: 218-108-0 Inspection Date: 12/19/2018 - Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well MT6-04 Type Inj w TVD 7984 - Tubing 1993 - 1995. 1993 - 1993 PTD 2181080 -Type Test SPT Test psi 1996 - IA 450 2800. 2720 _ 2710— BBL Pumped 2s BBL Returned: 2.8 - OA 647 646 638 " 836 - Interval INITAL�" P/F P Notes: Testing was performed with Little Red Services truck. Gauges were provided by DHD and were currently calibrated. In addition, this well also has an OOA. The pressures were as follows during the testing process: Pretest - 93 psi, Initial - I l I psi, 15 min - 107 psi and 30 min - 104 psi. Friday, January 11, 2019 Page I of I MEMORANDUM State of Alaska Insp Num: mi[GDC181221065512 Alaska Oil and Gas Conservation Commission TO: Jim Regg � P.I. Supervisor 1 \ V (�ZA I1''qq c7 DATE: Monday, December 24, 2018 SUBJECT: Mechanical Integrity Tests Type Inj CONOCOPHILLIPS ALASKA, INC. TVD 1 7275 MT6-04 FROM: Guy Cook GMTU MT6-04 Petroleum Inspector Src: Inspector PTD 2181080 - Reviewed By: SPT P.I. Supry -� NON -CONFIDENTIAL Comm Well Name GMTU MT6-04 API Well Number 50-103-20775-00-00 Inspector Name: Guy Cook Permit Number: 218-108-0 Inspection Date: 12/21/2018 Insp Num: mi[GDC181221065512 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well MT6-04 Type Inj H'' TVD 1 7275 ITubingl 1993 1995 1993; .L.-1993 PTD 2181080 - Type Test SPT Test psi 1819 IA Oso 2800 1 27202710 BBL Pumped: 2.s BBL Returned: 2.8 OA 647 1 — 846 838 836 Interval IINITAL P/F P Notes: Testing was performed with Little Red Services truck. Gauges were provided by DHD and were currently calibrated. In addition, this well also has an GOA. The pressures were as follows during the testing process: Pretest - 93 psi, Initial - 111 psi, 15 min - 107 psi and 30 min - 104 psi. Monday, December 24, 2018 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSFRVATION cnMMrnRInN nati,Ja-�VIt.:U DEC 18 9018 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ta.Well Status: Oil❑ Gas El SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ 20MC 25.101 20A 025.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: ib. Well Class: Development ❑ Exploratory ❑ Service Q Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 11/19/2018 14. Permit to Drill Number/ Sundry: 218-108 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/23/2018 15, API Number: 50-103-20775-00-00/ 50-103-20775-70-00 4a. Location of Well (Governmental Section): Surface: 253' FNL, 3152' FEL, Sec. 6, TI ON, R3E, UM Top of Productive Interval: 4046' FNL, 47' FEL, Sec. 36, T11 N, R2E, UM Total Depth: 4436 FNL, 1825 FEL, Sec 25, T11 N, R2E, UM 8. Date TO Reached: 11/14/2018 16. Well Name and Number: MT6-04/MT06-04PB1 9. Ref Elevations: KB: 86.72' . GL: 37.2 ' BF: 17. Field / Pool(s): Greater Moose's Tooth Unit/ Lookout Pool 10. Plug Back Depth MD/TVD: 10760 MD/ 8025 TVD 18. Property Designation: AA081818, AA092346, AA081798 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317078 y- 5945551 Zone- 4 TPI: x- 315204 y- 5947084 Zone- 4 Total Depth: x- 313547 y- 5952016 Zone- 4 11. Total Depth MD/TVD: 14790 MD/ 8001 TVD 19. DNR Approval Number: 932553, 340760, 340763, 932533 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1193 MD/ 1190 TVD 5. Directional or Inclination Survey: Yes LaJ (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: 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/Den/Neu 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE CASING FT SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE I CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 94 H-40 36.5 115 36.5 115 42" 10 yds 13-3/8" 68 L-80 36.1 2047 36.1 2029 16" 961 sx 110 ppg DeepCrete 331 sx 15.8 ppg Class G Tail Slurry 9-5/8" 40 L-80 34.2 7720 34.2 7394 12-1/4" 94.9 sx 12.2 ppg Class G Lead 205 sx 15.8 ppg Class G Tail 7" 26 L-80 52.3 9476 52.3 8002 10-1/4" 259 sx 15.8 ppg Class G Tail 4-1 /2" 12.6 L-80 9303 14765 7984 8002 6" uncemented pert pup 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): 1 Perforations: 9668'-14752' MD and 8021'-8002' TVD itIvisVe ✓-u` COMPLETION ADATE of I t'7 VERIFIED -� 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 9315 7546 MD/7275 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOLINT 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 --J� Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I lCalculated --iii, 124 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 L 2/B� o CONTINUED ON PAGE 2 1,Submit ORIGINAL only / 4Z i BDMS f.A(,t DEC 1 $ 2�G 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Permafrost - Base 1193 1190 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI -Alpine C 9556 8009 C-30 2097 2078 C-10 2471 2443 K-3 3441 3382 K-2 3717 3651 Albian 96 4283 4196 HRZ 7674 7363 Kalubik 7689 7373 LCU 7808 7453 Top Alpine C 9556 8009 TD 14790 8001 MT6.04PB1 12480 7986 Formation at total depth: Alpine C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production 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: Andy Marushack Authorized Title: Alaska Drilling Manager Contact Email: andy.j.marushack@cop.com Authorized Contact Phone: 265-6337 Signature: -�_C.� /2.(1.112,619 Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only MT6-04, Injector Complet' i Schematic WP10 0 -OC at least 500' MD ibove Alpine C. 'fanned to Liner Top. Top Alpine C 0 0 9,556' MD / 8,009' TVD 7" 29 ppf TN110SS Tenaris H563 Liner to 9,476' MD / 8,002' TVD @ 81 deg 4-%" 12.6# L-80 TN Blue With Perf Pups 0 0 0 0 0 0 0 6" Hole, TD at at 14,790' MD / 8001' TVD Oct. 3, 2018 — AK Rev 01 Oct. 10, 2018 - NZ 20" 79 ppf H-40 Insulated Conductor Tubing / Liner Completion: 80 feet, cemented to surface 1) 4'/z" Landing Nipple (3.813" X) 2) 4-'/z" x 1" GLM 0 3) 4-1/2" x 1"GLM 4) 4-1/2" Landing Nipple (3.813" XN w/ 3.725" NoGo) set at 74 deg 13-3/8" 68 ppf L-80 TXP (Surf to—1200')IBTCM to TD 5) Liner Top Packer / Hanger Surface Casing w/ Tie Back sleeve @ 2046' MD / 2028' TVD GL J cemented to surface 6) 4 % TN Blue Blank Pipe _ 7) 4'/z' TN Blue Liner with Perf Pups 4-112" 12.6 ppf L-80 Tenaris Blue to 9,314' MD 9 5/8" 40 ppf L-80 TXP (to 5,717 md) 9 5/8" 40 ppf TN -80 HS TXP (to TD) @ 7,719' MD / 7394' TVD 0 -OC at least 500' MD ibove Alpine C. 'fanned to Liner Top. Top Alpine C 0 0 9,556' MD / 8,009' TVD 7" 29 ppf TN110SS Tenaris H563 Liner to 9,476' MD / 8,002' TVD @ 81 deg 4-%" 12.6# L-80 TN Blue With Perf Pups 0 0 0 0 0 0 0 6" Hole, TD at at 14,790' MD / 8001' TVD Oct. 3, 2018 — AK Rev 01 Oct. 10, 2018 - NZ WNS INJ WELLNAME MTS -04 WELLBORE MT6-04 ConoeoPhillips Well Attributes MaxAngle&MD TD Galatia-w.n6o1. APBUWI WapOON Slows mcl(% MDmKe) lwt alm uppingNnSke, Ile. LOOKOUT 501032m]SW INJ 93.00 11,61fi.63 14,]90.0 Cemment HIS pro.) Oa& MMratlgr Entl Bale KBG. do Wp. Doh SSSV.NIPPLE LAST WO 36.52 11/19/2018 140R¢oNTAL-Mr6o+,lmarmle2:o2.3s PM Last Tag V¢neal M.emalc (aduell Dep1M1(mm) 1 End Dale I vvelwore I G.IMM By LAST TAG I IMT6-0d -? promad RAGES Z 7 -'JI Last Rev Reason AnmoNuon I Bad mo -e Lail sr Rev Reason: PDstnie Wo' 12/122018 MT6-04�-Iennall ..............._... __..._ ng Strings M<tlptlm oo(N) IDpml repmKat .Depen mkel seloidefir Wl... YMan n- Grade Top To. """...... - UCTOR M 19.12 36.5 1150 115.0 INGO H-40 Waited Dee, to- BD(in) ID pn) 2epmKe) eal DeplM1 atl(91 Sae Dep'nW1... VNten p...GMe Tep Tnresa CE 133/8 1240 M.1 2,046.6 $0289 68.00 1410 T%P DNwlpelm BD am ID poi TepmKal sM Depth (WR) Sial Dep' FROG_ YMen a... Gretle Top Mrutl MEDIATE 9518 BBd V 342 ],]19.9 ],394.0 4000 180 TXP Dow."'. BBpp IDpnl Top mKa) SN Dep'mKB Bee Dep'mD1... YNLen p_. Graaa Top lnreea CK STRING ) 6.28 52.3 ],564.3 >,2880 2600 L00 TSH BlueDea.mad. DG 9n) ID(Inl Top RIJOB Ser Dep1n DIKB1sel Deyn(rv01 WVten (1... Cr<tl< TopTnma CGBOGCTOR M51150 ] 6.18 ],548.1 94]60 8,0024 2900 TN -110 H563 LN-'aul', IDDetnfl910 r Detalla.,ee, FLd-DYrI L61.0, loonm xm Ame,v pftlal Top(rvol mKB) Topincl(•) IRm cee eom mmaIMvvad-0aellER Dorn) 7,5461 ].2]50 0430 PACKER HBOE SLIXP Tro left "Cater of 7 V' 6.190 Bore) ]5]94 72979 45.33 NIPPLE 'RS'PacHOR 5eal NiDDle 6.190 NIPgE20130 ].6084 7.3189 4629 HANGER 'DG'Fkx-Lock Harper 6.210 [solo, dttNPron DO (in) ID (In) TopmKB) See Depin mKB Bal Dep'(LVDI... MM an (1. Grade TapTme.d suaFACE 76.I;Dds.B LINER 4112 3.98 9,302.8 14,7650 8,002.1 1260 L-80 TXP Liner Details Ila. a.dn o 1,400 Rwd.fr.n,vAdi. <p1a6000Avn1A19 rnP nMBI TOPmol mkal TOP InaI t•1 Ihm oea m mmolm olm) 9334.0 ]. 8Z5 63.86 HANGER I 5'x TfIBx LDCk Her H521 Pinx Pa 4.200 ..r 11.-Sellwalevearm um.Dseda.Gnmrmle Tubing Strings PnuMr Flud.s.rvmmrenre. AUDDst20: nn&Afa ruolne Deacnpnon sRlnp Me... 1p (In1 TOPmKe) fiel Gepin (R. SND aP'Te0)( Brads rmpemmecaon TUBING 0112 398 20J 9.31 d.9 ],9855 12PNq 12.60 L-80 IDlue PRODUCTION Completion Details ToplrvG) Topinel Top mia) (RK61 I'1 Item Gee Com Nominal ID Qn) ni.8ACK6TRIA 523 7oGd,3 287 28.1 0.00 HANGER FMC Bd2' To" Hanger Hydril 563 3.958 2,0130 1.996.1 1466 NIPPLE NIPPLELANDING411T.%3813'. TSH efve 3813 3,477,0 3,417.6 10.8 INJ 4-12' x 1' Camco KBG-2 GLM of DV. TSH Blue b,o 3 865 85124 7S06.8 WAS INJ 4 -12'x1 -Carom KBG-2 GLM ev OCK-2 SOV parried for 2000 3.865 psi cse W Me 9M1ear, TSH Blue 168' INTERMEGInTE: M2-17199- 86496 ],852.8 7193 NIPPLE NIPPIE.LANDING 412' 3813'XN TSH Blue 3.725 9,296.6 T9835 83.89 LOCATOR Lomor NA -Go 5>P OD 3.950 Iw: 6.a247 9,296.9 1.9836 8389 SEALASSY Seal Assembly 3.950 Perforations 8 Slots NP%E:a,6198 M 85, F A...wewr9is ii, aS12G9 0: 11niR018 iop TVGI Blmr., 9net Dena (anolefrt LOLaTOR: AMM Top OWS) Blm jorm) (RNBI (nKm tlnxe02one Dab ) iype Com 9,6fi8.0 14.)52.0 8.020] 8,0024 11/1512018 PERFP SEAL "By 92966 Mandrel Inserts sr n N rop(rvG To (3,41 mate model oDB1 sen Or. rope roaS':e TRORun type pn) (WI Gun Dale cam 3,4r + aan.D 3.41)6 Comm KBG2 1 GAS LIFT MY OMY BK -5 11/1]/2018 2 85124 7.8068 Carrico KBG-2 1 GAB LIFT OV BK 313 1112112018 LINFR: rsea.I.... Notes: General & Safety Erie Gare NOTE: PERFP:9.eR.D14.M0� 11NER: 9, La.Btd,165.0� . perations Summary (with Timelog L,. pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time EM Tme Dur(hr) Phase Op COEe Activiy Cotle Time P -T -x Operztion stmt Depth (W) End Depth (W) 10/22/2018 10/22/2018 1.00 MIRU MOVE RURD P Empty cellar tote, secure tree Prep for 0.0 0.0 07:00 08:00 rig move. 10/22/2018 10/2212018 1.50 MIRU MOVE RURD P Blow down water, steam lines. 0.0 0.0 08:00 09:30 Disconnect power and service lines. 10/22/2018 10/22/2018 2.00 MIRU MOVE MOB P PJSM, Pull pits and motor complexes 0.0 0.0 09:30 11:30 away from sub. Skid rig floor to move position. 10/22/2018 10/22/2018 0.50 MIRU MOVE MOB P Jack up sub to move position. 0.0 0.0 11:30 12:00 10/22/2018 1022/2018 0.50 MIRU MOVE MOB P PJSM, Move sub off MT6-06 0.0 0.0 12:00 12:30 1022/2018 10/22/2018 2.50 MIRU MOVE MOB P Mobilize cellar equipment from MT6- 0.0 0.0 12:30 15:00 06 to MT6-04 and clean up around 06. 1022/2018 10/22/2018 3.00 MIRU MOVE MOB P Spot sub over MT6-04 and shim. 0.0 0.0 15:00 18:00 SIMOPS-Terminating dog house power cable. 1022/2018 1022/2018 1.00 MIRU MOVE MOB P Set stompers, skid rig floor to drill 0.0 0.0 18:00 19:00 position. 10/22/2018 10/22/2018 1.50 MIRU MOVE MOB P Spot pipe shed, pit and motor 0.0 0.0 19:00 20:30 complexes, shim. SIMOPS- lower stair landings and place grating in place. 10/222018 10/22/2018 1.50 MIRU MOVE MOB P Spot Ball Mill, Safe Shack, Site 0.0 0.0 20:30 22:00 Control and pipe shed heater. SIMOPS- Begin testing alarms, innerconnecting pits and motors. 10/22/2018 10/23/2018 2.00 MIRU MOVE RURD P Make service line connections on rig, 0.0 0.0 22:00 00:00 steam, water, air, diesel, mudlines. Swap over to main generator power. Working on rig acceptance checklist. Begin taking on mud @ 23:15 hrs. 10/23/2018 10/232018 2.00 MIRU MOVE RURD P Work on rig acceptance check list. 0.0 0.0 00:00 02:00 Accept rig 02:00 Hrs. 1023/2018 1023/2018 4.00 MIRU MOVE RURD P Install conductor slip lock adaptor. M/U 0.0 0.0 02:00 06:00 riser any. Install flow line, hole fill & bleeder lines. M/U black water line. Test flow meter & gas alarms. SIMOPS - Mobilize BHA components to rig floor. 1023/2018 10123/2018 3.50 MIRU MOVE BHAH P WU BHA to 93' (TFO 246° / 1.5° bend 0.0 93.0 06:00 09:30 motor) 10/232018 10/23/2018 0-30r MOVE SFTY P Pre -spud meeting 93.0 93.0 09:30 10:00 10/2312018 10/232018 0.50 MIRU MOVE SEQP P Fill riser w/spud mud & check for 93.0 93.0 10:00 10:30 leaks. Test surface equipment to 3500 psi (good) 1023/2018 1023/2018 0.75 MIRU MOVE REAM P W&R to base of conductor @ 115' 93.0 115.0 10:30 11:15 w/450 gpm, 600 psi, 10 rpm, 1.5 k trq. 101232018 10/23/2018 0.50 SURFAC DRILL DDRL P Drill ahead fill 5'to 185' MD / 185' 115.0 185.0 11:15 11:45 TVD, ADT A Hrs 10/232018 101232018 2.25SURFAC DRILL DDRL P Drill ahead 1/185' to 367'. Shuffled drill 185.0 367.0 11:45 14:00 o MIU remaining BHA. (NMFC's, -5 -23-/2-08 -0 ) 10/24/2018 00 SURFAC DRILL DDRL Phead f/367'to 1,115' MD/ 1,114' 367.0 1,115.0 14:00 00:00 tk./r'60 ADT 5.5 Hrs, 700 gpm, 1600 psi, t 95 k, S/O wt 95 k, ROT wt 95 rpm, Drig Trq 3 / OBT 2 k /fl/Ibs. Page 1120 Report Printed: 1112012018 aerations Summary (with Timelog L�pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Tim Dir (hr) Phase op code Adhity Cotle Imre P -T-% Dperotlon SW Depth (0Ka) End Depth (MB) 10/24/2018 10/24/2018 9.50 SURFAC DRILL DDRL P Drill ahead V1,115'to 2,047' MD / 1,115.0 2,047.0 00:00 09:30 2,029' TVD, ADT 6.2 Hrs, 900 gpm, 2750 psi, P/U wt 112 k, SIO wt 112 k, ROT wt 110 k, 60 rpm, Ddg Trq 4 / OBT 3 k /ft/lbs. Pumping nut plug drill zone sweeps to aid in bit balling & hole cleaning. (Flow line packed off Q 2,047') 10/24/2018 10/24/2018 1.50 SURFAC DRILL CIRC T Work on removing clay from packed 2,047.0 2,047.0 09:30 11:00 off flow line. Circ w/2 - 8 bpm, 250 - 2100 psi, 20 rpm 1.5 k trq. Huge clay balls observed in flow line. 10/24/2018 10/24/2018 0.25 SURFAC DRILL DDRL P Drill ahead f/2,047'to TO of 2,057' 2,047.0 2,057.0 11:00 11:15 MD / 2,039' TVD, ADT .3 Hrs, 900 gpm, 2500 psi, P/U wt 112 k, S/O wt 112 k, ROT wt 110 k, 60 rpm, Drlg Trq 4 / OBT 3 k Ki/lbs. 10/24/2018 10/24/2018 0,50 SURFAC CASING CIRC P Pump 40 bbl nut plug sweep drill zone 2,057.0 2,057.0 11:15 11:45 sweep w/900 gpm, 2490 psi, 60 rpm, 1.5 k trq 10124/2018 10/24/2018 2.75 SURFAC CASING BKRM P Pump up final survey. BROOH f/2,057' 2,057.0 1,777.0 11:45 14:30 to 1,777'& circ hole clean for w/900 gpm, 2490 - 2340 psi, 60 rpm, 1.5 k trq. Pumped 3 40 bbl nut plug drill zone sweeps. 10/24/2018 1024/2018 0.50 SURFAC CASING SRW P Gyro survey @ 613'& 866' 1,777.0 1,777.0 14:30 15:00 10/24/2018 10/24/2018 2.00 SURFAC CASING TRIP P POOH on elevators f/1,777'to 367' 1,777.0 367.0 15:00 17:00 10/24/2018 10/24/2018 0.25 SURFAC CASING OWFF P F/C (static) - SIMOPS - PJSM on BHA 367.0 367.0 17:00 17:15 10/24/2018 1024/2018 3.25 SURFAC CASING BHAH P Rack back HWDP, Jars & NMFC. L/D 367.0 0.0 17:15 20:30 BHA as per Baker reps. (Bit, motor & string stab significantly balled up) 10124/2018 10/24/2018 0.50 SURFAC CASING BHAH P Clean & clear floor of BHA tools & 0.0 0.0 20:30 21:00 equipment. 10/24/2018 10/24/2018 1.75 SURFAC CASING RURD P Mobilize casing tools & equipment to 0.0 0.0 21:00 22:45 rig floor. R/U to run rasing. R/U Volant & casing tongs, slips & elevators. 10/24/2018 10/252018 1.25 SURFAC CASING PUTB P M/U 13-3/8" 68" BTC shoe track to 0.0 122.0 22:45 00:00 122' 10/252018 1025/2018 3.50 SURFAC CASING PUTB P Cont. to make up shoe track & check 122.0 786.0 00:00 03:30 floats (good). RIH w/13-318" 68# L-80 BTC/TXP casing to 786'. Observe slack off start to diminish. (SO wt 75k) 10/25/2018 1025/2018 0.50 SURFAC CASING CIRC P Circ B/U w/6 bpm / 100 psi 786.0 786.0 03:30 04:00 70/25/2018 1025/2018 1.50 SURFAC CASING PUTB -F- RIH wl13-318"68#L-80 BTCrTXP 786.0 1,262.0 04:00 05:30 rasing f/786' to 1,262' (SO wt 110 k) 10/252018 1025/2018 1.25 SURFAC CASING CIRC P Circ B/U @ base of permafrost w/7 1,262.0 1,262.0 05:30 06:45 bpm / 210 psi 1025/2018 10/25/2018 3.00 SURFAC CASING -P-UT-13 P RIH w/13-3/8" 68# L-80 BTC/TXP 1,262.0 2,008.0 06:45 09:45 casing f/1,262'to 2,008' (SO wt 100 k) 10/25/2018 10/25/2o18 0.25 SURFAC CASING HOBO P M/U landing it & land casing on 2,008.0 2,046.0 09:45 10:00 hanger @ 2,046' 10/252018 10/25/2018 3.00 SURFAC CEMENT CIRC P Circ & cond mud for cement job w/8 2,046.0 2,046.0 10:00 13:00 bpm / 180 psi. Reciprocate pipe. (PU wt 165 k / SO wt 155 k) 10/25/2018 10/25/2018 0.50 SURFAC CEMENT RURD P R/U cement lines. Break cir thru 2,046.0 2,046.0 13:00 13:30 cementing lines. F/C (static) Page 2120 Report Printed: 11120120181 %,perations Summary (with Timelog L�pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log StanTim Bld rano Dur (hr) PhasaOp code Activity code Time P -T -X Opffadon SIaR DepN (fl a End Depth (ftKB) 10/25/2018 10/25/2018 3.50 SURFAC CEMENT CMNT P Dowell pump 1 bbl H2O & PT to 3500 2,046.0 2,046.0 13:30 17:00 psi (good). Dowell pump 100 bbis 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 297.5 bbis 11.0 ppg 1.92 ft3/sx yield LiteCRETE lead cement and 72 bbis 15.8 ppg 1.16 113/sx yield tail cement @ 3 - 5 bpm. Drop top plug. Dowell pump 20 bbis H2O. Rig displace with 273 bbis 12,730 stks 10 ppg DrillPlex with 8 bpm 1465 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. FIC good. CIP 16:54 Hrs. Calculate 154 bbis good cement to surface. Full returns during cementjob. 10/25/2018 10/25/2018 2.50 SURFAC CEMENT RURD P Flush riser w/black water. RID Volant 0.0 0.0 17:00 19:30 & casing running tools & equipment. LID landing jt. 10125/2018 10125/2018 2.00 SURFAC WHDBOP RURD P R/D surface riser assy. N/D speed lock 0.0 0.0 19:30 21:30 head adaptor. SIMOPS - clean pits. 10/25/2018 10/25/2018 1.50 SURFAC WHDBOP. NUND P N/U well head & test to 1000 psi for 10 0.0 0.0 21:30 23:00 min (good). SIMOPS - clean pits. 10/25/2018 10/26/2018 1.00 SURFAC WHDBOP NUND P N/U BOPE. SIMOPS - clean pits. 0.0 0.0 23:00 00:00 10/26/2018 10/26/2018 1.00 SURFAC WHDBOP NUND P N/U BOPE & N/U choke/kill lines. 0.0 0.0 00:00 01:00 SIMOPS - clean pits. 10/26/2018 10/28/2018 3.00 SURFAC WHDBOP MPDA P N/U RCD clamps & orbit valve. N/U 0.0 0.0 01:00 04:00 flow line & flow box. Install annulus valves. Obtain RKB's. Install trip nipple. Install KatchKan. 10/26/2018 10/26/2018 2.00 SURFAC WHDBOP RURD P R/U to test BOPE. Install test plug. Fill 0.0 0.0 04:00 06:00 stack w/H20. Purge air from system. 10/26/2018 10/26/2018 5.00 SURFAC WHDBOP BOPE P Test BOPE w/5 test joint. Annular 250 0.0 0.0 06:00 11:00 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 3-12" X 6" VBR's & blind rams, 5" DarUFOSV, HCR / Man choke/kill, Accumulator test, Initial 3,000 psi, final 1,500 psi, 1st 200 psi recharge = 23 sec's, full recharge = 150 seconds. Nitrogen Bottles x4 = 2,200 psi. Gas alarms and PVT alarms tested. Draw down on chokes 01100 psi. AOGCC Austin McLeod witness test, BLM Mutasim Elganzoory waived witness. 1026/2018 1012612018 0.50 SURFAC WHDBOP RURD P RID testing equipment. B/D lines. 0.0 0.0 11:00 11:30 Install 12.375" wear ring. 10/26/2018 10/262018 1.50 SURFAC CEMENT BHAH P Mobilize BHA components to rig floor. 0.0 0.0 11:30 13:00 R/U Baker BPA. 10/262018 1026/2018 3.00 SURFAC CEMENT BHAH P M/U 12-1/4" Intermediate BHA as per 0.0 621.0 13:00 16:00 Baker reps to 621' 1026/2018 10262018 1.00 SURFAC CEMENT TRIP P RIH f/621'to 1,937' 621.0 1,937.0 16:00 17:00 10/26/2018 10/262018 2.00 SURFAC CEMENT SLPC P Slip &cut drill line. 1,937.0 1,937.0 17:00 19:00 10/26/2018 10/26/2018 0.25 SURFAC CEMENT DHEQ P Shallow hole lest MWD 1,937.0 1,937.0 19:00 19:15 1 10/262018 10/26/2018 1.00 SURFAC CEMENT PRTS P R/U to test casing. Attempt to test 1,937.0 1,937.0 19:15 20:15 I casing & losing pressure. Page 3120 Report Printed: 11120120118 . fjerations Summary (with Timelog L„ pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (hr) Phase Op Cede Activity Code Time P -T-% Operation Start Depth (ftKB) End Depth(ftKB) 10/26/2018 10126/2018 1.00 SURFAC CEMENT PRTS T Trouble shoot & inspect surface 1,937.0 1,937.0 20:15 21:15 equipment. Function rams. Attempt to test. Observe fluid leaking from sensor hose fitting. C/O hose & fittings. Pressure test casing to 2500 psi & chart for 30 min. 10/26/2018 10/26/2018 0.50 SURFAC CEMENT RURD P R/D testing equipment. 1,937.0 1,937.0 21:15 2145 10/26/2018 10/26/2018 0.50 SURFAC CEMENT COCF P W&R f/1,937'to TOC @ 1,958' w/550 1,937.0 1,958.0 21:45 2215 gpm, 1070 psi, 30 rpm, 3 k trq. 10/26/2018 10/27/2018 1.75 SURFAC CEMENT DRLG P Drill out shoe track f11,958' to 2,005' 1,958.0 2,005.0 22:15 00:00 w/550 gpm, 1070 psi, 30 - 50 rpm, 3 - 5 k trq. (F/C on depth @ 1,964) 10/27/2018 10/27/2018 2.50 SURFAC CEMENT DRLG P Drill out shoe track 1/2,005' to 2,057' 2,005.0 2,057.0 00:00 02:30 w/600 gpm, 1200 psi, 50 rpm, 3 - 5 k trq. (Shoe on depth @ 2,046') 10/27/2018 10/27/2018 0.50 SURFAC CEMENT DDRL P Drill ahead 20' new formation f/2,057' 2,057.0 2,077.0 02:30 03:00 to 2,077' MD /2,058' ND, ADT .25 Hrs. Displace to new 10.5 ppg -SND on the fly. 10127/2018 10127/2018 0.75 SURFAC CEMENT BKRM P BROOH f/2,077'to 2,032'w/600 gpm, 2,077.0 2,032.0 03:00 03:45 680 psi. Mud 10.5 ppg In/Out. SPR's 10/27/2018 10/27/2018 0.50 SURFAC CEMENT FIT P R/U to FIT. FIT to 18.5 ppg (845 psi). 2,032.0 2,032.0 03:45 04:15 R/D testing equipment. 10/27/2018 10/27/2018 0.50 INTRM1 DRILL REAM P W&R f(2,032'to 2,077' w/800 gpm, 2,032.0 2,077.0 04:15 04:45 1580 psi, 100 rpm, 4 k trq. 10/27/2018 10127/2018 7.25 INTRMI DRILL DDRL P Drill ahead f/2,077' to 2,930' MD / 2,077.0 2,930.0 04:45 12:00 2,888' TVD, ADT 5.7 Hrs, ECD 11.24 ppg, 900 gpm, 2160 psi, PU wt 134 k, SO wt 126 k, ROT wt 129 k, Trq On/Off = 5/1.5 k ft/lbs. Pumping nut plug drill zone sweeps to aid in BHA balling and hole cleaning. 10/27/2018 10/28/2018 12.00 INTRM1 DRILL DDRL P Drill ahead f/2,930'to 4,740' MD / 2,930.0 4,740.0 12:00 00:00 4,651' TVD, ADT 9 Hrs, ECD 11.19 ppg, 925 gpm, 2700 psi, PU wt 165 k, SO wt 155 k, ROT wt 160 k, Trq On/Off = 10/2 k ft/lbs. Pumping nut plug drill zone sweeps to aid in BHA balling and hole cleaning. 10/28/2018 10/28/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/4,740'to 6,263' MD / 4,740.0 6,263.0 00:00 12:00 6,140' TVD, ADT 9.5 Hrs, ECD 11.15 ppg, 925 gpm, 2910 psi, PU wt 202 k, SO wt 180 k, ROT wt 190 k, 170 rpm, Trq On/Off = 12/3 k ft/lbs. Pumping nut plug drill zone sweeps to aid in BHA balling and hole cleaning. 10/28/2018 10/29/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/6,263'to 7,635' MD / 6,263.0 7,635.0 12:00 00:00 7,337' TVD, ADT 9.6 Hrs, ECD 11.21 ppg, 900 gpm, 2920 psi, PU wt 235 k, SO wt 194 k, ROT wt 205 k, 170 rpm, Trq On/Off = 14.5/5 k fUlbs. Pumping nut plug drill zone sweeps to aid in BHA balling and hole cleaning. 10/29/2018 10/29/2018 1.00 INTRMI DRILL DDRL P Drill ahead f/7,635'to TD of 7,730' 7,635.0 7,730.0 00:00 01:00 MD / 7,400' TVD, ADT 1 His, ECD 11.21 ppg, 900 gpm, 2850 psi, PU wt 235 k, SO wt 195 k, ROT wt 205 k, 170 rpm, Trq On/Off = 10/6 k ff/Ibs. 10/29/2018 10/29/2018 4.75 INTRM1 CASING CIRC P Pump up final survey. Circ hole clean 7,730.0 7,583.0 01:00 05:45 for 5 B/U w/950 gpm, 3100 psi, 170 rpm, 6 k trq. Pumping nut plug sweeps to aid in hole cleaning. Rack back 1 stand every other B/U to 7,583' Page 4/20 ReportPrinted: 11/20/2018 . perations Summary (with Timelog L-pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log StadTine End Time our (hr) Paas. Dip Code vdy Activity code Time P- T -X Operation Start Depth (n De End Depth (flue) 10/29/2018 10/29/2018 0.25 INTRMI CASING OWFF P F/C (static). B/D top drive. 7,583.0 7,583.0 05:45 06:00 10/29/2018 10/29/2018 2.50 INTRMI CASING TRIP P POOH f/7,583' to 6,161'. Various tight 7,583.0 6,161.0 06:00 08:30 spots & encounter 50k overfull 6,161' & not able to work through. 10/29/2018 10/29/2018 0.25 INTRMI CASING TRIP T RIH f/6,161'to 6,358' 6,161.0 6,358.0 08:30 08:45 10/29/2018 10/29/2018 0.75 INTRMI CASING CIRC T Circ B/U w900 gpm, 2600 psi, 50 rpm, 6,358.0 6,263.0 08:45 0930 4.5 k trq. Rack back 1 stand to 6,263' 10/29/2018 10/30/2018 14.50 INTRMI CASING BKRM P BROOH f/6,263' to 2,600' w/ 900 - 925 6,263.0 2,600.0 09:30 0000 gpm, 2530 - 2300 psi, 120 - 150 rpm, 5 - 3 trq. Pumping sweeps to aid in hole cleaning & BHA balling. Hole un- loading significant amounts of cuttings & attempting to pack off. 10/30/2018 10130/2018 10.75 INTRMI CASING BKRM T BROOH f/2,600'to w/900-925 gpm, 2,600.0 2,032.0 00:00 10:45 2300 - 2000 psi, 50 - 120 rpm, 5 - 3 trq. Pumping sweeps to aid in hole cleaning & BHA balling. Hole un- loading significant amounts of cuttings & caving's. Continuously attempting to pack off. Slight overpull while puylling BHA thru shoe. 10/30/2018 10/3012018 1.25 INTRMI CASING CIRC P Pump high vis nut plug sweeps & circ 2,032.0 1,654.0 10:45 12:00 casing clean w/900 gpm, 1900 psi, 100 rpm, 2.5 k trq. Racked back stands f/2,032'to 1,654' 10/30/2018 10/3012018 2.50 INTRMI CASING BKRM T Had to BROOH inside casing to allow 1,654.0 621.0 12:00 14:30 casing to dean up w/900 gpm 1900 - 1500 psi, 100 rpm, 1.5 Inc. Pumping sweeps to aid in hole cleaning. 10/30/2018 10/30/2018 1.00 INTRMI CASING PMPO P Pump OOH due to swabbing f/621'to 621.0 192.0 14:30 15:30 192'w/900 gpm, 1470 psi. (Rack back HWDP & Jars) 10130/2018 10/30/2018 0.50 INTRMI CASING OWFF P F/C (static). PJSM on BHA 192.0 192.0 15:30 16:00 10/30/2018 10/30/2018 1.00 INTRMI CASING SHAH P UD BHA as per Baker reps. 192.0 0.0 16:00 17:00 10/30/2018 10/30/2018 2.50 INTRMI CASING WWWH P Pull wear ring. M/U Johnny Wacker& 0.0 0.0 17:00 19:30 flush stack 2X. SIMOPS - stage casing equipment. Electrician replace camera in derrick. 10/30/2018 10/3012018 1.75 INTRMI CASING BOPE P PJSM-Change out upper pipe rams to 0.0 0.0 19:30 21:15 9 5/8". Set test plug & RPU to test BOPE. SIMOPS - Mobilize casing running tools to rig floor. 10/30/2018 10130/2018 0.75 INTRMI CASING BOPE P Test annular preventer to 250 for 5 0.0 0.0 21:15 22:00 min / /2500 psi for 10 min. Test upper pipe rams to 250 for 5 min I /3500 psi for 10 min. 10/30/2018 10/30/2018 1.00 INTRMI CASING BOPE P R/D testing equipment. Set 13.125" 0.0 0.0 22:00 23:00 1 wear ring. 10/3012018 10/31/2018 1.00 INTRMI CASING PUTB P PJSM on running casing. M/U 9-5/8" 0.0 80.0 23:00 00:00 40# TN -80 TXP shoe track to 80' 10/3172018 10/31/2018 12.00 INTRMI CASING PUTB P Cont. WU 9-5/8" 409 TN -80 TXP shoe 80.0 5,193.0 00:00 12:00 track f/80' to 162'. Check floats (good). RIH 9-5/8" casing f/162'to 5,193'. 10131/2018 10/31/2018 8.75 INTRMI CASING PUTS P RIH 9-5/8" rasing f/5,193'to 7,683'. 5,193.0 7,683.0 12:00 20:45 Washed thru tight hole f/6,820' to 6,875'& 7,540' to 7,683'w/2 - 5 bpm. 10/31/2018 10/31/2018 0.75 INTRMICASING H080 P M/U hanger & landing It. Wash down 7,683.0 7,720.0 20:45 21:30 w/4 bpm, 350 psi & land on hanger 7,7201. P/U wt 345 k / S/0 wt 250 k. Page 5120 ReportPrinted: 1112012018 �,perations Summary (with Timelog L pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log n De Sian Depth Stmt Tim Me ETune DW(hr) Phew Op COW Mvity Code Tune P -T -X OpeaaGan EM Depth (flKB) 10/31/2018 11/1/2018 2.50 INTRMI CEMENT CIRC P Circ& Gond for cement job. Stage flow 7,720.0 7,720.0 21:30 00:00 rate to 8 bpm, 400 psi. Not able to reciprocate pipe due to hanger hanging up in stack. 11/1/2018 11/112018 0.25 INTRMI CEMENT CIRC P Circ& Gond for cement job w/8 bpm, 7,720.0 7,720.0 00:00 00:15 400 psi. 11/1/2018 11/1/2018 0.25 INTRMI CEMENT RURD P Shut down, F/C static. Blow down top 7,720.0 7,720.0 00:15 00:30 drive, Rig up cement hose and 1502 equipment to cement line. 11/1/2018 11/1/2018 0.50 INTRMI CEMENT CIRC P Break circ w/8 bpm, 575 psi. PJSM on 7,720.0 7,720.0 00:30 01:00 1 1 Icementing. 11/1/2018 11/1/2018 3.00 INTRMI CEMENT CMNT P Dowell pump 1.2 bbls H2O & PT to 7,720.0 7,720.0 01:00 04:00 4000 psi (good). Dowell pump 60 bbls 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 40.5 bbis 12.2 ppg 2.3113/sx Yield Class G lead cement and 50.1 bbls 15.8 ppg 1.16113/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbls H2O. Rig displace with 559.2 bbls (5,605 stks Q 95%) 10.5 ppg LSND with 8 bpm 1440 - 960 psi. Reduce pumps to 3 bpm / 650 psi. last 10 bbls. Bump plug, pressure 500 psi over to 1150 psi for 5 min. Check floats. FIC good. CIP 3:49 Hrs. Full returns during cement job. 11/1/2018 11/1/2018 0.50 INTRMI CEMENT OWFF P Monitor well. Static. SIMOPS- R/D 0.0 0.0 04:00 04:30 Plant 11/1/2018 11/1/2018 0.50 INTRMI CEMENT RURD P Cont. R/D Volant. UD landing it. 0.0 0.0 04:30 05:00 11/1/2018 11/1/2018 2.00 INTRMI CEMENT WWSP P FMC Pull thin wall wear ring. Set 9- 0.0 0.0 05:00 07:00 5/8" packoff and test to 5000 psi for 10 minutes, CPAI witnessed (good) 11/1/2018 11/1/2018 2.00 INTRMI CEMENT BOPE P PJSM, C/O Upper Pipe Rams from 9- 0.0 0.0 07:00 09:00 5/8" SBR to 4W' x 7" VBR. 1111/2018 11/1/2018 1.00 INTRMI WHDBOP RURD P R/U to test BOPE, fill stack, choke and 0.0 0.0 09:00 10:00 kill lines and choke manifold with H2O, Purge air from system. 11/1/2018 11/1/2018 6.50 INTRMI WHDBOP BOPE P Test BOPE w/4", 5", & 7" test joints. 0.0 0.0 10:00 16:30 Annular 250 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; BOP's, Choke needle valve, Upper 4-1/2" X 7" VBR's, Lower 3-1/2" X 6" VBR's & blind rams, 5' Dad/FOSV, HCR / Man choke/kill, Accumulator test, Initial 3,000 psi, final 1,500 psi, 1st 200 psi recharge = 25 sec's, full recharge = 147 seconds. Nitrogen Bottles x4 = 2,200 psi. Gas alarms and PVT alarms tested. Draw down on chokes (/1100 psi. AOGCC Brain Bixby waived witness of test 11/1/2018 11/1/2018 0.25 INTRMI WHDBOP SFTY T Remove ice from derrick 0.0 0.0 16:30 16:45 1 I 11/1/2018 11/1/2018 1.25 INTRMI WHDBOP MPDA P Remove trip nipple & install MPD test 0.0 0.0 16:45 18:00 plug. 250 psi low 11200 psi high for 5 min. Remove test plug & install trip nipple. SIMOPS -AD LOT, H2Oflush & FP on 13-3/8" X 9-5/8" OA Page 6120 ReportPrinted: 1 112 012 01 8 operations Summary (with Timelog L�pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth StadTMe End Terre our IN) Phase Ed Code Ac ity Code Tune P -T -X Cpendlon (nrca) End oepm IttXe> 11/1/2018 11/1/2018 1.00 INTRMI WHDBOP ROPE T Miscommunication on how upper rams 0.0 0.0 18:00 19:00 were tested. Re -test upper 4-1/2" X 7" VBR's, dart valve, & 5" FOSV 250 psi for 5 min 13500 psi for 10 min. 11/1/2018 11/1/2018 1.50 INTRMI WHDBOP RURD P R/D testing equipment. B/D lines. Set 0.0 0.0 19:00 2030 8.75" ID weasr ring. 11/1/2018 11/2/2018 3.50 INTRMI CEMENT BHAH P PJSM. M1U 8-314"X 10-1/4" BHA as 0.0 555.0 20:30 00:00 per Baker & SLB reps to 555' (Up -load data to LWD tools & load sources) 11/2/2018 11/212018 0.75 INTRMI CEMENT TRIP P RIH f/555'to 1,965' 555.0 1,965.0 00:00 00:45 11/2/2018 11/212018 0.50 INTRMI CEMENT DHEO P Shallow hole test MWD tools w/550 1,965.0 1,965.0 00:45 01:15 gpm, 1440 psi, 30 rpm, 1.6 k trq. 11/2/2018 11/2/2018 3.00 INTRMI CEMENT TRIP P RIH 111,966to 7,422' 1,965.0 7,422.0 01:15 04:15 111212018 11/2/2018 0.75 INTRMI CEMENT CIRC P Circ B/U for casing test w/650 gpm, 7,422.0 7,517.0 04:15 05:00 2500 psi, 30 rpm, 1.5 k trq. f/7,422' to 7,517' 11/2/2018 11/2/2018 1.50 INTRMI CEMENT PRTS P R1U testing equipment. pressure test 7,517.0 7,517.0 05:00 06:30 casing to 3500 psi & chart for 30 min (good). RID testing equipment. 11/2/2018 11/212018 0.50 INTRMI CEMENT COCF P W&R f/7,517'to TOC @ 7,626'w/500 7,517.0 7,626.0 06:30 07:00 gpm, 1700 psi, 40 rpm, 9.3 k trq. 11/2/2018 11/212018 6.50 INTRMI CEMENT DRLG P Drill out shoe track & rat hole f/7,626' 7,626.0 7,730.0 07:00 13:30 to 7,730'w/500 gpm, 1700 psi, 40 - 80 rpm, 10 k trq. (Float collar & shoe track on depth) 11/2/2018 11/2/2018 0.50 INTRMI CEMENT DDRL P Drill 20'new formation f77,730'to 71730.0 7,750.0 13:30 14:00 7,750' MD / 7,413' TVD, ADT A H's, 600 gpm, 2300 psi, 80 rpm, 11 k trq. Start displacing to new 10.5 ppg LSND 11/2/2018 11/2/2018 0.75 INTRMI CEMENT DISP P Cont. to displace to new 10.5 ppg 7,750.0 7,706.0 14:00 14:45 -SND w/600 - 500 gpm, 2300 - 1580 psi, 80 rpm 7 trq. BROOH f/7,750' to 7,706'. Hole attempting to pack off just below shoe 11/2/2018 11/2/2018 1.00 INTRM1 CEMENT FIT P R/U testing equipment. FIT to 14.0 7,750.0 7,706.0 14:45 15:45 ppg w/1350 psi. R/D testing equipment 11/2/2018 11/2/2018 0.50 INTRM2 DRILL -WP —DA P Pull trip nipple & install RCD bearing. 7,706.0 7,706.0 15:45 16:15 11/2/2018 11/2/2018 0.75 INTRM2 DRILL MPDA P SPR's. Break in bearing. Perform 7,706.0 7,706.0 16:15 17:00 practice dynamic connections w/SLB cement unit. 1112/2018 11/2/2018 1.75 INTRM2 DRILL REAM P W7R V7,706to 7,750'w/615 gpm, 7,706.0 7,750.0 17:00 18:45 2200 psi, 80 rpm, 7 k trq. Hole attempting to pack off & significant amount of shale caving's across shakers. 11/2/2018 11/2/2018 3.50 INTRM2 DRILL DDRL P Drill ahead 8-3/4" hole f/7,750'to 7,750.0 7,895.0 18:45 22:15 7,895' MD / 7,511' TVD, ADT 3.3 Hrs, 11.44 ppg ECD, 615 gpm, 2200 psi, P/U wt 220 k, S/O wt 180 k, ROT wt 200 k, On/Off Btm trq 10/7 k fUlbs. Performing dynamic MPD connections with assistance from SLB cement unit. Page 7/20 Report Printed: 1112 012 01 8 operations Summary (with Timelog L,epths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log smd rano End Time Our(hm Phase op Cade Activity cone Time P -T-% Operation St dDepth End Depth (flKa) 11/2/2018 11/212018 1 o INTRM2 DRILL UREM P Drop 1.25" ball. BROOH while putting 7,895.0 7,895.0 22:15 23:15 ball on seat f/7,895' to 7,839'. Ball on seat 1027 stks. Pressure up to 1570 psi & activate reamer. Base parameters = Reamer closed 615 gpm, 2220 psi, 4884 trpm / Reamer open 615 gpm, 1750 psi, 4404 trpm. BROOH w/reamer open & open hole to 7,725' . Shut down rotary & pull 5 k against shoe & confirm reamer open. 11/2/2018 11/3/2018 0.75 INTRM2 DRILL REAM P W&R back to connection depth of 7,895.0 7,895.0 23:15 00:00 7,895'opening up hole to 10-1/4" w/750 gpm, 2380 psi, 100 rpm, 8 k trq. 11/312018 11/32018 12.00 INTRM2 DRILL DDRL P Drill ahead 8-3/4" X 10-1/4" hole 7,895.0 8,460.0 00:00 12:00 f/7,895'to 8,460' MD / 7,788' TVD, ADT 10.9 His, 11.62 ppg ECD, 750 gpm, 2560 psi, ROT wt 198 k, On/Off Btm trq 10.5/6.5 k ft/lbs. Performing dynamic MPD connections with assistance from SLB cement unit. 11/32018 11/4/2018 12.00 INTRM2 DRILL DDRL P Drill ahead 8-3/4"X 10-1/4" hole 8,460.0 9,160.0 12:00 00:00 f/8,460'to 9,160'MD/ 7,967'TVD, ADT 10.4 Hrs, 11.60 ppg ECD, 750 gpm, 2700 psi, ROT wt 195 k, On/Off Btm trq 11/7 k ftllbs. Performing dynamic MPD connections with assistance from SLB cement unit. 11/42018 11/42018 5.75 INTRM2 DRILL DDRL P Drill ahead 8-3/4"X 10-1/4" hole 9,160.0 9,476.0 00:00 05:45 f/9,160'to 9,476'MD / 8,003'TVD, ADT 5.7 Hrs, 11.66 ppg ECD, 750 gpm, 2730 psi, ROT wt 200 k, On/Off Bim trq 11.5/8 k ftAbs. Performing dynamic MPD connections with assistance from SLB cement unit. Observe high gamma zone @ 9,440' 1114/2018 11/4/2018 3.25 INTRM2 CASING CIRC P Circ & cond while racking back 1 9,476.0 9,309.0 05:45 09:00 stand per 2 B/U f/9,476'to 9,309' W/750 gpm, 2720 psi, 150 rpm, 9.5 - 7.5 k trq. Maintaining 11.5 ppg MPD connections. 11/4/2018 11/4/2018 0.75 INTRM2 CASING CIRC P Drop ball & close under reamer. Ball 9,309.0 9,309.0 09:00 09:45 on seat 1218 stks. Base parameters = Reamer open 650 gpm, 2220 psi, 4557 trpm / Reamer closed 650 gpm, 2460 psi, 5166 trpm. Rotate 30 rpm @ 6.5 k trq. 11/42018 11/4/2018 4.25 INTRM2 CASING CIRC P Wt up from 10.5 ppg to 11.2 ppg. 9,309.0 9,309.0 09:45 14:00 Initial 650 gpm, 2460 psi & Final 480 gpm, 1580 psi. Rotae 100 rpm @ 5 k trq, Max ECD 12.0 ppg. 11/4/2018 11/4/2018 0.50 INTRM2 CASING OWFF P SPR's. B/D top drive. F/C (static) 9,309.0 9,309.0 14:00 14:30 11/4/2018 11/4/2018 2.50 INTRM2 CASING §MPD P Strip OOH f/9,309' to 7,704' as per 9,309.0 7,704.0 14:30 17:00 MPD schedule. 11/4/2018 11/4/2018 1.00 INTRM2 CASING CIRC P Circ B/U w/485-530 gpm, 1580- 7,704.0 7,704.0 17:00 18:00 1700 psi, 60 rpm, 4 k trq. 11/4/2018 11/4/2018 o.75 INTRM2 CASING OWFF P B/D top drive. F/C (static). SIMOPS - 7,704.0 7,704.0 18:00 18:45 B/D cement lines. 11/42018 11/42018 4.25 INTRM2 CASING SMPD P Strip OOH V7,704' to 1,026' as per 7,704.0 1,026.0 18:45 23:00 MPD schedule. 11/42018 11/4/2018 0.50 INTRM2 CASING 0 F P F/C (static). SIMOPS - PJSM on 1,026.0 1,026.0 23:00 23:30 pulling RCD 11/4/2018 11/4/2018 0.25 INTRM2 CASING MPDA P Pull RCD bearing & install tdp nipple. 1,026.0 1,026.0 23:30 23:45 Page 8120 Report Printed: 11/20/2018 . ..perations Summary (with Timelog L. pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stertrime Ertl Tune our (hd Pnaseata op Cotle AcWdy Code rune P -T -X operetlon (rt „ Depth End Depth (fIKB) 11/4/2018 11/5/2018 0.25 INTRM2 CASING TRIP P POOH f/1,026'to 556' 1,026.0 556.0 23:45 00:00 11/5/2018 11/5/2018 0.75 INTRM2 CASING TRIP P POOH f/556'to 188' 556.0 188.0 00:00 00:45 11/5/2018 11/52018 1.75 INTRM2 CASING SHAH P UD BHA as per Baker/SLB reps. 188.0 0.0 00:45 02:30 (PJSM & remove sources) 11/5/2018 11/52018 1.00 INTRM2 CASING BHAH P Clean & clear floor of BHA tools & 0.0 0.0 02:30 03:30 equipment. SIMOPS - Stage casing tools & equipment at bottom of beaver slide. 11/5/2018 11/5/2018 0.75 INTRM2 CASING RURD P R/U to run liner. R/U 7" elevators, 0.0 0.0 03:30 04:15 double stack stongs, slips & fill up line. 11/5/2018 11/5/2018 3.25 INTRM2 CASING PUTB P P/U & RIH 7" Hyd 563 liner to 1,857' 0.0 1,857.0 04:15 07:30 11/5/2018 11/5/2018 1.00 INTRM2 CASING OTHR P M/U flex lock liner hanger, HRDE 1,857.0 2,038.0 07:30 08:30 packer, & wiper plug assy f/1,857' to 2,038' 11/5/2018 11/5/2018 0.50 INTRM2 CASING CIRC P Break circ & circ liner volume w/2 - 5 2,038.0 2,038.0 08:30 09:00 bpm, 130 - 220 psi. B/D top drive. 11/5/2018 11/5/2018 7.50 INTRM2 CASING RUNL P RIH w/liner on 5" DP f/2,038'to 7,686' 2,038.0 7,686.0 09:00 16:30 11/5/2018 11/5/2018 2.25 INTRM2 CASING CIRC P Stage pumps up to 6 bpm, 500 psi 7,686.0 7,686.0 16:30 18:45 and circ B/U. Base T&D parameters = P/U wt 200 k, SIO wt 190 k, ROT wt 195 k, 20 rpm 3.5 k lrq. 11/5/2018 11/6/2018 5.25 INTRM2 CASING RUNL P RIH w/liner on 5" DP f/7,686'to 9,120'. 7,686.0 9,120.0 18:45 00:00 Started taking wt at 8,670'. Start washing down w/1.5 bpm, 380 psi f/8,721' 11/6/2018 11/6/2018 2.25 INTRM2 CASING RUNL P RIH with liner on 5" DP from 9, 120'to 9,120.0 9,475.0 00:00 02:15 9,475' washing down @ 1.5 bpm, 360 psi. 11/62018 11/62018 0.50 INTRM2 CEMENT RURD P WU Baker cement swivel & cement 9,475.0 9,476.0 02:15 02:45 line with 5' pup. RIH & tag bottom @ 9,476', set down 20 k. PU=235k, S/0=175k 11/6/2018 11/6/2018 4.25 INTRM2 CEMENT CIRC P Circulate and condition for cement job, 9,476.0 9,476.0 02:45 07:00 stage up from 1.5 to 4.5 bpm, 360 psi ICP, 460 psi FCP. Heaviest mud weight out 11.4 ppg. No signs of packing off. SIMOPS- PJSM on cementjob. 11/6/2018 11/62018 1.00 INTRM2 CEMENT CMNT P SLB flood surface lines with water and 9,476.0 9,476.0 07:00 08:00 PT to 4000 psi -good. SLB pumped 30 bbl 11.5 ppg Mud Push @ 3.8 bpm, 450 psi. Drop bottom Dart. Pump 71.6 bbl 15.8 ppg Cement @ 4.8 bpm, 245 psi WHP. Drop Top Dart. SLB kicked out cement with 20.1 bbl water. 11/6/2018 11/6/2018 1.00 INTRM2 CEMENT CMNT P Rig displace cement with 1676 strokes 9,476.0 9,476.0 08:00 09:00 (168.8 bbl) 11.2 ppg LSND @ 4.5-3 bpm. Observed Dart #1 latch @ 350 stks, pressure up to 1460 psi, observe Dart #2 latch @ 1035 stks, pressure up to 1480 psi and release. Bumped plugs @ 1676 stks, pressure up from 580 psi FCP to 1100 psi and hold 5 minutes. CIP @ 08:56 hrs. OWFF while holding pressure, slight drop in annulus. Page 9120 ReportPrinted: 1112 012 01 8 . perations Summary (with Timelog r epths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Tim End Tim Oer(hd Phase op Corte Activity Cx$e Tire P -T -x Dperetw Steil Depth (Itl(B) EM Depth (MB) 11/6/2018 11/6/2018 0.25 INTRM2 CEMENT PACK P Set liner hanger, pressure up from 9,476.0 7,580.0 09:00 09:15 1100 psi to 2400 psi, slack off 50k down. Pressure up to 3750 to release running tool. Bleed off pressure. P/U=235k, S/0=175k. 11/6/2018 11/6/2018 0.25 INTRM2 CEMENT OWFF P Monitor well for flow-static.Check 7,580.0 7,580.0 09:15 09:30 floats, holding. 11/6/2018 11/6/2018 0.25 INTRM2 CEMENT PACK P Set SLZXP Liner Top Packer. P/U 4'to 7,580.0 7,580.0 09:30 09:45 expose rotating dog sub, S/O 50k down and observe packer set. P/U 4', rotate 15 rpm, 5.5k Tq. Slack off again 50k to confirm packer set. T' Shoe @ 9,476' MD, 8,003' TVD. TOL= 7,546' MD. 11/6/2018 11/6/2018 0.25 INTRM2 CEMENT PRTS P Test liner top packerto 2500 psi for 10 7,580.0 7,580.0 09:45 10:00 1 minutes, charted, good. 11/6/2018 11/6/2018 0.50 INTRM2 CEMENT TURD P Rig down Baker cement head and 7,580.0 7,580.0 10:00 10:30 1502 equipment. 11/6/2018 11/6/2018 0.50 INTRM2 CEMENT CIRC P Trap 400 psi and POOH until pressure 7,580.0 7,530.0 10:30 11:00 bleeding off as passes tie back sleeve, Circulate @ 2.2 bpm, 250 psi continue to wash up tie back sleeve. Increase to 8 bpm with bottom of running tool @ TOL, Circulate and clean up. RIB stand to 7,530' MD. 11/6/2018 11/6/2018 0.75 INTRM2 CEMENT CIRC P BU x 2 @ 18 bpm, 1430 psi. 7,530.0 7,530.0 11:00 11:45 P/U=200k, S/0=180k. Dumped 230 bbl cement contaminated mud, some high ph from Mud Push but no cement observed. 11/6/2018 11/6/2018 0.25 INTRM2 CEMENT OWFF P Monitor well for flow, ,static. 7,530.0 7,530.0 11:45 12:00 11/6/2018 11/6/2018 0.25 INTRM2 CEMENT OWFF P Continue monitorwell forflowstatic 7,530.0 7,530.0 12:00 12:15 1 30 minutes total. 11/6/2018 11/6/2018 2.75 INTRM2 CEMENT TOLD P POOH from 7,530' MD to 5,666' MD, 7,530.0 5,666.0 12:15 15:00 laying dawn 5" DP, cleaning and inspecting connections for cement rings. 11/6/2018 11/6/2018 0.25 INTRM2 CEMENT CIRC P Pump 25 bbl 12.6 ppg tlryjob, blow 5,666.0 5,666.0 15:00 15:15 down lop drive. 11/6/2018 11/6/2018 4.75 INTRM2 CEMENT PULD P Continue POOH from 5,666' MD to 5,666.0 0.0 15:15 20:00 surface, laying down 5" DP, cleaning and inspecting connections for cement rings. Lay down liner running tools, confined dog sub sheared. 11/6/2018 11/6/2018 1.00 INTRM2 CEMENT BHAH P Clean and clear rig floor, lay down 0.0 0.0 20:00 21:00 liner running tools. 11/6/2018 11/6/2018 0.75 INTRM2 TEMENT P Lay tlown HWDP and Jars from 0.0 0.0 21:00 21:45 Derrick via mousehole. Monitor well via trip tank, 0 gain/loss. 11/6/2018 11/6/2018 0.25 INTRM2 CEMENT PRTS P Pressure lest casing to 1000 psi 0.0 0.0 21:45 22:00 against blinds for 10 minutes charted, good. 3.1 bbl pumped. 11/6/2018 11/7/2018 2.00 INTRM2 CEMENT NUND P Blow down choke and kill, drain stack. 0.0 0.0 22:00 00:00 Remove mousehole, flow box, trip nipple. Back off speed head and remove stack, loosen choke line. Prep to install 7" casing spool. 11/7/2018 11I7I2018 1.00 INTRM2 CEMENT NUND p Install 7" casing spool. FMC test void 0.0 0.0 00:00 01:00 to 5000 psi witnessed. SIMOPS- Organize 7" Tie Back in pipe shed. Page 10120 ReportPrinted: 11/20/2018 . vperations Summary (with Timelog L dpths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log aid Depth S tart Tyne End roe our (hr) Phase Op Code Activity Code Time P -T-% Operation (like) e) End Depth (IIKB) 11/7/2018 11/7/2018 1.50 INTRM2 CEMENT NUND P N/U well head and BOPE, align 0.0 0.0 01:00 02:30 production port. Tighten up choke line under rig Floor. 11/7/2018 11/7/2018 1.00 INTRM2 CEMENT MPDA P R/U MPDE, Flow box, lines, drains, 0.0 0.0 02:30 03:30 1502 equipment, return lines, trip nipple and install mouisehole. 11/7/2018 11!7/2018 0.75 INTRM2 CEMENT BOPE P Pull wear ring and set lower test plug. 0.0 0.0 03:30 04:15 Fill stack with water and purge air from system. 11/7/2018 11/7/2018 0.75 INTRM2 CEMENT BOPE P Test with 5" test joint, Upper 4%" x 7" 0.0 0.0 04:15 05:00 pipe rams, HCR kill, choke valves 1,3,4,6. Test breaks @ 7" casing spool all to 250/3500 psi for 5110 min charted. Rig down test equipment and blow down lines. 11/7/2018 11!7/2018 2.00 INTRM2 CEMENT RURD P Rig up to run 7" Tie -Back casing. P/U 0.0 0.0 05:00 07:00 casing hanger and packoof via beaverslide. Rig up double stack power tongs and torque tum equipment, RFU Volant CRT with swivel, bail extensions and 7" casing elevators. 11/7/2018 11/7/2018 2.25 INTRM2 CEMENT PUTS P PJSM, P/U and RIH with Seal easy 0.0 972.0 07:00 09:15 and 7" Tanana Blue casing, torque turned to 9k to 972' MD. Bad make up on #23 box1#24 pin. 11/7/2018 11/7/2018 0.25 INTRM2 CEMENT PUTB T Change out collar on joint#23, swap 972.0 972.0 09:15 09:30 out #24. •'Tenaris" Blue rasing connection not making up properly. 11/7/2018 11/7/2018 2.50 INTRM2 CEMENT PUTS P Continue P/U and RIH with 7" Tie 972.0 2,209.0 09:30 12:00 Back from 972' MD to 2,209' MD. 11/7/2018 11/7/2018 7.75 INTRM2 CEMENT PUTB P Continue P/U and RIH with 7" Tie 2,209.0 7,523.0 12:00 19:45 Back from 2,209' MD to 7,523' MD. 104 jts TSH Blue, XO and 79 jts H563. 70.25 bbl Calc Disp, 71.5 bbl Actual Disp. 11/7/2018 11/7/2018 1.00 INTRM2 CEMENT HOSO P Rig up cement line to swivel, wash 7,523.0 7,546.0 19:45 20:45 down joint#184 and #185, P/U=225k, S/0=195k. Wash down @ 1 bpm, 240 psi, locate top of liner @ 28' in on joint #184,(7,551'), No -Go out at 6.5' in on joint #185 (7,569.26'). Lay down joint #184. 11/7/2018 11/7/2018 0.25 INTRM2 CEMENT PRTS P Rig up and test bullet seals to 1000 7,546.0 7,546.0 20:45 21:00 psi for 10 minutes via annulus, with casing open. 11/7/2018 11/7/2018 1.00 INTRM2 CEMENT HOSO P LID #184, Make up space out pup on 7,546.0 7,546.0 21:00 22:00 # 183, M/U hanger and landing joint. Wash down to TOL, P/U 2' with hanger just below annular. Grease landing joint for stripping. Close annular, PJSM on pumping inhibitor and diesel. 11/7/2018 11/7/2018 1.75 INTRM2 CEMENT CRIH P Line up and reverse in 21 bbl spacer, 7,546.0 7,546.0 22:00 23:45 followed by 177 bbl corrosion inhibited water @ 4 bpm, 850-1100 psi. Shut down and line up ball mill to pump 40 bbl diesel @ 2.5 bpm, 1200 psi. Shut down, shut in. 11/7/2018 11/8/2018 0.25 INTRM2 CEMENT HOSO P Slack off, stripping in T through 7,546.0 7,564.0 23:45 00:00 j j j j annular to engage bullet seals. Bleed off pressure, open annular and land hanger @ 7,564.26' MD. 11/8/2018 11/8/2018 0.75 INTRM2 CEMENT RURD P Rig down 7" elevators, Back off and 7,564.0 0.0 00:00 00:45 1 lay down 7" landing joint per FMC. Page 11120 Report Printed: 1 112 012 01 8 . operations Summary (with Timelog L �pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth startTmre End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation (fll®) Ertl Depth(ttNB) 11/8/2018 11/8/2018 1.25 INTRM2 CEMENT W WSP P Set 7" packoff and RILDS per FMC. 0.0 0.0 00:45 02:00 Test packoff to 250/5000 psi for 5110 minutes CPA] witnessed. SIMOPS-Rig down Volanl CRT, bail extensions, double stack tongs and lay down via beaverslide. 11/8/2018 11/8/2018 1.00 INTRM2 CEMENT PRTS P R/U and test 9-5/8" x 7" annulus to 0.0 0.0 02:00 03:00 2500 psi for 30 minutes using Ball Mill pump and diesel, charted at wellhead with rig chart. Bleed off, blow down lines and rig down. SIMOPS- Lay down 5" subs and equipment, PIU 4" FOSV/Dart via beaverslide. 11/8/2018 11/8/2018 1.50 INTRM2 WHDBOP RURD P Change out upper VBRs from 4Y2" x 7" 0.0 0.0 03:00 04:30 to 3F" x 6". Change out DS UPR door seal while changing rams. SIMOPS- Change out saver sub on top drive from NC50 to XT-39. Mechanic and electrician inspecting top drive. 11/8/2018 11/8/2018 0.50 INTRM2 WHDBOP RURD P Continue changing out saver sub. 0.0 0.0 04:30 05:00 SIMOPS- Mechanic and electrician inspecting and servicing top drive. 11/8/2018 11/8/2018 1.00 INTRM2 WHDBOP RURD P Rig up to test BOPE, set upper test 0.0 0.0 05:00 06:00 plug with 3W' test joint, fill stack and manifold with water, purge air from system. 11/8/2018 11/8/2018 3.75 INTRM2 WHDBOP BOPE P Test BOPE to BUM specs, Mutasim 0.0 0.0 06:00 09:45 Elganzoory'Nolification recieved' 11/5/18 13:41 his, AOGCC Guy Cook waived. With 3%" Test joint, test annular preventer to 250/2500 for 5/10 minutes charted, Upper and lower pipe rams, auto and manual IBOP, 4" Demco kill, HCR choke and kill, manual choke and kill, choke manifold valves #1-#14, needle valve above #1, 4" XT-39 FOSV and Dart valve all to 250/3500 psi for 5/10 minutes charted. 11/8/2018 11/8/2018 0.25 INTRM2 WHDBOP BOPE P Perform accumulator test. System 0.0 0.0 09:45 10:00 pressure=2900 psi, Pressure after functioning all rams, annular and HCR's=1500 psi. 200 psi attained=33 seconds with electric pump, Full system recovery=160 seconds with electric and 3 air pumps. 4 battle Backup Nitrogen average=2150 psi. Function test from remote panel in boiler room. 11/812018 11/8/2018 2.00 INTRM2 WHDBOP BOPE P with 4W' Testjoint, test annular 0.0 0.0 10:00 12:00 preventer to 250/2500 psi 5/10 minutes charted. Test UPR and LPR to 25013500 psi for 5110 minutes charted. Test blind rams 250/3500. Tested gas alarms, flow meter and PVT sensors. 11/8/2018 11/8/2018 0.50 INTRM2 WHDBOP BOPE P Continue testing blind rams to 3500 0.0 0.0 12:00 12:30 psi for 10 minutes. Test manual and hydraulic super auto choke to 1100 psi. 11/8/2018 11/8/2018 0.75 INTRM2 WHDBOP RURD P Rig down test equipment, blow down 0.0 0.0 12:30 13:15 I I I lines and choke manifold, Pull test plug, FMC set 6.1875" ID wear ring. Page 12120 ReportPrinted: 11120/2018 Summary (with Timelog L epths) Gioperations MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Twe End The Our (hr) phase op Code Activity code Time P-T-x Operation start � (fit®) End Oepih (fixe) 11/8/2018 11/8/2018 1.25 INTRM2 CEMENT RURD P Pickup BHA tools and equipment via 0.0 0.0 13:15 14:30 beaverslide. SIMOPS- Mechanic and electrician working on top drive hydraulic system 11/812018 1118/2018 0.75 INTRM2 CEMENT BHAH P PJSM, Make up 6" BHA#4 per 0.0 65.0 14:30 15:15 DD/MWD reps to 65' MD. 11/8/2018 11/8/2018 0.50 INTRM2 CEMENT BHAH P Baker plug into MWD @ 35' MD, 65.0 65.0 15:15 15:45 SIMOPS- Continue making up BHA in mousehole (M/U Floats, filter sub, NM Flex collars) 11/8!2018 11/8/2018 0.25 INTRM2 CEMENT BHAH P Continue making up BHA per Baker 65.0 145.0 15:45 16:00 DDIMWD reps to 145' MD. 11/8/2018 11/8/2018 0.25 INTRM2 CEMENT BHAH P Clear rig floor and load sources to 145.0 145.0 16:00 16:15 MWD 11/8/2018 11/8/2018 0.50 INTRM2 CEMENT BHAH P Continue M/U BHA #4 from 145'MDto 145.0 332.0 16:15 16:45 332' MD 11/8/2018 11/8/2018 1.75 INTRM2 CEMENT PULD P RIH with BHA W4, picking up 4" 14# 332.0 1,754.0 16:45 18:30 DP from pipe shed from 332' MD to 1,754' MD. 11/8/2018 11/8/2018 0.50 INTRM2 CEMENT DHEQ P Shallow pulse test MWD @ 200 gpm, 1,754.0 1,754.0 18:30 19:00 1070 psi-good. 11/8/2018 11/9/2018 5.00 INTRM2 CEMENT PULD P Continue RIH with BHA #4, picking up 1,754.0 7,268.0 19:00 00:00 4" 14# and 15.7# DP from pipe shed from 1,754' MD to 7,268' MD filling pipe every 20 stands. P/U=155k, S/0=140k @ 7,077' MD. 11/9/2018 11/9/2018 2.75 INTRM2 CEMENT PULD P Continue RIH with BHA #4 -on 4" DP 7,268.0 9,172.0 00:00 02:45 from 7,268' MD to 9,172' MD filling pipe every 20 stands. 11/9/2018 02:45 11/9/2018 0.50 INTRM2 CEMENT SLPC P PJSM, Cut and slip 90' ddlling line. 9,172.0 9,172.0 03:15 SIMOPS- circulate @ 3 bpm, reducing mud weight from 11.2 ppg to 10.4+ ppg 11/9/2018 11/9/2018 0.50 INTRM2 CEMENT SVRG P Service rig, top drive and draworks. 9,172.0 9,172.0 03:15 03:45 SIMOPS- Continue circulate and condition mud @ 3 bpm. 11/9/2018 11/9/2018 0.50 INTRM2 CEMENT CIRC P Continue circulating @ 200 gpm until 9,172.0 9,172.0 03:45 04:15 lighter mud coming out, one full circulation cumulative. 11/9/2018 11/9/2018 1.50 INTRM2 CEMENT PRTS P Rig up and test 7" casing to 3500 psi 9,172.0 9,172.0- 04:15 05:45 for 30 minutes charted. Blow down lines and rig down test equipment. 11/9/2018 11/9/2018 1.25 INTRM2 CEMENT COCF P Wash and ream down to landing collar 9,172.0 9,348.0 05:45 07:00 from 9,172' MD to 9,348' MD @ 200 gpm, 1440 psi, 60 rpm @ 4k Tq. Tag cement stringers @ 9,283', firmer cement @ 9,337' MD. Continue cutting mud weight to 10.2 -ppg- 11/912018 1119!2018 3.75 INTRM2 CEMENT DRLG P Drill out shoe track from 9,348' MD to 98.0 9,476.0 07:00 10:45 9,476' MD, 200-130 gpm, 1440-790 ,34 psi. 80-40 rpm, 5.5-10.5k Tq. 11/9/2018, 11/9/2018 1.25 INTRM2 CEMENT DDRL P Drill new formation from 9,476' MD to 9,476.0 9,486.0 10:45 12:00 9,486' MD, 8,003' TVD. 200 gpm @ 1550 psi, 11.32 ppg ECD. P/U=185k, S/0=145k, ROT=165k, 40-80 rpm. Tq on/off=7kl6k. ADT=.6 hrs, 11/9/2018 11/9/2018 1.00 INTRM2 CEMENT DDRL P Drill new formation from 9,486' MD to 9,486.0 9,496.0 12:00 13:00 9,496' MD, 8,004' TVD. 200 gpm @ 1550 psi, 11.32 ppg ECD. P/U=185k, S/0=145k, ROT=165k, 40-80 rpm. Tq on/off=7k/6k. ADT=.6 hrs, Page 13/20 Report Printed: 1112012018 .operations Summary (with Timelog vjpths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log alert'rtria Eno Tim Our (hr) Piece Op COCeACUVRy Code Time P -T -X Operation S(Pom)pN Entice flKa MK( ) 11/9/2018 11/9/2018 0.75 INTRM2 CEMENT CIRC P Circulate and condition @ 250 gpm, 9,496.0 9,457.0 13:00 13:45 1980 psi, 80 rpm 6.5k Tq. Work string inside the casing without rotation 4x. Rack back stand to 9,457' MD. 11/9/2018 11/9/2018 1.00 INTRM2 CEMENT FIT P R/U and perform FIT to 12.7 ppg, 9,457.0 9,457.0 13:45 14:45 1007 psi with 10.2 ppg mud in hole, no leak off. 1.3 bbl pumped and bled back. Shut in pressure 947 psi after ten minutes. 11/9/2018 11/9/2018 0.50 PROD1 DRILL MPDA P Pull trip nipple and install MPD 9,457.0 9,461.0 14:45 15:15 element. 11/912018 11/9/2018 1.75 PROD1 DRILL DISP P Displace well over from 10.2 ppg 9,461.0 9,461.0 15:15 17:00 LSND to 9.2 ppg FloPro @ 250 gpm, 1620 psi, 50 rpm, 5k Tq. Obtain SPR's. 11/9/2018 11/9/2018 0.50 PROD1 DRILL OWFF P Monitor well, slight flow. Close MPD 9,461.0 9,461.0 17:00 17:30 chokes and observe no pressure build. 11/9/2018 11/9/2018 0.50 PROD1 DRILL REAM P Wash and ream from 9,461' MD to 9,461.0 9,496.0 17:30 18:00 9,496' MD @ 225 gpm, 1420 psi, 80 pm 5k Tq. 11/9/2018 11/10/2018 6.00 PROD? DRILL DDRL P Directional drill from 9,496' MD to 9,496.0 9,812.0 18:00 00:00 9,812' MD, 8,034' TVD @ 225 gpm, 1600 psi, 140 rpm Tq on/off-6.5k/4.5k, ECD=10.43 ppg. ADT=4.1 hrs. SIMOPS- Lay down 11 stands 5" DP from derrick. 11/10/2018 11/10/2018 12.00 PRODt DRILL DDRL P Directional drill from 9,812' MD to 9,812.0 10,650.0 00:00 12:00 10,650' MD, 8,024' TVD @ 225 gpm, 1780 psi, 140 rpm Tq onloff=5.5k/4k, 8k WOB. P/U=180k, S/0=150k, ROT=163k. ECD=10.6 ppg. ADT=10.4 hrs. SIMOPS- Lay down remaining 5" DP from derrick. OA(B)=445 psi, OA(C)=100 psi @ 12:00 hrs. 11/1012018 11/10/2018 1.50 PRODt DRILL DDRL P Directional drill from 10,650' MD to 10,650.0 10,760.0 12:00 13:30 10,760' MD, 8,045' TVD Town Geo decided to go exploring for the bottom of zone. Had DO put a ramp (speed bump) @ 10,760' in the event we have to pull back and sidetrack. 11/10/2018 11/11/2018 10.50 PROD1 DRILL DDRL P Directional drill from 10,760' MD to 10,760.0 11,424.0 13:30 00:00 11,424' MD, 8,045' TVD @ 225 gpm, 2100 psi, 140 rpm Tq on/off--5.5k/3.3k, 5-10k WOB. P/U=186k, S/0=148k, ROT=165k. ECD=11.02 ppg. Tour ADT=10.4 hrs. OA(B)=550 psi, OA(C)=100 psi @ 22:00 hrs. 11/11/2018 11/11/2018 12.00 PROD1 DRILL DDRL P Directional drill from 11,424' MD to 11,424.0 12,148.0 00:00 12:00 12,148' MD, 8,013' TVD @ 225 gpm, 2040 psi, 140 rpm Tq on/off--6k/4.3k, 5 -10k WOB. P/U=190k, S/0=145k, ROT=163k. ECD=10.9 ppg. ADT=10.4 hrs. OA(B)=645 psi, OA(C)=100 psi @ 12:00 hrs. Page 14120 Report Printed: 1112 012 01 8 -, . . perations Summary (with Timelog s.epths) �-f MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Time End Tme Our (hr) Phase Op Cade Activity Code Time P -T-% Operation Start Depth (ftK6) End Depth(nKB) 11/11/2018 11/11/2018 5.25 PROD1 DRILL DDRL P Directional drill from 12,148' MD to 12,148.0 12,480.0 12:00 1715 12,480' MD, 7,957' TVD @ 225 gpm, 2040 psi, 140 rpm Tq on/off=6k/4.3k, 5 -10k WOB. P/U=190k, S/0=145k, R07=163k. ECD=10.9 ppg. ADT=3.9 hrs. 11/11/2018 11/11/2018 0.50 PROD1 DRILL BKRM X BROOH from 12,480' MD to 12,410 12,480.0 12,410.0 17:15 17:45 MD @ 230 gpm, 2075 psi, 140 rpm, 5.5k Tq. Circulate full open hole volume prior to stripping while BROOH, 11/11/2018 11/11/2018 2.75 PROD? DRILL SMPD X Blow down top drive, line up MPD and 12,410.0 10,729.0 17:45 20:30 Strip out of hole to 10,729' MD per schedule, holding 320 psi back presssure while stripping out. P/U=205k, some tight spots from 11,987' MD to 11,574' MD - able to work through. 11/11/2018 11/12/2018 3.50 PROD1 DRILL KOST X Troughing from 10,729' MD to 10,760' 10,729.0 10,760.0 20:30 00 00 @ 220 gpm, 1630 psi, 100 rpm, 3.4k Tq. Ream up/down @ 100% downforce, 180° TF. OA(B)=550 psi, OA(C)=100 psi @ 22:00 hrs. 11/12/2018 11/12/2018 0.50 PROD 1 DRILL KOST X Continue troughing from 10,729' MD 10,760.0 10,760.0 00:00 0030 to 10,760'@ 215 gpm, 1630 psi, 100 rpm, 3.4k Tq, 60 fph. Ream up/down @ 100% downforce, 180° TF. 11/12/2018 11/12/2018 11.50 PROD1 DRILL KOST X Time drill from 10,760' MD to 10,777' 10,760.0 10,777.0 00:30 12:00 per plan @ 215 gpm, 1620-1580 psi, 120 rpm, 3-3.5k Tq. ADT=11.1, TVD=8,025'. Begin with ribs closed @ .5 fph for 2 hr, 1 fph for 4 hr, 2 fph for 4 hr... SIMOPS- P/U and rack back 17 stands 4" HWDP for liner run. OA(B)=540 psi, OA(C)=100 psi @ 12:00 hrs. 11(1212018 11/12/2018 2.00 PROD? DRILL KOST X Continue time drilling from 10,777' and 10,777.0 10,789.0 12:00 1400 to 10,789' MD @ 220 gpm, 1570 psi, 3 -3.5k Tq. 4 fph, then 8 fph for 8'. 11/12/2018 11/12/2018 2.00 PROD1 DRILL KOST X Continue drilling ahead with ribs off to 10,789.0 10,815.0 14:00 1600 10,815' MD to achieve more separation. 11/12/2018 11/13/2018 8.00 PROD1 DRILL DDRL X Engage steering ribs @ 10,815' and 10,815.0 11,250.0 16:00 0000 drill ahead, steering back towards plan to 11,250' MD, 8,021' TVD. 220 gpm, 1800 psi, 10.48 ECD, 140 rpm, Tq on/off= 5.5k/3.5k. 7-10k WOB. TourADT=10.8 hrs OA(B)=575 psi, OA(C)=100 psi @ 22:00 hrs. 11/13/2018 11/13/2018 12.00 PROD? DRILL DDRL X Directional drill from 11,250' MD to 11,250.0 12,219.0 00:00 12:00 12,219' MD, 8,012' TVD @ 225 gpm, 1960 psi, 140 rpm Tq on/off-6.7k/4.8k, 5-10k WOB. P/U=190k, S/0=145k, ROT=165k. ECD=10.6 ppg @ 12,015' when lost PWD. ADT=10.1 hrs. OA(B)=660 psi, OA(C)=100 psi @ 12:00 his. 11/13/2018 11/13/2018 3.25 PROD1 DRILL DDRL X Directional drill from 12,219' MD to 12,219.0 12,480.0 12:00 15:15 12,480' MD@ 225 gpm, 1960 psi, 140 rpm Tq on/off-6.7k/4.8k, 5-10k WOB, P/U=190k, S/0=145k, ROT=165k. No ECD/PWD, Page 15120 Report Printed: 11/20/2018 �Iperations Summary (with Timelog L pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Tine End Time Dur (hr) Phase Op code AchNty Cede Time P -T -X Operation Start Depth (AKe) End Depth (ItKa) 11/13/2018 11/14/2018 8.75 PRODt DRILL DDRL P Directional drill from 12,480' MD to 12,480.0 13,174.0 15:15 00:00 13,174' MD, 8,013' TVD @ 225 gpm, 2150 psi, 140 rpm Tq on/off-7.8k/6k, 3 -7 k WOB. P/U=200k, S/0=143k, ROT=165k. No ECD / PWD. Tour ADT=9J hrs. OA(B)=550 psi, OA(C)=150 psi @ 22:00 hrs. 11/14/2018 11/14/2018 3.75 PROD1 DRILL DDRL P Directional drill from 13,174' MD to 13,174.0 13,459.0 00:00 03:45 13,459' MD, 8,017' TVD @ 225 gpm, 2150 psi, 140 rpm Tq on/off-7.8k/6k, 3 -7 k WOB. P/U=200k, S/0=143k, ROT=165k. No ECD / PWD. ADT=3.2 hrs. Started taking returns via MGS to reduce odor in pit room. Reduce from 6-8k units @ possum belly to >1k. Observed MPD element not spinning / sealing. OA(B)=550 psi, OA(C)=150 psi @ 22:00 hrs. 11/14/2018 11/14/2018 1.00 PROD1 DRILL CIRC P Circulate and condition @ 225 gpm, 13,459.0 13,459.0 03:45 04:45 2110 psi, 140-80 rpm, 6.5-5.5k Tq. SIMOPS- PJSM on C/O MPD. 11114/2018 11/14/2018 0.25 PRODi DRILL OWFF P OWFF- Slight flow for 5 -minutes, then 13,459.0 13,459.0 04:45 05:00 static. 11/14/2018 11/14/2018 0.25 PROD1 DRILL MPDA P Change out MPD bearing/ element 13,459.0 13,459.0 05:00 05:15 11/14/2018 11/14/2018 6.75 PROD1 DRILL DDRL P Directional drill from 13,459' MD to 13,459.0 14,221.0 05:15 12:00 14,221' MD, 7,994' TVD @ 225 gpm, 2560 psi, 140 rpm Tq on/off-10k/7k, 8 -12k WOB. P/U=197k, S/0=130k, ROT=164k. No ECD / PWD. ADT=5.2 hrs. Gas up to 8k units max, after MGS. OA(B)=470 psi, OA(C)=100 psi @ 12:00 hrs. 11/14/2018 11/1412018 6.00 PROD1 DRILL DDRL P Directional drill from 14,221' MD to 14,221.0 14,790.0 12:00 18:00 14,790' MD, 8,001' TVD @ 225 gpm, 2660 psi, 140 rpm Tq on/off=10k/7k, 6 -9k WOB. P/U=185k, S/0=132k, ROT=164k. No ECD / PWD. ADT=5.0 hrs. Gas up to 7-8k units max, after MGS. OA(B)=470 psi, OA(C)=100 psi @ 12:00 hrs. 11/14/2018 11/14/2018 1.75 PRM CASING CIRC P CBU x 2 @ 250 gpm, 2640 psi, 140 14,790.0 14,790.0 18:00 19:45 rpm, 7.5k Tq. Gas reduced to 300- 400 units after bottoms up. SIMOPS- PJSM on displacing to 9.4 ppg brine. 11/14/2018 11/1412018 0.25 PROD1 CASING OWFF P Close chokes and observe for 14,790.0 14,790.0 19:45 20:00 pressure build, 0 psi. OWFF, static. Swap returns back from MGS to flowline. 11/14/2018 11/14/2018 2.50 PROD1 CASING DISP P Pump 30 bbl HV Brine spacer, 14,790.0 14,697.0 20:00 22:30 displace to 9.4 p ppg Vis brine @ 250 gpm, 2050 psi, 140 rpm, 6.5k Tq. Obtain SPR's. Rack back stand to 14,697' MD. No gas on bottoms up after flow check. 11/14/2018 11/14/2018 0.50 PROD? CASING OWFF P OWFF, static 30 minutes. Blow down 14,697.0 14,697.0 22:30 23:00 1 I top drive, screw back in and rotate 5 1 rpm while flow checking. Page 16120 Report Printed: 1112012018 operations Summary (with Timelog L. pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time Es Tme our (ho Phase Op Code Acdvdy Cotte Time P -T -x Oper w star) Depth (dKB) ErW Depth(ftKB) 11/14/2018 11/15/2018 1.00 PROW CASING SMPD P Strip out of hole with MPD, holding 80 14,697.0 14,125.0 23:00 00:00 psi pulling and in slips, good hole fill, P/U=2o0k. OA(B)=50 psi, OA(C)=100 psi @ 22:00 hrs. 11/15/2018 11/15/2018 0.50 PROD1 CASING SMPD P Strip outwith MPD from 14,125' MD to 14,125.0 13,747.0 00:00 0030 13,747' MD holding 80 psi pulling and in slips. P/U=195k, S/0=147k. 11/15/2018 11/15/2018 0.25 PROW CASING CIRC P Pump 60 bbl 10.0 ppg Vis Brine for 13,747.0 13,747.0 00:30 00:45 dry job via head pin @ 4 bpm, 750 psi. 11/15/2018 11/15/2018 3.75 PROD1 CASING SMPD P Continue stripping out of hole from 13,747.0 9,458.0 00:45 04:30 13,747' MD to 9,458' MD holding 80 psi. P/U=181k, S/0=142k, ROT 170k. 11/15/2018 11/15/2018 1.25 PROD1 CASING CIRC P Circulate 2X bottoms up @ shoe, 5.8 9,458.0 9,458.0 04:30 05:45 bpm, 1140-1240 psi, 100 rpm 4.3 Tq. 9.4 ppg in/out. 11/15/2018 11/15/2018 0.50 PROD1 CASING OWFF P Flow check, static. 9,458.0 9,458.0 05:45 06:15 SIMOPS- Perform weekly function test Ion annular, upper and lower VBR's. 11/15/2018 11/15/2018 0.25 PROD1 CASING CIRC P Pump 60 bbl 10.0 ppg Vis Brine for 9,458.0 9,458.0 06:15 06:30 dry job via head pin @ 5.8 bpm, 1240 psi. Blow down top drive, line up MPD. 11/15/2018 11/15/2018 3.50 PROD1 CASING SMPD P Continue stripping out of hole from 9,458.0 2,298.0 06:30 10:00 9,458' MD to 2,298' MD holding 80 psi. P/U=181k. 11/15/2018 11/15/2018 0.50 PROD1 CASING MPDA P Flow check, static. Pull RCD and 2,298.0 2,298.0 10:00 10:30 install trip nipple. 11/15/2018 11/15/2018 1.00 PROD1 CASING TRIP P POOH on elevators from 2,298' MD to 2,298.0 333.0 10:30 11:30 1 333' MD. 11/15/2018 11/15/2018 0.50 PROD1 CASING BHAH P Remove 2.11" Hollow drift and tail 333.0 243.0 11:30 12:00 from Jar stand. PJSM on L/D BHA. Lay down Jars/Bumper sub to 243' MD, WU HWDP stand for liner run, rack back in derrick (19 total). 11/15/2018 11/15/2018 1.75 PROD1 CASING BHAH P PJSM and pull sources. UD BHA per 243.0 0.0 12:00 13:45 DD/MWD from 243' MD. Clean and clear rig floor. Calc fill=96 bbl, Actual Fill -108 bbl. 11/15/2018 11/15/2018 1.50 COMPZN CASING RURD P P/U and R/U liner running equipment, 0.0 0.0 13:45 15:15 double stack tongs, elevators, slips. PJSM on running liner. 11/15/2018 11/15/2018 7.00 COMPZN CASING PUTB P WU 436" 12.6# L-80 TXP Orange 0.0 5,420.0 15:15 22:15 peel, Perf Pups and liner per detail to 5,420' MD. 132 jts in hole, 4W x 51/2' Split rib centralizers one per joint. P/U=115k, S/0=115k. 11/152018 11/15/2018 0.75 COMPZN CASING OTHR P P/U Baker HRDE ZXP liner hanger 5,420.0 5,462.0 22:15 23:00 and packer assembly, WU inner string and SCMT tools on bottom. Make up to liner string. Mix and Pour Zanplex. SIMOPS- R/D 4W" Liner handling equipment 11/15/2018 11/16/2018 1.00 COMPZN CASING RUNL P RIH with liner on 4" DP from 5,462' 5,462.0 5,765.0 23:00 00:00 MD to 5,765' MD. Break circulation @ 5,574'@ 4 bpm, 190 psi to ensure clear flow path. Pumped 15 bbl total. OA(B)=0 psi, OA(C)=100 psi 11/16/2018 11/162018 2.00 COMPZN CASING RUNL P Continue running 4%"TXP Liner on 4" 5,765.0 9,469.0 00:00 02:00 DP from 5,765' MD to 9,469' MD. 11/162618 11/16/2018 0.25 COMPZN CASING CIRC P Obtain parameters before open hole, 9,469.0 9,469.0 02:00 02:15 Fill pipe and circulate @ 3.5 bpm, 220 psi. P/U=162k, S/0=148k. Blow down top drive. Page 17120 Report Printed: 1112 012 01 8 operations Summary (with Timelog L epths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sbrt Tyne EM Time Dur (hr) Rose op Cotle Acta ity CWa Time P -T -X opere Start DBPN (f1KB) End Depth (fiKB) 11/16/2018 11/16/2018 4.25 COMPZN CASING RUNL P Continue RIH with 4%;' TXP Liner on 9,469.0 14,742.0 02:15 06:30 4" DP/ HWDP from 9,469' MD to 14,742' MD. 11/1612018 11/16/2018 1.50 COMPZN CASING CIRC P Space out liner on depth @ 14,765' 14,742.0 14,765.0 06:30 08:00 MD. Circulate S -S volume @ 4 bpm, 530 psi. P/U=205k, S10=146k. 11/16/2018 11/16/2018 1.00 COMPZN CASING PACK P Flow check well- Static. Drop 1.625" 14,765.0 14,765.0 08:00 09:00 Ball per Baker. Pump ball down @ 3 bpm, 340 psi for 550 stks, reduce to 2 bpm, 150 psi. Ball on seat @ 638 stks. Pressure up to 2300 psi to set liner hanger, S/O to 75k to confirm set. Pressure up to 3500 psi to release, S/0 to 65k. Bleed off, confirm release. P/U 6' to expose dog sub, S/O 50k to set Packer. P/U to 185k, rotate 20 rpm 185k, 2.5k Tq. SIO 50k to confirm set. P/U 10', space out for pressure lest P/U=205k, S/0=165k. 11/16/2018 11116/2018 0.50 COMPZN CASING PRTS P, Close annular prevenler, Pressure test 14,765.0 14,755.0 09:00 09:30 ZXP via annulus to 3300 psi for 30 minutes charted. Monitor 7" x 9 5/8" annulus during test, 280 psi increase from expansion. Blow down kill line. Line up and pressure up to 400 psi while pulling tools clear of liner hanger, (pressure bled off to confirm clear) 11/16/2018 11/16/2018 1.00 COMPZN CASING CIRC P P/U to 9,250' MD, CBU @ 5 bpm, 625 14,755.0 9,250.0 09:30 10:30 1 psi. 9./4 ppg Vis brine, P/U=187k. 11/16/2018 11/16/2018 0.50 COMPZN CASING OWFF P OWFF, static. Blow down top drive. 9,250.0 9,250.0 10:30 11:00 11/16/2018 11/16/2018 1.00 COMPZN WELLPR OEVL P POOH from 9,250' MD to 8,352' MD 9,250.0 8,352.0 11:00 12:00 logging with SCMT Q 2500 fph. P/U=177k 11/16/2018 11/16/2018 2.50 COMPZN WELLPR QEVL P Continue POOH from 8,352' MD to 8,352.0 7,431.0 12:00 14:30 7,431' MD logging with SCMT @ 2500 fph. 11/16/2018 11/16/2018 4.25 COMPZN WELLPR PULD P POOH laying down Drill pipe to the 7,431.0 213.0 14:30 16:45 pipe shed from 7,431' MD to 213' MD. Culled out 2 jts 15.7# DP, 5 jts 14# and 5 jts 14# new with 35OXT test pipe. 11/16/2018 11/16/2018 0.75 COMPZN WELLPR PULD P Leave last stand DP and running 213.0 213.0 18:45 19:30 tools/SCMT in hole in slips/ dog collar. Lay down 4 stands 4" DP from derrick while waiting for personnel to arrive on location. (CD4 road closed due 141 shop move) 11/16/2018 11/16/2018 1.50 COMPZN WELLPR SHAH P Lay down 1 stand 4" DP, P/U Baker 213.0 0.0 19:30 21:00 Liner running tools. Break off SLB SCMT tools and break down in mousehole. L/D Baker liner running tools. Calc Fill=63 bbl, Actual Fi11=63.5 bbl. 11/16/2018 11/16/2018 0.50 COMPZN WELLPR WWWH P M/U stack washer, flush slack@ 10 0.0 0.0 21:00 21:30 bpm, 20 rpm. 11/16/2018 11/16/2018 0.50 COMPZN WELLPR RURD P FMC pull 6.1875" ID wear ring. 0.0 0.0 21:30 22:00 11/16/2018 11/16/2018 0.25 COMPZN WELLPR WWWH P M/U stack washer, flush stack again 0.0 0.0 22:00 22:15 @ 10 bpm, 20 rpm. 11/16/2018 11/16/2018 1.50 COMPZN RPCOMP RURD P Rig up to run 4'/:" Upper completion, 0.0 0.0 22:15 23:45 count and flag pipe /jewelry. R/U torque tum equipment. Page 18120 ReportPrinted: 1 112 012 01 8 . perations Summary (with Timelog . apths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time End Time D., the) Plass Op Corte Activity Carte Time P -T -X Operation Start Depth (flKB) End Depth(NI(B) 11/16/2018 11/17/2018 0.25 COMPZN RPCOMP PUTS P PJSM on P/U completion. P/U seal 0.0 0.0 23:45 00:00 assembly, P/U joint#1 and perform dump test on power tongs. 11/17/2018 11/17/2018 12.00 COMPZN RPCOMP PULD P PIU and RIH with4%" TSH Blue 12.6# 0.0 9,220.0 00:00 12:00 L-80 completion per detail to 9,220' MD. 11/17/2018 11/17/2018 1.25 COMPZN RPCOMP HOSO P Rig up to circulate down tubing to 9,220.0 9,318.0 12:00 13:15 locate top of SBE on joint #230. Circulate down @ 2 bom, 130 psi observe pressure increase. Pumps off, bleeder open slack off to fully locate on no-go on joint #231, 9,318' MD mule shoe depth. 11/17/2018 11/17/2018 0.75 COMPZN RPCOMP HOSO P POOH, laying down joint#231 and 9,318.0 9,220.0 13:15 14:00 #230 and #229. Make up space out pups (3) as calculated for 4' off fully located and joint #229. 11/17/2018 11!17/2018 0.50 COMPZN RPCOMP PULD T Swap out joint #229 for Jt#231due 9,220.0 9,282.0 14:00 14:30 bad Torque Tum make up curve. Replace collar on spaceout pup. 11/17/2018 11!17/2018 0.75 COMPZN RPCOMP THGR P Make up tubing hanger and landing 9,282.0 9,282.0 14:30 15:15 jointA with heart pin. 11117/2018 11/17/2018 0.25 COMPZNP RPCOMP SFTY PJSM on displacement to 9.4 ppg 9,282.0 9,282.0 15:15 15:30 clear brine and 20 bbl inhibited brine. 11/17/2018 11/17/2018 1.50 COMPZN RPCOMP CRIH P Displace wellwith 200 bbl 9.4 ppg 9,282.0 9,282.0 15:30 17:00 clear brine, followed by 39 bbl corrosion inhibited brine, displace with 135 bbl clear brine. 11/17/2018 11/17/2018 0.25 COMPZN RPCOMP OWFF P Observe wellfor flow, static. 9,282.0 9,282.0 17:00 17:15 11/17/2018 11/17/2018 0.25 COMPZN RPCOMP THGR P Land hanger and RILDS, seal shoe 9,282.0 9,314.0 17:15 17:30 depth 9,314' MD, 4.08' off fully located. 11!17/2018 11717/2018 0.75 COMPZN RPCOMP RURD P Rig up for pressure testing hanger 9,314.0 9,314.0 17:30 18:15 seals and tubing/ann. 11/17/2018 11/17/2018 0.75 COMPZN RPCOMP PRTS P Pressure test hanger seals to 250 psi 9,314.0 9,314.0 18:15 19:00 5min and 5000 psi for 10 minutes charted via production port, good. 11/17/2018 11/17/2018 0.75 COMPZN TPCOMP P Drop ball and rod. R/U and test tubing 9,314.0 9,314.0 19:00 19:45 string to 4200 psi for 30 minutes charted. Bleed tubing down to 2000 psi. 11/17/2018 11/17/2018 0.50 COMPZN RPCOMP RGRP T Attempt to test 7" x 4%" annulus. No 9,314.0 9,314.0 19:45 20:15 pressure to cement line. Troubleshoot and change out Lo-Torq valve on mud manifold rig floor due cement plug. 11/1712018 11/17/2018 0.75 COMPZN RPCOMP PRTS P Test 7" x 4W' annulus to 3300 psi for 9,314.0 9,314.0 20:15 21:00 30 minutes charted. (w/ 2000 psi on tubing). Bleed annulus to 0 psi, bleed tubing to 0 psi. 11/17/2018 11/17/2018 0.50 COMPZN RPCOMP PRTS P RIU and pump down IA with tubing 9,314.0 9,314.0 21:00 21:30 open to shear DCK-2 shear orifice valve. Observe shear out @ 2570 psi. Continue pumping @ 2 bpm, 670 psi for 2 bbl. 11/1712018 11/17/2018 0.50 COMPZN RPCOMPOWFF P Observe well foor flow -static. 9,314.0 9,314.0 21:30 22:00 SIMOPS- R/U to set and test HP-BPV. 11!1712018 11/17/2018 0.25 COMPZN WHDBOP MPSP P Lay down landing joint A. FMC set HP- 9,314.0 0.0 22:00 22:15 I BPV. Page 19120 Report Printed: 11/20/2018 . perations Summary (with Timelog r. pths) MT6-04 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log startTmm End Time Dur (hr) Phase Op Ogle Acti,rity Cade Time P-T-x Operation Siert DBPM (fixB) End Depth (PoCB) 11/172018 11/17/2018 0.50 COMPZN WHDBOP MPSP P Install Landing joint B. Test HP-BPV 0.0 0.0 22:15 22:45 via annulus to 2500 psi for 15 minutes charted. Lay doom landing joint B. SIMOPS- Blow down choke and kill lines, mudline, cellar lines, disconnect choke line. 11/1712018 11/17/2018 0.25 COMPZN WHDBOP SFTY P PJSM on N/D MPDE and BOPE 0.0 0.0 22:45 23:00 11/172018 11/182018 1.00 COMPZN WHDBOP MPDA P Rig down MPDE and flow box. 0.0 0.0 23:00 00:00 11/18/2018 11/18/2018 0.50 COMPZN WHDBOP MPDA P Remove and lower Orbit valve and 0.0 00:00 00:30 MPD clamp. 11/18/2018 11/18/2018 4.50 COMPZN WHDBOP NUND P Break door bolts on stack for BWM, 0.0 0.0 00:30 05:00 N/D BOP stack. SIMOPS- C/O saver sub to NC50 11/182018 11/18/2018 1.00 COMPZN WHDBOP NUND P Install Smooth Bore Metal Seal, install 0.0 0.0 05:00 06:00 plug off tool in HP-BPV profile per FMC. 11/18/2018 11/18/2018 1.50 COMPZN WHDBOP NUND P NIU tree adapter Flange, test to 5000 0.0 0.0 06:00 07:30 psi CPAI witnessed. Fill tree with diesel. 11/182018 11/18/2018 1.00 COMPZN WHDBOP PRTS P Test tree to 250 psi low, 5000 psi hi for 0.0 0.0 07:30 08:30 10 minutes each charted. 11/1812018 11/18/2018 1.00 COMPZN WHDBOP MPSP P Verify 0 psi, FMCremove HP-BPV. 0.0 0.0 08:30 09:30 SIMOPS- R/U circulating lines to freeze protect. 11/1812018 11/18/2018 0.75 COMPZN WHDBOP FRZP P PJSM with GIS, Flood lines with water, 0.0 0.0 09:30 10:15 PT surface lines to 2500 psi-good. GIS pumped 47 bbl diesel @ 400-700 psi. 11/18/2018 11/18/2018 1.25 COMPZN WHDBOP FRZP P Shut down, line up and allow well to U 0.0 0.0 10:15 11:30 -Tube for 1 hour. Tubing=100 psi, IA (A)=100 psi. SIMOPS- Mobilize BHA components to rig Floor for surface hole. Clean top drive for inspection, rig down lines. 11/18/2018 11/18/2018 0.50 COMPZN WHDBOP KURD P Rig up FMC lubricator, test to 1000 0.0 0.0 11:30 12:00 psi. 11/18/2018 11/18/2018 -0 75 COMPZN WHDBOP MPSP P Install HP-BPV, test to 2500 psi-good. 0.0 0.0 12:00 12:45 Final Tubing=100 psi, IA=100 psi. 11/18/2018 11/182018 2.25 DEMOB MOVE KURD P Blow down, dg down lines to cellar. 0.0 0.0 12:45 15:00 Prep cellar for rig move. Rig off highline power Q 15:00 his. 11/18/2018 11/18/2018 8.50 DEMOB MOVE PULD P UD 71 stands 4" 15.7# DP and 18 0.0 0.0 15:00 23:30 stands 4" HWDP from derrick via mousehole. Culled out 1 HWDP due worn hard bantling. SIMOPS- Pull Ball Mill module away. Move MWD, Site control and ancilliary parts from rig. Prep pipe shed for backing away. 11/18/2018 11/19/2018 0.50 DEMOB MOVE RURD P Prep for rig move, blow down water to 0.0 0.0 23:30 00:00 sub, disconnect service lines in mezzanine and pits. Rig release Q 00:00 him 11/19/18 Page 20120 ReportPrinted: 11120/2018 Cement Detail Report MT6-04 String: Conductor Cement Job: DRILLING ORIGINAL, 10/22/2018 07:00 Cement Details Description Conductor Cement Cementing Start Date 2/17/2018 14:00 Cementing End Date 2117/2018 16:00 Wellbore Name MT6-04 Comment Cement Stages Stage # 1 Description Conductor Cement ObjectiveTop Depth (ftKB) Cement Conductor 36.5 Bottom Depth (ftKB) 115.0 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bblhn... Q Pump Final (bbll... Q Pump Avg (bbt/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8 Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 12111/2018 Cement Detail Report MT6-04 String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/22/2018 07:00 Cement Details Description Surface Casing Cement Cementing Start Date 10/25/2018 13:30 Cementing End Date 10/25/2018 17:00 Wellbore Name MT6-04 Comment Cement Stages Stage # 1 Description Surface Casing Cement ObjectiveTop Cement Surface Casing Depth (ftKB) Bottom Depth (ftKB) 38.0 2,046.6 Full Return? Yes Vol Cement... 154.0 Top Plug? Yes Btm Plug? No O Pump Init (bbl/m... 19 8 13 Pump Final (bbi/... O Pump Avg (bbl/... 16 P Pump Final (psi) P PIu9 Bump (psi) 400.0 900.0 Recip? Yes 110,00 I Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 154 bbls good cement returns to surface Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 38.0 Est Elm (ftKB) 1,546.0 Amount (sacks) 857 Class G Volume Pump id (bbi) 297.5 Yieltl (ft'/sack) 1.95 Mix H2O Ratio (gal/sa... 7.08 Free Water (%) Density (Ib/gal) 11.00 Plastic Viscosity (cP) Thickening Time (hr) 5.50 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,546.0 Est Elm (ftKB) 2,046.6 Amount (sacks) 348 Class G Volume 72.0 Pumped (bbl) Yield (ft'/sack)Miz 1.16 H2O Ratio (gal/sa... 5.10 Free Water I%) Density (Ib/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 5.10 i (psi) Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 12/11/2018 Cement Detail Report MT6-04 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 10/22/2018 07:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 11/1/201801:00 11/1/201804:00 MT6-04 Comment Break circ w/8 bpm, 575 psi. PJSM on cementing. Dowell pump 1.2 bbls H2O & PT to 4000 psi (good). Dowell pump 60 bbis 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 40.5 bbis 12.2 ppg 2.3 ft3/sx yield Class G lead cement and 50.1 We 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbis H2O. Rig displace with 559.2 bbis (5,605 stks @ 95%) 10.5 ppg LSND with 8 bpm / 440 - 960 psi. Reduce pumps to 3 bpm / 650 psi. last 10 bbis. Bump plug, pressure 500 psi over to 1150 psi for 5 min. Check floats. F/C good. CIP @ 3:49 Hm. Full returns during cement job. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top PIu97 Fat --Plug? Intermediate Casing 1000' of cement from 6,720.0 7,719.9 Yes Yes Yes Cement Shoe Q Pump Init (bbl/m... Q Pump Final (bb0... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Related? Pipe RPM (rpm) 8 3 6 650.0 650.0 No N0 Tagged Depth (ftKB) Tag Method Depth Plug Drilletl Out To (ftKB) Drill Out Diameter (in) Comment Break circ w/8 bpm, 575 psi. PJSM on cementing. Dowell pump 1.2 bbis H2O & PT to 4000 psi (good). Dowell pump 60 bbis 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 40.5 bbis 12.2 ppg 2.3 ft3/sx yield Class G lead cement and 50.1 bbis 15.8 ppg 1.16 ft3/sx yield tail Cement @ 4 bpm. Drop 2 top plugs. Dowell pump 20 bbis H2O. Rig displace with 559.2 bbis (5,605 stks @ 95%) 10.5 ppg LSND with 8 bpm 1440 - 960 psi. Reduce pumps to 3 bpm / 650 psi. last 10 bbls. Bump plug. pressure 500 psi over to 1150 psi for 5 min. Check floats. F/C good. CIP @ 3:49 Hrs. Full returns during cement job. Cement Fluids & Additives Fluid Fluid Type Fluid Description 16E led Top (ftKB) Est etm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 6,720.0 7,219.9 99 G 40.5 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (ol Density (ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 2.30 13.18 12.20 6.20 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid DescriptionEstimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 7,220.0 7,720.0 243 G 50.1 Yield Ift'/sack) IMIx H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP)Thickening Time (hr) CmprStr 1 (psi) 1.16 5.08 15.80 4.50 Additives Additive Type Concentration Conc Unit Iabel Page 111 ReportPrinted: 12/11/2018 Cement Detail Report MT6-04 String: Liner Cement Job: DRILLING ORIGINAL, 10/22/2018 07:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Liner Cement 11/6/2018 06:00 11/6/2018 0800 MT6-04 Comment M/U Baker cement swivel & cement line with 5' pup. RIH & tag bottom @ 9,476', set down 20 k. PU=235k, 5/0=1 75k. Circulate and condition for cement job, stage up from 1.5 to 4.5 bpm, 360 psi ICP, 460 psi FCP Heaviest mud weight out 11.4 ppg. No signs of packing off. SIMOPS- PJSM on cement job. SLB flood surface lines with water and PT to 4000 psi -good. SLB pumped 30 bbl 11.5 Ppg Mud Push @ 3.8 bpm, 450 psi. Drop bottom Dart. Pump 71.6 bbl 15.8 ppg Cement @ 4.8 bpm, 245 psi WHP. Drop Top Dart. SLB kicked out cement with 20.1 bbl water. Rig displace cement with 1676 strokes (168.8 bbl) 11.2 ppg LSND @ 4.5-3 bpm. Observed Dart 01 latch @ 350 silks, pressure up to 1460 psi, observe Dart 02 latch @ 1035 stks, pressure up to 1480 psi and release. Bumped plugs @ 1676 silks, pressure up from 580 psi FCP to 1100 psi and hold 5 minutes. CIP @ 08:56 hrs. OWFF while holding pressure, slight drop in annulus. Set liner hanger, pressure up from 1100 psi to 2400 psi, slack off 50k down. Pressure up to 3750 to release running tool. Bleed off pressure. P/U=235k. S/0=175k. Monitor well for flow- static. Check floats, holding. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Bum Plug? Liner Cement 1000' above Shoe 7,708.0 9,476.0 Yes 0.0 Yes Yes O Pump [flit (bbl/m... O Pump Final (bb9... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 3 4 580.0 1,100.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 6 Comment M/U Baker cement swivel & cement line with 5' pup. RIH & tag bottom @ 9,476', set down 20 k. PU=235k, S/O=175k. Circulate and condition for cement job. stage up from 1.5 to 4.5 bpm, 360 psi ICP, 460 psi FCP. Heaviest mud weight out 11.4 ppg. No signs of packing off. SIMOPS- PJSM on cement job. SLB flood surface lines with water and PT to 4000 psi -good. SLB pumped 30 bbl 11.5 ppg Mud Push @ 3.8 bpm, 450 psi. Drop bottom Dart. Pump 71.6 bbl 15.8 ppg Cement @ 4.8 bpm, 245 psi WHP. Drop Top Dart. SLB kicked out cement with 20.1 bbl water. Rig displace cement with 1676 strokes (168.8 bbl) 11.2 ppg LSND @ 4.5-3 bpm. Observed Dart #1 latch @ 350 stks, pressure up to 1460 psi, observe Dart #2 latch @ 1035 stks, pressure up to 1480 psi and release. Bumped plugs @ 1676 stks, pressure up from 580 psi FCP to 1100 psi and hold 5 minutes. CIP @ 08:56 hrs. OWFF while holding pressure, slight drop in annulus. Set liner hanger, pressure up from 1100 psi to 2400 psi, slack off 50k down. Pressure up to 3750 to release running tool. Bleed off pressure. PIU=235k, S/0=175k. Monitor well for flow- static. Check floats, holding. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped Ibbl) Intermediate Cement 8,476.0 9,476.0 346 G 71.5 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP)Thickening Time (hr) CmprStr t (psi) 1.16 s.o7 16.80 6.00 Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 12/11/2018 ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-04 50-103-20775-00 Baker Hughes INTEQ Definitive Survey Report 06 December, 2018 8AI UGHES GE.""" 12 0189:5716AM Paget COMPASS 500014 Build 850 ConocoPhillips SAr Q ConocoPhilli P s Defnitive Survey Report >•ro-� Company: Con0CDP61Wpl(Alaska)Ino-MS Local Co rdinate Refeednce: MU MTS-04 Proles: NMatem NOM Slope TVD Reference: ACTUAL MT6 @ 88]2us8(DWonl 9) Sib: GMTI Lookoul Pad MD Reference: ACTUAL MTM4 Q 88J2uslt(Doyonl 9) Well: MTM4 North Reference: Two Wellbore: MT64M Survey Calculation Malted: Mannum Curvature Design: Cl-aryD1 Database: EDT 14 Alaska Production Project Western North Slope. North Slope Alaska, United Stales Map System: US Stele Plane 1927 (Exact solution) System Datum: Mean See Level Geo Datum: NAD 1927 (NADCON CONUS) Using Mll Reference Point Map Zone: Alaska Zone 04 Using geodetic scale fas., Well MT6-04 Well Poston aNl3 0.00 use Northing: 5.945.550.61 unit Latitude: TO- 1523.035 N .Ef-W 0.00 halt Eaandii: 31707875us6 Longitude: 151°28'42.389W Position Uncertainty DUO usit Wellhead Elevation: 000usfi Ground Level: 37.20ust1 Walloped MT6-0 Megread. Madel Name Sample Date Declined.. Up Angle Field Strengdr M 1°I (nT) BGGM2018 10;22/2018 16.34 8069 57 369 Design MT&04 Audit Name: Version: 10 Flaw: ACTUAL i On Depth: 10.760.24 Vortical Section: Detain Frons (TVD) eNl4 a£I-W Dlrectbn (Mall) (Malt) (han) 1°I W52 0.OD 0,00 329.93 12 0189:5716AM Paget COMPASS 500014 Build 850 le- C0f10C0f11ll1pS Inc ConocoPhillips TVD en1�m b %w +NIS +E1:W Map Definitive Survey Report Vertks (cat) Co.,.,: C..PNIII s(Akska) Inc. AVMS Local Coon irate Refemnce: Wall MT6-04 lues) No(ft) MI.EE Mean North Slope TVD Reference: ACTUAL MT64I4® 88]2usft(Doyonl 9) Site: Gall Lookout Pad MD Reference: ACTUAL MT644@88.72ush(Doyonl9) to 1°Marl (ft) Well: MTB -04 &W Nonh Reference: Tme 0.00 000 Wellbore: MT6-04 000 Sumay Calculation Method; Minimum Curvature R37 234.14 Design'. C1-wpD1 -015 Database: EDT 14 Alaska Proth.O., 317,07854 a,17 Survey Pm9nm 207,03 Doh 240.34 207,07 -111,28 -0.46 From To 317078,05 007 405 GYDCT-0M811) ZS 00 0.71 lust) Idem Sarney(Wages.) Tool Nerve Description Survey Sbn Dab Survey End Data 115.00 613.00 1. Gyro0ata GyroSS 16"(MT6-04PB1) GYDCT-DMS Gyrodata eonl.onllplpe Ms 101232018 1012312018 678.41 772.43 2. BHGE MWD+IFR+MSA 16-(MT6.04P MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1012312018 101232010 866.00 S66A0 3. Gymdab GyroSS 16- (MTfi-041191) GYDCT-DMS Gyratlata conlArliplpe rNa 10232018 102312018 961.62 1,99223 4. BHGE MND OTK+IFR+MSA 16"(MT6 MWDAFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 101232018 10/302018 2,086]8 7.889.92 S. BHGE MND ATK+IFR+MSA 121/4"(M MND+IFR-AK-CAZ-SC MAID+IFR AK CAZ SCC 102712018 10292018 7,770.30 9,373.94 B. BHGE MWD+IFR+MSA6 W4'(MT64 MWD+IFR-AK-CAZSC MWD -IFR AK CAZ SCC 11122018 111412(118 9447.06 10.760.24 TBHGE MWD+IFR+MSA4 W1 (MT&0 MWDAFR-AK-0AZ-SC MWD+IFR AK CAZ SCC 11142018 111122010 10 791 14 762 S. BHGE MWD+IFR+MSA 43/4"(MT&D MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 11/1212010 11/152018 Survey 712.43 2.47 21464 772,16 483.46 , MD Inc A9 TVD TVDSS +NIS +E1:W Map Map Vertks (cat) (% 1% (ent) lust) Idea) lues) No(ft) Ea(ft) Sactian Survey That Name Annotation fat WI to 1°Marl (ft) 36.52 000 &W 36.52 5220 0.00 000 5.94555061 31707875 000 000 UNDEFINED 115.00 R37 234.14 IIS00 -28,28 -015 -0.21 5.94555047 317,07854 a,17 48.03 GYDCT{!8111 207,03 041 240.34 207,07 -111,28 -0.46 'D69 5,945.58.17 317078,05 007 405 GYDCT-0M811) ZS 00 0.71 242.90 26499 -17&27 -0.76 -1.25 5.9`5 549m 317.07746 046 1.03 GYDCT-oMB(1) 365.00 110 230,, 36490 -27626 -169 -260 5.945,540.90 317.07611 D.51 416 GYDCT-DM8111 450.00 V9 220.91 449.95 46123 -325 -1.15 5945547.4(5 317,074,53 0.78 -0.73 GYp T-068(1) 547,00 203 26.61 5%.6 458.16 -557 b39 5945.54519 317,0R.M 0.32 -152 GYDCT-0!511) 613W 197 224,70 61286 524.14 .7.18 4804 5945.54363 317.070.54 013 219 GYDLTZWS11) 67041 197 2246 67&23 569.51 -&79 4,61 5945,54206 317,069.93 003 -279 MWD°IFR-N(-CA C(2) 712.43 2.47 21464 772,16 483.46 -1161 -1190 5.945539.30 317,066W 08 4.08 MWDHFR-N({g2SC(2) BE6.W 305 2108 05564 -77692 -1540 44.33 5,945535.57 31706495 055 614 GYDCT-DMS(3) 961b2 4.10 211n 96107 672.6 -208 -1742 5,945.8055 317.x.84 t.t0 901 MWDHFR-PH{A25C (4) 1,05536 571 21&h 1054.47 665]5 -27.09 -21.99 5,945.524[6 3170%.14 178 -1244 MVgNFR-AK-CA CHI 1149.17 7.51 216,M 1.14765 -108.93 4575 -28 41 5945.51556 317.04949 1.92 -16]1 MvYD+IFR-AH{gZSLl4) 1243% 9.18 26.8 1 N1 33 -1.15261 46.47 -3707 59458506 31704004 186 8t66 MNDNFR1N{AZ-9C(4) 12162018 9:57184M Page 3 COMPASS 5000 14 Baits 850 ConocoPhillips ConocoPhillips lmh�4 TVD Definitive Survey Report 4hN; ComWnY: CohacoPhillps(AlaBka) Inc -MS Local Co -Ordinate Reference: MR MT84)4 Project Madera North Slope TVD Reference: ACTUAL MT"4@ 88.72usfl(Doyonl 9) Site: GMT1 Lookoul Pad MD Reference: ACTUAL MT"4@ 88,72ush(DWo,19) Well: kl NOdh Reference: True Wellbore: MT8 Survey Calculahon"haQ Knead. Cumatule Design: Ci,,ol Dabbase: EDT 14 Alaska Production Survey MD Inc Aad TVD mss 4hN; a044 Map Map Vertical lead) (7 ("m IMam (..ft) (Red) NatRin 0 Easen 9 MS ANO" Survey Tool Nanle Annotation 011007 (-2740 1,33633 10.98 219.01 13]4.34 .1.24562 59.20 ;]$5.945,492.59 317 ON 194 MWDHFR-A1CAZSC(41 143228 1185 215.67 1426.43 -1 33]]1 1399 -56.89 5945.4]80] 31]01615 1.15 -34.56 MW➢+I1R-AK-0P2SC(41 152621 11.53 214.07 151841 -1.429.69 _8956 259.79 594546279 31).0%.82 040 42.53 MWD1IFR-AK-CAZ5C 14) 1,61987 1103 21529 16102& -1,521.54 -10455 Sp.29 5.945"". 316995% 055 5026 MWD1IFR-PH-CAZSC (4) 1,715.13 1D.83 215.16 1,703.79 4615.07 -11931 -%.71 590.5433.54 318,98648 021 -57.81 MWDIFR-AKCAZSC(4) 1.8%.35 1076 215.27 1.795,36 4]06.84 -13353 -imn 5,945 419 53 3189ID.77 0.00 .8511 MWD1IFR-AKCAZSC(4) 1.%223 11.34 21&04 1.80750 -1.798,78 -14820 -111.27 594540617 316.963.93 064 -7250 MNDHFR-AK.CALSC 141 1.99223 11.67 21676 1.97570 -18%.95 152.64 -121.92 5,945,390.99 316.952.93 S. -79% MWDrIFR-AI(-CAZSC 14) 13J "x 16' 2066]8 11.61 213.28 2068.30 -1.97950 -176'16 -132% 5,945,375.64 318.941.61 075 -8769 M IFR-AKCAZSC(5) 2.181,07 1225 217,17 2.16056 -ZC718A AN 16 -144.11 5945.350.02 316.92998 1.09 -95 82 MWDHFR.gKCAZSCIS) 2,275.36 1252 ZP 08 2252.W -2,16394 -20909 -15764 5945,345,42 316.91609 227 -10195 MWDHFR-AKZAZE (5) 236968 1348 236% 2,4,57 -2,255.85 -222.23 -174.23 5.945.332.69 316,893.19 233 -10502 MW IF9-AK{AZSC(6) 2.454.53 14.07 237,73 2AW.70 -234798 -234.59 -19313 6.945 MW 316,880W 076 -163.25 MWDHFRAKLAZSC15) 2556.31 1403 23780 2.52767 -2438.95 -246,73 -21239 59453W13 316,850.45 0.05 -10.11 MNDaIFR-AH-CAZSC151 20330 IAA 23725 261903 -2,53111 -259.00 -231.79 5,945.99725 316.&075 0,14 -10..07 MM.IFR-AK-0AZSC(51 2.74759 13% 236.37 271133 -2622.61 871.55 -250,86 594526425 316821.39 023 -10931 h IFR- AZSC(51 2,84233 10.02 235.86 2.803,26 -271454 -28435 -26985 59452891 316.802.10 019 -110.87 MWDHFR-Al4CAZSC (5) 2, Sal 144 234.45 2.89362 -2,804.90 -297.52 -286,66 5915260.21 316.78299 0.62 -112.83 MWDHFR-AK-CAZ.SC(6) 3M9.87 1458 23470 2984.% -2,696.18 S1125 .'07.99 5,945246.85 316,763.31 0.09 -115.04 MVYDrIFRiKLAZSCIS) 312361 14M 2350.% 307583 -2.966,91 32464 52725 5,945.23384 316743.73 005 -117,15 MW7NIFRAKLAZSC(5) 321835 14.57 23535 3,167.32 -3.0MW 33,446 34579 5,9452207➢ 316.7Ya.87 012 -11914 MWI3+IFR-PH-CAZSC151 3.312.85 14.56 235114 325606 3,170.00 55202 x.31 5,945.20761 316,70AM 0.09 -121.10 MWDHFR-AKCAZSC(51 3406,% 1459 23546 3.31897 3]41.25 -355.39 386,7 5945,194 72 316694.45 0.12 -123.02 MWDHFRAKCA (5) 3.49983 14.31 236.19 3.439.W -3351.08 37853 404.94 5945.10204 3166M.77 035 -12459 MWDHFR-.HCAZSCI5) 3594.4 13.M 24000 3.531.75 Sp4303 .35051 424.12 5.945.170.54 316.6A533 1.40 -12544 MWD+IFR-AKCAZ4C(5) 3687.81 1231 244.70 3,62Z.83 3,534.11 406.14 44246 594516136 316826.73 the -12459 MWDHFRAKCAZSC(51 3,78189 1225 248.08 3.714.45 4625.73 40,11 40673 5945.161M 31660&27 075 -122.33 M IFR -A CAZSC(5) 3,876. 1225 248.W 3.80&2 $71790 4157 47922 5945146.62 31656961 0.27 -11970 MWDHFR-AKLAMC (5) 397027 1224 24582 3898n 4.01001 423.79 497.53 5.945.13906 316,57111 024 -11746 M +IFR -A CAZSC(51 4,06379 1225 P 1.A 3990.13 -3,90141 432.14 515.4 5.945.131.15 316.55292 032 -1157 AAD1IFRAKCAZSC(5) 4.159.06 12.8 24218 4083.23 -3.994.51 44111. SM51 5945.122.61 316,534.63 0.36 -114.30 MWDHFR-AKCAZ1111) 1ZW018 857:18" Page4 COMPASS 5000. 14 Suits BSD .: ConocoPhil ips Conocolshillips 6g Definitive Survey Repon Company: ConocoPh131p5(AMska) Ina -Mg LDcal ConNlnate Reference: MIN MT6-N P.,ct Nbstena Nonh Slope TVD Reference'. ACTUAL MT694@ W72usit(Doyon 19) Site: GMTI Lookout Ped MD Relerence: ACTUAL MT654@ 88]2u8n(0oyont 9) Well: MT694 Nonh Reference: Tme Wellaore: MT854 Survey Calculation Method Minimum C..t.. Design: Ct-wp01 Database EDT 14 Alaska Production Surrey MD Inc pal TVD MRS .W4 ♦F2 -W Map pap walled IOaRI fl fl loan) Ivan Nanning Fasting DM Bastion (0an) ryas) Iv10a) Survey Tool Nama Annotation AR Int nt 425352 1209 24182 d1T5.5] <.OBIi.85 15034 551 21 5.945,113.80 31651880 025 -11355 MWDIFR-AK{9250(51 434569 1207 241.69 4,26570 417698 -059,49 56821 5,94510506 31649059 0.04 -11294 MWDHFR-.KCAZSC151 443641 1202 24174 4,356.38 -0.26766 468.55 68524 5.945.09533 316,482.3a 008 -11234 VNAVOFR-AK{ASSC (5) 453106 1205 240.95 4447.78 -0359.06 41803 {02.33 5,90.5.00737 316955.03 0.22 -111.50 MWDHFRAK{A29C(5) 4.62564 1204 24039 4.53949 4,45.11 401.65 619.31 5.94501818 316,447.76 0.W -111.60 MWDHFR-PH{AZSC (5) 4,8056 12M 24105 4.632.31 4643.59 49734 535.65 594506891 316.430.25 0.15 -11140 MJrDNFR-AK-CA2SC 15) 481425 1203 24325 4723.95 4.635.23 506.41 {5394 5.94506o.w 31641215 0.49 41065 MWDAFRAK{AZSCI5) 4.90.11 ISM 24381 4,81673 4j28.01 615.27 511.61 5945,051.03 316394,87 OAS, .10041 MWDaIFR-N(-CAIS (W S.W387 12.05 N&M 4,90022 4.820,5 52400 88924 594504345 316.311.04 017 .1O&M MN➢HFRAWCAZSC 15) 5.09723 1203 24202 505.n 4,91200 333.07 -70156 5,945.034.88 318,35951 0.24 -107.31 MNDrIFRAK-CAZSC 15) 519137 1197 24143 50925 5,00408 542.35 -72379 5945.02628 316342.05 0.15 -106.139 MWDHFR-AKCAZSG (S) 5.285.53 11.97 24.65 5184.91 505,19 -55180 .140.88 5945011.00 31832414 017 -10631 MWDHFR-AK-00250151 531&54 1222 2416 5.216.84 -5.18812 56144 -75806 5.94.00778 316,301.33 0.27 -106,06 MWDHFRAK-CAZSC(5) 5,47365 1226 241,81 5.35081 _5 Mon 51128 -775.5 5.944.96092 3162561 034 405.57 M 0+lFR-AKCAZSG (5) 5.55791 1220 24309 5.45.93 5,37221 S80,26 -093.26 5006.90882 316.271.5 0.29 -10470 MNDHFRAK{AZSC15) 5.663,06 1220 24295 5553,95 -546523 55.36 411.18 5,95,93114 31625355 003 -103.61 MWDHFR-AK{AZSC(6) 5,75701 1218 2452 564516 555704 593.31 -8285 595,972M 316.23563 013 A0247 MWDaIFR-AH-CAZSCI6) S,8S1.4 1234 24335 5.13802 5,849.30 507.24 546.75 5.944,854,15 316.211.$ 0.07 40125 MJa➢HFR-AKLg25C15) 5.94311 12.17 2HW 5827.65 -5,13893 51519 513415 5944,9503 316,199.96 0.24 53.92 MWDHFRAK-0AZSC(5) 603804 1217 NTn 5920.45 5,51,13 523.91 9624 5944.gas 35 316181.49 075 -97.79 MWOHFRJ CAZSD(5) 6,13D.34 12.16 25.70 6,010.10 592186 52916 90103 5.95843.5 316,16211 290 $301 MND+IFRAK-1A25C 151 RM442 12M 27413 6.102.65 $,01393 53002 S20.8A 5944,9439 316.142.94 301 -83.83 MWDIFRAK-0AZSC (5) 83165 1299 281.73 6,194.51 $.10519 52715 -941,24 585.946.5a 3161nS2 180 41.13 MWDHFR-AK{AZSC(5) 641&49 1370 269.29 62568 {,198.16 -521,26 -95230 59595294 316.10171 1.90 5546 MWDHFR-AK-CAZSCI51 8,51.5 15.01 294,61 6.379.33 5.2561 512.45 93390 5,95.962.27 316,05.25 2.05 J700 MWDHFRAKLAZSC 15) 6,5277 1725 30281 64541 $,3575 .59969 4,007W 5944 97558 318051.55 333 -1442 "DIFR-M{AZSC(5) 8.893.5 1939 31270 655.57 y645.85 681,59 -10301a 495,994.25 316,02885 401 125 M FR-AK-CA,$CI5) 8191,00 21.85 317.30 6134692 4556.20 65.04 -1 MAR 5,945016.35 316,0125 3,12 4496 MWDHFR.-CA 15) 654.29 20.55 320.32 RM..5 4643.94 630.30 AO n 5945.045131 315.95 .53 3.16 8102 MWDHFR-AKLAZSCISI 697765 27.37 32155 6.816.59 9727.61 49862 -110346 5.94501805 315933.9 3.07 12136 MWDHFR-W(-CAZSC 151 7,07223 WR 324,03 R&S 40 4810.60 46222 -y 131.05 5.945,116 02 315935.89 35 16671 MMAFR-AK{AZ-SC I51 12762018 9:57'IMM Page 5 COMPASS 500014 Build 850 ConocoPhillips ConocoPhillips Definitive Survey Report AM Company: COnowPh111ms(Al83ka) Inc, -MS Local Cporelnam Reference: Wall MTB$4 Project Vyestem Nonh Slope TVD Refemnu: ACTUAL MT644(aq+ 88.72uafl(Doyonl 9) a": GMT1 Lookout Pad AD Relerence: ACTUAL MTG04@ 88.72usft(Doyonl9) Well: MT"4 Nonh Reiemnce: Tme mmom: MTB Survey Calculation Method Minimum Curvature Design: C1- of Database: EDT 14 Alaska Production Survey MD Inc AM TVD TW"!S HW3 rElm Map Map msVstical (ueRl N (1) (dal tum) (daft) Imat) NOMin9 Easing Sectio n survey Tool Neme IRI IRI 1.11w) IRI 7.1E6.50 3290 324.90 69]9.61 b,890.92 121-4 -1159.01 594515].4] 31590992 312 21601 MWDHFR-4 CAZSC(5) ],2608) 35,04 328.93 7,057," $,96832 57515 -1,107,30 5.945243-3 31500275 3.54 269.38 MWDHFR-AB-CAZSC (5) 7,35523 38,89 331.11 ].132.33 -7,04361 -32641 -1.21592 5945253& 315.855.31 332 32877 MW IFRdK-0AZSC(5) 7.9.80 4156 32416 7204.54 -7.115.02 -27217 -1.24394 5.915300.74 315828,65 3.51 387.75 MWDHFR-AKCAZSC(5) 7.543.71 4022 3M..07 7,273.34 -7.184.62 -21424 -1,27091 5945.367.31 315,OWN 309 45140 MWDHFR-AKZAZSC(1) 7,630,78 47.26 335.83 733968 -7,250.96 -151.07 -1,29821 5.944430.32 315777:32 328 51905 MWDHFR-AK-0AZSC 151 7.689.92 4&29 336.90 7374.. -728533 -117.0 -131309 5945465.49 315783.29 202 558.64 MWDHFR-AKLAZSCI51 7,77030 47,83 337.60 7427.77 -7,339.05 $191 -1,336.21 594552,11 315741.52 0.86 615.94 AW IFR-AK-CAZSC(61 7,854.50 5165 338.60 7.488.84 -7.39992 463 -135.6.95 5915.58&51 31571841 415 68707 M .IFR -AK -C -AC 181 7958 04 54,68 33502 7544.71 -7,455.99 74.57 -1 mw 5945658.91 315.690.90 3.24 781.01 MWDHFR-MH A2SC(6) aI .24 56.96 339.04 7,59]113 -750&91 14728 -1 41809 5,94573228 315664.74 2.43 836.01 MWDHFR✓J-CAZS0(61 8.146.95 59.A 338%5 76A7.46 -7,559,74 M. -144203 5945863,11 315.637.65 273 91754 MWDHFR-MK AZSC(81 8.24188 6170 338.63 7.634.03 -760,31 29959 -1476.85 5.945,885.96 315,609.71 228 999.26 M IFR-AK-CAZ$C(6) 8,335.211 6437 33&78 7.736.38 -7.64766 37721 -1,506,91 5945,964.20 315,591.54 263 1.04149 M +IFR4KCAZ$C(6) 8428.76 6663 338.% 777514 -7,686.42 45&47 -1,53778 5946.wz 31555281 2.42 1,16555 M.NDHFR-AKAAZSC(6) 0.523.56 69.12 33574 781065 -7]22.13 53&30 -1,569.69 5948.126.83 31652270 2.63 1,25335 MWDHFR-Al(-CAZ$C(61 8.61812 71.31 33942 784286 -7754.13 621.39 -1,60144 5.945.21067 315492.97 241 1,34017 MWDHFR-PK-CAZS n( 8]13.09 73.18 33961 7,87181 -7763,09 70.11 -1633,10 5946.2W 13 31546339 1.90 1429.35 M IFR-- AZSC(61 6,09135 7513 33979 7.097.54 4.80882 79116 -7,654.55 59/638190 315434.01 2.00 151871 M IFR-AK-CAZSC 15) 8,90146 77.55 33991 7919.77 -7,83105 87.w -1696,05 5,946.468,48 31540460 257 1.60&79 MWD+IFR-AK-0AL C(6) 8.996.03 79.84 .10 7,93831 -.049.59 964.14 -1.24].78 5.9456$35 31537502 243 1700,09 MWDHFR--CAZSC(61 9,09078 7988 310.41 7954.99 106327 1,05193 -1.75927 5,94Q644&3 315,345.66 032 1791.05 MWDHFR-AK-CAZSC(6) 9.18674 8184 340.45 7970,07 -7,80135 1,14026 -1790.67 5.946,73396 315,31641 206 1884,03 MWDHFR.AKCAZSL(61 927943 83.91 34089 7.98169 -7,892.97 1,227.98 -1,82144 6,94&822.38 315$8170 226 1,975.36 ~+IFR-AK-CAZSC(6) 937394 Wal 34o.70 1991.79 480307 1,31674 -1,852.29 5,946.911.85 31525910 015 2,-67.&1 MWDHFR-AK-CAZSC(61 9.447.68 8405 N0.60 7963.52 -7,91080 1,365.30 -1.87633 5946981.04 315236.73 0.10 2,139.08 MWDHFR-PN-CAZSC(71 9,485,08 A76 310.51 800331 -7914% 1.421.85 408922 5947,01764 3152'24.74 tW 217710 MWDHFR-AH-CAZ$COI 9.52346 84.40 34tm 8,006,63 -7,918.11 1457.15 -1,901.42 5.94705342 315.21339 233 3.21376 M IFR--CAZSC(7) 961994 84,51 Now 801598 -],927.26 1,547.10 4.93211 5947144.08 31510491 037 2."all M IFR-AK-CAZSC 171 971408 64.52 34264 6.025.08 493536 163707 4861M 59472N74 31515755 1,73 23]965 MWDHFR- AZSC(7) 980926 8767 343.16 503156 -7942.84 1II782 -19&9.58 5947326.13 315131,84 335 2492.16 MWDHFR-M-CA SC(7) e 1 ucrMs go Annotation B-S10'x 12-1/4^ 7"x831 - 1b 0199:67a8AM Page6 COMPASS 5000.14 Build 850 ConocoPhillips ConoC34tillips Definitive Survey Repon Company: C0n0coPh1lIIps(A1mka) Inc. -NNS Local Coordinate Reference: Nbll MT6 ProjeR Western North Slope TVI) Reference: ACTUAL MT6434@ 88.72usfl(DWonl9) Site', GMT1 Lookout Pad MD Reference'. ACTUAL MTB -04 ® W.72ush (Doyonl9) INNI: MT6.04 Nonh Reference: True Wellbore: hn`. SUNey Calculation Method: Minimum Curvature Design: C1-wpD1 Database: EDT 14 Alaska Pmducllon 9UNey MD 1. Axl TVD TVDSS .W4 11214111 Map i Vedcal (Maftl I% I') /uaM (-M loan) (I1a111 Northing Eam", us Stott, Survey That Name RI Irtl I°HOPI tftl 9,90302 90,89 24200 8,032.13 -].944.03 1,818M -201112 590]417.21 315.156,00 341 2,50424 MNDHFR41(CAZSC 171 9.99&83 9206 34309 8030.29 -7.1.57 1.939.20 -2,044.50 5901500.17 315001.31 1.37 2676.67 MWDHFR-A AZSC(7) 10,5386 9200 343.74 8.026.81 -7,938.12 2.50013 -207127 5907,600.33 315,0%.79 026 2.7687] MW IFRAK-CAZSC (7) 10109.70 90.44 3H24 8024,n -7.938.01 2,092.40 -2,097.75 5.947.893,21 315,032.56 179 2 N 89 MWOtIFR-AKLP23C(71 1020519 90.42 34393 802002 -7.93530 2104.23 -212393 59477M. 31500882 0.33 295448 MWDHFR-AI(-CAZSC 171 10,37878 9033 30371 BMAO -7,93468 227507 -2150.29 5,907,07109 314,980.40 025 3,04630 MWDHFR-A CAZSC (7) 10,47486 89.77 343.17 0.023.31 -7,924,59 2.36579 3,178.13 5Wat&45 314.&5885 1.73 3.1W76 M FRJJ AZ C(7) 1055&93 0974 24165 a023.72 -7.93500 2455.38 -2,27,00 594ILMn 314.931.17 055 3230.96 MW DHFR -MK AZSC17) 10.66514 0950 34005 8024.36 -193564 2,W27 -2,23&95 5,908.15034 31490244 1,67 3.32542 MWDHFR-AK-0AZSC OI 10 M,24 89.43 340.17 8,025.24 -7 M.52 2,63569 -2,27129 5.908240.52 314,8n.20 014 3,419.01 MW IFR-AK-CAZSC (7) 10,79174 87,85 =.. 8.026.05 -7.937.33 2.665.29 -2,282.03 5940.270.37 314062.26 5.70 3,050.01 MJYDHFR-AKLpZSC10) 10.05492 8770 33192 0020.57 -7.93985 272420 -2304.73 5948,32980 314801,00 32D 3,512.36 MND+1FR-Al(-LAZ4IC(A 10950.52 so'M 33866 803003 -7811.31 201237 -234163 590841084 314804.26 310 3,607.15 MMNHFRAK AZ uu 1101534 9161 331.74 8.(2815 -793943 2..%m -2.300.64 5,918.50815 314,769,36 247 3,70147 MWiN1FR- -CAZSC 18) 11,141J6 9180 33259 802544 1,936 42 2.984,59 242312 5948.59298 314 7M97 224 379103 MWDHFR-AH-CAZSC(o 11.23571 9074 330.33 "not -7.934.32 3,W162 -2.46620 590867700 314.60585 2.64 3,89152 MWDHFR4KCAZSCI81 11,331.00 902) 32821 8.02218 -7,933.46 3.14953 -251897 5908760.13 314.839.17 2.27 3.986]9 MW9HFR- -CAZSCIB) 1142885 90.26 32832 8.02172 1,93300 3.23087 -2.56720 594&8427 314 Eau oo 012 4,08240 MJVDHFR-AK-CAZSL(8) 11522.42 9181 32&11 0,020.W -7,93120 3.312.27 -2617.71 5.940,92526 310.54241 163 4178.11 M DHFR-AK-CAZS0101 11.61&65 9300 327.57 8.016.(1 -7 W732 3391.97 -2,66763 5,909.005.15 314.494.25 139 4.272.19 MWOHFRAK-0gZSC181 11.71259 9173 304,41 8,01208 -7M,M 347235 -2,7X),5 5,MM777 314441.00 1,79 437,92 MVV➢HFRN A&SC(8) 11,808.89 90.53 326'. 8.010.18 1,921.46 3562.56 -2773.29 5949,16028 314392M 1.25 4,46402 MNDHFR-AK AZSC (8) 11,60384 8976 32900 BOD994 -792122 3W118 -2823.43 5949,25106 310.300.% 3.63 4,55891 MWDHFR-AK-C -aCul) 11.999.01 8943 331,93 501062 -7,92190 3.716.30 -2.86976 5,9193359 314,303.26 228 4,51.5 M IFR-AK-0AZSC(8) 12594.W Wad 33329 8.01126 -79454 3.80000 -2,913(1 5.949.420% 314,25&47 148 474930 M IFR -M AZSC(a) 12109.70 .71 330.19 0.011om -792294 3.05.53 -2,9580 590950753 31421835 0.95 484450 MNDaIFR-AK-CAZSC(8) 12.M57 89.71 33370 801215 1,92343 3.973.39 -2.996 45 5,909.595.35 314179.86 1.57 0,940.02 MWDHFR-AK1AZSC(8l 12,30109 90.17 337.60 8,012.25 -7923.53 0,06102 3031.21 5.94950386 314104,25 213 5. 477 M IFR-AKCAZSC(8) 1247830 W.48 330.15 8011,71 -792299 4,149.24 370.00 594970492 31411061 059 5,12906 M +IFRAK{A25C (6) 1291,01 0955 34057 801104 -7922.96 423061 810367 594986300 31407913 271 5.22327 MWD+IFR-AK-CAZSC(8) 12,66697 8953 342.91 801245 -792373. 0,326... -3.13348 5.949954.13 31451$2 2.46 5.316.41 M +IFR-AK1A-SCI8) Annotation 9A ER FJ I�Wf188 1268016 95I:18AM Page 7 COMPASS 5000 14 Build 655 Annotation 4-112' .&110' sup,Aes is 11iEI1018 8:5728.404 P., 8 COMPASS 500014 BOO 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: COnocoPhuip(Alaska) Inc. -MS Local Coor8lnata Relndim.: Mill si Prpk4h Westem Nath SIOPe TVD Reference: ACTUAL MT6-04 ® ",72usft (DWonl9) 910e: GMT1 LOOkOul Pen MD Reference: ACTUAL MT6-04@08.72u5fl(Doyani 9) Well: MT604 Nanh ReMrence: True Wellbore: MT64)4 Survey Calculabon Method: Minimum Curvature Deslgn: C1-Wp01 Database: EDT 14 Alaska Pronucoon Survey MD Inc AM TMD Mn 0213 Map Map WRiul (uaRl(1) 1'1 WAR) (dairy (daft) luso) Nalhinp EaMln9 6eM) survey Tool Name 12]62.49 (.11w) a993 349.25 6.012.&5 -]8201.3 44N,59 3.160,48 59A0463] 31144,026.]5 1 A 5'4dan MWDHFR-AK.CAZaC (8) 12857,89 6999 344.M 8,012.87 -792415 4512,54 -3.185,88 5,950.138.91 314.003.56 063 550154 MW IFRAK-CAZSCI8) 12,953.00 Was 346,26 8,01291 -7,92449 4604,65 -3,209.62 5.950,231 55 31390210 148 559313 MADNFR-AK-CAZSC181 13.04779 90.02 34&52 8,012.92 -7,924.20 4696.n 3231.02 5.900.324,19 313.921A 828 594.03 MWDHFR) AZS 18, 13.14342 89.21 14267 8,01357 -7,924.05 478885 -325832 58.00,41695 313.93889 4.11 516,53 MWDHFR-AK-CAZSC (8) 13,23045 0937 34211 0.01474 -791 4,879.76 3,28528 5.950.508.41 313,913.15 0.49 5.86013 MAWIFR-AK-0g25CI0) 1333421 8940 34516 0.0157 -7,92705 497187 3311.45 5$0.60112 313,88922 214 59st95 MWDHFR-AK-CA (81 13,429.% 9.37 344.97 6016M -792807 5.06399 y336.03 5950.69300 313866,89 820 6,05399 MAR)HFRAK-CAZ4iC (8) 13,524.40 0925 34583 8,017.94 -].929.22 5,15875 3.359.95 5.950765.12 313,04520 008 6.14538 MW PR-AK-CAZSCIB) 13619w 9104 34575 0017.70 -],92890 5.246.30 438342 Ems. 313.024,80 1.80 8.23724 MADHFR-AH-CAZSCI81 13.71500 91.00 34609 8.01000 -].92].26 5,340.55 -3.40655 5950.971,98 313.803.11 0.36 6,32867 MWDaIFR-AK-CAZSC (8) 1381004 910d 343.56 0014,30 -7,92562 5.43225 a,131A2 5,951,004.25 313]04.4] 266 6,42049 M IFR--CAZSC(a) 13,90421 gluo 34341 8.01270 .7 823.90 552253 5,45817 5.951.155.15 313755.93 013 8.512.02 MADHFRA AZSC(8) 1399.76 91.00 34390 8.011.03 -TOM31 561423 -3.484.98 595124747 313]313] 857 8004.80 MWDHFR-4KCAZSC (8) 14.01)575 9137 34504 0005 -7,920.33 5,7002 5,59,46 5951340.81 313.79.13 259 SM737 MK IFRAK-CAZSC (8) 14,18089 9128 341.49 800685 4,91013 E799D7 5,533.33 5,95143341 3139751 205 6.789.OD M IFR -AK AZSO(0) 14.2MM 909 341.57 8005.22 .7,91650 5,89014 -355853 595152507 313.684.53 0,63 6.890,44 MWDHFR-41(-CA I8) 14,380.79 89.55 34548 000502 -7,916,30 5.932.30 -3,58310 5,951817]9 313.64212 1.53 6.94,55 MWDHFR-MH AZ -SC (8) 1447840 8000 344.@ 8,005.81 -0,917.08 6,074,54 360&33 5951710.60 313.61922 153 [004.9] MW 1FR-AK-CAZSCIm 11.5]2.95 90.23 34521 8005,04 -7917,M 5167.65 363395 5951804.31 313,59587 1.45 7.150.39 MWDaIFR-A Z{ C(8) 149715 9100 24634 8.004,62 ;81590 6,258,92 -3.65709 59518,16,11 313,574.96 1.81 7.248.97 MWDr1FR-.-CA CI81 1476201 91.46 34521 8.00217 101345 6350.04 S&WW 5,9519956 313.55390 1,19 ],MOW MWDrIFR- -CAZSC (8) 14.79000 91.46 N521 0.001.46 -0.91274 6.37780 3687.53 5952,015.70 313.54742 000 736719 PRDJEOTEDMTD Annotation 4-112' .&110' sup,Aes is 11iEI1018 8:5728.404 P., 8 COMPASS 500014 BOO 85D ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-04PB1 50-103-20775-70 Baker Hughes INTEQ Definitive Survey Report 06 December, 2018 BA, ICER UGHES .GE company r- C0nocoPhillips Conocolahillips DefinRNe Survey Report Company: ConocoPhillips(Alaska) Inc.-WNS Local Coordbrate Reference: WeII MT6-04 -Project: Westem North Slope TVD Reference: ACTUAL MT6-04@ 8812mot Doyon19) side: GMT1 Lookout Pad MD Reference: ACTUAL MT6-04@ 88]2usft(Doinji WeII: MTB -04 NOM Reference: True Wellbore: MT6-04P81 Surrey Calculetem Method: Minimum Curvature Design: Ci-wp01 Database: EDT 14 Alaska Production Project Wardsm 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 ge.dDtic scale factor Well MT6-04 ..... ._ .. ._.... ... Well Position 1111 0.00 huff Northing: 5,945,55061 usfl Lesions 70.1523.035N +El -W 0.00 usfl pasting: 31],018)5 usfl Longitude: 151.28.42389W Position Uncertainty 0.00 usft Wellhead Elevation: 000ustl Ground Level: 31.20 usfl Wellbore MT6D4P81 Magne4C5 Modal Name Sample Date Declination Dip Angle Feld 8Vength (`) (1) (DD BGGM2018 1012212018 16.34 80.69 51,389 Desire MT6 P81 .. _'.. .. - . Audit Noes: Version: 1.0 Phase: ACTUAL To On Depth: 38.52 Venieal Seceon: Depth From IWO) +WS +Who Direction lueftl (us") (..ft) (•) 36.52 ... _.. __...__ 0.00 0.00 329.93 1252018 956:42AM Page 2 COMPASS 500014 Build 85D ConocoPhillips RA ER W ConocoPhillips Definitive Survey Reportu Company: COAoCoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: 1,11-6-04 wellbore: MT6-04PB1 Design: Cl "01 survey Progrem new From To (.aft) (uaft) 115.00 61300 67841 T/2,43 &66.00 866.00 961.62 1.99223 2,085.78 7,689.92 7,770.30 9,373.94 9,447 06 12,381.03 survey Survey(Wellbom) 1. Gyrodata GyraSS 16-(MT6-04PB1) 2. BHGE MWD+IFR+MSA 19' (MT6-04P 3, Gyrodele GymSS 16' (MT6-04PB1) C BHGE MWD OTK+IFR+MSA 16" (MT6 5. BHGE MWD ATK+IFR+MSA 12 1M" (M 6, BHGE MWD+IFR+MSA6 3/4" (MT6-0 7. BHGE MWD+IFR+MSA 4 314" (MT6-0 Lecal Coordinate Reverence: Well MT6-04 WO Reference: ACTUAL MT6-04(gi8872usft lDoyonl9) MO Reference: ACTUAL MT6-04@88.72uaft(Doyon19) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Tool Name GYO-CTDMS MWD+IFR-AK-CAZSC GYD-CT-DMS MWT3+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK-CAZ-SC Description Gymdata WnLdnllpipe We MVVD+IFR AK CAZ SCC Gymdala contdnllpipe Ws MWD+IFR AK CAZ SCC MWT3+IFRAKCAZSCC MM+IFR AK CAZ SCC MWD+IFR AK CAZ SCC Survey Start Date 10/23/2018 10/23/2018 1012312018 10/23/2018 101272018 11212018 11148018 MO Inc Pat TVD TYDS5 +N65 +EI -W Map Map Wltical (uaftl1°) 1% (usX) IusXl IusX) rysR) NOrtll(n9 Easlirp Section Survey Tool Name Ift) (a) C�001 (ft) 38.52 0.00 000 38,52 52.20 0.00 000 5945.550.61 317,078,75 O.W OW UNDEFINED 1 11650 037 234.14 115.M 4826 615 -0.21 5,945,55017 317,018.51 0.9 -OW .1,CT-0MS(1) 20.00 041 24034 20000 -11128 1746 .e9 5,94655017 317,078 p5 007 -0.05 GYD-CT-DMS(1) 266.. 071 242.90 26498 -17627 -0]6 -1.25 5,945.54888 317,077.48 0.46 603 GYD-CT-0M5(1) 385.0 1.18 23077 3&.98 -27628 -189 -2.. 5.."48.98 317,076.11 0.51 -018 GYDCT-DMS(1) 450.00 179 220.91 44995 J61]. 325 4.15 5.945,54746 317,.4.53 078 -033 GYDCT-0MSNI 547,00 2.03 22661 518.90 -059.18 -5.57 8.38 5,945.545.19 317.07223 0,32 -162 GYPCT-UM5111 1313.00 1.97 22478 61288 42414 ;18 .. 5.945,54363 317,070,51 0.13 -219 GYDCT-DM8(1) e 87041 1.97 22420 67323 -58951 379 4.81 5,945,54208 317,.0.93 003 -2.79 MM+IFR-AWCAZSC(2) 77243 247 214.84 772.18 483.46 -11.61 -11,90 5945,53930 317,066.50 050 4.. MWD11FR-AKL -SC (2) W.00 3.05 21099 08584 17692 4540 -14.33 5.915,53557 317,.4.05 065 4.14 GYDLT-0M8(3) .162 410 21138 881.07 57235 -20,50 -1742 5945,530.55 317,06g) sat 1.10 -9.01 MVr9+IFR-AN-CAZSC M) 1,055.30 521 21879 105447 -93575 -27.09 -21.86 5,945,52406 317,056.14 178 -1244 MWDHFRAK-CAZSC (4) 1119,17 7.51 21855 114765 -in. 93 3575 4841 6945,5'556 317,049.49 191 -1671 MAC+IFR-AKAAZSC (4) 1,14386 9.13 22p 5D 1,24133 -1,15261 16.47 37,06 5,945,50506 3170/064 166 -21.69 MWD+I FR -AK CAZSC(4) 1,33633 1099 21801 133434 -1245fit -59.20 47,Sfi 5945.49259 317,ON. 77 184 4740 MWD°IFRA-L -SC (4) 12/62018 95647AM Pegg 3 Survey End Date 1023/2018 10/232018 10/232018 10/3012018 101292018 11/412018 11/12/2018 Annotation COMPASS 5000.14 Bond= �- ConocoPhillips ConocoPhillips FR a Definitive Survey Repoli Company: C.nccuPMIIIps(Almyka)Inc.-MS Local Co-andliate Reference: Wall MT5-04 Project: Western NoOM1 Slope NO Reference: ACTUAL MT6-04@88.72usfl (Doyonl9) - Site: GMTi Lookout Pad MD Reference: ACTUAL M16-04 Q? 8872usR(Doyon1g) E Well: M76-04 No 1,h Reference: Tme Wellbore: MT6-04PB1 Survey Calculation Method: Minimum Cu1M.1. 1 Design: C1-wp01 Database. EDT 14 Alaska Production 1 Survey _.-. _,... ... _.. .. i i MD Inc Aai ND TVDSS eN/4 4v N Map Map Vertical lusrtl 1°) 1°I lusftl IusX 1 lusX)(usR) gamble, lbuffl Section Survey Tool Name Annotation )n9 (yD100') 1,43320 1185 21567 1026.43 -1.31771 -73.99 50.62 5945.4]80] 111.111 11 1.15 3458 MWD°11R-AK-.C(4) 1,52821 1153 214.67 1,51841 -1,429.89 49.55 1979 5,945,462]9 311,008.82 040 4253 MMIWR-AK-CAZSC(4) 1,61987 11.03 215.29 'A1026 -1,52154 104.59 1029 5,945,44804 316,99595 055 -5026 MYA1IFR-MRCAZSC(4) 1]15.13 1083 215.18 1iIX1.79 -181507 -119.31 -90.71 $,945433.54 316,905.18 0.21 {]81 MWD1IFR-AKLAZ,3C (4) 1,808.35 10.76 215.27 1795.36 -1.706.64 -133.58 -100.77 5,945,419.53 316,974.77 008 1511 MWD°1FR.AK-CAZ-8C(4) 1.802.23 11.34 216.05 1,887,50 -17.78 -14820 -1119 6,945.4051] 316.96393 0.64 42.50 MVA1lFR-AKCAZSC(4) 1,992.23 1187 21078 19]5]0 -1,88890 -16264 -12192 5,945,35(g89 316.02.93 040 -7a. MWD•IFR-PACA210(4) 13-3R'%16" 2,008.18 11.61 21328 2,060.30 -1,970.58 -17826 -13208 5,945,37564 318,941.61 0 7 .8769 MWD-IFRAK-CAZSC S) 2,181.07 12.25 21].1] 2160.56 -2,0]184 -194.18 -144.11 5.945.36002 316.82898 1.09 -95.82 MWD°IFRAKCAZSC(5) 2.275.36 12.52 22706 2,252.66 -2,163.84 450.09 -157.64 594534542 318.91609 227 -10198 MkVD1IFR-M,CAZSC(5) 2,38988 13,411 235.86 2.M457 425585 -22223 -17423 5,84533269 316,a"19 2.33 -105.02 MWD-IFRAHCP23C (5) 2.484.63 1407 23]]3 243570 -2.34798 -234.59 -193.13 5.94532080 316,880.00 0.78 -10525 M%DHFR-AK-CAZSC(5, i 2.556.31 1403 23180 252].6] -2.43085 .246.73 -212.39 5,945.309.13 318.860.45 005 -10711 MND�IFR-AK-CAZSC(5) { 2653.30 1100 23].25 2.61903 4531.11 35906 33179 594529725 316,840]5 0.14 -100.07 MWDN"R-AKCAZSC(5) 2,]4].58 13.93 236.37 2]11.33 8,622.61 47155 -250.86 5.945 286 316,82139 0.23 -109.31 (5) 284233 14.02 23506 2,80325 -2.71454 -28435 -269.85 5,946.27291 318.002.10 019 4Ilgm MWD -FR AK-CA21C(5) 2,93557 14.52 23446 2,89362 380.90 -29].52 38868 5,945250.21 316,782.95 081 -11283 MND+IFR-AKCAZSC(6) r 3,02987 14.58 2M.70 2984.90 -209018 31135 3o7ee 5,945,24685 316]63.31 0.50 -1150 MWD°IFRAK-CAZ4SC(5) 3,12361 1455 23490 350563 -2,999.91 324.84 -32725 1,141.2Z3 g4 316.]43.]3 0.0 -11715 MWD1IFR-AK-CA21C(6) 1 3210.35 14.57 235.35 3.18732 5.500.80 338608 348.79 5,945220]0 318.713.87 012 -1183 MWpIIFR-AK-060240(5) 3.31286 14.56 235.04 3.26880 3,17008 352.02 366.31 5,a1520761 316,7003 OW -121.10 MWD1lFR-Al(CAZSC(6) 3,408.03 1459 .545 134897 5,28025 -36539 485.5] 5.945.194.]2 316,80445 0.12 -123.02 MWD•IFR-AI(CAZSC(5) 3,49983 1431 236.19 3./39.80 -3.351.08 476.53 404.94 5,06.1820 316,664.]] 038 -12468 MWD•IF&AK-CA2bC(5) 3.5052 13.34 24000 3,531.75 4t,44303 190.51 42412 5.05,1 7054 316,64530 1.40 -125." MN IFRAK-CAZSC(5) i 3.60793 12.31 24478 3,622.83 5,634.11 -40014 442.46 5945161 36 318,626]3 1.59 42459 MWD•IFR-AXCAZSC(5) 3]8169 1225 24808 3,71445 4,626.73 408.11 480]3 5,945,153 83 3166027 075 -122.33 MWD1lFRABCAZ-SC(5) 3,87601 1226 246.90 3808.62 -3,71790 415]] 4]922 5.945,148.62 316,58981 027 -119.70 MWDHFR AK-CPZSC(51 3.97027 1224 24582 3.88873 4,810.01 42379 AIDS3 5,05,13.05 311-4.5]1.11 024 41748 MWTHIFR-AK-CA21C(5) 4083]9 1225 24441 3.9013 -3.90141 432.14 115.52 5945,131.15 316,552.92 0.32 -115.6] MWD.IFR-AXLAZS1(1) 4, Is. no 1222 24278 4,003.23 3,994.51 441,11 -53381 5,945,12261 31653483 0.38 -114.38 MWD°IFRAK-0g2SC(5) 425352 1209 24182 417557 -000685 450.36 -55122 6.945,11380 316516 e0 025 -113.55 MMI IFRAK-CAZSC(5) 12/112018 9:56:47AM Page 4 COMPASS 500014 Build 85D r- C.onocoPhilli � ConocoPhillips RA aR p Definiiive Survey Repen 'Company: ConocoPhillips(Alaska)I in, -WNS Local Coordinate Retentions: Well MT6-04 PralecL Western North Slope TVD Reference: ACTUAL Iffil@ 8872usfl(Doyon 19) Sim: Call Lookout Pad MD Reference: ACTUAL kill@ 8672usft(Doyanl9) Well: MTfr04 North Famo e: True Wellbore: MT6-04PR1 Survey Calculation Marked: Minimum Curvature Design: CLwp01 Database: EDT 14 Alaska Production MD Inc A9 TVD N0a5 aNl eEm Map Map DLS Vertical (usft) (°) (1) (usft) (usft) (usft) (usft) Northing ees0ng Section Survey Tool Name Annotation (ft) NO (°1100') (ft) 4.569 1207 241.67 421l {1]858 <5949 -SSri 5,945,105.08 316,499.59 0. -11294 MWD+IFR-AKCAZSL 5 O 4439.41 1202. 24174 4358.38 -028166 460.86 58521 5,945098.33 315,48234 0 a -11234 MVr➢°IFR-AKLAZSC (5) 4,53196 1205 24075 4,44778 -0,359.06 478.03 5@.33 5.94508]37 31il.3 022 -111.0 MND+IFR-AK-0AZSC(5) 4fi2564 12. 240.39 453949 4.40.77 48]65 81937 5,945,070.18 316.447,76 008 -11186 MKD-IFF l(-CP2S0(5) "2055 12.06 24105 463231 4.54359 497.34 83865 5,845,068.01 316,43025 015 -111,0 MAD-lFR-M(-0AZ.C(6j 4.01425 1203 243. 4.723.95 1.63523 506.47 55394 5945,06020 316,41275 049 -11065 MWC DHFRAKAZSC(5) 4809.11 1200 243.81 481873 4,726(31 -51527 87161 6.945.05193 318.394.87 0.13 -10941 MN9�IFR-PHCPZSC(5) 5.00367 12.05 24309 490922 4,820.50 524.08 58924 5,945043 .45 31837709 017 -10820 MWDHFR-Pl(-CP25C(5) 5.087.23 1203 242. 6,00.72 4,91200 533.07 1.55 5,94503488 318,35).51 0.24 -107.31 MWD+IFRAKCAZSC(51 5,19137 11.87 24143 5,092.00 5004.08 54235 -02379 5.945026.03 318.342.05 0.15 -106. kSAD+IFRAKCAZ-.0(5) 528553 1197 240.55 5,184.91 5,00.19 -551.80 140.80 5,945,017.00 318,82474 0.17 -108.31 MWp4FR-AHCA28C(6) 5,37954 1222 24076 5.27684 5.188.12 56144 -758.06 5945,00776 316,30733 027 -108.05 MVA)eIFR-AWCAZSC(5) 5.47365 1228 24181 5,360.01 428009 57103 -77558 5.944,99862 316,28961 0.24 -10557 MWD+IFR-AK-CAZSC(5) 5,567.91 1220 24309 5,460.93 5.37221 580.28 -093.28 5,94490902 315,271.69 029 -104,70 MWD+6R-AKCAZSC(5) 586308 1220 242.0 5,553.95 5,465.23 -58930 ,11 .10 5,940.98114 316,25355 0.03 -10361 MVANFR-A140AZSC(5) 5757.1 12.10 24352 584578 5,55704 598.31 820.89 5,944,97264 316,238W 013 -102.47 MVA4FR-AM-CAZSC(a) 6.671,0 12.24 .335 5,738. 5,849.30 S07 24 446,75 5,944,964.15 315.217.56 0. -10125 MWDH1'RAKCAZSC(6) 5,943.11 1217 244.35 5,027.65 5,730.93 51579 4al 5.944.956.03 316.199. 024 -9992 MWDe1FRAKCAZSC(5) 603804 1217 24772 5.90.45 -5,63173 52391 .62.43 5,944,94835 316,101,9 0.75 ,779 MWD+1FR-M% -SC (5) I!) 6,... 1216 28078 601070 -5,92198 529.16 -901.03 5944.943.56 316.16277 2% 43.01 MNDgFR-AK-GMSC let S.ZMA2 12.34 Y1413 6.102 a5 4,013.93 530.02 -92004 5944043.17 316,14294 3.01 4383 MVVD-pil 15, 6,318.56 Was 28173 6.104.51 510679 89,16 -94124 5944946.54 318.12262 1.90 -7113 MWD+IFRAKCAZSC 15) 641349 1370 28929 disrobe 819818 82125 862.30 5,944,952.94 318.10171 198 -5540 MK9eIFR-AKCP29 , i 867709 1504 29467 8,37033 4,289.81 51246 -90398 5,944982.27 316,06.25 2.0 47.00 MNOHFR-AK-CAZSC(6) ' 6,al 1715 30201 6.0947 .38075 E9989 1007.00 5,944,975.58 316,0573 3.33 -1442 MAV+lFRAK-CAZSO 15) 6,69660 19.38 312.70 6,558.57 5468.85 581.59 -1,030.14 6.94499425 316.034,85 4.01 1205 MMIERAKCA24SC(5) 679100 21.05 31230 6,648.92 5,55820 558.04 -1,067,3 5,&5,01035 316,012,00 3.12 44.0 MYCOOR-M-CAZSC(6) 8.80429 2455 320.32 6,732.88 .84394 53..38 -1,077]3 5,945,04661 315,9&,53 3.16 8102 MaDIF&AK-L42S0(5) 6,7785 27.37 32155 A16.59 872787 408,62 1,10346 5,945.078& 316,963.57 3. 12138 MWD+IFRAK-C -SC (5) 707223 30.40 32403 6,09940 4,61068 462.22 -113105 5.945,fl802 315,935.89 344 167.71 MWL1+lFRAKCA2S0(5) 715650 3290 32698 6,97964 AM. 92 42144 -1.15901 5.945.15747 315,0992 3.12 21501 MVVDIFR-AK-WZ C(5) 1252018 9.56:47AM Page 5 COMPASS 500014 Build 650 r- ConocoPhillips ConocoPhillips qtl TVD Definitive Survey Report ♦NPS ' Co.,.,: C,A.coPhl11,P6(Alaaka) ne.-MS Local Coordinate Reference: Wkll MT6-04 Project: Mstem North Slope WO Reference: ACTUAL MT6-04 Q 88 72ush (Doyonl9) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-04@ 88.72usR(Dopn19) '.. Well: MT5-04 North Reference: Tore Wellbore: MT644PRI Survey Calculation Method: Minimum Curvature Design: Cl -wool Database: EDT 14 Alaska Production survey... MO Inc qtl TVD WEISS ♦NPS •W Map Map Vertical (uah) 1% 0 (bah) (usft) (.all) -(y luanl NONhin9 Seven, OLS Section Stony e Tool Name (h) (R) I°n 60.1 (h) )260.8] 3flpq 32898 ],05]44 5,986]2 -378.15 .18730 -118730 5,1 315882]5 3.54 269.30 MM1lFRAK-G2SC(5) 7,35523 3889 331.11 713233 4,04361 326.41 .1 ,21592 5.945.25384 315,855.34 332 326]] MWD°IFRAKCAZSC(5) ],44900 41,55 334.16 7,2N.54 -7.115.82 -2221] -1,.3.94 5,945.30814 315,02865 351 30]]5 MM.IERAK-W-SC(5) 7,54371 4422 .5.87 ].2]3.34 4,104.62 -21424 -117091 5,945,36].31 315,603.0 3.87 451.40 hl r +IFR�AK-CAISC(5) ],878.]0 4726 336.83 733988 7,250.96 -151.87 -1,29821 5.945430.32 315,2]].32 326 51905 MWD1F&AK4lAZSC(5) ],80992 4829 336911 ],3]4.05 -7285.33 -117.05 -1313.0 5,945,485.49 315]6329 20 558." MVrD11FR-AKC P13C(5) 7]]0.30 4783 337W ],42]]] -]339.05 61.91 -1,33631 5945,521.17 315.741.52 006 615.94 MWIIHFRAK QAISC(e) 7.834 a. 51 as 33860 7,48664 -7,39992 4.00 -1,36295 5"550851 316,71641 415 0707 MVN1IFRAKCAZSC(6) 7,958.N 54.68 33882 7,54411 -7455.99 ]45] -t.0.N 5,.5.658.91 315.0098 3.24 761.N MWD°IFR-AKCPZSC(6) 8.052,24 56.96 .9 04 7,59763 1,50691 147.28 44180 5,"5,732.28 315,8"]4 243 63801 MMD,lFRAK-CAZSC(6) 8.14695 5954 338115 7.64746 -],558.]4 222.44 -1,44703 5.945180811 315,63765 273 91754 MMIFRAKLAZSD(6) 8,24180 6170 338Me 769403 -7,605,31 Nose -1,47505 5..5,885.96 315 509,71 2.28 all MWD°IFR-AKL -SC (6) 8,33528 643] 338.18 ],]38.30 -7,64768 377]1 -1.606.81 5,945...20 315.581.54 2.06 1,061.49 MM+lFRAK-CAZSC(6) 8.42878 6883 338. 777514 -7,68642 45647 -1,53778 5."6,04426 315,55261 242 1,16555 MADHFRAKC -SC (6) 8.523.58 69.12 338,74 7,010.05 -0)22.13 53030 ;56969 e'Nelm.03 315,522.]0 2.87 1,25235 MWD°IFR-AK{ -SC (6) 0.61812 71 31 .942 7,.2.85 -),75413 62139 -1,60144 594621087 315.482.97 241 1.340.1] MM1lFRAKCAZSC (6) 8,71308 ]3.18 33961 7,8]181 -].]8309 70.11 4833.10 5.90.29613 315,46339 188 1429.35 MMIIFRAK- A -SC (6) 8.807.35 75.13 33979 7.89754 -],808.82 791,16 -1.%4.55 5.946.38180 315,43401 2.. 1,51871 MWDgFRAKCAZSC(6) 0,60146 7755 339.91 7,919.77 -7.03105 87700 -1,60.05 5948,488.40 315.4N.60 2,57 1,808.79 MuwUlFRAK-CAZSC(6) 8.958.03 .84 940.10 Tesa.31 -7,84959 934.14 -1.72776 5."8,558.36 315375.02 243 Voll 09 MWDIFRAK-CAZSC(6) 9.09078 7988 34041 7954.09 -7855.2] 1,05193 -1,759.27 5,.6,6.,88 315,34568 O. 1,]9105 MWD9FR-AKCAZSC(6) 9,105,74 11104 34045 7,970.07 -7,801.35 1,14026 -1,]906] 5,"6,]33.95 315,316.41 2,87 1,884.03 MWD°IFRAKC -SC (s) 9,279.43 8391 340.09 788169 -769297 1,22].98 -1821.44 5.946,8U2 38 31528778 228 1,975.36 MM11FRAK-OAZ4SC(6) 9,373.94 83.82 34078 7,991 7. -].9030] 1316]4 -1,85229 5,945,91186 315259.10 0.15 2,08763 MWD1IFRAKCAZSC(6) 9,.708 8405 mow 7,099.52 -7,910.80 1,38536 -1.07633 5948,981.04 315.23673 040 2,139.06 MWD°IFRAWC42SC (]) 9.48595 .76 34051 0,003.31 Q914.59 1,421.06 -1.88922 5.94701784 315.22474 184 2,17710 MN911FRAK-CAZSC (7) 9,52346 8448 311" 8.018.03 -7,91811 145715 -1$01.42 5,9].05342 31521339 2.33 2,213]6 MWD11FRAKCAZSO(7) 961894 84.51 340.99 6.015.90 -],92].26 1,5210 ;932.11 5"7,14408 315.181.91 0,37 2308.90 MWO°IFR-A SC 17) 9.214.8 .12 34264 802508 -7836.36 1,63].0] -1,931.86 5.947 224 315,157.55 1 7 2,3]9.85 MM11FRAK-CAZSC ni 9ve0 c 0]6] 34316 00156 -7,94284 172782 .1,909.58 5,947.326 13 315.131.84 3.35 2492.18 MM-FRAKCAZSC (7) 99.362 90.09 34296 603275 -],944.03 1812fi .201712 594741721 315.106,60 341 2.504.24 MWDIIFRAK-CA2SC(7) R4 ER DaHES Annotation 9-53" x 12-114" A' x 8-314" 123!1018 956:47AM Page 6 COMPASS 5000.14 Suild 85D �.- Conocolohillips Rapp ConocoPhillips Definitive Survey Report ll 0 company: ConoccPhill,s(Aeeks) Inc -V S pfoject 40eo1eln North Slope Site: GMT1 Lookout Pad Well: MT6-04 r Wellbore: WS 04P81 Design: C1-wp01 Survey ... Local CooNinate Reference: Mil MT6-04 TVD Reference: ACTUAL MT6-04 Q 8872usS(Doyonl9) MD Reference: ACTUAL MT644®80.72usS(Doyonl9) North Reference: True Survey Calculation Method Minimum Cal Deal EDT 14 Alaska Pmduclion MD Inc ABt TVP TVDSS +N/ -S aE/.µr Map Map DLS (uMD (1) (0) (soft) (soft) hal push) Northing Easting 1X1 1X1 (°1100') 9,078.83 92.00 31348 8,03029 ;9415] 1,9.20 -2044,54 5,947,50877 315.081.31 IX 1009368 9209 34374 0,026.84 -7,93812 2000.13 -2,07127 S.."m00,33 31steal ]8 028 10.18870 WA4 34424 8.024.73 -7936.01 207240 -2,00775 5,947,60.21 315m2.56 Ire 10,28519 9042 39393 8,024.@ 4,93530 2,184.23 1.123.93 5,947]8564 315,038.62 0.33 10,379.78 90.33 34371 8,02340 -7.9..68 227507 -2,15029 5,947,077.09 314.904.48 0.25 10,47468 0877 .2.17 8,23,31 1934.59 2,36579 -2,178.13 5.947,9.45 314958.85 173 10.568. 8974 34165 8,2372 -7,93500 2,955.38 1,207,40 5,948.058]2 314.01" 055 10,5514 89.50 3400 6,024.36 -7935.64 254827 -2,23895 5,948,150,34 314,902.44 1,67 10,780.24 8943 34017 8,@5.24 -7938.52 2.655 69 -2271.29 5,948,24052 314,87226 014 10,855.10 9048 340.81 802532 -7,OW,60 2,725.18 -2.300 5,.8,330.7a 314,84275 1.30 Wedged 87el 34084 8,026,89 -7.938.17 281548 -233458 594042177 314,013.38 297 11,.640 87. .168 8031.35 4,94263 2.579 -2,36541 5,948,51280 31478475 126 11.141.56 8704 342.47 8,038.30 -7,947.58 2,098.20 -2,39467 5,9a8603.90 314,757% 085 11,2570 8852 342.93 8,039.89 1,95127 3.087.00 -2,422..1 51948895.39 314731.62 163 11.33220 00.58 34334 8,.240 -7,95360 3,178.33 -245064 5.94878732 314)06.17 043 11426.97 80.67 34346 8,04488 -7,95596 3 A 13 -247771 5.8,828.70 314.681J2 0.16 11,52285 90.61 342.97 8.04528 -7,95866 3.%091 -2,505.39 5,948.971.17 314,655.87 2.09 1161847 9258 34186 8,042.62 1.953.90 3.452.02 -2,53427 5,949,062.94 31462822 25 1171336 .93.09 We 28 8,037. 7..921 3.l 11 -2,5°4.57 5,949.15270 3145.,9 381 11,808.02 93.03 330.06 8.03285 -7.944.13 362923 -2,60187 5,W9 241.72 314,565.95 024 its... 9308 337.55 13,027]6 1,939.04 3.717.81 -2,638.05 5,949,33126 314,531,93 053 11,999.. 93.12 33785 son. ;93392 some,19 -2mN,15 5,949,41868 311.49707 0.12 12,00361 94.01 33807 0,01877 -752805 3,892.77 -2,709.68 5.949507.79 $14464.58 1. 12.190.30 93.95 33813 B,olow 4.921.34 3.992.26 -2,74564 5,948,59613 310,430.60 080 12 285 46 93.95 338.28 BA.44 -7.91472 4,07134 -2781.25 5,949.688.03 314,397. 0.16 12381.03 95.50 338,12 7,99565 -7,906.93 9,158& -281625 599971636 314,3..50 165 1298000 95.50 33812 7986.16 1ter a4 4,250.26 2, 65297 5, 949 H6 63 314 330 02 Ino Vertical Section survey Tool Name 01) 2,678.67 MWD+llAK-0AZ.O p) 2768.77 MVA+IFR-AK-CA24C(7) 2,Ml89 MWD+I1FRAK-CAZSC(7) 29-%.48 MWD+IFR-N AZSC(7) 3,045.30 MVA+KRAK-CAZSC(7) 3,13876 MWD+IFRAK-0 -SC (7) 3.230.96 MWD+IFR AM-CAZSC (7) 3,32542 MKD+IFR-AK-CA25C(7) 3.41901 MWD+IFRAKCAZSC(7) 3.512.3a MWD+IFR- -CAitSC(7) 3505.31 MVA+IFR-AK-CA25C(7) 3.89992 MWD+IFRAKL -SC (7) 3,792.83 MWD+IFR-AK-0AZSC(7) 3,88562 MWD+IFRAWCAZSC(7) 3.07800 MWD+IFRAK{ -SC (7) 4.07062 MWD+IFRA -CAZSC 9) 4,18393 MWD+IFRAK-CA24lC(7) 425725 MWD+IFRAK-0 4C (7) 4,350.52 MWD+IFRAK AZ-SC(7) 444447 MM41FR-AK-C -SC(7) 4,539.35 MWD+IFRAK-CAZ50(7) 4.633.22 MWD+IFRAK CAZSC(7) 475.55 MN9+IFRAK-C Z4C (7) 4,822.03 MWD+IFRAK-0A C(7) 4,916.86 MWD+IFRAKSAZSC(7) 5.010.22 MKD+IFRAWCA25C(7) 5.10773 PROJECTED b TO Annotation 4-112'x6-110' 1241(2019 9:56.47AM Page 7 COMPASS 5000.14 Build 850 BA ER PRINT BAT GE company COMPANY ConocoPhillips Alaska Inc. WELL NAME MT6-04 & MT6-04PB1 FIELD Greater Mosses Tooth Unit COUNTY BHI DISTRICT ALPINE Alaska AUTHORIZED BY Paul Canizares EMAIL Paul.Canizaresrabhoe.com STATUS COMPANY 218108 ;0 120 DISTRIBUTION LIST 'lease sign and return a of this transmittal form to: -onocoPhillips Alaska, Inc. iicky Elgarico. Richard.E.Elgarico@conocophillips.com \TO 3-380. 100'G' Street. Anchorage, AK 99501 LOG TYPE GR-RES-DEN-NEU LOG DATE November it 2018 TODAYS DATE December 12, 2018 Revision Final Replacement: No Details: Rev. Requested by: ADDRESS (FEDE%WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION .._.__...Phill!_..AIau._.._..c. ____........_-'__......_.._ � !ConocoPhillips Alaska, lnc. 'Ricky Elgarico. A'to 3-380. 700'G'street. 2 Alpine Wells Supervisor, NSK-33 P.O. Box 196860 Anchorage, Alaska. 99519-6860 3 :ASRC, Attn: Teresa Imm 'C' Street, Sucre 901 gage, Alaska 99593-5963 A Stare Office W. 7th Ave., Suite#13 horage, Alaska 99513-7504 TCC ATTN: Natural Resources Tech W. 7th Ave., Suite 100 horage, Alaska 99501-3539 FIELD I FINAL CD/DVD PRELIM LOGS (las, dlis, PDF, META, FINAL SURVEY REPORT LOGS CGM, Final Surveys) # OF PRINTS4 UF PKIN I b # OF COPIES # OF COPIES # OF COPIES �.Ci�` tion L 11 Iva i o-uyl Is located In a federal on and gas unit. Only with respect to the JMT6-041 Well Data, CPA[ hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 4 0 0 BAN UGHES PRINT DISTRIBUTION LIST a GE company COMPANY_ ConocoPhillips Alaska Inc WELL NAME M76-04 & MT6-04PB1 FIELD Greater Mosses Tooth COUNTY ALPINE BHI DISTRICT AUTHORIZED BY Paul Canizares EMAIL Paul.CanizaresAbhae com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V I Conocorhi Ili, Alaska, I". !Ricky Elgarico. ATO 3-380. ;700 -G, Street. Anchorage, Alaska 99501 2 3 le Wells Supervisor, NSK-33 Box 196860 arise, Alaska. 99519-6860 :, Arm; Teresa Imm 'C' Street, Suite 801 xage, Alaska 99503-5963 4 State Office W. 7th Ave., Suite#13 horage, Alaska 99513-7504 3CC ATTN: Natural Resources Tech W. 7th Ave, Sulte 100 howge. Alaska 99501-3539 218103 30121 Please sign and return a of this transmittal form to: ConocoPhillips Alaska, Inc. Ricky Elgarico. Richard.E.Elgarico@conocophillips.com ATO 3-380. 700'G' Street. Anchorage, AK 99501 to acknowledge recei t of this data. LOG TYPE GR-RES-DEN-NEU LOG DATE November 11, 2018 TODAYS DATE December 12, 2018 Revision No Details: Rev. Requested by: _- FIELD / FINALCD/DVD PRELIM LOGS (las, dlis, PDF, META, FINAL REPORT LOGS CGM, Final Surveys) SURVEY # OF PRINTS # OF COPIES # OF COPIES # OF COPIES w IVa 1 u -u41 is tocarea 1n a federal oil and gas unit. Only with respect to the MT6-041 Well Data. CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communicationshould be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). TOTALS FOR THIS PAGE: 0 0 4 0 0 300 9 b Originated: Delivered to:TRANSMITTAL DATE 11-Dec-18 Schlumberger , AOGCC TRANSMITTAL #11 Dec18JW04 PTS -PRINT CENTER ATTN! Natural Resources Technician 11 6411 A Street Alaska Oil & Gas Conservation Commision Anchorage, AK 99518 333 W. 7th Ave, Suite 100 (907)273-1700 main (907)273-4760 fax .+ Anchorage, AK 99501 ORDERSERVICE FIELD NAME DESCRIPTION DELIVERABLE r • •. r. • r Prints CD's MT6-04 50-103-20775-00 E57Z-00011 Greater Mooses Tooth Memory SCMT I FINAL FIELD 16-Nov-18 1 GEI Ee 1 Transmittal Rey 1p _ I��� A Transmittal Receipt signature confirms that a package (box, /V/IL/ i//911 envelope, etc.) has been received and the contents of the X Com` package have been verified to match the media noted above. The P int a Sia 4ey' 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 return via courier or sign/scan and email a copy o chlumberger and CPAI. point. Alaska PTSPrintCenter slb.com Tom.Osterkam conoco li s.com 1 SLB Auditor- -TW BA ER BAT a GEcompany Date: December 6, 2018 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 2'rsi48 30075 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 lease find enclosed the directional survey data for the following well(s): MT6-04PB1 MT6-04 RECE�vE® DEC 0 7 2018 AOGCC (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@BakerHushes.com ConocoPhillips ConocoPhill ips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-04 50-103-20775-00 Baker Hughes INTEQ Definitive Survey Report 06 December, 2018 BA ER F�UGHES a GE company 21 81 08 30075 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Site: GMTt Lookout Pad MD Reference: Well: MT6-04 North Reference: Wellbore: MT6-04 Survey Calculation Method: Design: C1-wp01 Database: Project Western North 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 Well MT6-04 Well Position +N/ -S 0.00 usft Northing: +El -W 0 00 usft Easting: Position Uncertainty 0.00 Usti Wellhead Elevation: Wellbore MT6-04 Magnetics Model Name Sample Date BGGM2018 10/22/2018 Design MT6-04 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 36.52 Well MT6-04 ACTUAL MT6-04 @ 88.72usft (Doyonl 9) ACTUAL MT6-04 @ 88.72usft (Doyonl 9) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,945,550.61 usft 317,078.75usft 0 00usft Declination (I 16.34 Tie On Depth: 10,760.24 +N/ -S (usft) 0.00 +E/ -W (usft) 0.00 Latitude: Longitude: Ground Level: Dip Angle (1) 8069 Direction (°) 329.93 70° 15'23 035 N 151° 28'42.389 W 37.20 usft Field Strength (nT) 57,389 12/6/2018 9: 57: 18AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips 131% s ConocoPhillips Definitive Survey Report Company: Project: Site: Well: Wellborn: Design: ConocoPhillips(Alaska) Inc. -NMS Western North Slope GMT1 Lookout Pad MT6-04 W6 -Di C1-wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-04 ACTUAL MT6-04 @ 88.72usft (Doyonl9) ACTUAL MT6-04 @ 8872usft (Doyoni 9) True Minimum Curvature EDT 14 Alaska Production Survey Program _-� Date,._ r From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 115.00 613.00 1. Gyrodata GyroSS 16" (MT6-04P81) GYD-CT-DMS Gyrodata cont.drillpipe m/s 10/23/2018 10/23/2018 678.41 772.43 2. BHGE MWD -IFR -MSA 16"(MT6-04P MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/23/2018 10/23/2018 866.00 866.00 3. Gyrodata GyroSS 16" (MT6-04PB1) GYD-CT-DMS Gyrodata cont.drillpipe m/s 10/23/2018 10/23/2018 961.62 1,992.23 4. BHGE MWD OTK+IFR+MSA 16" (MT6 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/23/2018 10/30/2018 2,086.78 7,689.92 5. BHGE MWD ATK+IFR+MSA 121/4"(M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/27/2018 10/29/2018 7,770.30 9,373.94 6. BHGE MWD+IFR+MSA 6 3/4" (MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/2/2018 11/4/2018 9,447.06 10,760.24 7. BHGE MWD+IFR+MSA43/4"(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/4/2018 11/12/2018 10,79174 14,762.01 8, BHGE MWD+IFR+MSA43/4"(MT6-0 MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/12/2018 11/15/2018 Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (% (°) (usft) (usft) (usft) (usft) (°/100') Survey Tool Name Annotation (ft) (ft). (ft) 3652 0.00 0.00 36.52 5220 0.00 0.00 5,945,550.61 317,078.75 0.00 0.00 UNDEFINED 115.00 0.37 234.14 115.00 -26.28 -0.15 -0.21 5,945,55047 317,078.54 0.47 603 GYD-CT-DMS(1) 200.00 041 240.34 200.00 -111.28 -0.46 -0.69 5,945,550.17 317,078.05 0.07 -0.05 GYD-CT-DMS(1) 265.00 0.71 242.90 264.99 -176.27 -0.76 -1.25 5,945,54988 317,077.48 0.46 -0.03 GYD-CT-DMS(1) 365,00 1.18 230.77 364.98 -276.26 -1.69 -2.60 5,945,548.98 317,076.11 0.51 -0.16 GYD-CT-DMS(1) 450.00 1.79 220.91 449.95 -361.23 3.25 -0.15 5,945,547.46 317,074.53 0.78 -073 GYD-CT-DMS(1) 54200 2.03 226.61 546.90 -458.18 -5.57 6.39 5,945,545.19 317,072.23 0.32 -1.62 GYD-CT-DMS(1) 613.00 1.97 224.78 612.86 -524.14 -7.18 6.04 5,945,543.63 317,070.54 0.13 -2.19 GYD-CT-DM8(1) 678.41 1.97 22420 678.23 -589.51 -8.79 -9.61 5,945,542.06 317,068.93 003 -2.79 MWD+IFR-AK-CAZ-SC(2) 772.43 2.47 214.84 772.18 683.46 -11.61 -11.90 5,945,539.30 317,066.58 0.66 4.08 MWD+IFR-AK-CA7-SC (2) 86600 3.05 21099 865.64 -776.92 -15.40 -14.33 5,945,53557 317,064.05 0.65 6.14 GYD-CT-DMS(3) 961.62 4.10 211.39 961.07 -872.35 -20.50 -1742 5,945,53055 317,060.84 1.10 -901 MWD-IFR-AK-CAZ-SC (4) t( I 1,055.36 5.71 216.79 1,054.47 -96575 -27.09 -2196 5,945,524.06 317056.14 1.78 -1244 MWD+IFR-AK-CAZSC(4) 1 1,149.17 7.51 216.55 1,147.65 -1,05893 -35.75 -2841 5,W,51556 317,04949 1.92 -16.71 MWD+IFR-AK-CAZSC(4) j 1,243.86 9.18 22050 1,241.33 -1,152.61 -4647 -37.00 5,945,505.06 317,040.64 186 -21.68 MWD+IFR-AK-CAZ-SC(4) 12161018 9:5718AM Page 3 COMPASS 5000.14 Build 85D ��. ConocoPhillips ER ConocoPhIIII UGMES Definitive Survey Report rk Company: ConocoPhillips(Alaska) Inc.-WNS Project• Western North Slope Site: GMT1 Lookout Pad Well: MT6-04 Wellbore: MT6-04 Design: C1-Wp01 Survey Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MTB -04 ACTUAL MT6-04 @ 88.72usft (Doyonl9) ACTUAL MT6-04 @ 88.72usft (Doyonl9) True Minimum Curvature EDT 14 Alaska Production Annotation 13-3/8" x 16" 12/62018 9'57'18AM Page 4 COMPASS 500014 Build 85D Map Map VerticalDSS MD Inc Azi ND N +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) usft Northing Easting (°/100') Section Survey Tool Name 181 (ft) (fl) 1,338.33 10.99 219.01 1334.34 -1,245.62 -59.20 A7.56 5945,492.59 31],029]7 1.94 -27.40 MWD+IFR-AK-CAZ-SC(4) 1,432.28 11.85 215.67 1,426.43 -1,337.71 -73.99 -58.82 5,945,478.07 317,018.15 1.15 -34.56 MWD+IFR-AK-CAZ-SC (4) 1,526.21 11.53 21467 1,518.41 -1,429.69 -89.5565.79 5,945,46219 317,006.82 0.40 42.53 MWD+IFR-AK-CAZ-SC(4) 1,619.87 1103 215.29 1,610.26 -1,521.54 -104.56 -83.29 5,945,448.04 316,995.96 0.55 -50.26 MWD+IFR-AK-CAZ-SC(4) 1,715.13 10.83 215.16 1,703.79 -1,615.07 -119.31 -90.71 5,945,433.54 316,985.18 0.21 -57.81 MWD+IFR-AK-CAZSC(4) 1,808.35 1076 21527 1795.36 -1,706.64 -133.58 -100.77 5,945,419.53 316,974.77 0.08 -65.11 MWD+IFR-AK-CAZSC(4) 1,902.23 11.34 216.05 1,887.50 -1,798.78 -148.20 -111.27 5,945,405.17 316,963.93 0.64 -72.50 MWD+IFR-AK-CAZSC(4) 1,992.23 11.67 216.76 1,975.70 -1,886.98 -162.64 -121.92 5,945,390.99 316,952.93 0.40 -79.66 MWD+IFR-AK-CAZSC(4) 2,086.78 11.61 213.28 2,068.30 -1,979.58 -178.26 -132.86 5.945,375.64 316,941.61 0.75 -8769 MWD+IFR-AK-CAZSC(5) 2,181.07 12.25 217.17 2,160.56 -2,071.84 -194.16 -144.11 5,945,360.02 316,929.98 1.09 -9582 MWD+IFR-AK-CAZSC(5) 2,275.36 12.52 227.08 2,25266 -2,163.94 -209.09 -157.64 5,945,345.42 316,916.09 2.27 -101.96 MWD+IFR-AK-CAZSC(5) 2,369.68 13.48 235.86 2,344.57 -2,25585 -222.23 -174.23 5,945,332.69 316,899.19 2.33 -105.02 MWD+IFR-AK-CAZSC(5) 2,464.53 14.07 237.73 2,436.70 -2,347.98 -234.59 -193.13 5,945320.80 316,880.00 0.78 -106.25 MWD+IFR-AK-CAZSC(5) 2,558.31 14.03 237.80 2,52767 -2,438.95 -246.73 -212.39 5,945,309.13 316,860.45 0.05 -107.11 MWD+IFR-AK-CAZSC(5) 2,653.30 14.00 237.25 2,619.83 -2,531.11 -259.08 -231.79 5,945,297.25 316,840.75 0.14 -108.07 MWD+IFR-AK-CAZ-SC(5) 2,74759 13.96 236.37 2,711.33 -2,622.61 -271.55 -250.86 5,945,285.25 316,821.39 0.23 -109.31 MWD+IFR-AK-CAZ-SC(5) 2,842.33 14.02 235.66 2,803.26 -2,714.54 -284.35 -269.85 5,945,272.91 316,802.10 0.19 -110.87 MWD+IFR-AK-CAZ-SC(5) 2,935.57 14.52 234.46 2,893.62 -2,804.90 -297.52 -288.68 5,945,260.21 316,782.95 0.62 -112.83 MWD+IFR-AK-CAZ-SC(5) 3,029.87 14.58 234.70 2,984.90 -2,896.18 -31125 507.99 5,945,246.95 316,763.31 0.09 -115.04 MWD+IFR-AK-CAZ-SC(5) 3,123.61 14.55 234.90 3,075.63 -2,986.91 -324.84 -327.25 5,945,233.84 316,743.73 0.05 -117.15 MWD+IFR-AK-CAZSC(5) 3,218.35 14.57 235.35 3,167.32 -3,078.60 -338,6 -346.79 5,945,220.70 316,723.87 0.12 -119.14 MWD+IFR-AK-CAZSC(5) 3,312.86 14.56 235.04 3,258.80 -3,170.08 552.02 366.31 5,995,207.61 316,704.03 0.08 -121.10 MWD+IFR-AK-CAZSC(5) 3,406.03 14.59 235.46 3,348.97 -3,260.25 365.39 385.57 5,945,194.72 316,684.45 0.12 -123.02 MWD+IFR-AK-CAZSC(5) 3,499.83 14.31 236.19 3,439.80 -3,351.08 378.53 404.94 5,945,182.04 316,664.77 0.36 -124.69 MWD+IFR-AK-CAZSC(5) 3,594.52 13.34 240.00 3,531.75 -3,443.03 -390.51 424.12 5,945,170.54 316,645.30 1.40 -12544 MWD+IFR-AK-CAZSC(5) 3,687.93 12.31 244.78 3,622.83 -3,534.11 400.14 442.46 5,945,161.36 316,626.73 1.58 -124.59 MWD+IFR-AK-CAZSC(5) 3,78169 12.25 24808 3,714.45 -3,625.73 408.11 460.73 5,945,15383 316,608.27 0.75 -122.33 MWD+IFR-AK-CAZSC(5) 3,876.01 12.25 246.90 3,806.62 -3,717.90 415.77 479.22 5,945,14662 316,589.61 0.27 -119.70 MWD+IFR-AK-CAZSC(5) 3,970.27 12.24 245.82 3,898.73 3,810.01 423.79 497.53 5,945139.05 316,571.11 0.24 -117.46 MWD+IFR-AK-CAZSC (5) 4,063.79 12.25 244.41 3,990.13 -3,901.41 432.14 -515.52 5,945,131.15 316,552.92 0.32 -115.67 MWD+IFR-AK-CAZ-SC(5) 4,159.06 12.22 24278 4083.23 -3,994.51 441.11 -533.61 5,945,122.61 316,534.63 0.36 -114.38 MWD+IFR-AK-CAZ-SC(5) Annotation 13-3/8" x 16" 12/62018 9'57'18AM Page 4 COMPASS 500014 Build 85D 110� ConocoPhillips Bn�cER ConocoPhillips Definitive Survey Report 9.� Company: ConowPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-04 Project: Western North Slope TVD Reference: ACTUAL MT6-04 @ B8.72usft (Doyonl9) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-04 @ 88.72usft (Doyonl9) Well: MT6.04 North Reference: True Wellbore: MT6-04 Survey Calculation Method: Minimum Curvature Design: Ct-wp01 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +E/ -W DLS (usft) (°) (°) (waft) (i (usft) (usft) NO(ft) Ea(ft) (°1100') Section Survey Tool Name Annotation 4,253.52 12.09 241.82 4,175.57 4,086.85 450.36 -551.22 5,945,11380 316,516.80 0.25 -113.55 MM.IFR-AK-CAZ-SC(5) 4,345.69 12.07 241.67 4,26570 4.176.98 459.49 -568.21 5,945,105.08 316,499.59 0.04 412.94 MWD+IFR-AK-CAZSC(5) 4,438.41 12.02 241.74 4,356.38 4,26766 468.66 -585.24 5,945096.33 316,482.34 0.06 -112.34 MNID+IFR-AK-CAZSC(5) 4,531,86 12.05 240.75 4,447.78 4,359.06 478.03 502.33 5,945,087.37 316,465.03 0.22 -111.90 MWD+IFR-AK-CAZ-SC(5) 4,625.64 12.04 240.39 4,539.49 4,450.77 487.65 519.37 5,945,078.18 316,447.76 0.08 -11168 MWD+IFR-AK-CAZSC(5) 4,720.55 12.06 241.05 4,632.31 4.543.59 497.34 536.65 5,945,068.91 316,430.25 0.15 -111.40 MWD+IFR-AK-CAZSC(5) 4,814.25 12.03 243.25 4,723.95 4.635.23 -W(5.47 653.94 5,945,060.20 316,412.75 0.49 -110.65 MWD+IFR-AK-CAZSC(5) 4,909.11 12.00 243.81 4,816.73 4,728.01 -515.27 671.61 5,945,051.83 316,394.87 0.13 -10941 MWD+IFR-AK-CAZSC(5) 5,003.67 12.05 243.09 4,909.22 4.820.50 -524.08 589.24 5,945,043.45 316,377.04 0.17 -108.20 MWD+IFR-AK-CAZSC(5) 5,097.23 12.03 242.02 5,000.72 4,912.00 -533.07 -706.56 5,945,034.88 316,359.51 0.24 -107.31 MWD+IFR-AK-CAZSC(5) 5,191.37 11.97 241.43 5,092.80 -5,004.08 -542.35 -723.79 5,945,026.03 316,342.05 0.15 -106.69 MN/D+IFR.AK-CAZSC(5) 5,285.53 11.97 240.65 5,184.91 -5,036.19 -551.80 -740.88 5,945,017.00 316,324.74 0.17 -106.31 MWD+IFR-AK-CAZSC(5) 5,379.54 12.22 24076 5,276.84 -5,188.12 -561.44 -758.06 5,945,007.78 316,307.33 0.27 -10605 MWD+IFR-AK-CAZSC(5) 5,473.65 12.26 241.81 5,368.81 5,280.09 571.03 -775.56 5,944,998.62 316,289.61 0.24 -105.57 MWD+IFR-AK-CAZSC(5) 5,567.91 12.20 243.09 5,460.93 5,372.21 -580.26 -793.26 5,944,989.82 316,271.69 0.29 -104.70 MWD+IFR-AK-CAZSC(5) 5,663.06 12.20 242.96 5,553.95 -5,465.23 -589.38 611.18 5,944,981.14 316,253.55 0.03 -10361 MWD+IFR-AK-CAZSC(5) 5,75201 12.18 243.52 5,645.76 -5,557.04 -598.31 -828.89 5,944,972.64 316,235.63 0.13 -102.47 MWD+IFR-AK-CAZSC (5) 5,851.40 12.24 243.35 5,738.02 -5,649.30 .607.24 -846.75 5,944,964.15 316,217.56 0.07 -101.25 MWD+IFR-AK-CAZSC(5) = 5,943.11 12.17 244.35 5,82265 5,738.93 .615.79 -864.15 5,944,956.03 316,199.96 0.24 -99.92 MWD+IFR-AK-CAZSC(5) w 6,038.04 12.17 247.72 5,920.45 -5,83173 623.91 -882.43 5,944,948.35 316,181.49 0.75 -97.79 MND+IFR-AK-CAZSC(5) 6,130.34 12.16 260.78 6,010.70 -5,921.98 629.16 -901.03 5,941,943.56 316,162.77 2.98 -93.01 MWD+IFR-AK-CAZSC(5) 6,224.42 12.34 274.13 6,102.65 .6,013.93 630.02 -920.84 5,944,943.17 316,142.94 3.01 63.83 MWD+IFR-AK-CAZSC(5) 6,318.56 12.99 28173 6,194.51 5,105.79 627.15 -941.24 5,944,946.54 316,122.62 1.90 -71.13 MWD+IFR-AK-CAZSC(5) 6,413.49 13.70 269.29 6,286.88 5,198.16 621.26 -962.30 5,944,952.94 316,101.71 1.98 -55.48 MWD+IFR-AKCAZSC(5) 6,50789 15.04 294.67 6,378.33 6,28961 512.46 -983.98 5,944,962.27 316,080.25 2.00 -37.00 MWD+IFR-AKCAZSC(5) 6,602.77 17.25 302.81 6,469.47 5,380.75 599.69 -1,007.00 5,944,975.58 316,057.55 3.33 -14.42 MWD+IFR-AK-CAZSC(5) { 6,696.60 19.39 31270 6,55857 6,469.85 681.59 -1,030.14 5944,994.25 316,034.85 4.01 12.85 MND+IFR-AK-CAZSC(5) 6,791.00 21.85 317.30 6,646.92 5,558.20 55804 -1,053.58 5,945,018.35 316,012.00 3.12 44.96 MWD+IFR-AK-CAZSC(5) 6,884.29 24.55 320.32 6,732.66 5,643.94 530.36 -1,07.73 5,945,046.61 315,988.53 3.16 81.02 MWD+IFR-AK-CAZ-SC(5) 6,977.65 27.37 321.55 6,816.59 5,727.87 49862 -1,103.46 5,945,078.96 315,963.57 3.07 121.38 MWD+IFR-AK-CAZ-SC(5) 7,072.23 3040 324.03 6.89940 -6,810.68 46222 -1,131.05 5,945,11602 315,936.89 344 166.71 MWD+IFR-AK-CAZ-SG(5) 12/6@018 9:57: 184M Page 5 COMPASS 5000. 14 Build 85D ConoccPhillips D ER a ConocoPhilli UGHES Ix Definitive Survey Report "" """ Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-04 Wellbore: MT6-04 Design: C1-wp01 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-04 ACTUAL MT6-04 @ 88.72usft (Doyonl9) ACTUAL MT6-04 @ 88.72usft (Doyonl9) True Minimum Curvature EDT 14 Alaska Production 12/6/2018 9:57: 18AM Page 6 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi ND TVDSS +N/ -S +E/ -W DLS (usft) V) (1) (usft) (usft) (usft) (usft) Northing Easting (°/100' Section Survey Tool Name Annotation 7,166.50 32.90 326.98 6,979.64 6,890.92 A21.44 -1,159.01 5,945,15747 315,909.92 3.12 21601 MWD+IFR-AK-CAZSC(5) 7,260.87 36.04 328.98 7,05744 6,968.72 -376.15 -1,187.30 5,945,203.43 315,882.75 3.54 269.38 MWD+IFR-AK-CAZSC(5) 7,355.23 38.89 331.11 7,132.33 -7,043.61 -326.41 -1,215.92 5,945,25384 315,855.34 3.32 326.77 MWD+IFR-AK-CAZ-SC(5) 7,449.80 41.56 334.16 7,204.54 -7,115.82 -272.17 -1,243.94 5,945,30874 315,828.65 3.51 387.75 MAD+IFR-AK-CAZ-SC (5) 7,543.71 44.22 335.87 7,273.34 -7,184.62 -214.24 -1,270.91 5,945,367.31 315,803.09 3.09 451.40 MWD+IFR-AK-CAZ-SC (5) 7,638.78 47.26 336.83 7,339.68 -7,250.95 -151.87 -1,298.21 5,945,43032 315,777.32 328 519.05 MWD+IFR-AK-CAZ-SC(5) 7,689.92 48.29 336.90 7,374.05 -7,285.33 -11785 -1,313.09 5,945,465.49 315,763.29 202 556.64 MWD+IFR-AK-CAZ-SC (5) 9-5/8" x 12-1/4" 7,770.30 47.83 33260 7,427.77 -7,339.05 61.91 -1,336.21 5,945,521.17 315,741.52 0.86 615.94 MWD+IFR-AK-CAZ-SC(6) 7,864.50 51.65 33868 7,488.64 -7,399.92 4.80 -1,362.95 5,945,588.51 315,716.41 4.15 687.07 MWD+IFR-AK-CAZSC(6) 7,958.04 54.68 338.82 7,544.71 -7,455.99 74.57 -1,390.08 5,945,658.91 315,690.98 3.24 761.04 MWD+IFR-AK-CAZSC(6) 8,052.24 56.96 339.04 7,597.63 -7,508.91 14228 -1,418.09 5,945,732.28 315,664.74 2.43 838.01 MWD+IFR-AK-CAZSC(6) 8,146.95 59.54 338.85 7,647.46 -7,558.74 222.44 -1,47.03 5,945,808.11 315,637.65 2.73 917.54 MWD+IFR-AK-CAZSC(6) 8,241.88 61.70 33888 7,694.03 -7,605.31 299.59 -1,476.85 5,945,885.96 315,609.71 2.28 999.26 MWD+IFR-AK-CAZSC(6) 8,335.28 64.37 338.78 7,736.38 -7,647.66 377.21 -1,50691 5,945,964.28 315,581.54 2.86 1,081.49 MWD+IFR-AK-CAZSC(6) 8,428.76 66.63 338.66 7,775.14 -7,686.42 45647 -1,537.78 5,946,044.26 315,552.61 242 1,165.55 MWD+IFR-AK-CAZ-SC(6) 8,523.58 69.12 338.74 7,810.85 -7,722.13 538.30 -1,569.69 5,946,126.83 315,522.70 2.63 1,252.35 MWD+IFR-AK-CAZ-SC(6) 8,618.12 71.31 339.42 7,842.85 -7,754.13 621.39 -1,601.44 5,946,21067 315,492.97 241 1,340.17 MWD+IFR-AK-CAZ-8C(6) 8,713.09 73.18 339.61 7,871.81 -7,783.09 706.11 -1,633.10 5,946,296.13 315,463.39 198 1,429.35 MWD+IFR-AK-CAZ-SC (6) 8,807.35 75.13 339.79 7,897.54 -7,808.82 79116 -1,664.55 5,946,381.90 315,434.01 2.08 1,518.71 MWD+IFR-AK-CAZ-SC(6) 8,901.46 7255 339.91 7,919.77 -7,831.05 877.00 -1,696.05 5,946,468.48 315,404.60 2.57 1,608.79 MWD+IFR-AK-CA7-SC(6) 8,996.03 79.84 340.10 7,938.31 -7,849.59 964.14 -1,727.76 5,946,556.36 315,375.02 2.43 1,700.09 MWD+IFR-AK-CAZSC(6) 9,090.78 79.88 34041 7,954.99 -7,866.27 1,051.93 -1,759.27 5,946,644.88 315,345.66 0.32 1,791.85 MW +IFR-AK-CAZ-SC(6) 9,185.74 81.84 34045 7,970.07 -7,881.35 1,140.26 -1,790.67 5,946,733.95 315,316.41 2.06 1,884.03 MWD+IFR-AK-CAZ-SC(6) 9,279.43 83.91 340.89 7,981.69 -7,892.97 1,227.98 -1,821.44 5,946,822.38 315,287.78 2.26 1,975.36 MWD+IFR-AK-CAZSC(6) 9,373.94 83.82 340.78 7,991.79 -7903.07 1,316.74 -1,852.29 5,94,911.86 315,259.10 0.15 2,06783 MWD+IFR-AK-CAZSC(6) 7"x8-3/4" 9,447,06 84.05 34060 7,999.52 -7,910.80 1,385.36 -1,876.33 5,946,981.04 315,2W.73 0.40 2,139.06 MWD+IFR-AK-CA26C(7) 9,485.95 8,176 340.51 8,003.31 -7,914.59 1,421.86 -1,889.22 5,947,017.84 315,22414 184 2,177.10 MWD+IFR-AK-CAZSC(7) 9,523.46 84.48 341.34 8,006.83 -7,918.11 1,457.15 -1,901.42 5,947,05342 315,213.39 2.33 2,213.76 MWD+IFR-AK-CAZSC(7) 9,618.94 84.51 340.99 8,015.98 -7927.26 1,547.10 -1,932.11 5,947144.08 315,184.91 0.37 2,306.98 MWD+IFR-AK-CAZSC(7) 9,714.08 84.52 342.64 8,025.08 -7,936.36 1,637.07 -1,96166 5,947,23474 315,15755 1.73 2,399.65 MM+IFR-AK-CAZ-SC(7) 9.80926 8767 343.16 8,031.56 -7,942.84 _ 1,727.82 -1,989.58 5947,326.13 315,13184 335 2,492.18 MWD+IFR-AK-GAZ-SC(7) 12/6/2018 9:57: 18AM Page 6 COMPASS 5000.14 Build 85D �p� ConocoPhillips ER a COflOCOPhIlltF t1GHFS p`' Definitive Survey Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-04 Project: Western North Slope TVD Reference: ACTUAL MT6-04 @ 88.72usft (Doyonl9) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-04 @ 88.72usft (Doyonl9) Well: MTB -04 North Reference: True Wellbore: MT6-04 Survey Calculation Method: Minimum Curvature Design: C1-Wp01 Database: EDT 14 Alaska Production Survey MD Inc Azi ND N +N/ -S -E/.W Map Map DLS VerticalDSS (usft) (') V) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) (ft) 9,903.82 90.89 342.96 8,032.75 -7,944.03 1,818.26 -2,017.12 5,947,417.21 315,106.50 3.41 2,584.24 MWD+IFR-AK-CAZ-SC(7) 9,998.83 92.08 343.49 8,030.29 -7,941.57 1,909.20 -2,044.54 5,947,508.77 315,081.31 1.37 2,676.67 MWD+IFR-AK-CAZSC(7) 10,093.68 92.08 343.74 8,026.84 -7,938.12 2,000.13 -2,071.27 5,947,600.33 315,056.79 0.26 2,76877 MWD+IFR-AK-CAZSC(7) 10,189.70 90.4 344.24 8,024.73 -7,936.01 2,092.40 -2,097.75 5,947,693.21 315,032.56 1.79 2,861.89 MWD+IFR-AK-CAZSC(7) 10,285.19 90.42 343.93 8,024.02 -7,935.30 2,184.23 -2,123.93 5,947,785.64 315,008.62 0.33 2,954.48 MWD+IFR-AK-CAZSC(7) 10,37918 90.33 343.71 8,023.40 -7,934.68 2,275.07 -2,150.29 5,947,877.09 314,984.48 0.25 3,046.30 MWD+IFR-AK-CAZSC(7) 10,474.68 89.77 342.17 8,023.31 -7,934.59 2,36579 -2,178.13 5,947,96845 314,958.85 1.73 3,138.76 MWD+IFR-AK-CAZSC(7) 10,568.93 89.74 341.65 8,023.72 -7,935.00 2,455.38 -2,207.40 5,948,058.72 314,931,77 0.55 3,230.96 MWD+IFR-AK-CAZ-SC (7) 10,665.14 89.50 34086 8,024.36 -7,935.64 2,54627 -2,238.95 5,948,150.34 314,902.44 1.67 3,325.42 MM+IFR-AK-CAZ-SC(7) 10,760.24 89.43 340.17 8,025.24 -7,936.52 2,635.69 -2,271.29 5,948,240.52 314,872.28 0.14 3,419.01 MWD+IFR-AK-CAZSC(7) 10,791.74 87.65 339.94 8,026.05 -7,937.33 2,665.29 -2,282.03 5,948,270.37 314,862.26 5.70 3,450.01 MWD+IFR-AK-CAZSC(8) 10,854.92 87.78 337.92 8,028.57 -7,939.85 2,724.20 -2,304.73 5,948,329.80 314,841.00 3.20 3,512.36 MWD+IFR-AK-CAZSC(8) 10,950.52 90.46 336.66 8,030.03 -7,941.31 2,812.37 -2,341.63 5,948,418.84 314,806.26 3.10 3,607.15 MWD+IFR-AK-CAZSC(8) 11,045.34 91.81 334.74 8,028.15 -7,939.43 2,89876 -2,38064 5,948,506.15 314,769.36 2.47 3,701.47 MWD+IFR-AK-CAZ-SC(8) 11,141.16 91.80 332.59 8,025.14 -7,936.42 2,984.59 -2,42312 5,948,592.98 314,728.97 2.24 3,797.03 MWD+IFR-AK-CAZ-SC(8) 11,235.71 9074 330.33 8,023.04 -7,934.32 3,067.62 -2,468.28 5,948,677.08 314,685.85 2.64 3,891.52 MWD+IFR-AK-CAZ-SC (8) 11,331.00 90.29 328.21 8,022.18 -7,933.46 3,149.53 -2,516.97 5,948,760.13 314,639.17 2.27 3,986.79 MWD+IFR-AK-CAZ-SC(8) 11,426.65 90.26 328.32 8,021.72 -7,933.00 3,230.87 -2,567.28 5,948,842.67 314,590.85 0.12 4,08240 MWD+IFR-AK-CAZSC(8) 11,522.42 9181 328.11 8,020.00 -7,931.28 3,312.27 -2,617.71 5,948,925.26 314,542.41 1.63 4,178.11 MWD+IFR-AK-CAZSC(8) 11,616.65 93.00 327.57 8,016.04 -7,927.32 3,391.97 -2,667.83 5,949,006.15 314,49425 1.39 4,272.19 MWD+IFR-AK-CAZSC(8) 11,712.59 91.73 326.41 8,012.08 -7,923.36 3,472.35 -2,720.05 5,949,087.77 314,444.00 1.79 4,367.92 MWD+IFR-AK-CAZ-SC(8) 11,808.89 90.53 326.44 8,010.18 -7,92146 3,652.56 -2,773.29 5,949,169.25 314,392.72 1.25 4,464.02 MWD+IFR-AK-CAZ-SC(8) 11,903.84 89.76 329.80 8,009.94 -7,921.22 3,633.18 -2,823.43 5,949,251.06 314,344.56 3.63 4,558.91 MW0+IFR-AK-CAZ-SC(8) 11,999.01 89.43 33193 8,010.62 -7,921.90 3,716.30 -2,869.76 5949,335.27 314,30026 2.26 4,654.05 MWD+IFR-AK-CAZ-SC(8) 12,094.36 89.80 333.29 8,011.26 -7,922.54 3,800.96 -2,913.63 5,949,420.96 314,258.47 1.48 4,749.30 MWD+IFR-AK-CAZ-SC(8) 12,189.78 8971 334.19 8,011.66 -7,922.94 3,886.53 -2,955.84 5,949,507.53 314,218.35 0.95 4,844.50 MWD+IFR-AK-CAZ-SC(8) 12,285.67 69.71 33570 8,012.15 -7,923.43 3,973.39 -2,996.45 5,949,595.35 314,179.86 1.57 4,940.02 MWD+IFR-AK-CAZ-SC (8) 12,381.09 90.17 337.68 8,012.25 -7,923.53 4,061.02 5,034.21 5,949,683.86 314,144.25 2.13 5,034.77 MWD+IFR-AK-CAZ-SC(8) 12,476.30 90.48 338.15 8,011.71 -7,922.99 4,149.24 -3,07080 5,949,772.92 314,110.61 0.59 5,129.06 MWD+IFR-AK-CAZSC(8) 12,571.81 89.55 340.57 8,011.68 -7,922.96 4,23861 -3,10367 5,949,863.08 314.079.13 2.71 5,223.27 MWD+IFR-AK CAZ-SC(8) 12666.97 89.53 342.91 8,012.45 -7,923.73 4,328.97 -3.133.48 5,949,954.13 314,051.52 2.46 5,31641 MWD+IFR-AK-CAZ-SC(8) 12/6/2018 9: 57.18AM Page 7 Annotation COMPASS 5000.14 Build 85D 10 ConocoPhillips BA ER '' ConocoPhilli s p Definitive Survey Report Company: ConomPhillips(Alaska) Inc -WNS Local Cc -ordinate Reference: Well MT6-04 Project: Western North Slope TVD Reference: ACTUAL MT6-04 @ 88.72usft (Doyonl9) TVD Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-04 @ 88.72usft (Doyon19) Map Well: MT6-04 North Reference: True Wellbore: MT6-04 Survey Calculation Method: Minimum Curvature (usft) Design: C7-Wp01 Database: EDT 14 Alaska Production Nod; ng Survey MD Inc Azl TVD TVDSS +N/-5 +E/ -W Map Map Vertical ".. (usft) V) V) (usft) (usft) (usft) (usft) Nod; ng Ea(aft)ng (-M 00') Section( Survey Tool Name Annotation (fti 12,762.49 89.99 34425 8,012.85 -7,924.13 4,420.59 -3,16048 5,950,046.37 314,026.75 1.48 5,409.22 MWD+IFR-AK-CAZ-SC(8) 12,857.89 89.99 344.85 8,012.87 -7,924.15 4,512.54 5,185.89 5,950,138.91 314,003.58 0.63 5,501.54 MWD+IFR-AK-CAZSC(8) 12,953.00 89.96 346.26 8,012.91 -7,924.19 4,604.65 5,209.62 5,950,231.55 313,982.10 1.48 5,593.13 MWD+IFR-AK-CAZSC(8) 13,047.79 90.02 346.52 8,012.92 -7,924.20 4,696.77 5,231.92 5,950,324.19 313,962.04 0.28 5,684.03 MWD+IFR-AK-CAZSC(8) 13,143.42 89.21 342.67 8,013.57 -7,924.85 4,788.95 5,257.32 5,950,41695 313,938.89 4.11 5,776.53 MWD+IFR-AK-CAZSC(8) 13,23845 89.37 343.11 8,014.74 -7,926.02 4879.76 5,285.28 5,950,50841 313,913.15 0.49 5,869.13 MWD+1FR-AK-CAZ-SC(8) 13,334.21 89.40 345.16 8,015.77 -7,927.05 4,971.87 -3,311.45 5,9WADI12 313,889.22 2.14 5,961.95 MWD+IFR-AK-CAZ-SC(8) 13,429.56 89.37 344.97 8,016.79 -7,928.07 5,063.99 5,336.03 5,950,693.80 313,866.89 020 6,053.99 MWD+IFR-AK-CAZ-SC(8) 13,524.40 8925 345.80 8,017.94 -7,929.22 5,155.75 5,359.95 5,950,786.12 313,845.20 0.88 6,145.39 MWD+IFR-AK-CAZ-SC(8) 13,619.88 91.04 345.75 8,017.70 -7,928.98 5,248.30 5,383.42 5,950,879.20 313,824.00 1.88 6,237.24 MWD+11FR-AK-CAZSC(8) 13,715.00 91,00 346.09 8,016.00 -7,927.28 5,340.55 5,406.55 5,950,971.98 313,803.11 0.36 6,328.67 MWD+IFR-AK-CAZSC(8) 13,810.04 91.00 343.56 8,014.34 -7,925.62 5,432.25 -3,43142 5,951,064.25 313,780.47 2.66 6,420.49 MWD+IFR-AK-CAZSC(8) 3 13,904.21 91.00 343.44 8,01270 -7,923.98 5,522.53 5,458.17 5,951,155.15 313,755.93 0.13 6,512.02 MWD+IFR-AK-CAZ-SC(8) 13,999.76 91.00 343.98 8,011.03 -7,922.31 5,61423 5,484.96 5,951,247.47 313,731.37 0.57 6,604.80 j1 MWD+IFR-AK-CAZSC(8) Y 14,095.75 91.37 346.44 8,009.05 -7,920.33 5,70702 5,509.46 5,951,340.81 313,709.13 2.59 6,697.37 MWD+IFR.AK-CAZ-SC(8) 14,190.88 91,28 344.49 8,006.85 -7,918.13 5,799.07 5,533.33 5,951,433.41 313,687.51 205 6,789.00 ill MWD+IFR-AK-CA7-SC (8) i 14,285.39 90.69 344.57 8,005.22 -7,916.50 5,890.14 5,558.53 5,951,525.07 313,664.53 0.63 6,880.44 MWD+IFR-AK-CAZ-SC (8) 14,380.79 89.55 34548 8,005.02 -7,916.30 5,992.30 -3,583.18 5,951,617.79 313,642.12 1.53 6,972.55 MWD+IFR-AK-CAZSC(8) 14,47640 89.50 344.02 8,005.81 4,91709 6,074.59 -3,608.33 5,951,71060 313,619.22 1.53 7,064.97 MWD+IFR-AK-CAZSC(8) 14,572.98 90.23 345.21 8,006.04 -7,917.32 6,167.65 -3,633.95 5,951,804.31 313,595.87 1.45 7,158.39 MWD+IFR-AK-CAZSC(8) 14,667.15 91.50 346.34 8,00462 -7,915.90 6,258.92 5,657.09 5,951,696.11 313,574.96 1.81 7,248.97 MWD+IFR-AK-CAZ-SC(8) 14,762.01 91.46 345.21 8,002.17 -7,913.45 6,350.84 5,680.39 5,951,988.56 313,553.90 1.19 7,340.20 MWD+IFR-AK-CAZSC(8) E 14,790.00 91.46 345.21 8,001,46 -7,912.74 6,37290 5,687.53 5,952,015.78 313,547.42 0.00 7,367.19 PROJECTED to TO 4-1/2' X 6-118" (!t 12/6/2018 9:57.18AM Page 8 COMPASS 5000.14 Build 850 BA {ER 0 I Date: F�UGHES aGEcompany Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 December 6, 2018 218108 30 07 6 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 lease find enclosed the directional survey data for the following well(s): MT6-04PB1 MT6-04 REcENE® DEC 0 7 2018 AOGCC (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@BakerHughes.com ConocoPhillips ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-04PB1 50-103-20775-70 Baker Hughes INTEQ Definitive Survey Report 06 December, 2018 BA ER F�UGHES a GE company 21 81 08 30075 12/6/2018 9: 56.47AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BAERHES a ConocoPhillips Definitive Survey Report Company: Conoco Phillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-04 Project: Western North Slope TVD Reference: ACTUAL MT6-04 @ 88.72usft (Doyonl 9) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-04 @ 88.72usft (Doyonl 9) Well: MT6-04 North Reference: True Wellbore: MT6-04PB1 Survey Calculation Method: Minimum Curvature Design: C1-wp01 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 MT6-04 Well Position +N/ -S 0.00 usft Northing: 5,945,550.61 usft Latitude: 70° 15 23.035 N +EI -W 0.00 usft Easting: 317,078 75usff Longitude: 151" 28'42 389 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00usft Ground Level: 37.20 usft Wellbore MT6-04PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength l°) (°) (l BGGM2018 10/22/2018 16.34 80.69 57,389 Design MT6-04PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.52 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 36.52 0.00 0.00 329.93 12/6/2018 9: 56.47AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Definitive Survey Report W E Company: ConocoPhillips(Alaska) Inc.-WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Site: GMT1 Lookout Pad MD Reference: Well: MT6-04 North Reference: Wellbore: MTB-04PB1 Survey Calculation Method: Design: C1-Wp01 Database: Well MT6-04 ACTUAL MT6-04 @ 88.72usft (Doyonl9) ACTUAL MT6-04 @ 88.72usft (Doyonl9) True Minimum Curvature EDT 14 Alaska Production Survey Program Date From TO Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 115.00 613.00 1. Gyrodata GyroSS 16" (MT6-04PBl) GYD-CT-DMS Gyrodata cont.drillpipe m1s 10/23/2018 10/23/2018 678.41 772.43 2. BHGE MWD+IFR+MSA 16"(MT6-04P MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/23/2018 10/23/2018 866.00 866.00 3. Gyrodata GyroSS 16" (MT6-04PB7) GYD-CT-DMS Gyrodata cont.drillpipe mis 10/23/2018 10/23/2018 961.62 1,992.23 4. BHGE MWD OTK+IFR+MSA 1611(MT6 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/23/2018 10/30/2018 2,086.78 7,689.92 5. BHGE MWD ATK+IFR+MSA 121/4"(M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/27/2018 10/29/2018 7,770.30 9,373.94 6. BHGE MWD+IFR+MSA 6 3/4" (MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/2/2018 11/4/2018 I 9,447.06 12,381.03 7. BHGE MWD+IFR+MSA43/411(MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/4/2018 11/12/2018 Survey I I Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section 1. (usft) (°) (°) (usft) (usft) (usft) (usft) (°M00') Survey Tool Name y Annotation (ft) (ft) (ft) 3652 0.00 0.00 36.52 52.20 0.00 0.00 5,945,55061 317,078.75 0.00 0.00 UNDEFINED 115.00 0.37 234.14 115.00 -2628 -0.15 -0.21 5,945,550.47 317,078.54 0.47 -0.03 GYD-CT-DMS(1) 200.00 0.41 240.34 200.00 -11128 -0.46 -0.69 5,945,550.17 317,078.05 0.07 -0.05 GYD-CT-DMS(1) 1 265.00 0.71 242.90 264.99 -176.27 -0.76 -1.25 5,945,549.88 317,077.48 0.46 -0.03 GYD-CT-DMS(1) j 365.00 1.18 230.77 364.98 -276.26 -1.69 -2.60 5,945,548.98 317,076.11 0.51 -0.16 GYD-CT-DMS(1) 450.00 1.79 22091 449.95 -361.23 -3.25 1.15 5,945,547.46 317,074.53 0.78 -0.73 GYD-CT-DMS(1) 547.00 2.03 226.61 546.90 458.18 -5.57 5.39 5,945,545.19 317,072.23 0.32 -1.62 GYD-CT-DMS(1) 613.00 1.97 224.78 612.86 -524.14 -7.18 -8.04 5,945,543.63 317,070.54 0.13 -2.19 GYD-CT-DMS(1) 67841 1.97 22420 678.23 -589.51 -8.79 -9.61 5,945,542.06 317,068.93 0.03 -2.79 MWD+11FR-AK-CAZ-SC(2) 3 772.43 2.47 214.84 772.18 583.46 -1161 -11.90 5,945,539.30 317,066.58 0.66 -1,06 MWD+IFR-AK-CAZSC(2) 866.00 3.05 210.99 865.64 -776.92 -15.40 -14.33 5,945,535.57 317,064.05 0.65 5.14 GYD-CT-DMS (3) 96162 4.10 211.39 961.07 -872.35 -20.50 -17.42 5,945,530.55 317,060.84 1.10 -9.01 MWD+IFR-AK-CAZ-SC (4) ( 1,055.36 5.71 21679 1,054.47 -965.75 -27.09 -21.96 5,945,524.06 317,056.14 1.78 -12.44 MWD+IFR-AK-CAZ-SC(4) 1,149.17 7.51 216.55 1,147.65 -1,058.93 -35.75 -28.41 5,945,515.56 317,049.49 t.92 -16.71 MWD+IFR-AK-CAZ-SC(4) 1,243.86 9.18 220.50 1,241.33 -1,152.61 -06.47 -37.00 5,945,505.06 317,04064 1.86 -21.68 MWD+IFR-AK-CAZ-SC(4) pip I 1,338.33 10.99 219.01 1,334.34 -1,245.62 -59.20 -0].56 5,945,492.59 317,D29]] 1.94 -27.40 MWDgFR-AK-CAZ-SC (4) I p 12/6/2018 9:56.47AM Page 3 COMPASS 5000.14 Build 850 ConocoPhilli s p ConocoPhillips Definitive Survey Report RAUGNES 0 _- - Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well MT6-04 Project: Western North Slope TVD Reference: ACTUAL MT6-04 @ 88.72ush (Doyon19) Site: GMT1 Lookout Pad MD Reference: ACTUAL MT6-04 @ 88.72usft (Doyonl9) Well: MT6-04 North Reference: True Wellbore: MT6-04PB1 Survey Calculation Method: Minimum Curvature Design: C1-wp01 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS +N1 -S -E/-W Map Map DLS Vertical lush) (°) V) (usR) (usft) (usft) (usR) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 1,432.28 11.85 21567 1426.43 -1,337.71 -73.99 -58.82 5,945,478.07 317,016.15 115 -34.56 MWD+IFR-AK-CAZ-SC(4) 1,526.21 11.53 214.67 1,518.41 -1,429.69 -89.55 59.79 5,945,462.79 317,006.82 0.40 -02.53 MWD+IFR-AK-CA7SC(4) 1,619.87 11.03 215.29 1,610.26 -1,521.54 -104.56 50.29 5,945,448.04 316,935.96 0.55 50.26 MWD+IFR-AK-CAZ-SC(4) 1,715.13 10.83 21516 1,703.79 -1,615.07 -119.31 -90.71 5,995,433.54 316,985.18 0.21 -57.81 MWD+IFR-AK-CAZSC(4) 1,808.35 10.76 215.27 1,795.36 -1,706.64 -133.58 -100.77 5,945,419.53 316,974.77 0.08 55.11 MWD+IFR-AK-CAZ-SC(4) 1,902.23 11.34 216.05 1,887.50 -1,798.78 -148.20 -111.27 5,945,405.17 316,963.93 0.64 -72.50 MWD+IFR-AK-CAZSC(4) 1,992.23 11.67 216.76 1,975.70 -1,886.98 -162.64 -121.92 5,945,390.99 316,952.93 0.40 -79,66 MWD+IFR-AK-CAZSC (4) 13-318" x 15" 2,086.78 11.61 213.28 2,068.30 -1,979.58 -178.26 -132.86 5,945,375.64 316,941 61 0.75 .87B!) MND+IFR-AK-CAZSC (5) 2,181.07 12.25 217.17 2,160.56 -2,071.84 -194.16 -144.11 5,945,360D2 316,929.98 1.09 -95.82 MWD+IFR-AK-CAZ-SC(5) 2,275.36 1252 227.08 2,252.66 -2,163.99 -209.09 -157.64 5,945,34542 316,916.09 2.27 -101.96 MWD+IFR-AK-CA7-SC(5) 2,369.68 13.48 23586 2,344.57 -2,255.85 -222.23 -174.23 5,945,332.69 316,899.19 2.33 -105.02 MWD+IFR-AK-CAZ-SC(5) 2,464.53 14.07 237.73 2,43610 -2,347.98 -234.59 -193.13 5,945,320.80 316,880.00 0.78 -106.25 MWD+IFR-AK-CAZSC(5) 2,566.31 14.03 237.80 2,527.67 -2,438.95 -246.73 -212.39 5,945,309.13 316,860.45 0.05 -107.11 MWD+1FR-AK-CAZSC(5) 2,653.30 14.00 237.25 2,61963 -2,531.11 -259.08 -231.79 5,945,297.25 316,840.75 0.14 -108.07 MWD+IFR-AK-CAZSC(5) 2,747.59 13.96 236.37 2,711.33 -2,622.61 -271.55 -250.86 5,945,28525 316,821.39 0.23 -109.31 MWD+IFR-AK-CAZSC(5) 2,842.33 14.02 235.66 2,803.26 -2,714.54 -284.35 -269.85 5,945,272.91 316,802.10 0.19 -110.87 MWD+IFR-AK-CAZ-SC(5) 2,935.57 14.52 234.46 2,893.62 -2,804.90 -297.52 -288.68 5,945,260.21 316,782.95 0.62 -112.83 MWD+IFR-AK-CAZ-SC(5) 3,029.87 14.58 234.70 2,984.90 -2,896.18 -311.25 -307.99 5,945,246.95 316,763.31 0.09 -115.04 MWD+IFR-AK-CAZ-SC(5) 3,123.61 14.55 234.90 3,075.63 -2,986.91 524.84 527.25 5,945,233.84 316,743.73 0.06 -117.15 MWD+IFR-AK-CAZSC(5) 3,218.35 14.57 235.35 3,167.32 -3,078.60 -338.46 346.79 5,945,220.70 316,723.87 0.12 -119.14 MWD+IFR-AK-CAZSC(5) 3,312.86 14.56 235.04 3,258.80 -3,170.08 -352.02 -366.31 5,945,207.61 316,704.03 0.08 -121.10 MND+IFR-AK-CAZSC(5) 3,406.03 14.59 23546 3,348.97 3,260.25 -365.39 -385.57 5,945,19412 316,684.45 0.12 -123.02 MND+IFR-AK-CAZSC(5) 3,499.83 14.31 236.19 3,439.80 3,351.08 -378.53 404.94 5,945,18204 316,664.77 0.36 -124.69 MND+IFR-AK-CAZ-SC(5) 3,594.52 13.34 240.0 3,531.75 -3,443.03 390.51 124.12 5,945,170.54 316,645.30 1.40 -125.44 MWD+IFR-AK-CAZ-SC (5) 3,687.93 12.31 244.78 3,622.83 -3,534.11 -400.14 -442.46 5,945,161.36 316,626.73 1.58 -124.59 MWD+IFR-AK-CAZ-SC (5) 3,781.69 12.25 248.08 3,714.45 -3,625.73 408.11 -060.73 5,945,15383 316,608.27 075 -122.33 MWD+IFR-AK-CAZ-SC(5) 3,876.01 1225 246.90 3,806.62 -3,717.90 415.77 -079.22 5,945,146.62 316,589.61 0.27 -119.70 MWD+IFR-AK-CAZ-SC(5) 3,970.27 12.24 24582 3,898.73 -3,810.01 423.79 497.53 5,945,139.05 316,571.11 0.24 -117.46 MWD+IFR-AK-CAZSC(5) 4,063.79 12.25 244.41 3,990.13 -3,90141 -432.14 515.52 5,945,131.15 316,552.92 0.32 -11567 MWD+IFR-AK-CAZSC(5) 4,159.06 12.22 242.78 4,083.23 3,994.51 441.11 -53361 5,945,12261 316,534.63 0.36 -114.38 MWD+IFR-AK-CAZ-SC(5) 4,253.52 1209 24182 4,175.57 -,086.85 -450.36 -551.22 5,945,113.60 316,516.80 0.25 -113.55 MWD+IFR-AK-CAZ-SC(5) 121612018 9:56.47AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-04 Wellbore: MT6-04PB1 Design: C1-wp01 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-04 ACTUAL MT6-04 @ 88.72usft (Doyonl9) ACTUAL MT6-04 @ 88.72usft (Doyonl9) True Minimum Curvature EDT 14 Alaska Production BA ER F�WHES - Survey i Map Map Vertical MD Inc Azf TVD ND55 +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name y, Annotation (ft) (ft) (ft) 4,345.69 12.07 241.67 4,265.70 -4,176.98 -45949 -568.21 5,945,10508 316,499.59 0.04 -112.94 MWD+IFR.AK-GAZSC(5) 4,438.41 12.02 241.74 4,356.38 4.267.66 -468.65 -585.24 5,945,096.33 316,482.34 0.06 -112.34 MWD+IFR-AK-CAZSC(5) 4,531.86 12.05 240.75 4,447.78 4359.06 478.03 602.33 5,945,087.37 316,465.03 0.22 -111.90 MWD+IFRAK-CAZSC(5) { 4,625.64 12.04 240.39 4,53949 4,450.77 487.65 619.37 5,945,078.18 316,447.76 0.08 -111.68 MWD+1FR-AK-CAZ-SC(5) 4,720.55 1206. 241.05 4,632.31 4,543.59 497.34 636.65 5,945,068.91 316,430.25 0.15 -111.40 MWD+IFR-AK-CAZ-SC(5) 4,814.25 12.03 243.25 4,723.95 4,635.23 -506.47 653.94 5,945,06020 316,412.75 049 -110.65 MWD+IFR-AK-CAZ-SC(5) 4,909.11 1200 243.81 4,816.73 4,728.01 -515.27 671.61 5,945,051.83 316,394.87 0.13 -109.41 MWD+IFR-AK-CAZ-SC(5) 5,00367 12.05 243.09 4,909.22 4,820.50 -524.08 689.24 5,945,04345 316,37204 0.17 -108.20 MWD+IFR-AK-CAZ-SC(5) 5,097.23 12.03 242.02 5,000.72 4,91200 -533.07 -706.56 5,945,034.88 316,359.51 0.24 -107.31 MWD+IFR-AK-CAZ-SC(5) 5,191.37 11.97 241.43 5,092.80 5,004.08 -542.35 -723.79 5,945,026.03 316,342.05 0.15 -106.69 MWD+IFR-AK-CAZ-SC(5) 5,285.53 11.97 240.65 5,184.91 5,096.19 -551.80 -740.88 5,945,017.00 316,324.74 0.17 -106.31 MWD+1FR-AK-CAZ-SC(5) 5,379.54 12.22 24016 5,276.84 5,188.12 -55144 -758.06 5,945,007.78 316,30.33 027 -106.05 MWD+IFR-AK-CAZ-SC(5) 3 5,47365 12.26 241.81 5,368.81 -5,280.09 -571.03 -]]5.56 5,944,998.62 316,289.61 0.24 -105.57 MWD+IFR-AK-CAZ-SC(5) 5,587.91 72.20 243.09 5,460.93 5,372.27 -580.26 -79326 5,944,98982 316,271.69 0.29 -104.70 MWD+IFR-AK-CAZ-SC (5) 5,663.08 12.20 242.96 5,553.95 -5,465.23 589.38 -811.18 5,94,981.14 316,253.55 0.03 -103.61 MWD+IFR-AK-CAZ-SC (5) 5,757.01 12.18 243.52 5,645.76 -5,557.04 598.31 -828.89 5,944,972.64 316,235.63 0.13 -102.47 MW1D+IFR-AK-CAZ-SC(5) 5,851.40 1224 243.35 5,738.02 -5,649.30 -60724 -846.75 5,944,964.15 316,217.56 007 -101.25 MWD+IFR-AK-CAZ-SC(5) 5,943.11 12.17 244.35 5,827.65 -5,738.93 515.79 664.15 5,94,956.03 316,199.96 0.24 -99.92 MWD+IFR-AK-CAZ-SC (5) 6,038.04 12.77 247.72 5,920.45 -5,831.73 -62391 682.43 5,944,948.35 316,181.49 0.75 -97.79 MWD+IFR-AK-CAZ-SC(5) 6,130.34 12.16 260.78 6,010.70 -5,921.98 629.16 -901.03 5,944,943.56 316,162.77 2.98 -93.01 MWD+IFR-AK-CAZ-SC(5) I 6,224.42 12.34 274.13 6,102.65 -6,013.93 530.02 -920.84 5,94,943.17 316,142.94 3.01 -83.83 MWD+IFR-AK-CAZ-SC(5) 6,318.56 1299 281.73 6,194.51 5,105.79 62215 -941.24 5,94,946.54 316,122.62 1.90 -71.13 MWD+IFR-AK-CAZ-SC(5) 6,413.49 1370 289.29 6,286.88 6,198.16 521.26 562.30 5,944,952.94 316,101.71 1.98 55.48 MWD+IFR-AK-CAZ-SC(5) 6,507.89 1504 29467 6,378.33 6,289.61 512.46 -983.98 5,94,962.27 316=25 2.00 -37.00 MWD+IFR-AK-CAZSC(5) ' 6,60277 17.25 302.81 6,46947 6,360.75 -599.69 -1,007.00 5,944,975.58 316,057.55 3.33 -1442 MWD+IFR-AK-CAZ-SC(5) !I 6,696.60 19.39 312.70 6,558.57 6,469.85 -581.59 -1,030.14 5,94,994.25 316,039.85 4.01 12.85 MWD+IFR-AK-CAZ-SC (5) 6,791.00 21.85 317.30 6,646.92 5,558.20 55804 -1,053.58 5,945,018.35 316,012.00 3.12 44.96 MWD+IFR-AK-CAZ-SC(5) 6,889.29 24.55 320.32 6,732.66 5,64394 530.36 -1,0T7.73 5,945,046.61 315,988.53 3.16 81.02 M1JVD+IFR-AK-CAZ-SC(5) I 6,977.65 27.37 321.55 6,816.59 5,727.87 498.62 -1,10346 5,945,078.96 315,963.57 3.07 121.38 MWD+IFR-AK-CAZ-SC(5) 7,072.23 30.40 324.03 6,899.40 5,810.68 462.22 -1,131.05 5,945,116.02 315,936,89 3.44 166.71 MWD+IFR-AK-CAZ-SC 15) 7,166.50 32.90 326.98 6,97964 5,89092 -421.44 -1,159.01 5,945,157.47 315,909.92 3.12 216.01 MWD+IFR-AK-GA -SC(5) 121612018 9:56:47AM Page 6 COMPASS 5000.14 Build 850 16: ConocoPhillips BA ER WHES COnOcoMillips Definitive Survey Report "` Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-04 Wellbore: MT6-04PB1 Design: Cl-wp01 Survey Local Co-ordinate Reference: Well MT6-04 TVD Reference: ACTUAL MT6-04 @ 88.72usft (Doyonl9) MD Reference: ACTUAL MT6-04 @ 88.72usft (Doyonl9) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production MD Inc An TVD TVDSS +N/ -S +E/ -W Map Map Vertical (usft) (') V) (usft) (usft) (usft) (usft) Northing Easting X00 Section Survey Tool Name (ft) (ft) ( ) (ft) 7,260.87 36.04 328.98 ],057.44 8968.72 -376.15 -1,187.30 5,945,203.43 315,882.75 3.54 269.38 MWD+IFR-AK-CAZSC(5) 7,355.23 38.89 331.11 7,132.33 -7,043.61 526.41 -1,215.92 5,945,253.84 315,855.34 3.32 326.77 1VlWD+IFR-AKCAZSC(5) 7,449.80 41.56 334.16 7,204.54 -7,115.82 -272.17 -1,243.94 5,945,308.74 315,828.65 3.51 387.75 MWD+IFR-AKCAZSC(5) 7,543.71 44.22 335.87 7,273.34 -7,184.62 -214.24 -1,270.91 5,945,367.31 315,803.09 3.09 451.40 MM+IFR-AKCAZSC(5) 7,638.78 47.26 336.83 7,339.68 -7250.96 -151.87 -1,298.21 5,945,43032 315,777.32 328 519.05 MWD+IFR-AK-CAZ-SC(5) 7,689.92 48.29 336.90 7,374.05 -7,285.33 -117.05 -1,313.09 5,945,465.49 315,76329 2.02 556.64 MWD+IFR-AK-CAZ-SC(5) 7,770.30 47.83 33760 7,427.77 -7,339.05 61.91 -1,336.21 5,945,521,17 315,741.52 0.86 615.94 MM+IFR-AK-CAZ-SC(6) 7,864.60 51.65 338.68 7,488.64 -7,399.92 4.80 -1,362.95 5,945,588.51 315,716.41 4.15 687.07 MWD+IFR-AKCAZSC(6) 7,958.04 54.68 338.82 7,544.71 -7,455.99 74.57 -0,390.08 5,945,658.91 315,690.98 3.24 761.04 MWD+IFR-AKCAZSC(6) 8,052.24 56.96 339.04 7,59763 -7,508.91 147.28 -1,418.09 5,945,732.28 315,664.74 2.43 838.01 MWD+IFR-AK-CA -SC(6) 8,14695 59.54 338.85 7,647,46 -7,558.74 222.44 -1,447.03 5,945,808.11 315,637.65 2.73 917.54 MWD+IFR-AK-CA7-SC(6) 8,241.88 61.70 338.88 7,694.03 -7,605.31 299.59 -1,476.85 5,945,885.96 315,609.71 2.28 999.26 MWD+IFR-AK-CAZ-SC (6) 8,335.28 64.37 33878 7,736.38 -7,647.66 377.21 -1,506.91 5,945,964.28 315,581.54 2.86 1,081.49 MWD+IFR-AK-CAZ-SC(6) 8,428.76 66.63 338.66 7,775.14 -7,686.42 458.47 -1,537.78 5,946,044.26 315,552.61 2.42 1,165.55 MWD+IFR-AK-CAZSC(6) 8,523.56 69.12 338.74 7,810.85 -7,722.13 538.30 -1,569.69 5,946,126.83 315,522.70 2.63 1,252.35 MWD+IFR-AKCAZSC(6) 8,618.12 71.31 339.42 7,842.85 -7,754.13 621.39 -1,601.44 5,946,210.67 315,492.97 2.41 1,340.17 MWD+IFR-AK-CAZSC(6) 8,713.09 73.18 339.61 7,871.81 -7,783.09 706.11 -1,633.10 5,946,296.13 315,463.39 1.98 1,429.35 MWD+IFR-AK-CAZ-SC(6) 8,80235 75.13 339.79 7,897.54 -7,808.82 791.16 -1,664.55 5,946,381.90 315,434.01 2.08 1,518.71 MWD+IFR-AK-CAZ-SC (6) 8,901.46 7].55 339.91 7,919.77 -7,831.05 877.00 -1,696.05 5,946,468.48 315,404.60 2.57 1,608.79 MWD+IFR-AK-CAZSC(6) 8,996.03 79.84 340.10 7,938.31 -7,849.59 96,1A4 -1,727.76 5,946,556.36 315,375.02 2.43 1,700.09 MWD+IFR-AK-CAZSC(6) 9,090.78 79.88 340.41 7,954.99 -7,866.27 1,051.93 -1,759.27 5,946,644.88 315,345.66 0.32 1,791.85 MWD+IFR-AK-CAZSC(6) 9,18574 81.84 340.45 7,970.07 -7,881.35 1,140.26 -1,79067 5,946,73395 315,316.41 2.06 1,884.03 MWD+IFR-AK-CAZSC(6) 9,279.43 83.91 340.89 7,961.69 -7,892.97 1,227.98 -1,821.44 5,946,822.38 315,287.78 226 1,975.36 MWD+IFR-AK-CAZ-SC(6) 9,373.94 83.82 340.78 7,991.79 -7,903.07 1,31674 -1,852.29 5,946,911.86 315,259.10 0.15 2,067.63 MWD+IFR-AK-CAZ-SC (6) 9,447.06 84.05 Most) 7,999.52 -7,910.80 1,385.36 -1,876.33 5,946,981.04 315,236.73 0.40 2,139.06 MWD+IFR-AK-CAZ-SC(7) 9,485.95 84.76 340.51 8,003.31 -7,914.59 1,421.86 -1,889.22 5,947,017,84 315,224.74 1.84 2,177.10 MWD+IFR-AK-CAZ-SC(7) 9,523.46 84.48 341.34 8,006.83 -7,918.11 1,457.15 -1,901.42 5,947,053.42 315,213.39 2.33 2,213.76 MWD+IFR-AK-CAZSC(7) 9,618.94 84.51 34099 8,015.98 -7,927.26 1,547.10 -1,932.11 5,947,144.08 315,184.91 0.37 2,306.98 MW0+1FR-AKCAZSC(7) 9,714.08 84.52 342.64 8,025.08 -7,936.36 1,637.07 -1,961.66 5,947,234.74 315,157.55 1.73 2,39965 MM+IFR-AKCAZSC(7) 9,803.26 87.67 343.16 8,031.56 -7,942.84 1727.82 -1,989.58 5,947,326.13 315,131.84 3.35 2,492.18 MWD+IFR-AK-CAZ-SG(7) 9,903.82 90.89 342.96 8,032.]5 -7,944.03 1,818.26 -2,017.12 5,947,41721 315,106.50 3.41 2,584.24 MWD+1FR-AK-CAZ-SC (7) Annotation 9-5/8" x 12-1/4" 7" x 8-3/4" 121612018 9: 56.47AM Page 6 COMPASS 5000.14 Build 85D ✓ ConocoPhillips BA�cER ConocoPhilll ucHEps IK Definitive Survey Report '.'Company: ConomPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: GMT7 Lookout Pad Well: MT6-04 Wellbore: MT6-04P81 Design: Ct-wp01 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-04 ACTUAL MT6-04 @ 88.72usft (Doyonl9) ACTUAL MT6-04 @ 88.72usft (Doyonl9) True Minimum Curvature EDT 14 Alaska Production MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name Annotation (R) (ft) (R) 9,998.83 92 92.09 34 343.49 8,030.29 -7,941.57 1,90920 -2,044.54 5,947508.77 315,081.31 1.37 2,676.67 MWD+IFR-AK-CA7-SC (7) 10,093.68 92.08 343.74 8,02684 -7,938.12 2,000.13 -2,071.27 5,947,60033 315,055.79 0.26 2,768.77 MWD+IFR-AK-CAZ-SC(7) 10,189.70 90.44 344.24 8,024.73 -7,936.01 2,092.40 -2,097.75 5,947,693.21 315,032.56 1.79 2,861.89 MWD+1FR-AK-CAZ-SC(7) 10,285.19 WW2 343.93 8,024.02 -7,935.30 2,184.23 -2,123.93 5,947,785.64 315,008.62 0.33 2,954.48 MWD+IFR-AK-CAZSC(7) 10,379.78 90.33 343.71 8,023.40 -7,93468 2,275.07 -2,15029 5,947,87709 314,984.48 0.25 3,046.30 MWD+IFR-AK-CAZSC(7) 10,474.68 89.77 342.17 8,023.31 -7,934.59 2,365.79 -2,178.13 5,947,96645 314,958.85 1.73 3,13816 MWD+IFR-AK-CAZ-SC(7) 10,568.93 89.74 341.65 8,023.72 -7,935.00 2,455.38 -2,207.40 5,948,058.72 314,931.77 0.55 3,230.96 MWD+IFR-AK-CAZSC(7) 10,665.14 89.50 340.06 8,024.36 -7,935.64 2,546.27 -2,238.95 5,948,150.34 314,902.44 1.67 3,325.42 MWD+1FR-AK-CAZSC(7) 10,760.24 89.43 340.17 8,025.24 -7,936.52 2,635.69 -2,271.29 5,948,240.52 314,872.28 0.14 3,419.01 MWD+1FR-AK-CAZSC(7) 10,855.18 90.48 340.81 8,025.32 -7,936.60 2,725.18 -2,303.00 5,948,33074 314,84215 1.30 3,512.34 MWD+IFR-AK-CAZSC(7) 10,950.86 87.64 340.64 8,026.89 -7,938.17 2,815.48 -2,334.58 5,948,421.77 314,813.38 2.97 3,606.31 MWD+1FR-AK-CAZ-SC(7) 11,046.40 87.00 34166 8,031.35 -7,942.63 2,905.79 -2,365.41 5,948,512.80 314,784.75 1.26 3,699.92 MWD+IFR-AK-CAZSC(7) 11,141.56 87.04 342.47 8,036.30 -7,947.58 2,996.20 -2,394.67 5,948,603.90 314,757,69 0.85 3,792.83 MWD+IFR-AK-CAZSC(7) 11,236.78 88.52 342.93 8,039.99 -7,951.27 3,087.04 -2,422.97 5,948,695.39 314,731.62 1.63 3,885.62 MWD+IFR-AK-CAZSC(7) 11,332.20 88.58 343.34 8,042.40 -7,953.68 3,178.33 -2,450.64 5,948,787.32 314,706.17 0.43 3,978.48 MWD+IFR-AK-CAZ-SC(7) 11,426.97 8867 343.46 8,044.68 -7,955.96 3,269.13 -2,477.71 5,948,878.74 314,681.32 0.16 4,070.62 MWD+IFR-AK-CAZ-SC(7) 11,522.85 90.61 342.97 8,045.28 -7,956.56 3,360.91 -2,505.39 5,948,971.17 314,655.87 2.09 4,163.93 MWD+IFR-AK-CAZSC(7) 11,618.47 92.58 341.86 8,042.62 4,953.90 3,452.02 -2,534.27 5,949,062.94 314,629.22 2.36 4,257.25 MWD+1FR-AK-CAZSC(7) 11,713.36 93.09 338.28 8,037.93 -7,949.21 3,541.11 -2,566.57 5,949,152.78 314,599.09 3.81 4,350.52 MWD+IFR-AK-CAZ-SC(7) 11,808.42 93.03 338.06 8,032.85 -7,944.13 3,629.23 -2,601.87 5,949,241.72 314,555.95 0.24 4,444.47 MWD+IFR-AK-CAZ-SC(7) 11,904.34 93.06 337.55 8,027.76 -7,939.04 3,717.91 -2,638.05 5,949,331.26 314,531.93 0.53 4,539.35 MWD+1FR-AK-CAZ-SC (7) 11,999.20 93.12 33766 8,022.64 -7,933.92 3,805.49 -2,674.15 5,949,419.68 314,497.97 0.12 4,633.22 MWD+IFR-AK-CAZSC(7) 12,093.61 94.01 338.07 8,016.77 -7,928.05 3,892.77 -2,70966 5,949,507.79 314,464.59 1.04 4,726.55 MWD+IFR-AK-CAZSC(7) 12,190.30 93.95 338.13 8,010.06 -7,921.34 3,982.26 -2,745.64 5,949,598.13 314,430.80 0.09 4,822.03 MWD+IFR-AK-CAZSC(7) 12,286A6 93.95 338.28 8,003.44 -7,914.72 4,071.34 -2,781.25 5,949,688.03 314,397.36 0.16 4,916.96 MWD+IFR-AK-CAZ-SC(7) 12,38103 95.50 338.12 7935.65 -7,906.93 4,158.84 -2,816.25 5,949,776.36 314,364.50 1.65 5,01022 MWD+IFR-AK-CAZ-SC(7) 12,480.00 95.50 338.12 7,986.16 -7,89744 4,25026 -2,852.97 5,949,868.63 314,330.02 0.00 5,107.73 PROJECTED WTD 41/7'%6-1/8" 1216/2018 9: 56 47A Page 7 COMPASS 5000.14 Build a50 PTo R i8 -lost Loepp, Victoria T (DOA) From: Marushack, Andy J <Andy.J.Marushack@conocophillips.com> Sent: Monday, November 19, 2018 12:44 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: MT6-04 7" liner SCMT Log Attachments: MT6-04 Intermediate 2 Cement Review.pdf Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria, I believe the attached will be more to your liking. We currently only have the field logs to go off of, but should have the SLB town interpretations today or tomorrow. I can update this once those are in. I apologies for the confusion and will be sure to pass this on to the other engineers so wells will have better consistency on MT6. Please let me know if you need anything else. Sincerely, Andy From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Monday, November 19, 2018 10:32 AM To: Marushack, Andy J <Andy.J.Marushack@conocophillips.com> Subject: RE: [EXTERNAL]RE: MT6-04 7" liner SCMT Log Please provide the cement job summary for the intermediate cement. The WBS is not readable. What was the LOT? Thanx, Victoria From: Marushack, Andy J <Andy.J.Marushack@conocophillips.com> Sent: Monday, November 19, 2018 8:22 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: RE: [EXTERNAL]RE: MT6-04 7" liner SCMT Log Hello Victoria, Sorry about that. Here is the file in PDF form. If it does not match what you send me, I will chase it down. Sincerely, Andy From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Monday, November 19, 2018 8:19 AM To: Marushack, Andy 1 <Andy.J.Marushack@conocophillips.com> Subject: [EXTERNAL]RE: MT6-04 7" liner SCMT Log Andy, I cannot read a zip file. Please send a PDF of relevant sections. I am forwarding an example of what is expected for the intermediate cement review(KRU 35-612). Please submit in this format. Thanx, Victoria From: Marushack, Andy <Andy.J.Marushack@conocophillips.com> Sent: Monday, November 19, 2018 7:57 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: MT6-04 7" liner SCMT Log Good Morning Victoria, Please find attached the SCMT logs for the 7" cement job on MT6-04. Top of cement was called at 7708' MD. Sincerely, Andy A JOE WNS SVC WELLNAME MT6°04 WELLBORE MT6-04 COnoc6P 11111p5 i. Weft Attributes Max Mgle SMD TD Alaska. Inc. FkL Nnme Weave KNRV1 1WRpn SY4s LMI') Ma1BKa) ..mm' LOOKOUT 5010320D5m SVC 930.0 11,618.86 14,790.0 Cemme,K Kuehl Gtle MUMIM FM en .64 Rq Rebee Bcm 36.52 HORIMWAL- MTs,11)142018 Casing Strings Cairo BeecBevee GG M) all" TwOU(B) Bel Bagh lnxe) etl bautlVBt_. IL. Gra4F TwT. No 20'.rWudor 20 19.12 38.5 115.0 115.0 94,00 H40 Welled Ceelw Dea,:4plFn GO M) IBlin) iw MiBl elVaau, MKal Be seta, (Iver- WBVn O.. l+re4e Tw TnraE Sullece 133/8 12.40 36.1 2.046.6 2.028.9 68.00 L40 lWs (N( B) rota (9 (ft KB Vertical scifBlnelk (xWeQ CUYq dxrlptlon W1.0 Ie llnl Tw 91KB1 setpapq lMtal Bk PeFBi fTWL_vMp, 11...GMe ToPTn,a4 tiBeimedimell 998 8.84 34.2 ],)19.9 ],394.0 40.00 L40 TXP w m Cairo Gamlplbn GBM) IB MI Tw IBKBI BetBMn MKeI 9a Bgm/TvvF.. WBLen(110aee TV". Tim4ark Siring ] 628 32.1 7,564.3 ].288.0 26.00 M TSH Blue Cairo Bamletim OpIW IB INI Twflllml BMBepn iKKBl Bei Barn llvBl... wVlen a.. BIW Tw Tnatl _ Gne, J 8.18 ],518.1 9.4]fi.0 6.002.4 29.00 TN•110 H563 Des:Cmp Liner Details Nom4ylW .. m ester .. Calmest a T"MB) iw RVB11RKa1 Tw1wr) mmBCun Ilnl 1,546.1 ], .0 Pecker StZXP LiIVerlDp pecker (21.35 O1 ]. 6.190 Bpei Dept MD.X& 115.OWB;B Dale:2)1] ' 1--&-ff NlPple(RS) -RS' PR ff Seel Nipple 6.190 T,314 4628 Hanger ' P1eRLer% Helper 6.210 201 ssss DBB:4Uffa+ Caslry Caec,lptlon BB MI Ip lkll Tw (BKaj sNOegn mKel ort DMn(TVM.. WIM1an O... elle Twinresl w Cednp" i liner 412 3.98 9,302.6 14,)65.0 8,002.1 12.60 LA0 TXP Conti' , .38N0. MD:98 2,040.6e; We; Dme:1a25 Uner Details Tw IBKB) Tw f1YB11BKe1 rwlMn Kem Da Cun ra 9,334.0 ),98). .68 Hanger NNIbrA HO 1 nx Pin a20D Tubing Strings 2016 + Timme eesys^n BnFp Ma... p11I11 Tw IB101 3el GeNn M. BR BCIn (IVBI I.. W10MN GrW Tw Cwnalbn Tubing-ProGudion 412 3.98 28.] 9,314.9 ),985.5 1260 LA0 TNYe _ Completion Details Tw M'D) Twlrci Rgnlnal Tw (WO)IBNR) (') Ibm Bez Com 10 gn) ---2T7 n.7 Hl,s,, WC42'TG-ft HengetHydtll 3.958 DeelMeim 1513.0 1,996.1 1 Nipple -X NPPLErt NDI G.412',X,3.813'. SH blue 3.813 elate Caerg CemeSt 9.6 ),84.8 )1.93 NiPpie-XN NIPPLE,IANDIN .4UC, 813°XN. TSH ewmR PW9 J abdv InveBea p rr @a.sso .r •� Depin 6 ), .5 63.89 N�C Lb.lbr LCCetwN p5. 11 00 3.5 r MOB,T20. ._._ _.... __ x-7.719.9 9. 7, .6 8389 Beat/ Assemblyeel y 3.950 flan Oate:1111/ 2018 Other In Hob (Wirellne retrievable plugs, valves, pumps, fish, etc.) Tw (BKB) (BKB) r) Be Com Run Bax N19n1 and Rod 11/1)201 0. __._ _-._ B,fi500 ],8529 1.94 NHC PIu9 it/1J/201 1. B IMrtorallons a slots snp rofts,a) Bte's") I 141wem e Cement DlW MD:7,708. iw OBcar Bnn lnNBl (BKBI BBiel u,4xtllone Mx 1 type can 1474D .] .d 1V1 1 R P Mandrel Inserts ".4740 WB; si Dodello s 2018 N rw RVD) vYw Use IbIBYe TAa Run gn) W) wble Cpm iw iBKBI MKBI tieke MMeI OD(p) Sem,TyM TA's,R 1 u 3.4T1.p 3.417.6 Comm 1 LIFE Omm b 1111) 18 _ y ------ - 2 a . 7,806.8 Cam. KBG L T OVB K /92018 Open El 0 Y � O U c m LL O N U O E E N m C - Q H F 0 O L c > O F d C L N L L C EEW N w c ��I��N����11111111 E -L n deo='a a� m + o 0 o N E O� o E O � � Y m r N O o O G a Y ' LL N cn � N O LL co O N r Q d� O J a C r j Y U. O i .O t0 W C 001 fd d Q 1- C + r L N L O y v O O N 2 LL N L" -aa a. m,.2 .a,e4 W a D a �.0 NlOO « N of O W Y W J U O �I W N CD i CL Z J O C ti W =CL y O ro D O a C. (1) O E Cl) Z O ,,, a aUJ ' a' U ° o CL T n t Y LL L N LL \ C N li U LL O 1� L L N LL C - `N (9 C: .. W d F e O = ei a � aC U � E R N ♦- N Y Z C fn a — = d v 3 - 0` z 0 ' N U c m LL O U O Go aJ J J a a C H F n Obi a 3 t N O d C L N L L EEW N w c ��I��N����11111111 E -L n deo='a a� m + o 0 o N E O� o u0 W O Kto m r N m v m O G Y ' LL cn � N O LL co O N r Q d� O J a C r j Y U. O i .O t0 001 fd d Q 1- C + r L N L O y v O O N m E a-> O X N L" -aa a. m,.2 .a,e4 W fn �.0 NlOO « F -S m 00 of O W Y W J U O �I CD i ' N U c m LL O U O Go aJ J J a a C H F n Obi a 3 t N O d C L N L L EEW N w c U) E -L n deo='a a� m + o 0 o N E O� o u0 W O Kto m r N m v m O G Y ' LL cn � N O LL co O N r Q d� O J a C r j Y U. O i .O t0 001 fd d Q 1- C + r L N L O y v O O N m E a-> O X N L" -aa a. m,.2 .a,e4 W fn �.0 NlOO « F -S m 00 of O W Y W J U O �I CD i I I I I I F I I I I I IF+++ -I I 1+++b o O m O N S N O N aanssaad Cement Detail Report MT6-04 String: Liner Cement Job: DRILLING ORIGINAL, 10/22/2018 07:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Liner Cement 71/6/2016 06:00 11 /612018 08:00 MT6-04 Comment MR) Baker cement swivel & cement line with 5' pup. RIH & tag bottom @ 9,476'. set down 20 k. PU=235k, S/0=175k. Circulate and condition for cement job, stage up from 1.5 to 4.5 bpm, 360 psi ICP, 460 psi FCP. Heaviest mud weight out 11.4 ppg. No signs of packing off. SIMOPS- PJSM on cement job. SLB flood surface lines with water and PT to 4000 psi -good. SLB pumped 30 bbl 11.5 ppg Mud Push @ 3.8 bpm, 450 psi. Drop bottom Dart. Pump 71.6 bbl 15.8 ppg Cement @ 4.8 bpm, 245 psi WHP. Drop Top Dart. SLB kicked out cement with 20.1 bbl water. Rig displace cement with 1676 strokes (168.8 bbl) 112 ppg LSND @ 4.5-3 bpm. Observed Dart #1 latch @ 350 slits, pressure up to 1460 psi, observe Dart #2 latch @ 1035 stks. pressure up to 1480 psi and release. Bumped plugs @ 1676 stks, pressure up from 580 psi FCP to 1100 psi and hold 5 minutes. CIP @ 08:56 his. OWFF while holding pressure, slight drop in annulus. Set liner hanger, pressure up from 1100 psi to 2400 psi, slack off 50k down, Pressure up to 3750 to release running tool. Bleed off pressure. PIU=235k, S/0=175k. Monitor well for flow- static. Check floats, holding. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ttKB) FullRatum7 Vol Cement... Top Plug? Son Plug? Liner Cement 1000' above Shoe 7,708.0 9,476.0 Yes 0.0 Yes Yes Q Pump but (6bllm... IQ Pump Final (bbir... IQ Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (K) Rotated? Pipe RPM (rpm) 5 13 4 580.0 1,100.0 No No I Tagged Depth (11i Tag Method Depth Plug Drilled Out To (rtKB) Drill Out Diameter (in) 6 Comment M/U Baker cement swivel & cement line with 5' pup, RIH & tag bottom @ 9,476', set down 20 k. PU=235k, SI0=175k. Circulate and condition for cement job, stage up from 1.5 to 4.5 bpm, 360 psi ICP, 460 psi FCP. Heaviest mud weight out 11.4 ppg. No signs of packing off. SIMOPS- PJSM on cement job. SLB flood surface lines with water and PT to 4000 psi -good. SLB pumped 30 bbl 11.5 ppg Mud Push @ 3.8 bpm, 450 psi. Drop bottom Dart. Pump 71.6 bbl 15.8 ppg Cement @ 4.8 bpm. 245 psi WHP. Drop Top Dart. SLB kicked out cement with 20.1 bbl water. Rig displace cement with 1676 strokes (168.8 bbl) 11.2 ppg LSND @ 4.5-3 bpm. Observed Dart #1 latch @ 350 elks, pressure up to 1460 psi, observe Dart #2 latch @ 1035 stks, pressure up to 1480 psi and release. Bumped plugs @ 1676 stks, pressure up from 580 psi FCP to 1100 psi and hold 5 minutes. CIP @ 08:56 hrs, OWFF while holding pressure, slight drop in annulus. Set liner hanger, pressure up from 1100 psi to 2400 psi, slack off 50k down. Pressure up to 3750 to release running tool. Bleed off pressure. PIU=235k, S/0=175k. Monitor well for flow- static. Check floats, holding. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimaled Top (Ii Est Bon (HKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 8,476.0 9.476.0 346 G 71.5 Yield (IPlsack) Mia H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.07 15 1 6.00 Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 11/1912018 • 7" Int. 2 Liner • Set at 9,476' MD/ 8,002' TVD • Cement Slurry: • 346 sks 15.8 ppg Class G • Job Comments • Maintained proper mixing parameters • Full returns to surface • Saw good lift pressure • Bumped plugs and Floats Held • Pressure tested 7" liner to 3,500 psi for 30 min • FIT to 12.6 ppg Strong bonding • Cement Evaluation (SCMT) 87! • SLB called TOC at 7708' MD/ 7386' TVD • Good bond signal was seen from 9,070' to 8,120' MD • Particularly good bond at 8,900', 8,790', and 8,370' MD • Cement started to string out from 7,815' to TOC @ 7,780' MD Start of good bond 9070' ConocoPhillips Weekly Progress Report for BLM Text Area Weekly Progress Report 11117/18 Well: MT6-04 Field: Lookout API: 5010320775 Mer Semnge Curve -Well Name (MTS ) M DailyRep n LaSQ4 - Well Name: (MT6 4) Weekly Progress Report for BLM Hole Depth vs. Day I IX4 z 5w 99W 9.R0 5 W2 19M 150.00 FIR., S Igge cm . 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OaC1•I001.1 IOir WD 108.1= 01,411i 9Oi£ W4.111 W 13 µ000C { 111.Y1 Sincerely, Andy 2 Loepp, Victoria T (DOA) From: Marushack, Andy J <Andy.J.Marushack@conocophillips.com> Sent: Sunday, November 11, 2018 3:57 PM To: Loepp, Victoria T (DOA) Subject: Re: [EXTERNAL]Re: MT6-04 Open Hole Sidetrack Follow Up Flag: Follow up Flag Status: Flagged Thank you, and correct, The BHA will not be brought back to surface Sent from my iPhone On Nov 11, 2018, at 3:55 PM, Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> wrote: Andy, Thanx for the update. Approval is granted to proceed as outlined below with the sidetrack. I'm assuming the BHL remains unchanged? Victoria Sent from my iPhone On Nov 11, 2018, at 3:40 PM, Marushack, Andy J <Andy J Marushack@conocophillips.com> wrote: Hello Victoria, Over the past 24 hours on MT6-04 we have drilled deeper in the Alpine C and found poor quality sand/silt. We intend to pull back to -11000' MD where a good dogleg exists and perform an open hole side track to drill higher in the Alpine C and track better pay. We have done this operation multiple times on MT6 and have had good success kicking off. Below is a diagram of our current well path in the C, we will redrill to stay in the middle light sand. <image002.png> Please let me know if you have any questions. Sincerely, Andy 832-S25-8923 P7 -D AIT-10'i- Loepp, !T—/off Loepp, Victoria T (DOA) From: Marushack, Andy J <Andy.J.Marushack@conocophill ips.com> Sent: Wednesday, November 7, 2018 12:23 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: MT6-04 Update (218-108) Attachments: MT6-04 7in Liner TRT Report.pdf Hello Victoria, Please find attached the cement report from Int. 2. Please let me know if you would like anything else. Sincerely, Andy From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, November 7, 2018 11:01 AM To: Marushack, Andy J <Andy.J.Marushack@conocophillips.com> Subject: RE: [EXTERNAL]RE: MT6-04 Update (218-108) Great, thanx Andy, Could you please send a summary of the cement job including lift pressure plots? Thanx, Victoria From: Marushack, Andy J <Andy.J.Marushack@conocophillips.com> Sent: Wednesday, November 7, 2018 10:59 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Rov> Subject: RE: [EXTERNAL]RE: MT6-04 Update (218-108) Hello Victoria, We will have the SCMT data once the production liner is ran. On MT6, if the Int. 2 cement job went well, we have been running the SCMT tool with the production liner and logging the cement once the liner is released on the way out. We will have this data and get it to you around the 15`h if all goes well. Sincerely, Andy From: Loepp, Victoria T (DOA) <victoria.Ioepp@alaska.gov> Sent: Wednesday, November 7, 2018 10:52 AM To: Marushack, Andy J <Ani.J.Marushack@conocophillips.com> Subject: [EXTERNAL]RE: MT6-04 Update (218-108) Andy, Do you have the results of the required CBL on the 7" liner cement? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppCd)alaska.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 or disclosure of such information may violate state or federal low. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victona.Loel,) alaska.ao.v- From: Marushack, Andy J <Andy.J.Marushack@conocophillips.com> Sent: Tuesday, November 6, 2018 10:36 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: FW: MT6-04 Update (218-108) Hello, As of this morning we have landed and cemented the Intermediate 2, 7" liner. The plan forward is to install the 7" spool in the well head, run the 7" tie back to surface, and will be drilling out on Friday. 03i 3 R Report Mart Report Enid Dole Cote General Raman. 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COppr ao.r•Y on to 7 750 DIP lace 10 re.:05:ag LVD FIT to 140 Leg Dr LI area] f7 )i0 CA - 130 PSI: SIC PE lasted l I V., 8 !s 1 E 96' 1 Can n sn] v r,.- 'pm : l" a- h C.., M 7.:s et»ve I:.IN'rre. 11ry:31i I: 00 n.a.:CMZ Iq aS Rrgvd C."c,Mlgnl ne CMu anel]7^[95 b9160 0<• gDofl nSCpE luted n.O+.+E Ica"R;•ra Ca^p on High ore Cnll ahead El16:to TOc•9C5-G: 6C.IS .nJe nclong W:.starts :c9307 Clostenderres^e a.sp to n!PC; F'C S'p CCMb 77W C."D.0 F.0 CA- 110P 1.+ 5Cp: Wall ;101nZ COe:aID:6F_P,RCO Sl6 mlIDler,, nmpple PJC. L, 0:6' I, fb6 `....-.. ".f0'd Na<15 R.g vd Cs -pan High ll COM 11POOM Is l ll RN to run ern R r r bne. to 7 l Girt 5V S caromom] CO Al Cort to n,n ern ea9 q0 CA. 75 Dsl r 8C1PE tell 11 -DI -IE Sincerely, Andy a WWI W6-04 .W4 MT6 1a65LN Nov/06/2018 a.. .a Cona[oMilhi Jae xum6ar WM TIm4 244x 'lark TrB4BM Prwure Pffi Now Rad B/N Bex411V M/B *,1.4 BBL NT 9f6 -VOL BBL "P xeswpe PSI 11/06/2018 04:30:19 1 0.0 7.77 6.1 3.0 300 11/06/2018 04:31:59 3 0.0 7.76 6.1 3.0 327 11/06/2018 04:33:39 4 0.0 7.76 6.1 3.0 336 11/06/2018 04:35:19 3 0.0 7.75 6.1 3.0 331 11/06/2018 04:36:59 2 0.0 7.75 6.1 3.0 345 11/06/2018 04:38:39 3 0.0 7.74 6.1 3.0 328 11/06/2018 04:40:19 1 0.0 7.73 6.1 3.0 334 11/06/2018 04:41:59 4 0.0 7.72 6.1 3.0 330 11/06/2018 04:43:39 1 0.0 7.71 6.1 3.0 329 11/06/2018 04:45:19 3 0.0 7.69 6.1 3.0 344 11/06/2018 04:46:59 1 0.0 7.67 6.1 3.0 343 11/06/2018 04:48:39 3 0.0 7.66 6.1 3.0 381 11/06/2018 04:50:19 3 0.0 7.64 6.1 3.0 374 11/06/2018 04:51:59 -1 0.0 7.63 6.1 3.0 369 11/06/2018 04:53:39 3 0.0 7.61 6.1 3.0 380 11/06/2018 04:55:19 1 0.0 7.59 6.1 3.0 377 11/06/2018 04:56:59 1 0.0 7.57 6.1 3.0 370 11/06/2018 04:58:39 3 0.0 7.56 6.1 3.0 371 11/06/2018 05:00:19 3 0.0 7.54 6.1 3.0 380 11/06/2018 05:01:59 2 0.0 7.52 6.1 3.0 412 11/06/2018 05:03:39 1 0.0 7.51 6.1 3.0 40B 11/06/2018 05:05:19 1 0.0 7.49 6.1 3.0 417 11/06/2018 05:06:59 0 0.0 7.47 6.1 3.0 405 11/06/2018 05:08:39 1 0.0 7.45 6.1 3.0 407 11/06/2018 05:10:19 2 0.0 7.44 6.1 3.0 413 11/06/2018 05:11:59 2 0.0 7.42 6.1 3.0 386 11/06/2018 05:13:39 3 0.0 7.39 6.1 3.0 385 11/06/2018 05:15:19 1 0.0 7.38 6.1 3.0 439 11/06/2018 05:16:59 1 0.0 7.36 6.1 3.0 439 11/06/2018 05:18:39 3 0.0 7.35 6.1 3.0 447 11/06/2018 05:20:19 1 0.0 7.33 6.1 3.0 432 11/0612D18 05:21:59 -2 0.0 7.32 6.1 3.0 436 11/06/2018 05:23:39 0 0.0 7.30 6.1 3.0 437 11/06/2018 05:25:19 1 0.0 7.29 6.1 3.0 440 11/06/2018 05:26:59 1 0.0 7.26 6.1 3.0 433 11/06/2D18 05:28:39 1 0.0 7.26 6.1 3.0 427 11/06/2018 05:30:19 -1 0.0 7.24 6.1 3.0 429 11/06/2018 05:31:59 1 0.0 7.23 6.1 3.0 411 11/06/2018 05:33:39 -1 0.0 7.20 6.1 3.0 418 11/06/2018 05:35:19 2 0.0 7.20 6.1 3.0 431 11/06/2018 05:36:59 3 0.0 7.18 6.1 3.0 441 11/06/2018 05:38:22 2 0.0 7.17 6.1 3.0 426 Reset Total, Vol - 3.04 bbl 11/06/2018 05:38:39 -1 0.0 7.17 0.0 0.0 423 11/06/2018 05:40:19 1 0.0 7.16 O.D 0.0 422 11/06/2018 05:41:59 3 0.0 7.14 0.0 0.0 434 11/06/2018 05:43:39 1 0.0 7.14 0.0 0.0 412 11/06/2018 05:45:19 1 0.0 7.13 0.0 0.0 402 11/06/2018 05:46:59 1 0.0 7.12 0.0 0.0 403 11/06/2018 05:48:39 1 0.0 7.11 0.0 0.0 417 11/06/2018 05:50:19 0 0.0 7.10 0.0 0.0 425 11/06/2018 05:51:59 2 0.0 7.10 0.0 0.0 409 11/06/2018 05:53:39 2 0.0 7.09 0.0 0.0 404 11/06/2018 05:55:19 0 0.0 7.08 0.0 0.0 411 11/06/2018 D5:56:59 D 0.0 7.08 0.0 0.0 405 Papa 2 of 5 Well MT6-04 ...w MT6 3"6 A Nov/06/2018 Cuero...-. Con ftlllim kr6 Num r Dab Thne 244v dark 7 Ung ewseure P8f Mow kale k/N D .tv We vmu. BBL m WNP m 14 e . 11/06/2018 06:00:19 2 0.0 7.06 0.0 0.0 422 11/06/2018 06:01:59 1 0.0 7.05 0.0 0.0 409 11/06/2018 06:03:39 0 0.0 7.05 0.0 0.0 368 11/06/2018 06:05:19 -0 0.0 7.04 0.0 0.0 411 11/06/2018 06:06:59 2 0.0 7.03 0.0 0.0 416 11/06/2018 06:08:39 -1 0.0 7.02 0.0 0.0 419 11/06/2018 06:10:19 0 0.0 7.01 0.0 0.0 427 11/06/2018 06:11:59 3 0.0 7.02 0.0 0.0 427 11/06/2018 06:13:39 1 0.0 7.01 0.0 0.0 423 11/06/2018 06:15:19 3 0.0 7.00 0.0 0.0 421 11/06/2018 06:16:59 -1 0.0 6.99 0.0 0.0 407 11/06/2018 06:18:39 1 0.0 6.99 0.0 0.0 422 11/06/2018 06:20:19 0 0.0 6.98 0.0 0.0 382 11/06/2018 06:21:59 3 0.0 6.98 0.0 0.0 394 11/06/2018 06:23:39 2 0.0 6.98 0.0 0.0 389 11/06/2018 06:25:19 1 0.0 6.98 0.0 0.0 389 11/06/2018 06:26:59 .1 0.0 6.98 0.0 0.0 394 11/06/2018 06:28:39 -0 0.0 6.97 0.0 0.0 376 11/06/2018 06:30:19 1 0.0 6.97 0.0 0.0 376 11/06/2018 06:31:59 -1 0.0 6.98 0.0 0.0 378 11/06/2018 06:33:39 -0 0.0 6.97 0.0 0.0 367 11/06/2018 06:35:19 0 0.0 6.97 0.0 0.0 374 11/06/2018 06:36:59 0 0.0 6.97 0.0 0.0 378 11/06/2018 06:38:39 3 0.0 6.96 0.0 0.0 387 11/06/2018 06:40:19 1 0.0 6.96 0.0 0.0 375 11/06/2018 06:41:59 1 0.0 6.% 0.0 0.0 378 11/06/2018 06:43:39 0 0.0 6.97 0.0 0.0 377 11/06/2018 06:45:19 3 0.0 6.97 0.0 0.0 374 11/06/2018 06:46:59 -0 0.0 6.97 0.0 0.0 384 11/06/2018 06:48:39 -1 0.0 6.96 0.0 0.0 379 11/06/2018 06:50:19 -0 0.0 6.97 0.0 0.0 383 11/06/2018 06:51:59 1 0.0 6.97 0.0 0.0 389 11/06/2018 06:53:39 -1 0.0 6.97 0.0 0.0 397 11/06/2018 06:55:19 2 0.0 6.97 0.0 0.0 401 11/06/2018 06:56:59 1 0.0 6.96 0.0 0.0 391 11/06/2018 06:58:39 2 0.0 6.96 0.0 0.0 386 11/06/2018 07:00:19 1 0.0 6.97 0.0 0.0 386 11/06/2018 07:01:59 2 0.0 6.97 0.0 0.0 395 11/06/2018 07:02:23 1 0.0 6.96 0.0 0.0 395 MSM Done 11/06/2018 07:03:39 2 0.0 6.% 0.0 O.D 393 11/06/2018 07:05:19 -1 0.0 6.96 0.0 0.0 394 11/06/2018 07:06:59 -0 0.0 6.97 0.0 0.0 397 11/06/2018 07:08:39 -1 0.0 6.97 0.0 0.0 389 11/06/2018 07:09:32 118 0.0 6.97 0.0 0.0 392 Bbw air down hard hire 11/06/2018 07:10:19 1 0.0 6.96 0.0 0.0 393 11/06/2018 07:11:59 3 0.0 6.97 0.0 0.0 407 11/06/2018 07:13:39 2 0.0 6.96 0.0 0.0 393 11/06/2018 07:15:19 2 0.0 6.96 0.0 0.0 389 11/06/2018 07:16:59 -1 0.0 6.96 0.0 0.0 -22 11/06/2018 07:18:39 2 0.0 6.97 0.0 0.0 -29 11/06/2018 07:19:57 55 0.0 7.37 0.0 0.0 -37 Fluid Park Herd Um 11/06/2018 07:20:19 15 1.1 7.49 0.2 0.2 -37 11/06/2018 07:21:59 109 0.0 7.37 1.3 1.3 60 11/06/2018 07:22:45 110 0.0 7.37 1.3 1.3 68 Low R u2 Test/Ched(T X Well MT6-04 ..eid MT6 lab Start .Nov/06/2018 Csmts- Coiccomillips Jab Nueber Dare Tara 24 -hr Cb Tread" Plelaure YNi New Nate a/N Density re/G ViWma NK 8r6 VOL e6L WNP PSt Nawpa 11/06/2018 07:23:21 1209 0.0 7.38 1.3 1.3 1180 FBgh Pre sum Test 11/06/2018 07:23:39 2978 0.1 7.38 1.3 1.3 2970 11/06/2018 07:25:04 3920 0.0 6.97 1.3 1.3 3870 Pressure test good 11/06/2018 07:25:19 84 0.0 6.97 1.3 1.3 16 11/06/2018 07:26:40 183 0.0 8.32 1.3 1.3 16 Reset TOW, Vol = 1.32 bol 11/06/2018 07:26:59 176 0.0 8.32 0.0 0.0 16 11/06/2018 07:28:39 173 0.0 8.32 0.0 0.0 18 11/06/2018 07:29:08 171 0.0 8.76 0.0 0.0 19 Sart batching up MucW sn 11/06/2018 07:30:19 169 0.0 9.54 0.0 0.0 18 11/06/2018 07:31:59 171 0.0 10.81 0.0 0.0 24 11/06/2018 07:33:39 167 0.0 11.46 0.0 0.0 24 MudR6h Smled 11.4 henry 11/06/2018 07:35:19 164 0.0 11.45 0.0 0.0 21 11/06/2018 07:36:11 190 1.1 11.45 0.1 0.1 110 Start MucPsh Down Hole 11/06/2018 07:36:59 638 3.6 11.08 2.6 2.6 421 11/06/2018 07:38:39 658 3.6 11.32 8.6 8.6 409 11/06/2018 07:40:19 694 3.8 11.58 14.9 14.9 406 11/06/2018 07:41:59 679 3.8 11.50 21.2 21.2 381 11/06/2018 07:43:39 652 3.8 11.53 27.6 27.6 386 11/06/2018 07:44:30 68 0.0 11.38 30.0 30.0 25 End MudPsh 11/06/2018 07:45:19 64 0.0 11.36 30.0 30.0 21 11/06/2018 07:46:59 55 0.0 8.20 30.0 30.0 18 11/06/2018 07:48:29 72 0.0 9.40 30.0 30.0 IS Start Satchlrg Gerhart 11/06/2018 07:48:39 80 0.0 10.25 30.0 30.0 16 11/06/2018 07:49:42 109 0.0 14.00 30.0 30.0 i5 Resp Total, Vol = 30.00 bbl 11/06/2018 07:50:19 121 0.0 15.55 30.0 0.0 17 11/06/2018 07:51:13 111 0.0 15.89 30.0 0.0 46 Cement Staled 15.8 heave 11/06/2018 07:51:23 119 0.0 15.90 30.0 0.0 67 Start cement do. hole 11/06/2018 07:51:46 995 4.D 15.90 30.9 0.9 477 Dettat 11/06/2018 07:51:59 1112 3.9 15.77 31.7 1.7 535 11/06/2018 07:53:39 1367 4.8 15.92 38.9 8.9 554 11/06/2018 07:55:19 1254 4.8 15.91 47.0 17.0 409 11/06/2018 D7:56:59 1130 4.8 15.85 55.0 25.0 320 11/06/2018 07:58:39 1032 4.8 15.81 '63.0 33.0 246 11/06/2018 08:00:19 1019 4.8 15.62 71.1 41.1 213 11/06/2018 08:01:59 987 4.7 is." 79.1 49.1 207 11/06/2018 08:03:39 970 4.7 15.80 87.0 57.0 239 11/06/2018 08:05:19 989 4.8 15.91 94.8 64.8 231 11/06/2018 08:06:54 24 0.0 15.89 101.6 71.6 17 End Ceram Slurry 11/06/2018 08:06:59 21 0.0 15.88 101.6 71.6 19 11/06/2018 08:07:04 23 0.0 15.88 101.6 71.6 19 Drop tap tart 11/06/2018 08:07:55 21 0.0 15.88 101.6 71.6 15 1 Reset Total, Vol - 71.59 bbl 11/06/2018 08:08:08 221 1.0 15.91 101.6 0.0 47 Fresh wate'beand 11/06/2018 08:08:39 557 5.6 15.92 103.5 1.9 91 11/06/2018 08:10:19 518 5.7 15.93 112.9 11.3 43 11/06/2018 08:11:56 12 0.3 15.93 121.7 20.1 -19 Eno 6sh w behind 11/06/2018 08:11:59 30 0.0 15.89 121.7 20.1 -27 11/D6/2018 08:12:12 11 0.0 15.84 121.7 20.1 -46 Swap t0 rig to displace 11/06/2018 08:12:30 9 0.0 15.83 121.7 20.1 27 Reset lb W, Vol - 20.09 bbl 11/06/2018 08:13:39 -3 0.0 15.80 121.7 0.0 20 11/06/2018 08:15:19 -3 0.0 12.61 121.7 0.0 38 11/06/2018 08:16:59 -3 0.0 12.26 121.7 0.0 29 11/06/2018 08:18:39 -3 0.0 12.26 121.7 0.0 23 11/06/2018 08:19:01 54 0.0 11.94 121.7 0.0 16 film air down the hard line 11/06/2018 08:20:19 -7 0.0 11.17 121.7 0.0 23 Race 4 lar 5 Wall MT6-04 ..elb MT6 jab Start Nov/06/2018 Cum CMMOp OMM 2o6 Nambar prte rum 2a.br dock Teatlng p.me PS[ MoW Rate B/M penalty LB/6 Voluma Bk }Tg_VM BBL WNp Message M 11/06/2018 08:23:39 -5 0.0 8.92 121.7 0.0 24 11/06/2018 08:25:19 -3 0.0 8.71 121.7 0.0 11 11/06/2018 08:26:59 -3 0.0 7.79 121.7 0.0 22 11/06/2018 08:28:39 -3 0.0 8.16 121.7 0.0 27 11/06/2018 08:30:19 3 0.0 8.37 121.7 0.0 124 11/06/2018 08:31:59 -4 0.0 6.57 121.7 0.0 221 11/06/2018 08:33:39 -2 0.0 5.81 121.7 0.0 262 11/06/2018 06:35:19 -2 0.0 5.50 121.7 0.0 302 11/06/2018 08:36:59 -1 0.0 8.32 121.7 0.0 320 11/06/2016 08:38:39 -2 0.0 8.32 121.7 0.0 330 11/06/2018 08:40:19 52 0.0 6.74 121.7 0.0 316 11/06/2018 08:41:59 1 0.0 8.31 121.7 0.0 323 11/06/2018 08:43:39 62 1 0.0 8.31 121.7 0.0 333 11/06/2018 08:45:19 62 0.0 8.31 121.7 0.0 353 11/06/2018 08:46:59 68 0.0 8.31 121.7 0.0 395 11/06/2018 08:48:39 -2 0.0 8.31 121.7 0.0 414 11/06/2018 08:50:19 -5 0.0 8.29 121.7 0.0 475 11/06/2018 08:51:59 -4 0.0 8.29 121.7 0.0 476 11/06/2018 08:53:39 -5 0.0 0.01 121.7 0.0 500 11/06/2018 08:55:19 -8 0.0 0.00 121.7 0.0 524 11/06/201808:56:59 4 0.0 0.00 121.7 0.0 647 11/06/2018 08:57:30 -4 0.0 -0.00 121.7 0.0 1052 Bump Rug. Post Job Summary Pape 5 at 5 Avenge pump Was, 661/min volume al Mole Inim l egg bbl SIUM 4.1 N3 MW Maximum Rata 6.1 Tolyl 9ulry 71.5 Mud 0.0 Spavar 30.0 N 2 Treepns preuum SLmmall pal Beeeb4gwn Mui4 Maximum 3992 Nnal -6 Average 161 Bump Mug m 1100 s mkaoam Type volume bd fiensNy Ib/pal Avg. N3 Portent % p gme4 Slurry Yuluma 71.5 bbi 10splacement 0.0 bbl NIYWear Temp ftF Cement tllaulaRE m Surtaca? VaNnm bbl Was6a4 Thm pert To R Cualembr or Authmiuml Representative A m D6lr ScblumberyprSuperNaar Lance KBlivas Cimule6w taut lob Cgmpletea ❑% Pape 5 at 5 THE STATE o1 A LASKA GOVERNOR 1311 WALKER Graham Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.ojoska.gov Re: Greater Mooses Tooth Field, Lookout Pool, MT6-04 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-108 Surface Location: 352' FNL, 3152' FEL, SEC. 6, T10N, R3E, UM Bottomhole Location: 4443' FNL, 1825' FEL, SEC. 25, Tl 1N, 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, Cathy F. Foerster Commissioner DATED this e. day of September, 2018. "Ir-UtiVtU STATE OF ALASKA r ALASKA OIL AND GAS CONSERVATION COMMISSi,-A AUb 28 2018 PERMIT TO DRILL 20 AAC 25.005 A t N ^ /1 1a. Type of Work: tb. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp ❑ 1 i posed for: Drill ❑•' ' Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ 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. o MT6-04 - 3. Address: 6. Proposed Depth: 9 tg 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14813 • TVD: - 7987 Greater Mooses Tooth Unit Lookout Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 253' FNL, 3152' FEL, Sec. 6, TI ON, R3E, UM AA081818, AA092346, AA081798 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 4571' FNL, 4643' FEL, Sec. 31, T11N, R3E, UM 932553, 340760, 340763, 932533 10/24/2018 Total Depth:14. 9. Acres in Property: q�+ Distance to Property: 4443' FNL, 1825' FEL, Sec. 25, T11N, R2E, UM 609 t�rO�1 35633 to LookoutNearest 4b. Location of Well (Stale Base Plane Coordinates -NAD 27):Be 10. KB Elevation above MSL (ft): jq jt 15. Distance to Nearest Well Open Surface: x- 317078 • y- 5945551 Zone -4 GL / BF Elevation above MSL (ft): to Same Pool: n/a 16. Deviated wells: Kickoff depth: 800 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hale Angle: 90 degrees Downhole: 3810 Surface: 3015 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 42" 20" 94 H40 Welded 80 34 34 115 115 10 yds 16" 13.375" 68 L-80 BTC -M 2068 34 34 2100 2080 961 sx Deeperete Lead at 11.0 ppg, 331 sx Class G Tail Slu" at 15.8 ppg 7636 7395 95 sx Class G Lead at 12.2 ppg -7' 12.25" 9.625" 40 L-80 TXP 7604_ 3'l ���' I 1 34 N 34 205 sx Class G Tail at 15.8 ppg 10.25" 7.0" 29 TN110SS H563 4191 8827 7945 259 sx Class G Tail at 15.8 ppg t47 ij 6" 4.5" 12.6 L-80 TXP 6136 8677 7913 14813 7987 uncemented pert pup liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑4 20. Attachments: Property Plat ❑ Sketch B Drillingv. Depth tm a a DivertOP er Sketch Seabed Report Drilling Fluid Program a20 AAC 25.050 requ ementsB 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Andy Marushack Authorized Name: Graham Alvord (265-6120) Contact Email: And ..marushack CO .com Authorized Title: Drilling Maner Contact Phone: 832-525-8923 Authorized Signature: Date: Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 0 8 50- Date: ( requirements. Conditions of approval : If box is checked, well ma/y not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: Js� Pg" of ��T ry Samples req'd: Yes ❑ No[R' Mud log req'd: Yes No L� n -7 "L -"4 t �^ HiS measures: Yes ❑ NoQ" Directional say req'd: Yes D No E]c.SL yam'/jJ wr�u.J' >.� �r.y�+u�CX Spacing exception req'd: Yes ❑ No[1]� Inclination -only svy req'd: Yes❑ o[9-' �1✓� ,r..� j�.y¢C -$.6�0 CtikL� Post initial injection MIT req'd: Yes 5Z No❑ PAPPROVED BY 7 Approved b . COMMISSIONER THE COMMISSION Date:Submit -. an orm1u,1u7Rev1aedWv17Inis permit s vaild for Z4 mon S rgal a eyo a pfgVeperzu C Xismuisillip Attachments in Dupflixle X31 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 14th, 2018 Alaska Oil and Gas Conservation Commission 333 West 7`^ Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT6-04 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the MT6 drilling pad. The intended spud date for this well is October 24th, 2018. It is intended that Do oRig 19 be used to drill the well. MT6-04 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 and landed at an inclination of— 43°. 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 a 8 3/d' x 10 '/d' drilling assembly, ultimately landing in the Alpine C sand. This assembly will consist of a 8 3/4" bit and be underreamed out to 10 %d' for increased annular clearance on the 7" liner run. Managed Pressure Drilling technology will be utilized to assist with providing stability through the HRZ, Kalubik, and Miluveach formations. This interval will build from —43° to —83° inclination. The section will be lined with a 7" liner to TD. The production interval will compris of a 6" horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed as an injector with 4.5" liner with pre -perforated pup joints and tied back to surface with a 4.5" tubing upper completion 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 Andy Marushack at 832-525-8923 (andy.j.marushack@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, cc: MT6-04 Well File / Ann Haggerty -Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Andy Marushack John Cookson ATO 1750 Drilling Engineer Application Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 MT6-04 Application for Permit to Drill Document Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f))............................................................ 3 2. Location Summary, (Requirements of20AAC25.005(c)(2))............................................3 Requirementsof 20 AAC 2-5.050(b).. ........................................... ......................................................... 3 3. Blowout Prevention Equipment Information (Requirements of20AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of20AAC25.005 (c)(4)) ........................4 5. Procedure for Conducting Formation Integrity Tests (Requirements oj20 AAC 25.005 (c) (5))......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) .......... 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) ......................... 5 8. Drilling Fluid Program (Requirements of20AAC 25.005(c)(8)) ....................................6 9. Abnormally Pressured Formation Information (Requirements of20AAC 25.005 (c)(9)) ................................................................................................................................... 8 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ......................................... 8 11. Seabed Condition Analysis (Requirements of 20AAC 25.005 (c)(11)) ........................ 8 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................... 8 13. Proposed Drilling Program (Requirements of20AAC25.005 (c)(13)) .........................8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 9 (Requirements of 20 AAC 25.005(e)(14))............................................................................. 9 15. Attachments............................................................................................................. 11 Attachment1 Cement Summm y............................................................................................................... 11 MT6-04 APD Page 1 of 18 Printed. 28 -Aug -18 Attachment 2 Drilling Hazards Summary -..... Attachment 3 Completion Schematic .............. Attachment 4 Area of Review .......................... Attachment S Directional Plan ...................... MT6-04 APD Page 2 of 18 Printed: 28 -Aug -18 Application. Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 1. Well Name (Requirements of20AAC25.005 )g) The well for which this application is submitted will be designated as MTU MT6-04 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 253' FNL, 3152' FEL, Sec. 6, TION, ME, UM NAD83 Northings: 5,945,296Pad Eastings: 1,457,1133 RKB Elevation �9c0' AMSL Elevation 34'0"AMSL Location at Top of Productive Interval Heel 4751' FNL, 4643' FEL, Sec. 31 Tl IN, R3E, UM NAD83 Northings: 5,946,114 Eastings: 1,455,638 Measured Depth, RKB: 8,807' Total Vertical De th, RKB: 7,941' Total Vertical Depth, SS: 1 7,87P Location at Total Depth Toe 4443' FNL, 1825' FEL, Sec. 25, Tl IN, R2E1UM NAD83 Northings: 5,951,753 Eastings: 1,453,580 Measured Depth, RKB: 14,812' Total Vertical De th, RKB: 7,987' Total Vertical Depth, SS: 7,917' Requirements q(20 AAC 25.050(6) 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.. •'1'I -P -..a MT6-04 APD Page 3 of 18 Printed., 28 -Aug -18 Application Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 4. Drilling Hazards Information(Requirements of20AAC 25.005 (c)(4)) 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 Gradienti rilling 20 115 / 115 10.9 13.375 2100/2080 14.5 W�N/A 0 9.625 7636/7395 13.5 15 7 8827/7945 12.5 4 4.5 14813/7987 12.5 6 ?•�-ro.z �- 5- z AY63 f PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) rI if 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) -0.111) Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 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) = 910 - (0.1 x 2031) = 707 psi 2. Drilling below surface casing (13-3/8") ASP = [(FG x 0.052) - 0. I ] D OR _ [(14.5 x 0.052) - 0.1] x 2080' = 1360 psi ASP = FPP - (0.1 x D) = 3176 - (0.1 x 7395') = 2436 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 7395 = 4451 psi OR ASP =FPP - (0.1 x D) = 3810- (0.1 x 7945') = 3015 psi u MT6-04 APD Page 4 of 18 Printed.. 28 -Aug -18 Applicatioi. Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 4. Drilling below production liner (711) [fill ASP = [(FG x 0.052) — 0.1 ] D = [(12.5 x 0.052) — 0.l ] x 7945 = 4369 psi ASP=FPP—(0.1 xD) = 3773 — (0.1 x 7987) = 2974 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 of20AAC25.005 (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 Cementin Program Csg7Tbg OD (in) Hole size WeightE (1�) n. Lengfh Top MD/TVD Btm MD?VD Cement Program in (h) (h) (0) 20 42 94 ed 80 Surf 115/115 Cemented to surface with 10 yds slurry Cement to Surface with 13-3/8 16 66 2,068 Surf 2,100 / 2,080 961 sx DeepCrete Lead at 11.0 ppg, 331 sx Class G Tail Slurryat 15.8 ppg 9-5/8 12-1/4 40 7,604 Surf 7,636 / 7,395 95 sx Class G Lead at 12.2 ppg 205 sx Class G Tail at 15.8 ppg 7 6 x 8- 3/4 26 il 3,000' 4,636' / 4,559' 8,827 / 7,945 259 sx Class G Tail at 15.8 ppg 4-1/2 n/a 12.6 L-80 yil Blue 8,645 Surf 8,677 / 7,913 n/a 41/2 6 12.6 L-80 TXP 6,135 8,677 / 7,913 14,812 / 7,987 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 have been four surface penetrations that have been completed and there has not been a significant indication of shallow gas or gas hydrates above the C30 where casing will be set. MT6-04 APD Page 5 of 18 Printed.. 28 -Aug -18 Application. ?ermit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 S. Drilling Fluid Program (Requirements of20AAC25.005(c)(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: Freshwater polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight MPJ 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. /i 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. MT6-04 APD Page 6 of 18 Printed: 28 -Aug -18 Surface Intermediate Intermediate Production #1 #2 Hole Size in. 16 12.25 8.75 x 10.25 6.0 Casing Size in. 13.375 9.625 7 4.5 Density PPG 9.0 - 10.0 ' 9.4 -10.2 10.0 - 11.0 - 8,8-9,2 - 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 lb./1000ftZ 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 Fluid c Loss min. Loss min. n/a 8.0-12.0 8.0-12.0 10.0 PH 11.0 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: Freshwater polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight MPJ 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. /i 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. MT6-04 APD Page 6 of 18 Printed: 28 -Aug -18 Application, Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 MT6-04 APD Page 7 of 18 Printed: 28 -Aug -18 Application . Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -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 of20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of20 AAC 25.005 (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 of 20 AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 19 onto GMTU MT6-04 over pre-installed 20" insulated conductor. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16" hole to the surface casing point as per the directional plan. (LWD Program: GR/). 4. Run and cement new 13-3/8" 68 ppf L-80 surface casing to surface. 5. Install BOPE with the following equipment/configuration: 13-5/8" annular preventer, 3-1/2" x 6" VBR, blind ram and 3-1/2" x 6" VBRs. 6. Test BOPE to 250 psi low / 3500 psi high (2448 hr. AOGCC notice, 72 Hr BLM notice). 7. Pick up and run in hole yvith 12-1/4" drilling BHA to drill intermediate 41. 3 8. Chart casing pressure test to 2500 psi for 30 minutes. (_ 9. Drill out shoe track and 20' of new hole. sr r,r(„g✓10. Perform LOT to maximum EMW of 18.0 ppg. Minimum LOT required to drill ahead is 12pg EMW. 5 � Foryvard data to the AOGCC.+c 1-0 11. Displace well to 9.4 ppg LSND mud. 12. Drill 12-1/4” hole to the casing point -- 7,636 ft MD / 7,395 ft TVD. (LWD Program: GR/RES). 13. Circulate wellbore clean and POOH. 14. Change upper VBRs to 9-5/8" solid body rams. Test same to 250 psi low / 2,500 psi high. 15. Run 9-5/8" intermediate casing to TD. 16. Pump single stage cementjob to isolate the casing shoe or 500' MD or 250' TVD, whichever is larger, above uppermost hydro -carbon bearing zone. 17. Change upper 9-5/8" solid body rams to 3-1/2" x 6" VBRs. Test BOPE to 250/3500 psi. 18. Pick up and run in hole with 8-3/4" bit and drilling assembly. Perform a LOT down the 13-3/8" x 9 5/8" casing annulus with�B6TjI mill and freeze protect. Forward data to AOGCC. (LWD Program: GR/RES- 19. Pressure test casssing to 3000 asi for 30 minutes and record results. 20. Drill out shoe track and 20' of new hole. MT6-04 APD Page 8 o118 Printed: 28 -Aug -18 Application . ?ermit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 21. Perform FIT to 14 ppg EM W. Minimum required to drill ahead is 12.5 ppg EM W. 22. Drill 8-3/4" x 10 '/4" Int. 2 to production casing point into the Alpine C sand using Managed Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES). to PD 23. Circulate hole clean and POOH. 24. Pick up and run 7" liner to TD. 25. Circulate and condition mud in preparations for cementing. 26. Cement 7" liner 500' MD or 250' TVD from the Alpine C. Set liner hanger and packer. Circulate excess cement from top of liner. POOH laying down 5" drill pipe. 27. Pick up 4" DP. Test BOPE to 250 psi low / 3,500 psi high. �28. Pick up and RIH with 6" drilling assembly. (LWD Program: GR/Azimuthal RES/Density). L &' 29. Chart casing pressure test to 3500 psi for 30 minutes and record results. ✓t 30. Drill out and perform FIT to 12.5. Minimum acceptable leak -off for drilling ahead is 11.5 ppg EMW. 31. Drill 6" horizontal hole to section TD (LWD Program: GR/RES/Dens). 32. Circulate the hole clean and POOH with drilling BHA. 33. Run in hole with 4.5" liner with pre -perforated pup joints on 4"drill pipe. 34. Set liner top packer and release from lines 35. Displace well to kill weight brine. 36. Run 4.5" upper completion. 37. Space out and land hanger. 38. Install HP back pressure valve and pressure test hanger seals to 5000 psi. Nipple down BOP. 39. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove back pressure valve. IV 40. Test tubing and tubing -casing annulus separately to 3500psi/ 30 mins. / p 41. Shear circulation valve in GLM. /V 9 e. `4-' Mll 42. Circulate tubing to diesel and install freeze protection in the annulus. f 43. 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 MT6-04 will be injected into a permitted surface casing x production casing annulus on CD 1. In the event that annular injection is approved on MT6-06. Cuttings will be disposed of according to approved permit down the annulus. MT6-04 APD Page 9 of 18 Printed: 28 -Aug -18 Application _ .1e"it to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 The MT6-04 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' of cement placed above the top of the Alpine reservoir. Once MT6-04 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10403 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 (C-40). 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 bbl 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) * (2,100') + 1,500 psi = 2810 psi Pore Pressure = 910 psi Therefore Differential = 2767 —910 = 1900 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 (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst us 85% of 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 35 �0 MT6-04 APD Page 10 of 18 Printed: 28 -Aug -18 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Area of Review Attachment S Directional Plan Application. permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 MT6-04 APD Page 11 of 18 Printed: 28 -Aug -18 Application I_ ermit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 Attachment 1 - Cement Summary GMTU MT6-04 wpO5 MT6-04 APD Page 12 of 18 Printed.. 28 -Aug -18 Attachment t — Cement Summary GMTU MT6-04 wp05 Applicatio r Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 13-3/8" Surface Casing run to 2.100' MD / 2,0801 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 (1,100' MD), zero excess in 20" conductor. Lead slurry from 1,600' MD to surface with DeepCrete @ 11.0 ppg Conductor (115'— 36) X 1.0190 ft3/ft X 1.0 (0% excess) = 81 ft3 Permafrost to Conductor (1,100'— 1151 X 0.4206 ft3/ft X 3.5 (250% excess) = 1,450 ft3 Top of Tail to Permafrost (1,600'— 1,100 X 0.4206 ft3/ft X 1.5 (50% excess) = 315 ft3 Total Volume = 81 + 1,450 + 315 = 1,846 W => 961 sx of 11.0 ppg DeepCrete @ 1.92 ft3 /sk Shoe Joint 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) = 316 W Shoe Joint (80� X 0.8407 W/ft X 1.0 (0% excess) = 68 W Total Volume = 316 + 68 = 384 ft3 => 331 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk 9-5/8" Intermediate casing to 7,636 MD / 7.395' TVD / z,z S" Ott Cement 1000' up from 9-5/8" casing shoe from 7,636' MD to 6,636' MD. Assume 40% excess annular volume. Lead slurry from 6,636' MD to 7,136' MD with 12.2 ppg Class G + additives Top of Tail to Top of Cement (7,136'— 6,636) X 0.3132 W/ft X 1.40 (40% excess) = 219 W Total Volume = 219 ft3 => 94.9 sx of 12.2 ppg Class G + additives @ 2.31 ft3/sk Tail slurry from 7,136' MD to 7,636' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (7,636'— 7,136) X 0.3132 ft3/ft X 1.30 (30% excess) = 204 ft3 Shoe Joint (80� X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft3 Total Volume = 204 + 34 = 238 ft3 => 205 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk MT6-04 APD Page 13 of 18 Printed., 28 -Aug -18 A T' Intermediate liner run to SA27' MD / 7,945' TVD Top of slurry is designed to be — 1000' up from the T' liner shoe. Assume 30% excess annular volume. 8 3/4" x 10''A" underreamer to be —80'ft behind the drill bit. Tail slurry from 8,827' MD to 7,827' MD with 15.8 ppg Class G + additives 101/4" Hole to Top of Tail (8,827'— 7,8271 X 0.3055 ft'/ft X 1.30 (30% excess) = 413 W Shoe Joint (801 X 0.2148 ft;/ft X 1.0 (0% excess) = 17W Total Volume = 413 + 17 = 420 ft3 => 357 sx of 15.8 ppg Class G + additives 0 1.16 W/sk Applicatioi. Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 7" Intermediate liner run to 8,827' MD / 7,945' TVD Top of slurry is designed to be — 700' up from the 7" liner shoe. Assume 30% cess annular volume. 8 3/4" x 10 ''/d' underreamer to be —80'ft behind the drill bit. Tail slurry from 8,827' MDZ7,94S'MD5. pg Class G +additives 10 1/4" Hole to Top ofTail) X 0.3055 ft3/ft X 1.30 (30% excess) = 284 ft3Shoe Joint ft3/ft X 1.0 (0% excess) = 17ft3Total Volume = 284 + 17 15.8 ppg Class G + additives @ 1.16 ft3/sk MT6-04 APD Page 14 of 18 Printed: 28 -Aug -18 Applicatioi. . Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole 13-3/8" Casina Interval Event 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, Low Reduce pump rates, reduce trip speeds, real time 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 Reduce trip speeds, condition mud properties, hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost monitoring, Liner will be in place at TD circulation material, use of low density cement Low Well control drills, check for flow during slurries ort collar control i e runnin seeds 12-1 4 Hole L V-0/5 Casing Intervai Event Event Risk Level Miticiation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time Increase mud weight, control ROP, connection and ECD monitoring, mud rheology, add lost circulation trip speeds, sweeps, and real time equivalent material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, liner proper hole filling, pump out of hole, real time ECD Low Reduce pump rates, reduce trip speeds, real time monitoring,MPD stripping ractices Abnormal Pressure in Low Well control drills, check for flow during Overburden Formations material connections, increase mud weight. Shallow hazard Medium Reduce trip speeds, condition mud properties, study noted minimal risk Hole Cleaning Low Monitor ECD and torque/drag trends, control drill monitoring, Liner will be in place at TD and use best hole cleanin radices 8-3 4" x 10 1/4" Hole 7" Liner - Casing Interval Event Risk Level Miti ation Strategy Sloughing shale, Tight High MPD for shale stability, Underreamed hole, 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 MT6-04 APD Page 15 of 18 Printed.28-Aug-18 Applicatio.. ; Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 Hydrogen Sulfide gas Low Hz5 drills, detection systems, alarms, standard well control practices mud scavengers 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 movin control mud weight Hydrogen Sulfide gas Low 1-12S drills, detection systems, alarms, standard well control radices mud scaven ers MT6-04 APD Page 16 of 18 Printed.. 28 -Aug -18 Applicatio . r Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 Well Proximitv Risks: MT6-04 will be the fifth 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. Managed Pressure Drilling will be used in conjunction with a 4 -string casing design to mitigate shale instability in the aforementioned formations. 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 MT6-04 APD Page 17 0/ 18 Printed: 28 -Aug -18 Applicatio,( Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 Attachment 3 —Completion Schematic MT6-04, Injector Completion Schematic WPO5 TOC at least 500' MD above Alpine C. Planned to Liner Top. Top Alpine C 8,807' MD / 7941' TVD IM 4-%" 12.6# L-80 Tenaris TXP - Win Pert Pups O 0 0 0 0 0 0 0 0 0 7" 29 ppf TN11t1SS Tenaris H563 Liner to 8,827'M D / 7945' TVD @ 80 deg 6" Hole, TD at at 14,812' MD/ 7987' TVD August 23, 2018 -AK MT6-04 APD Page 18 of 18 Printed. 28 -Aug -18 20" 79 ppf H40 Insulated Conductor Tubing/ Liner Completion: 80 feet, cemented to surface 1) 4JA" Landing Nipple (3.813" X) 0 2) 4-W x V GLM rs" 3) 4-h" x 1" GLM gs 4) 4-h" Landing Nipple (3.725" DB NOGo) set at 74 deg 73-3/8" 68 ppf L-80 TXP (Surf to-1200')IBTCM to TD 5) Liner Top Packer/ Hanger W A Surface Casing w/ Tie Back sleeve @ 2100' MD / 2080' TVD i cu O cemented to surface 6) 4'/," TXP Blank Pipe per' 7) 411W TXP Linerwith Pert Pups y t 4-1/2" 12.6 ppf L-80 Tenaris Blue to 8,67T MD 9 5/8" 40 ppf L-80 TXP (to 5636 md) 9 5/8" 40 ppf TN -80 HIS TXP (to TD) @ 7,636' MD / 7395' ND TOC at least 500' MD above Alpine C. Planned to Liner Top. Top Alpine C 8,807' MD / 7941' TVD IM 4-%" 12.6# L-80 Tenaris TXP - Win Pert Pups O 0 0 0 0 0 0 0 0 0 7" 29 ppf TN11t1SS Tenaris H563 Liner to 8,827'M D / 7945' TVD @ 80 deg 6" Hole, TD at at 14,812' MD/ 7987' TVD August 23, 2018 -AK MT6-04 APD Page 18 of 18 Printed. 28 -Aug -18 Applicatio, Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 Attachment 4 —Area of Review ✓ MT6-04 Area of Review: This Area of Review is required as MTK04 is being permitted as an Alpine C Sand Injector. There are currently no wells that fall within % mile of the well's entry point into the Alpine C sand. (Draft plot is being permitted for file permit). MT6-08 falls within % mile of the wells toe and will be an injector as well. No injection will have occurred before the drilling of MT6-04. MT6-04 APD Page 19 of 18 Printed: 28 -Aug -18 Application . Permit to Drill, Well MTU MT6-04 Saved: 28 -Aug -18 'nwt:tzueNup Attachment 5 — Directional Plan MT6-04 MT6-04wp05 Objective: Planned final wellpath for Injector GMTU MT6-04 MT6-04 APD Page 20 of 18 Printed 28 -Aug -18 c racr� 4 � y 'nwt:tzueNup Attachment 5 — Directional Plan MT6-04 MT6-04wp05 Objective: Planned final wellpath for Injector GMTU MT6-04 MT6-04 APD Page 20 of 18 Printed 28 -Aug -18 ConocoPhillips ConocoPhillips Export Company Western North Slope GMT1 Lookout Pad MT6-04 MT6-04 Plan: MT6-04 wp05 Drilling Summary Report 23 August, 2018 BT�a GHES GE company 8/232018 11:30.'56AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips BA, KER Drilling Summary Report j FGHES aUcompany Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MTE04 Project: Western North Slope TVD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) . She: GMT1 Lookout Pad MD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Well: MT6-04 North Reference: True Wellbore: MT6-04 Survey Calculation Method: Minimum Curvature Design: MT6-04 wp05 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) Map Zone: Alaska Zone 04 Using geodetic scale factor SRe GMTi 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 MT6-04 Weli Position +N/S 0.00 usft Northing: 5,945,550.61 usft Latitude: 70° 15' 23.035 N +EI•W 0.00 usft Easting: 317,078.75 usft Longitude: 751' 28' 42.389 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 37.20 usft Wellbore MT6-04 -- Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGGM2018 10/1/2018 16.37 80.69 57.391 Design MT6-04 wp05- Audit Notes: Version: Phase: PLAN Tie On Depth: 37.20 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 329.93 8/232018 11:30.'56AM Page 2 COMPASS 5000.14 Build 85 n ConocoPhillips BA, �(ER ConocoPhillips Drilling Summary Report UGHES a GE company Company: _ConocoPhillips Export Company Local Co ordinate Reference: Well MT6-04 Project: Western Norm Slope V. Sec Northing Site: GMT1 Lookout Pad TVD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Well: MT604 MD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Wellborn: MT6-04 North Reference: True 0.00 -89.40 Survey Calculation Method: Minimum Curvature Design: MT6-04 wp05 Database: EDT 14 Alaska Production Survey Tool Program From (usft) 37.20 1,100.00 1,100.00 2,053.00 2,053.00 7,516.00 7,516.00 8,824.00 8,824.00 Planned Survey MD (usft) O.D0 100.00 200.00 300.00 400.00 500.00 600.00 700.00 737.20 • Start Build 2.00 800.00 900.00 1,000.00 1,100.00 1,200.OD 1,300.00 Date TO (usft) Survey (Wellbore) 1,100.00 MT604 wp05 (MT6-04) 2,053.00 MT6-04 wp05 (MT6-04) 2,053.00 MT6-04 wp05 (MT6-04) 7,516.00 MT6-04 wp05 (MT6-04) 7,516.00 MTG-04 wp05 (MT6-04) 8,824.00 MT6-04 wp05 (MTS -04) 8,824.00 MT6-04 wp05 (MT644) 14,812.64 MT6-04 wp05 (MT6-04) 14,812.64 MT6-04 wp05 (MT6-04) Tool Name GYD-GC-SS MWD MWD-IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD-IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC Description Gyrodata gyro single shots MWD - Standard MWD+IFR AK CAZ SCC MWD - Standard MWD -IFR AK CAZ SCC MWD - Standard MWD+IFR AK CAZ SCC MWD - Standard MWD+IFR AK CAZ SCC Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) 0.00 0.00 0.00 -89.40 0.00 0.00 0.00 5,945,550.61 317,078.75 0.00 0.00 100.00 10.60 0.00 0.00 0.00 5,945,550.61 317,078.75 0.00 0.00 200.00 110.60 0.00 0.00 0.00 5,945,550.61 317,076.75 0.00 0.00 300.00 210.60 0.00 0.00 0.00 5,945,550.61 317,078.75 0.00 0.00 400.00 310.60 0.00 0.00 0.00 5,945,550.61 317,078.75 0.00 0.00 500.00 410.60 0.00 0.00 0.00 5,945,550.61 317,078.75 0.00 0.00 600.00 510.60 0.00 0.00 0.00 5,945,550.61 317,078.75 0.00 0.00 700.00 610.60 0.00 0.00 0.00 5,945,550.61 317,078.75 0.00 0.00 737.20 647.80 0.00 0.00 0.00 5,945,550.61 317,078.75 1.26 215.00 799.99 710.59 2.00 215.00 -0.29 5,945,550.06 317,078.35 3.26 215.00 899.91 810.51 2.00 0.00 -1.95 5,945,546.89 317,076.01 5.26 215.00 999.63 910.23 2.00 0.00 -5.08 5,945,540.91 317,071.61 7.26 215.00 1,099.03 1,009.63 2.00 0.00 -9.67 5,945,532.14 317,065.14 9.26 215.00 1,197.99 1,108.59 2.00 0.00 -15.72 5,945,520.59 317,056.62 11.26 215.00 1,296.39 1,206.99 2.00 0.00 -23.23 5,945,506.25 317,046.06 82312018 11:30:56AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips BA. ICER ConocoPhillips Drilling Summary Report �j IGHES BAT GE company Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-04 Project: Western North Slope Site: GMT1 Lookout Pad TVD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Well: MT6-04 MD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Wellbore: MT6-04 North Reference: True (usft) (°) Survey Calculation Method: Minimum Curvature Design: MT6-04 wp05 Database: EDT 14 Alaska Production Planned Survey MD Inc Azt(azimuth) TVD TVDSS DLeg TFace V. Sec Northing Fasting (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) 1,311.23 11.48 215.00 1,307.40 1,218.00 2.00 0.00 -24.16 5,945,504.47 317,044.75 Start 706.74 hold at 1311.23 MD 1,400.00 11.48 215.D0 1,394.39 1,304.99 0.00 -21.71 -31.61 5,945,490.25 317,034.27 1,500.00 11.48 215.00 1,492.39 1,402.99 0.00 0.00 -40.00 5,945,474.23 317,022.46 1,600.00 11.48 215.00 1,590.39 1,500.99 0.00 0.00 48.39 5,945,458.21 317,010.65 1,700.00 11.48 215.00 1,668.39 1,596.99 0.00 0.00 -56.78 5,945,442.19 316,998.64 1,800.00 11.48 215.00 1,786.39 1,696.99 0.00 0.00 -65.17 5,945,426.17 316,987.03 1,900.00 11.48 215.00 1,884.39 1,794.99 0.00 0.00 -73.56 5,945,410.14 316,975.23 2,000.00 11.48 215.00 1,982.39 1,892.99 0.00 0.00 -81.95 5,945,394.12 316,963.42 2,017.97 11.48 215.00 2,000.00 1,910.60 0.00 0.00 -83.46 5,945,391.24 316,961.30 Start 100.00 hold at 2017.97 MD 2,053.00 11.48 215.00 2,034.33 1,944.93 0.00 0.00 -86.40 5,945,385.63 316,957.16 133/8" x 16" r 2,100.00 11.48 215.00 2,080.38 1,990.98 0.00 0.00 -90.34 5,945,378.10 316,951.61 2,117.97 11.48 215.00 2,096.00 2,008.60 0.00 0.00 -91.85 5,945,375.22 316,949.49 Start DLS 2.00 TFO 66.00 2,200.00 12.26 222.02 2,178.27 2,088.87 2.00 65.00 -97.97 5,945,362.32 316,938.66 2,300.00 13.43 229.35 2,275.78 2,186.38 2.00 58.13 -103.37 5,945,347.26 316,922.37 2,400.00 14.76 235.46 2,372.77 2,283.37 2.00 50.98 -106.49 5,945,332.95 316,902.71 2,428.19 15.17 236.98 2,400.00 2,310.60 2.00 45.06 -106.96 5,945,329.05 316,896.56 Start 1000.00 hold at 2426.19 MD 2,500.00 15.17 236.98 2,469.31 2,379.91 0.00 169.68 -107.93 5,945,319.20 $16,880.57 2,600.00 15.17 236.98 2,565.83 2,476.43 0.00 0.00 -109.27 5,945,305.48 316,858.29 2,700.00 15.17 236.98 2,662.34 2,572.94 0.00 0.00 -110.62 5,945,291.76 316,836.01 2,800.00 15.17 236.98 2,758.86 2,669.46 0.00 0.00 -111.97 5,945,276.04 316,813.73 2,900.00 15.17 236.98 2,855.36 2,765.98 0.00 0.00 -113.31 5,945,264.32 316,791.45 3,000.00 15.17 236.98 2,951.89 2,862.49 0.00 0.00 -114.66 5,945,250.60 316,769.17 3,100.00 15.17 236.98 3,048.41 2,959.01 0.00 0.00 -116.00 5,945,236.88 316,746.89 W32018 11:30:56AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips BATER COnoCoPhilllPS Drilling Summary Report UGHES aGEcompany Company: Export Company _ConocoPhillips Local Coordinate Reference: Well MT6-04 Project: Western North Slope MD Inc Site: GMT1 Lookout Pad TVD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Well: MT6-04 MD Reference: MT"4 @ 89.40usft (Doyon 19 Plan) (usft) V) North Reference: True Wellbore: MT6-04 Survey Calculation Method: Minimum Curvature Design: MT6-04 wp05 Database: EDT 14 Alaska Production Planned Survey MD Inc Azl (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easgng (usft) V) V) (waft) (usft) ('1100usft) V) (usft) (usft) (usft) 3,200.00 15.17 236.98 3,144.92 3.055.52 0.00 0.00 -117.35 5,945,223.16 316,724.62 3,300.00 15.17 236.98 3,241.44 3,152.04 0.00 0.00 -118.69 5,945,209.44 316,702.34 3,400.00 15,17 236.98 3,337.96 3,248.56 0.00 0.00 -120.04 5,945,195.72 316,680.06 3,428.19 15.17 236.98 3,365.16 3,275.76 0.00 0.00 -120.42 5,945,191.86 316,673.78 Start DLS 3.00 TFO 179.86 3,500.00 13.01 237.01 3,434.81 3,345.41 3.00 179.84 -121.31 5,945,182.69 316,658.89 3,600.00 10.01 237.06 3,532.79 3,443.39 3.00 179.82 -122.32 5,945,172.24 316,641.89 3,677.92 7.68 237.14 3,609.78 3,520.38 3.00 179.77 -122.92 5,945,165.98 316,631.68 Start 2442.26 hold at 3677.92 MD 3,677.99 7.67 237.14 3,609.84 3,520.44 3.00 179.69 -122.92 5,945,165.98 316,631.67 3,700.00 7.67 237.14 3,631.66 3,542.26 0.00 0.00 -123.06 5,945,164.44 316,629.16 3,800.00 7.67 237.14 3,730.76 3,641.36 0.00 0.00 -123.71 5,945,157.47 316,617.77 3,900.00 7.67 237.14 3,829.86 3,740.46 0.00 0.00 -124.36 5,945,15D.50 316,606.38 4,000.00 7.67 237.14 3,928.97 3,839.57 0.00 0.00 -125.01 5,945,143.53 316,594.99 4,100.00 7.67 237.14 4,028.07 3,938.67 0.00 0.00 -125.67 5,945,136.55 316,583.61 4,200.00 7.67 237.14 4,127.18 4,037.78 0.00 0.00 -126.32 5,945,129.58 316,572.22 4,300.00 7.67 237.14 4,226.28 4,136.88 0.00 0.00 -126.97 5,945,122.61 316,560.83 4,400.00 7.67 237.14 4,325.39 4,235.99 0.00 0.00 -127.62 5,945,115.64 316,549.44 4,500.00 7.67 237.14 4,424.49 4,335.09 0.00 0.00 -128.27 5,945,108.67 316,538.05 4,600.00 7.67 237.14 4,523.59 4,434.19 0.00 0.00 -128.92 5,945,101.70 316,526.66 4,700.00 7.67 237.14 4,622.70 4,533.30 0.00 0.00 -129.57 5,945,094.72 316,515.27 4,800.00 7.67 237.14 4,721.80 4,632.40 0.00 0.00 -130.22 5,945,087.75 316,503.86 4,900.00 7.67 237.14 4,820.91 4,731.51 0.00 0.00 -130.88 5,945,080.78 316,492.49 5,000.00 7.67 237.14 4,920.01 4,830.61 0.00 0.00 -131.53 5,945,073.81 316,481.10 5,100.00 7.67 237.14 5,019.12 4,929.72 0.00 0.00 -132.18 5,945,066.84 316,469.72 5,200.00 7.67 237.14 5,118.22 5,028.82 0.00 0.00 -132.83 5,945,059.87 316,458.33 5,300.00 7.67 237.14 5,217.33 5,127.93 0.00 0.00 -133.48 5,945,052.89 316,446.94 81232018 11:30:56AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips BA. �(ER 0 ConocoPhillips Drilling Summary Report UGHES aUcompany Company: _ConocoPhillips Export Company Local Coordinate Reference: Well MT6-04 Project: Western North Slope TVD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Site: GMT1 Lookout Pad MD Reference: MTS -04 @ 89.40usft (Doyon 19 Plan) Well: MT6-04 North Reference: True Wellbore: MT6-04 Survey Calculation Method: Minimum Curvature Design: MT6-04 wp05 Database: EDT 74 Alaska Production Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Seating (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) 5,400.00 7.67 237.14 5,316.43 5,227.03 0.00 0.00 -134.13 5,945,045.92 316,435.55 5,500.00 7.67 237.14 5,415.53 5,326.13 0.00 0.00 -134.78 5,945,038.95 316,424.16 5,600.00 7.67 237.14 5,514.64 5,425.24 0.00 0.00 -135.44 5,945,031.98 316,412.77 5,700.00 7.67 237.14 5,613.74 5,524.34 0.00 0.00 -136.09 5,945,025.01 316,401.38 5,800.00 7.67 237.14 5,712.85 5,623.45 0.00 0.00 -136.74 5,945,018.04 316,389.99 5,900.00 7.67 237.14 5,811.95 5,722.55 0.00 0.00 -137.39 5,945,011.06 316,376.60 6,000.00 7.67 237.14 5,911.06 5,821.66 0.00 0.00 -138.04 5,945,004.09 316,367.22 6,100.00 7.67 237.14 6,010.16 5,920.76 0.00 0.00 -138.69 5,944,997.12 316,355.83 6,120.19 7.67 237.14 6,030.17 5,940.77 0.00 0.00 -138.82 5,944,995.71 316,353.53 Start DLS 3.00 TFO 102.01 6,120.25 7.67 237.14 6,030.23 5,940.83 0.00 0.00 -138.82 5,944,995.71 316,353.52 6,200.00 7.55 255.25 6,109.29 6,019.89 3.00 101.99 -137.70 5,944,991.72 316,343.88 6,300.00 8.40 276.12 6,208.34 6,118.94 3.00 84.04 -131.65 5,944,991.16 316,330.25 6,400.01) 10.11 291.58 6,307.05 6,217.65 3.00 63.37 -120.45 5,944,995.54 316,314.92 6,500.00 12.31 302.10 6,405.15 6,315.75 3.00 48.10 -104.14 5,945,004.85 316,297.95 6,600.00 14.80 309.32 6,502.36 6,412.96 3.00 37.78 -82.75 5,945,019.06 316,279.37 6,700.00 17.44 314.44 6,598.43 6,509.03 3.00 30.76 -56.35 5,945,038.14 316,259.25 6,800.00 20.18 318.23 6,693.08 6,603.68 3.00 25.84 -25.01 5,945,062.03 316,237.63 6,900.00 22.99 321.14 6,786.06 6,696.66 3.00 22.25 11.18 5,945,090.68 316,214.57 7,000.00 25.83 323.44 6,877.12 6,787.72 3.00 19.54 52.13 5,945,123.99 316,190.14 7,100.00 28.71 325.31 6,966.00 6,876.60 3.00 17.45 97.73 5,945,161.88 316,164.41 7,200.00 31.60 326.87 7,052.46 6,963.06 3.00 15.78 147.84 5,945,204.24 316,137.44 7,300.00 34.52 328.19 7,136.26 7,046.86 3.00 14.43 202.33 5,945,250.96 316,109.31 7,400.00 37.44 329.33 7,217.18 7,127.78 3.00 13.33 261.06 5,945,301.92 316,080.09 7,500.00 40.37 330.32 7,294.98 7,205.58 3.D0 12.41 323.86 5,945,356.96 316,049.87 7,516.00 40.84 330.47 7,307.13 7,217.73 3.00 11.63 334.27 5,945,366.14 316,044.95 9-6/8" x 12-1/4" 8!23/2018 11:30:56AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips BAI(ER ConocoPhillips Drilling Summary Report UGHES a GEmmirany Company: _ConocoPhillips Export Company Local Coordinate Reference: Well MT6-04 Project: Western North Slope TVD Reference: MT6-04 @ 89.40us% (Doyon 19 Plan) Site: GMT1 Lookout Pad MD Reference: MTB -04 @ 89.40usR (Doyon 19 Plan) Well: MT6-04 North Reference: True Wellbore: MT6-04 Survey Calculation Method: Minimum Curvature Design: MTB -04 wp05 Database: EDT 14 Alaska Production Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (9 (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) 1 7563.81 42.25 330.90 7,342.91 7,253.51 3.00 11.52 365.98 5,945,394.15 316,030.10 HRZ 7,600.00 43.32 331.20 7,369.47 7,280.07 3.00 11.20 390.55 5,945,415.94 316,018.73 7,700.00 46.26 331.99 7,440.43 7,351.03 3.00 10.98 460.97 5,945,478.70 315,986.75 - 7,800.00 49.22 332.71 7,507.68 7,418.28 3.00 10.42 534.90 5,945,545.07 315,954.02 7,900.00 52.17 333.36 7,571.01 7,481.61 3.00 9.93 612.16 5,945,614.86 315,920.64 8,000.00 55.13 333.97 7,630.27 7,540.87 3.00 9.52 692.52 5,945,687.88 315,886.68 8,100.00 58.10 334.53 7,685.29 7,595.89 3.00 9.16 775.77 5,945,763.94 315,852.26 8,200.00 61.06 335.06 7,735.92 7,646.52 3.00 8.85 861.68 5,945,842.82 315,817.45 8,300.00 64.03 335.56 7,782.02 7,692.62 3.00 8.58 950.02 5,945,924.31 315,782.36 8,400.00 67.00 336.03 7,823.46 7,734.06 3.00 8.35 1,040.54 5,946,008.18 315,747.08 8,500.00 69.97 336.48 7,860.13 7,770.73 3.00 8.16 1,133.00 5,946,094.21 315,711.71 8,600.00 72.94 336.92 7,891.94 7,802.54 3.00 7.99 1,227.13 5,946,182.15 315,676.35 8,700.00 75.91 337.34 7,918.78 7,829.38 3.00 7.85 1,322.69 5,946,271.78 315,641.08 8,721.51 76.55 337.43 7,923.90 7,834.50 3.00 7.74 1,343.40 5,946,291.25 315,633.52 1 Alpine C 8,800.00 78.89 337.75 7,940.59 7,851.19 3.00 7.72 1,419.41 5,946,362.83 315,606.02 8,824.00 79.60 337.85 7,945.07 7,855.67 3.00 7.65 1,442.76 5,946,384.87 315,597.64 7" x 8.SW' 8,900.00 81.86 338.16 7,957.32 7,867.92 3.00 7.63 1,517.02 5,946,455.07 315,571.25 9,000.00 84.83 338.55 7,968.90 7,879.50 3.00 7.58 1,615.27 5,946,548.24 315,536.87 9,005.61 85.00 338.58 7,969.40 7,880.00 3.00 7.54 1,620.79 5,946,553.49 315,534.96 9,005.63 85.00 338.58 7,969.40 7,880.00 0.00 0.00 1,620.81 5,946,553.51 315,534.95 Start DLS 3.00 TFO 0.00 9,100.00 87.83 338.58 7,975.30 7,885.90 3.00 0.06 1,713.92 5,946,641.98 315,502.69 9,168.68 89.89 338.58 7,976.66 7,887.26 3.00 0.06 1,781.79 5,946,706.48 315,479.18 9,168.69 89.89 338.58 7,976.66 7,887.26 0.00 0.00 1,781.81 5,946,706.50 315,479.17 Start 6643.95 hold at 9168.69 MD MZXZU7U 77 JU.*bMM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips BAER Drilling Summary Report UG, ES a GEcompany Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MTG-04 Project: Western North Slope TVD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Site: GMT1 Lookout Pad MD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Well: MTS -04 North Reference: True Wellbore: MT6-04 Survey Calculation Method: Minimum Curvature Design: MT6-04 wp05 Database: EDT 14 Alaska Production Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) V) (°) (usft) lush) (°HDOusft) (°) (usft (usft) (usft) 9,200.00 89.89 338.58 7,976.72 2887.32 0.00 0.00 1,812.76 5,946,735.91 315,468.45 9,300.00 89.89 338.58 7,976.91 7,887.51 0.00 0.00 1,911.63 5,946,829.86 315,434.21 9,400.00 89.89 338.58 7,977.10 7,887.70 0.00 0.00 2,010.49 5,946,923.80 315,399.96 9,500.00 89.89 338.58 7,977.29 7,887.89 0.00 0.00 2,109.35 5,947,017.75 315,365.72 9,600.00 89.89 338.56 7,977.48 7,888.08 0.00 0.00 2,208.21 5,947,111.70 315,331.47 9,700.00 89.89 338.58 7,977.67 7,888.27 0.00 0.00 2,307.08 5,947,205.64 315,297.22 9,800.00 89.89 338.58 7,977.86 7,888.46 0.00 0.00 2,405.94 5,947,299.59 315,262.98 9,900.00 89.89 338.58 7,978.04 7,888.64 0.00 0.00 2,504.80 5,947,393.54 315,228.73 10,000.00 89.89 338.58 7,978.23 7,888.83 0.00 0.00 2,603.66 5,947,4B7.48 315,194.49 10,100.00 89.89 338.58 7,978.42 7,889.02 0.00 0.00 2,702.53 5,947,581.43 315,160.24 10,200.00 89.89 338.58 7,978.61 7,889.21 0.00 0.00 2,801.39 5,947,675.38 315,125.99 10,300.00 89.89 338.58 7,978.80 7,889.40 0.00 0.00 2,900.25 5,947,769.32 315,091.75 10,400.00 89.89 338.58 7,978.99 7,889.59 0.00 0.00 2,999.11 5,947,863.27 315,057.50 10,500.00 89.89 338.58 7,979.18 7,889.78 0.00 0.00 3,097.98 5,947,957.22 315,023.26 10,600.00 89.89 338.58 7,979.36 7,889.96 0.00 0.00 3,196.84 5,948,051.16 314,989.01 10,700.00 89.89 338.58 7,979.55 7,890.15 0.00 0.00 3,295.70 5,948,145.11 314,954.76 10,800.00 89.89 338.58 7,979.74 7,890.34 0.00 0.00 3,394.56 5,948,239.05 314,920.52 10,900.00 89.89 338.58 7,979.93 7,890.53 0.00 0.00 3,493.43 5,948,333.00 314,886.27 11,000.00 89.89 338.58 7,980.12 7,890.72 0.00 0.00 3,592.29 5,948,426.95 314,852.03 11,100.00 89.89 338.58 7,980.31 7,890.91 0.00 0.00 3,691.15 5,948,520.89 314,817.78 11,200.00 89.89 338.58 7,980.50 7,891.10 0.00 0.00 3,790.02 5,948,614.84 314,783.53 11,300.00 89.89 338.58 7,980.68 7,891.28 0.00 0.00 3,888.88 5,948,708.79 314,749.29 11,400.00 89.89 338.58 7,980.87 7,891.47 0.00 0.00 3,987.74 5,948,802.73 314,715.04 11,500.00 89.89 338.58 7,981.06 7,891.66 0.00 0.00 4,086.60 5,948,896.68 314,680.80 11,600.00 89.89 338.58 7,981.25 7,891.85 0.00 0.00 4,185.47 5,948,990.63 314,646.55 11,700.00 89.89 338.58 7,987.44 7,892.04 0.00 0.00 4,284.33 5,949,084.57 314,612.30 11,800.00 89.89 338.58 7,981.63 7,892.23 0.00 O.DO 4,383.19 5,949,178.52 314,578.06 8/232018 11:30.56AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips BAT BAA. ICER TVD Drilling Summary Report IGHES TFace V. Sec OEcompary Company: _ConocoPhillips Export Company Local Co-ordinate Reference: Well MT6-04 Project: Western North Slope TVD Reference: MT6-04 Q 89.40usfi (Doyon 19 Plan) Site: GMT1 Lookout Pad MD Reference: MTS -04 @ 89.40usft (Doyon 19 Plan) Well: MT6-04 North Reference: True Wellbore: MT6-04 Survey Calculation Method: Minimum Curvature Design: MT6-04 wp05 Database: EDT 14 Alaska Production 4,482.05 5,949,272.47 314,543.81 I Planned Survey 89.89 338.58 MD Inc Azi (azimuth) TVD TVDSS DLeg TFace V. Sec Northing Easting (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) 11,900.00 89.89 338.58 7,981.82 7,892.42 0.00 0.00 4,482.05 5,949,272.47 314,543.81 12,000.00 89.89 338.58 7,982.00 7,892.60 0.00 0.00 4,580.92 5,949,366.41 314,509.57 12,100.00 89.89 338.58 7,982.19 7,892.79 0.00 0.00 4,679.78 5,949,460.36 314,475.32 12,200.00 89.89 338.58 7,982.38 7,892.98 0.00 0.00 4,778.64 5,949,554.31 314,441.07 12,300.00 89.89 338.58 7,982.57 7,893.17 0.00 0.00 4,877.50 5,949,648.25 314,406.83 12,400.00 89.89 338.58 7,982.76 7,893.36 0.00 0.00 4,976.37 5,949,742.20 314,372.58 12,500.00 89.69 338.58 7,962.95 7,893.55 0.00 0.00 5,075.23 5,949,836.14 314,338.34 12,600.00 89.89 338.58 7,983.14 7,893.74 0.00 0.00 5,174.09 5,949,930.09 314,304.09 12,700.00 89.89 338.56 7,983.33 7,893.93 0.00 0.00 5,272.95 5,950,024.04 314,269.64 12,800.00 89.89 338.58 7,983.51 7,894.11 0.00 0.00 5,371.82 5,950,117.98 314,235.60 12,900.00 89.89 338.56 7,963.70 7,894.30 0.00 0.00 5,470.68 5,950,211.93 314,201.35 13,000.00 89.89 338.58 7,983.89 7,894.49 0.00 0.00 5,569.54 5,950,305.88 314,167.11 13,100.00 89.89 338.58 7,984.08 7,894.68 0.00 0.00 5,668.41 5,950,399.82 314,132.86 13,200.00 89.89 338.58 7,984.27 7,894.87 0.00 0.00 5,767.27 5,950,493.77 314,098.61 13,300.00 89.89 338.58 7,984.46 7,895.06 0.00 0.00 5,866.13 5,950,567.72 314,064.37 13,400.00 89.89 338.58 7,964.65 7,895.25 0.00 0.00 5,964.99 5,950,681.66 314,030.12 13,500.00 89.69 338.58 7,984.83 7,895.43 0.00 0.00 6,063.86 5,950,775.61 313,995.88 13,600.00 89.89 338.58 7,985.02 7,895.62 0.00 0.00 6,162.72 5,950,869.56 313,961.63 13,700.00 89.89 338.56 7,985.21 7,895.81 0.00 0.00 6,261.58 5,950,963.50 313,927.38 13,800.00 89.89 338.58 7,985.40 7,896.00 0.00 0.00 6,360.44 5,951,057.45 313,893.14 13,900.00 89.89 338.58 7,985.59 7,896.19 0.00 0.00 6,459.31 5,951,151.40 313,858.89 14,000.00 89.89 338.58 7,985.78 7,896.38 0.00 0.00 6,558.17 5,951,245.34 313,824.65 14,100.00 89.89 338.58 7,985.97 7,896.57 0.00 0.00 6,657.03 5,951,339.29 313,790.40 14,200.00 89.89 338.58 7,986.15 7,896.75 0.00 0.00 6,755.89 5,951,433.23 313,756.15 14,300.00 89.89 338.58 7,986.34 7,896.94 0.00 0.00 6,854.76 5,951,527.18 313,721.91 14,400.00 89.89 338.58 7,986.53 7,897.13 0.00 0.00 6,953.62 5,951,621.13 313,687.66 14,500.00 89.89 338.58 7,986.72 7,897.32 0.00 0.00 7,052.48 5,951,715.07 313,653.42 W32018 11:30:56AM Page 9 COMPASS 5000.14 Build 85 ConocoPhillips TVDSS (usft) Company: _ConocoPhillips Export Company TFace (°) Project: Western North Slope Northing (usft) Site: GMT1 Lookout Pad 7,986.91 Well: MT6-04 0.00 Wellbore: MT6-04 7,151.34 Design: MT6-04 wp05 313,619.17 Planned Survey 7,897.63 MD Inc Azi (azimuth) (usft) 7,215.61 14,600.00 89.89 338.58 14,665.00 89.89 338.58 4-112" x 6.1/8" 0.00 14,700.00 89.89 338.58 14,800.00 89.89 338.58 14,812.64 89.89 338.58 TD at 14812.64 7,349.07 14,812.65 89.89 338.58 Casing Points ConocoPhillips Drilling Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: BA ER I IGHES BAT Well MT6-04 MT6-04 @ 89.40usft (Doyon 19 Plan) MT6-04 @ 89.40usft (Doyon 19 Plan) True Minimum Curvature EDT 14 Alaska Production TVD (usft) TVDSS (usft) DLeg (°/1DDusft) TFace (°) V. Sec (usft) Northing (usft) Easting (usft) 7,986.91 7,897.51 0.00 0.00 7,151.34 5,951,809.02 313,619.17 7,987.03 7,897.63 0.00 0.00 7,215.61 5,951,870.09 313,596.91 7,987.10 7,897.70 0.00 0.00 7,250.21 5,951,902.97 313,584.92 7,987.29 7,897.89 0.00 0.00 7,349.07 5,951,996.91 313,550.68 7,987.31 7,897.91 0.00 0.00 7,361.57 5,952,008.79 313,546.35 7,987.31 7,897.91 0.00 0.00 7,361.58 5,952,008.80 313,546.35 7,342.91 HRZ 8.721.51 7,923.90 Alpine C Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,053.00 2,034.33 13-3/8" x 16" 13.375 16.000 7,516.00 7,307.13 9-5/8" x 12-1/4" 9.625 12.250 8,824.00 7,945.07 7"x8-3/4" 7.000 8.750 14,665.D0 7,987.03 4-1/2"x6-1/8" 4.500 6.125 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology, 7.563.81 7,342.91 HRZ 8.721.51 7,923.90 Alpine C 823/2018 11:30:56AM Page 10 COMPASS 5000.14 Build 85 ConocoPhillips BA, ICER COnOCOPhiIIipS Drilling Summary Report IGHES aGEcompany Company: _ConocoPhillips Export Company Local Coordinate Reference: Well MT6-04 Project: Western North Slope TVD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Site: GMT1 Lookout Pad MD Reference: MT6-04 @ 89.40usft (Doyon 19 Plan) Well: MT6-04 North Reference: True Wellbore: MT6.04 Survey Calculation Method: Minimum Curvature Design: MT6-04 wp05 Database: EDT 14 Alaska Production Plan Annotations Measured Vertical Depth Depth (usft) (usft) 737.20 737.20 1,311.23 1,307.40 2,017.97 2,000.00 2,117.97 2,098.00 2,428.19 2,400.00 3,428.19 3,365.16 3,677.92 3,609.78 6,120.19 6,030.17 9,005.63 7,969.40 9,168.69 7,976.66 14,812.64 7,987.31 Checked By: Local Coordinates +N/4 +E/ -W (usft) (usft) 0.00 0.00 -46.95 -32.88 -162.18 -113.56 -178.49 -124.98 -225.93 -176.77 -368.51 -396.17 -395.40 -437.63 -572.38 -711.58 965.17 -1,567.80 1,116.77 -1,627.28 6,370.88 -3,688.43 Comment Start Build 2.00 Start 706.74 hold at 1311.23 MD Start 100.00 hold at 2017.97 MD Start DLS 2.00 TFO 65.00 Start 1000.00 hold at 2428.19 MD Start DLS 3.00 TFO 179.86 Start 2442.26 hold at 3677.92 MD Start DLS 3.00 TFO 102.01 Start DLS 3.00 TFO 0.00 Start 5643.95 hold at 9168.69 MD TD at 14812.64 Approved By: Date: 823/2018 11:30:56AM Page 11 COMPASS 5000.14 Build 85 ConocoPhillips(Alaska) Inc. -WNS Western North Slope GMT1 Lookout Pad MT6-04 MT6-04 MT6-04 wp05 ConocoPhillips Clearance Summary Anticollision Report 24 August, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) Reference Design: GMT1 Lookout Pad - MT6-04 - MT6-04 - MT6-04 wp05 Well Coordinates: 5,945,295.47 N, 1,457,113.24 E (701 15' 21.79" N, 151° 28' 53.66" W) Datum Height: MT6-04 @ 89.40usft (Doyon 19 Plan) Scan Range: 0.00 to 14,812.64 usft. Measured Depth. Scan Radius is 9,999.98 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: . • - _ Scan Type: ConocoPhillips ConocoPhillips (Alaska) Inc. -WNSConocoPhillips Western North Slope Anticollision Report for MT6-04 - MT6-04 wp05 819.14 Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) 819.53 Reference Design: GMT1 Lookout Pad - MT6-04 - MT6-04 - MT6.04 wp05 Clearance Factor Scan Range: 0.00 to 14,812.64 usft. Measured Depth. MT6-05 - MT6-05 - MT6-05 Scan Radius is 9,999.98 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 19.97 Measured Minimum @Measured Ellipse Site Name @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft GMT1 Lookout Pad MT6-03 - MT6-03 - MT6-03 819.14 17.84 819.14 4.46 819.53 1.333 Clearance Factor Pass - Major Risk MT6-05 - MT6-05 - MT6-05 37.20 19.97 37.20 18.75 36.50 16.311 Centre Distance Pass - Major Risk MT6-05 - MT6-05 - MT6-05 296.95 21.50 296.95 15.16 296.26 3.390 Clearance Factor Pass - Major Risk MT6-05 - MT6-051-1 - MT6-0511 37.20 19.97 37.20 18.75 36.50 16.311 Centre Distance Pass - Major Risk MT6-05 - MT6-051-1 - MT6-051-1 296.95 21.50 296.95 15.16 296.26 3.390 Clearance Factor Pass - Major Risk MT6-05 - MT6-05PB1 - MT6-05PB1 37.20 19.97 37.20 18.75 36.50 16.311 Centre Distance Pass - Major Risk MT6-05 - MT6-05PB1 - MT6-05PB1 296.95 21.50 296.95 15.16 296.26 3.390 Clearance Factor Pass - Major Risk MT6-05 - MT6-05PB2 - MT6-05PB2 37.20 19.97 37.20 18.75 36.50 16.311 Centre Distance Pass - Major Risk MT6-05 - MT6-05PB2 - MT6-05PB2 296.95 21.50 296.95 15.16 296.26 3.390 Clearance Factor Pass - Major Risk MT6-06 - MT6-06 - MT6-06 wp05 319.40 39.98 319.40 34.06 319.40 6.759 Centre Distance Pass - Major Risk MTB -06 - MT6-06 - MT6-06 wp05 399.99 40.45 399.99 33.15 400.00 5.546 Clearance Factor Pass - Major Risk MTB -08 - MT6-08 Lower Let - MT6-08 1,153.80 70.21 1,153.80 52.71 1,149.35 4.010 Clearance Factor Pass - Major Risk MT6-08 - MT6-08PB1 Lower Let -MT6-08PB7 1,153.80 70.21 1,153.80 65.71 1,149.35 15.582 Clearance Factor Pass - Minor 1/20 Survey too/ program From To Survey/Plan Survey Tool (usft) (usft) 37.20 1,100.00 MT6-04 wp05 GYD-GC-SS 1,100.00 2,053.00 MT6-04 wp05 MWD 1,100.00 2,053.00 MT6-04 wp05 MWD+IFR-AK-CAZ-SC 2,053.00 7,516.00 MT6-04 wp05 MWD 2,053.00 7,516.00 MT6-04 wp05 MWD+IFR-AK-CAZ-SC 7,516.00 8,824.00 MT6-04 wp05 MWD 7,516.00 8,824.00 MT6-04 wp05 MWD+IFR-AK-CAZ-SC 8,824.00 14,812.64 MT6-04 wp05 MWD 8,824.00 14,812.64 MT6-04 wp05 MWD+IFR-AK-CAZ-SC 24 August, 2018 - 11:45 Page 2 of 5 COMPASS ConocoPhillips Anticollision Report for MT6-04 - MT6-04 wpO5 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. ConocoPhillips(Alaska) Inc. -WNS Western North Slope 24 August, 2018 - 11:45 Page 3 of 5 COMPASS ConocoPhillips Anticollision Report for MT6-04 - MT6-04 wp05 Lnleulvll ellu wulmna[es are relative to I rue North Reference. Vertical Depths are relative to MT6-04 @ 89.40usft (Doyon 19 Plan). Northing and Easting are relative to MT6-04. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -1.39 ". Con ocoPhillips(Alaska) Inc. -WNS Western North Slope Ladder Plot C I I I I I E3SFJ AGO I � I I I I C3 I I 1 I I I ----- ----; -- - - ----------------------;--- LEGEND C I I I I I 0 -�- MT6-03, MT6-03, MT6-03 VO tE 300 $ MT6-05, MT6-05, MT6-05 VO C 1 MT6-05, Mr6-05PB1, MT6-05PB1 V0 I $ MT6-05, MT6-05PB2, MT6-05PB2 VO -___t___ a)- - i I � I 1 $MT6-06, Mi6-06, Mi6-06 wp05 VO I I -d- MT6-08, MT6-08 Lower Lal MTS -08 V0 -E- MT6-08,MT6-0SP81Lower La MT6-08PB1V0 U 1500--1 1 t O $ M16-05, MT6-051-1, MT6-0511 VO $ WB -04 wpO5 I I I I I L I_ —I _I_ — I I I I I I I f I I 1 1 I I I I I I I 1 0 0 3000 6000 9000 12000 15000 Measured Depth (3000 usft/in) 24 August, 2016 - 11:45 Page 4 of 5 COMPASS ConocoPhillips Anticollision Report for MT6-04 - MT6-04 wp05 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 10.00- 0.008.757.506.250 8.75- 7.50-- 6.25-- 0 m LL 5.00 `m iu U) 3.75 2.50- 1.25- 0.00 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 Measued Deloth (2500 usfn) ConocoPhillips(Alaska) Inc. -WNS Western North Slope LEGEND -)(- MT6-03, MT6-03, MT6-03 V0 $ MT6-05,MT6-05,MT6-05V0 -1E- MT6-05,MT6{15PB1,MT6-05PB1 V0 "rte MT505,MT6-05PB2,MT6-05PB2V0 MT6-06, MT6-06, MT6-06 wp05 V0 -� MT6-08, MT6-08 Lower Lat MT6-08 V0 -if MT6-08,MT6-08PB1 Lower Lat MT6-08PB1 V0 $ MT6-05,MT6-05L1,MT6-05L1V0 $ MT6-04wp05 24 August, 2018 - 11:45 Page 5 o/5 COMPASS Schwartz, Guy L (DOA) From: Marushack, Andy J <Andy.J.Marushack@conocophiIli ps.com> Sent: Tuesday, September 25, 2018 10:30 AM To: Schwartz, Guy L (DOA) Cc: Davies, Stephen F (DOA); Rixse, Melvin G (DOA) Subject: RE: [EXTERNAL]Mt6-04 Injector. (PTD 218-108) Attachments: Surface Casing Plot.xps; MT6 Spider Plot.xps Follow Up Flag: Follow up Flag Status: Flagged Hello Guy, 1) 1 have attached the requested spider plots. Please let me know if you need more detail. 2) The idea for dropping the tie back was to eliminate the need for a 7" casing spool. We have been running the tie back to cover the lower section of the 9 5/8" casing that fails production load tests due to casing wear. With us not running SDL on 04, 1 was able to extend the length of the liner lap to cover the weak sections of the 9 5/8" casing. As of yesterday though, my plans have been over ruled and we will be setting the 7" liner similar to previous wells with —150+' inside the 9 5/8" casing and tying back to surface. With this in mind, I will probably increase the volume of cement pumped on the 7" liner. I apologies the PTD does not reflect these changes, I had previously had buy in form management. 3) As you suggest, we will run the SCMT tool to log the 7" cmt job when running the production liner. If you have any more questions, please let me know. Sincerely, Andy 832-525-8923 From: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Sent: Monday, September 24, 2018 2:53 PM To: Marushack, Andy <Andy.J.Marushack@conocophillips.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: [EXTERNAL]Mt6-04 Injector. (PTD 218-108) Andy, A couple of questions for you regarding permit. 1) Since you are requesting a waiver on the Diverter system I need a spider map showing existing and proposed surface casing shoe locations. 2) Why are you omitting the 7" tieback casing in this well as opposed to the previous MT6 wells? 3) A CBL will be required in the 7" liner ... suggest using memory CBL when you install the 4.5" perfed liner. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell r 907-793-1226 office CONFIDENTIALITY NOTICE., This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz®alaska.gov). 40D k'b0S �6 j' MT6. p' MT6, p� Wp p3 0raftA 0 �p09 M�0 0g1��6 09 08 px1 v 1 ISO s° 600[ i 5000 i O�atP .9m TiirrP -10000 -8000 -7000 -6000 -5000 4000 -3000 3-3/6" x 16" 3000 3000 From: Marushack, Andy J To: Boyer David L (DOA) Subject: Re: [EXTERNAL]Correct KB & GL for MT6-04 Well Date: Friday, September 7, 2018 6:12:09 PM Hello Dave, That is correct. Sorry for the confusion. Sincerely, Andy Sent from my iPhone On Sep 7, 2018, at 3:57 PM, Boyer, David L (DOA) <davd.boyer2 a)alaska.gov> wrote: Hi Andy, In reviewing the Permit to Drill for the MT6-04 well, Steve noticed that on the permit form, the KB=70' and the GL=34'. On the Baker Hughes Directional Survey, the KB=89.4' and the GL=37.20'. Can we assume that the values in wp05 are the ones we should enter into our database since those are the ones the DD will be using on wellsite? Thanks, Dave B. & Steve D. From: Marushack, Andy J To: Boyer David L (DOA) Subject: RE: [EXTERNAL]Digital Survey File forMT6-04 Well Date: Thursday, August 30, 2018 7:47:56 AM Attachments: MT6-04 wo5 xlsx Hello Dave, No problem. Let me know if you need anything else. Sincerely, Andy From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Wednesday, August 29, 2018 4:32 PM To: Marushack, Andy J <Andy.J.Marushack@conocophillips.com> Subject: [EXTERNAL] Digital Survey File forMT6-04 Well Hi Andy, We are beginning the review of the Permit to Drill packet for the ConocoPhillips MT6-04 proposed well. Is it possible to send an e-mail with the digital file of the directional plan in Excel or ASCII format so we can load it more efficiently into our PTD database? The whole file is fine but we only need the MD, inclination, and azimuth columns for our program. Thank you, Dave Boyer AOGCC TRANSMITTAL LETTER CHECKLIST WELLNAME: G MTU, tlr-Fr—n[+ PTD: d,1 R -I oR Development y Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: M DOs&S TCbI� POOL: l ewk5= cL+ 100 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. SO - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_ -� from records, data and logs acquired for well name on permit). ' The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, leer curves for well logs run must be submitted to the AOGCC ,v Icomposite within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool GRTR MOOSES TOOTH, LOOKOUT OIL - 2821 PTD#:2181080 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: GMTU MT§_04_ ____ Program SER Well bore seg ❑ SER / PEND GeoArea 890 Unit 1070 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven, gas conforms to AS31,05.030(j 1.A),(j ZA-D) _ _ _ _ _ NA 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 Conservation Order No. 747, issued -May 29, 2018.. governs Lookout Oil Pool. 5 Well located proper distance from drilling unit. boundary _ _ _ _ Yes 6 Well located proper distance from other wells _ Yes 7 Sufficient acreageavailable indrillingunit_ _ _ _ _ _ _ _ _ _ _ _ _ Yes 8 If deviated, is wellbore plat. included _ No - 9 Operator only affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 10 Operator hasappropriatebond in force _ _ _ _ _ _ Yes Appr Date 11 Permit can be issued without conservation order- _ _ _ _ . _ _ ... Yes 12 Permit can be issued without administrative approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes DLB 9/5/2018 _ _ _ _ 13 Can permit be approved before 15 -day wait. _ _ ................ . . . . . NA 14 Well located within area and strata authorized by Injection Order # (put 10# in.comments)_(For. Yes _ .... Area Injection Order No.. 40, issued May 29, 2016, governs Lookout Oil Pool. 15 All wells. within 1/4. mile area of review identified (For service well only). _ _ _ _ _ Yes _ _ _ _____ 16 Pre -produced injector: duration of pre production less than 3 months (For service well only) ...NA ______ 18 Conductor stringprovided- - - - - - - - _ _ _ _ _ _ _ _ _ _ _Yes - - - - - - - 20" conductor set at 115' Engineering 19 Surface casing. protects all known USDWs.. _ _ _ _ _ NA - - no freshwater,. Permafrost.. 20 CMT vol adequate to circulate on conductor & surf csg Yes 13 318" casing will be fully cemented 21 CMT vol adequate to tie-in long string to. surf csg. ..... .. _ .. _ _ _ Yes _ _ ... 9 5/8"_ int -l-casing will be cemented 500 it 22 CMT will cover all known. productive horizons. _ _ _ _ _ _ _ _ Yes .. - Horz. Lateral will have pre perf liner 23 _Casing designs adequate for C, T, B & permafrost... _ _ _ _ _ _ Yes 24 Adequate tankage. or reserve pit _ _ _ _ _ _ _ _ _ _ _ .. Yes _ Rig has steel pits, All waste to approved AD well.. _ 25 If a re -drill, has. a 10-403 for abandonment been approved ........ _ NA _ _ _ grassroots injector well. 26 Adequate. wellbore separation proposed _ _ _ _ Yes No issues with collision_ 27 If diverter required, does it meet regulations_ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA Diverter waived ... 4 other pad penetrations had -no -indication. of shallow gas, Appr Date 28 Drilling fluid program schematic & equip list adequate. _ . _ . _ Yes _ _ _ Max form pressure= 3810 -psi- ( 9.2 ppg EMW) will drill using 9.5 ppg mud and -MPD tocontrol BHP. - GLS 9/24/2018 29 BOPEs, do they meet regulation _ _ Yes Doyon 19 has-BOPE_info on file 30 BOPE.press rating appropriate; test to (put psig in comments) . . . ......... . Yes _ _ _ _ _ _ MASP =3015 psi _ Will test BOPE to 3500 psi 31 Choke. manifold complies w/API RP -53 (May 84) _ _ _ _ _ _ _ _ Yes 32 Work will occur withoutoperationshutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - Frac stimulation is not planned, 33 Is presence of H2S gas probable _ .. No 34 .Mechanical -condition of wells within AOR verified (for service well only) _ _ _ _ _ Yes _ _ _ _ _ 1/4 mile review completed. No current wells in the study area, 35 Permit can be issued w/o hydrogen_ sulfide measures _ _ .... Yes _ _ _ Only MT6-03 bas been flowed back to date but no H2S was. encountered -in that well.. Geology 36 Data presented on potential overpressure zones . . . . . ... ...... _ _ Yes Drilling fluid programappears adequate. to control operator's forecast pressures. Appr Date 37 Seismic analysis of shallow gas zones. .... ...... _ _ NA DLB 9/5/2018 38 _Seabed condition survey (if off -shore) _ _ _ _ NA - - - - - - - J 39 Contact name/phone for weekly.progress reports [exploratory only] _ _ _ _ _ _ NA _- Geologic Engineering Public Date This well will not be drilled with the steerable 7" liner. Using MPD for BHP & shale control. GIs Date: Date Commissioner: Commissioner: Commissioner
