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219-009
DATA SUBMITTAL COMPLIANCE REPORT 5/24/2019 Permit to Drill 2190090 Well Name/No. GMTV MT6-021-1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20792-60-00 MD 19930 TVD 7868 Completion Date 2/14/2019 Completion Status WAGIN Current Status WAGIN UIC Yes REQUIRED INFORMATION Mud Log No.,/ Samples No ✓ Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR/Res/CBL/Density (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments ED C 30441 Digital Data 3/13/2019 Electronic File: MT6-0211 EOW - NAD27.pdf ED C 30441 Digital Data 3/13/2019 Electronic File: MT6-0211 EOW - NAD27.txt ED C 30441 Digital Data 3/13/2019 Electronic File: MT6-021-1 EOW - NAD83.pdf ED C 30441 Digital Data 3/13/2019 Electronic File: MT6-0211 EOW - NAD83.txt Log C 30441 Log Header Scans 0 0 2181340 GMTU MT6-09 LOG HEADERS ED C 30830 Digital Data 76 19931 5/22/2019 Electronic Data Set, Filename: MT6-0211 LTK Memory Drilling Data.las ED C 30830 Digital Data 5/22/2019 Electronic File: MT6-0211 Drilling Mechanics Depth Log.cgm ED C 30830 Digital Data 5/22/2019 Electronic File: MT6-0211 LTK 21AD Memory Log.cgm ED C 30830 Digital Data 5/22/2019 Electronic File: MT6-0211 LTK 5MD Memory Log.cgm ED C 30830 Digital Data 5/22/2019 Electronic File: MT6-0211 LTK 5TVD Memory Log.cgm ED C 30830 Digital Data 5/22/2019 Electronic File: MT6-0211 LTK Memory Drilling Data.dls ED C 30830 Digital Data 5/22/2019 Electronic File: MT6-0211 Drilling Mechanics Depth Log. pdf ED C 30830 Digital Data 5/22/2019 Electronic File: MT6-021-1 LTK 2MD Memory Log.pdf ED C 30830 Digital Data 5/22/2019 Electronic File: MT6-0211 LTK 5MD Memory Log.pdf ED C 30830 Digital Data 5/22/2019 Electronic File: MT6-021-1 LTK 5TVD Memory Log.pdf AOGCC Page 1 of 2 Friday, May 24, 2019 DATA SUBMITTAL COMPLIANCE REPORT 5/24/2019 Permit to Drill 2190090 well Name/No. GMTU MT6.021-7 Operator CONOCOPHILLIPS ALASKA, INC. MD 19930 TVD 7868 Completion Date 2/14/2019 ED C 30830 Digital Data ED C 30830 Digital Data ED C 30830 Digital Data ED C 30830 Digital Data Log C 30830 Log Header Scans Well Cores/Samples Information Name INFORMATION RECEIVED Completion Report 0 Production Test Information Y / J9 Geologic Markers/Tops YY COMPLIANCE HISTORY Completion Date: 2/14/2019 Release Date: 1/30/2019 Description Comments: Compliance Reviewed Interval Start Stop Directional / Inclination Data /( API No. 50-103-20792-60-00 Completion Status WAGIN Current Status WAGIN UIC Yes 522/2019 Electronic File: MT6-021-1 EOW - NAD27.pdf 5/22/2019 Electronic File: MT6-021-1 EOW - NAD27.txt 522/2019 Electronic File: MT6-021-1 EOW - NAD83.pdf 5/22/2019 Electronic File: MT6-021-1 EOW - NAD83.txt 0 0 2181340 GMTU MT6-091-1 LOG HEADERS Mechanical Integrity Test Information Y / NA Daily Operations Summary Date Comments Sample Set Sent Received Number Comments Mud Logs, Image Files, Digital Data Y Composite Logs, Image, Data Files P Cuttings Samples Y/® Date: Core Chips Y / 6 Core Photographs Y / " Laboratory Analyses Y / J� AOGCC Page 2 of 2 Friday, May 24, 2019 Winston, Hugh E (DOA) From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod @co ntractor.conocophiIli ps.com> Sent: Thursday, March 21, 2019 3:20 PM To: Winston, Hugh E (DOA) Cc: Beat, Andrew T Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Attachments: MT6-02 10-407 PTD NEW WELL Completion.pdf, MT6-021-1 10-407 PTD NEW WELL COMPLETION.pdf Good afternoon, I have attached copies of the updated page 1 of both MT6-02 and MT6-021-1 and I will come by with hard copies after work today. I will put them in an envelope addressed to you. Again my apologies for this inconvenience and thank you very much for your patience. Thanks, Ann From: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Sent: Thursday, March 21, 2019 9:39 AM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Sounds good, let me know when you hear back Huey From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Sent: Wednesday, March 20, 2019 3:32 PM To: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Hi, It is looking very much like I will need to reprint page one for both MT6-02 and MT6-021-1 because we may need to swap the liner (box 24). I am waiting to hear back from the engineer. I am so sorry for this delay. From: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Sent: Tuesday, March 19, 2019 1:13 PM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Haggerty -Sherrod @contractor.conocophil I ips.com> Cc: Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Hi Ann, Great, that fixed both! Thanks for the quick reply. No need to send a new copy, I will hand edit the form we have. Thanks Huey From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann Haggerty-Sherrod@contractor.conocophillips.com> Sent: Tuesday, March 19, 2019 12:20 PM To: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Subject: RE: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Hi Huey, I am so sorry, I have no clue how I made this error but I have checked this morning twice and these boxes are incorrect for both MT6-02 and MT6-021-1 API# 50103207920000 PTD#218-160 Well: MT6-02 Box 4a Total dept 4802' FNL, 1732' FEL, Sec 13, T11N, R2E, LIM API# 50103207926000 PTD#219-009 Well: MT6-021-1 Box 4a Total dept 2359' FNL, 1641' FEL, Sec 24, T11N, R2E, LIM Do these calculate with your coordinates? And if so should I send you a new top sheet. I will change ours if you agree that these are correct. From: Winston, Hugh E (DOA) <hugh.winston@alaska.gov> Sent: Tuesday, March 19, 2019 11:56 AM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann Haggerty-Sherrod@contractor.conocophillips.com> Cc: Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Subject: [EXTERNAL]MT6-02, PTD#218-160, Well Location Verification Hi Ann, My name is Huey, I'm a Stat Tech for the AOGCC. I am inputting data from a well completion report and I was hoping you could verify that the coordinates given in the report are accurate. Our database calculates the state coordinates and compares them with what is given in box 4b and the numbers aren't aligning for location at total depth. The survey report has the same numbers as what is listed is 4b so perhaps the problem is with the coordinates in box 4a. Could you please verify the information is both boxes for the TD? Thanks API# 50103207920000 PTD#218-160 Well: MT6-02 Huey 4, •v-C� STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION MAR WELL COMPLETION OR RECOMPLETION REPORT AND, ta. Well Status: Oil❑ Gas El SPLUG E]Other ElAbandoned ❑ Suspended El1b. 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WAG[7] WDSPL❑ No. of Completions: Well Class: ° � i Development ❑ Exploratory ❑ Service ❑� Stratigraphic Test E] 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 2/14/2019 14. Permit to Drill Number / Sundry: 219.009 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 1/31/2018 15. API Number: 50-103-20792-60-00 4a. Location of Well (Governmental Section): Surface: 239' FNL, 3115' FEL, Sec 6, T1 ON, R3E, UM Top of Productive Interval: 4260' FNL, 1847' FEL, Sec 30, T11 N, R3E, UM Total Depth: 2359' FNL, 1641' FEL, Sec 24, T11N, R2E, UM 8. Date TO Reached: 216/2019 16. Well Name and Number: MT6-02L1 9. Ref Elevations: KB:89 GL: 37 BF: 17. Field / Pool(s): Greater Mooses Tooth Unit(Lookout Pool 10. Plug Back Depth MDfrVD: NIA 18. Property Designation: AA 81818, 92346, 81798, 92345, 81743 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317115 y- 5945564 Zone- 4 TPI: x- 318516 y- 5952070 Zone- 4 Total Depth: x- 313911 y- 5959366 Zone- 4 11. Total Depth MD/TVD: . 19930/7868 - 19. DNR Approval Number: 932563. 340761. 932533, 340760 12. SSSV Depth MD/TVD: NIA 20. Thickness of Permafrost MDfTVD: 1198/1189 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (ft MSL) 21. Re-drill/Lateral Top Window MD11 VD: • 11728/7932 - 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/CBL/Density 23. CASING, LINER AND CEMENTING RECORD CASING WT' PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 20 94 H-40 37 115 37 115 42 10 yds 13.375 68 L-80 36 2080 36 2020 16 1101 sx 11.Oppg, Class B. 9.625 40 L-80 34 8742 34 7070 12.25 239 sx 12.2ppg, Class G 7 26 L-80 32 //p S9' 32 4 p 8.75 263 sx 15.8ppg, Class G 4.5 12.6 L-80 10898 19391 l(7V 7888 7914 y TL 15 Slotted Liner 24. Open to production or injection? Yes 0 No If Yes, list each interval open (MDfTVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: 14917-20905 MD and 7888-7914...219/2019 COMPLETION D E ZD 9 VE- I IFI D r� 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDRVD) 4 112 10909 10897/7888 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): INJECTION ONLY - NOT PRE -PRODUCED Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casinq Press: I lCalculated 124 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (cord: Form 10-407 Revised 512017 lX ��9 / y CONTINUED ON PAGE 2 Submit ORIGINAL only �t it ly RBDMS� MAR 2 2 2019 1/`�Ar " F.�1�w"11 V Lel STATE OF ALASKA MAR 10 2019 ALASKA OIL NO GAS CONSERVATION COMMISSION WELL COM - R RECOMPLETION REPORT A 1a., Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory ❑ Service ❑� Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 2/13/2019 14. Permit to Drill Number/ Sundry: 219-009 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 1/31/2018 15. API Number: 50-103-20792-60-00 4a. Location of Well (Governmental Section): Surface: 239' FNL, 3115' FEL, Sec 6, T10N, R3E, UM Top of Productive Interval: 4260' FNL, 1847' FEL, Sec 30, T11 N, R3E, UM Total Depth: 2351, /ot l zN HEW ASS "FNL, 2,W FEL, Sec O, T11N, R2E, UM 8. Date TO Reached: 2/6/2019 16. Well Name and Number: MT6.02L1 9. Ref Elevations: KB:89 GL: 37 BF: 17. Field / Pool(s): Greater Mooses Tooth UnitiLookout Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: AA 81818, 92346, 81798, 92345, 81743 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317115 y- 5945564 Zone- 4 TPI: x- 318516 y-5952070 Zone- 4 Total Depth: x- 313911 y- 5959366 Zone- 4 11. Total Depth MO/TVD: 19930/7868 19. DNR Approval Number: 932563. 340761. 932533, 340760 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1198/1189 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 11728/7932 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/CBL/Density 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 20 94 H-40 37 115 37 115 42 10 yds 13.375 68 L-80 36 2080 36 2020 16 1101 sx 11.0ppg, Class B, 9.625 40 L-80 34 8742 34 7070 12.25 239 sx 12.2ppg, Class G 7 26 L-80 32 7885 32 6454 8.75 263 sx 15.8ppg, Class G 4.5 12.6 L-80 10897 19391 7888 7904 6 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Slotted Liner @: 14917-20905 MD and 7939- 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 10909 10897/7888 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑e Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): INJECTION ONLY - NOT PRE -PRODUCED Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas-MCF:Water-Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casino Press: I lCalculated 124 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑Q If Yes, list formations and intervals cored (MDRVD, 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 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1198 1189 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 11000 7897 information, including reports, per 20 AAC 25.071. Formation @ TPI - C-30 2144 2078 C-10 2574 2455 K-3 3702 3406 K-2 4025 3669 Albian 96 4479 4218 HRZ 8361 6797 LCU 6264 7406 Top Alpine C 10714 7872 22228 7834 Formation at total depth: 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 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Andrew Beat Authorized Title: Alaska Drilling Manager Contact Email: andrew.t.beat co .com Authorized Contact Phone: 265-6341 e,. + IAC 2Di Signature: Date: 51 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 ta: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Page 1 of 1 TOO ec Nan 300' MO 4-A" 11.Y L46 TIN Dkm above Packer 8600' v pw pupa MO abov. Alpin. C. 3ldetreck PoInt MT8-020 Planned W liner Top 11,728' MD / 7,932' TVD 19,930' MD 17,8881 TVD Top Alpin. 0 t 1 000 M0171"07' TVO 7^ zf ppr Lao MT8-02 TD 22,228' MD / 7,834' TVD Feb uery 1019 - ATO file:///S:/ANC/Longtenn/Drilling%20&%20 Wells%200ps/Alpine/MT6/MT6-02%20(E)/S... 3/19/2019 t0• Tf pp, H401nauNfW Conductor 13 00 feet. ofmonted to audaoe 1941' 09 Pot L-00 TEPIOTCM 6.0... C.elnf 4112" 12.6 PPI 410 T.oerN elua f Wil" 10 ppl140 TXP Ito-A,ffO' M01 9 549" e0 opt TN40 Hb TAP Ito TD) TOO ec Nan 300' MO 4-A" 11.Y L46 TIN Dkm above Packer 8600' v pw pupa MO abov. Alpin. C. 3ldetreck PoInt MT8-020 Planned W liner Top 11,728' MD / 7,932' TVD 19,930' MD 17,8881 TVD Top Alpin. 0 t 1 000 M0171"07' TVO 7^ zf ppr Lao MT8-02 TD 22,228' MD / 7,834' TVD Feb uery 1019 - ATO file:///S:/ANC/Longtenn/Drilling%20&%20 Wells%200ps/Alpine/MT6/MT6-02%20(E)/S... 3/19/2019 WNS INJ WELLNAME MT6-02 WELLBORE MT6-02 g'� 7 Well Attribute' Fax t TD �0�''I'ia� 1 [LOOK Name WellOore APYUWI WeIIM,e status ncl l'1 MGInA ---17"2' CI BIm IRKS) Alaska. ITC: LOOKOUT 5010320]9200 WJ 5.15 19,]21 J4 22228.0 eRy-m.ardpGd bd sGPM Last Tag Vee�vxnmmlamnn Annotation ae iftal 1 End Dao I W¢IIWre Usst MI By ...._._ ...... .......... ._._.... _LAST TAG: I ldalp2 ijennalt HANGER: mS-a Last Rev Reason Annotation End pate Yhllaw. bast Moa By REV REASON. Post Rig Well Work ZIt&2019 H,I jenUs1 Casing Strings casing Gesnnplbn do (an) to ('In) TOPIRKBI Set Oegn(MB) sH Upo tnum) ANL.. p_. Grade Toamasina! CONDUCTOR 20 19.12 360 115.0 115.0 9400 H40 Welded Using Descnprs. OD 6n) to (in) Top(nKB) SN annual (MB) Se[ oeptn OVER... VALLE 0... Goals moorlandood SURFACE 133M 12.40 38.0 2,0604 2,0202 68.00 1430 TXP Casing oesadp[bn apple to lin) To, WSJ BN oepnall W Depth 1TVa1... VHM1en O... Giants Top Thread INTERMEDIATE 9518 8.84 34.3 8,742.5 70]B4 40.00 TN -80 TXP CONDUCiOFL J§,61t50 .,"zap Using oescriptbn Oa lin) In (in) TIEBACK STRING ] 6.18 Tap We) SN Cape, We) SM mI Trial WBLen 11...Grade Top Thread 32.3 ],685.1 6.453.9 2900 TN110 H563 Casire Description OD (in) In(in) Tap (KKB) Set DepM MBI Bet ae 11v01.-W1I.n(L.. Grade Tap Tbaad 1...O: L1NAIg Areuu F.-DNr:aza INTERMEDIATE 2 SDL ] 6.28 ].8]2.4 11,059.9 ],9027 32.00 L-80 Tenaris Blue 1 sed "Reds'. Casing Dnarandon .0 (an) to (in) 1 1 Tap InKe Set De Ka Set RV06- O... Tmem 1 T4h MKS) LINER 4112 3.96 4,2 1260 L80 10,89].] 19391B ],9042 12.60 L80 TX TXP ausa-E 2.021 Liner Details Nominal ID INJECT' VALVE12@]B Tap We) ioplrvDI INK Bj Top Incl l') Ikm pas dean, (in) SURFACE. 0,2080.4 10.89]] ].888.1 84.91 PACKER HRDE ZXP 5 75- SEE (16,19) 5000 10,9242 7,890.5 64.90 HANGER 4-112" x 7- Flex Lock HS H521 Bax x TXP Pin 3875 Amcor Fun -Substance-. 11,9973 7,924.2 92.88 CROSSOVER XO 4112" TXP B x GG P, 12. mi L-80 3958 Saonowso,n+vm+e 11,999.2 7,924.1 92.90 EXTERNAL Swell Packer Baker Water Expanding Elastomer 3958 CASING PACKER TIESACK3TBWG;S23 12,019.3 7,9230 93.01 CROSSOVER X04112" 563 B x TXP P, 12.6a, L-60 3.958 2amf Tubing Strings Tubing Descapnon sting Ma._ m Top InNO) ser Depth (n.. apt Depth lrvD) (-. wIpEM) Grade Tap connttnon TUBING WATER 4112 6 3.9fi 28.9 10,908.] ],089.1 1260 LA0 TElue INJECTION Completion Details Top I'm 'Plant Noust INTERMEDN,TE, 34.]425 Taipe l dal (°) Mm Das Com to (in) 28.9 HANGER FMC 4-112' Tubing Hanger 3,958 2,0278 1,972.5 24.58 NIPPLE 3813- X LANDING NIPPLE. TSH Blue 3813 9,843.2 7,681 J 68.11 INJ - x Carmaid K w7 LM K V pinned r 3. 865 Iru;saavz psi csg to Mg shear, TSH Bin @682°@ 9,849'MD 7.6&3' TVD 10,028.9 7,744.3 7211 NIPPLE 3.813"XN LANDING NIPPLE Sal 3726'NOLO, TSH Blue 3725 NIPPLE; moms 10,8934 7,8877 8491 LOCATOR Locator Ne -Go 5]5"OD 3.930 10,894.4 7,8878 8491 SEAL ASSY Seal Assembly 3.930 LDCATGR; td eaa4 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) TI(mi Top Incl TopinKB) MIKS r) Oes Co. RYn EaM 10 In) ( sEALAssv; to.re..S 2,0278 1,98.5 24.58 1 3.813"X Lurk&A-1 pillvalue (wal HRS -66) 2/113@019 1.(2 VALVE Mandrel Inserts w an INTERMEDUTE 250E 7,8724an -11.basS R Top (nKe) TOp (TVOI (REST Mahe MNeI 00 OeSery VaM Tyce LaRn Type Port3iss TRO lin) Run (psi) Run Sala Co. 1 9,8432 7.681.3 CSmco KBG-2 1 GAS LIFT DMY BK 2/1 812 0 1 9 Notes: General & Safety End DahAnnounon NOTE: LINER: ID.BSI7-19,3mg� WN$ INJ WELLNAME MT6-02 WELLBORE MT6-02L1 [• �" Well Attribute Max Angle 7 TO ConocoPhilhPs .IalAt we110 reApuDW wMlp lesmo: _," Moron Ad B1MmK0) AleSka, InC LOOKOUT 5010320J92fi0 INJ fi23 19]1Nl 199,UU MTeo2u, SURaU. 1 SO a PM Casing Strings V v1`i•&Imll Czsio9I,—......000.1 LINER 4112 mMl TnP ME) 3.96 14,896.3 sM Cep,n(WBl SO DeNh 1TM01..,ML.n 11... L%F 20,905.0 1260 L-80 TopTrAnn TXP ..__............. ..................... ......................1......_......._........ HANGER: 29.9— Liner Details N.nS 10 Top (hNO) Top (IVD)(M(B) top incl )°) Ham095 Can ni Dn) ..-.............................._........................ _. 14,896,3 ),939.9 91.06 MANGER HflDE Liner Seeing Sleeve 4.200 14,912D ],9396 9L29 X X05 "H521 Pinx 4112"TXPPin 3960 ........................................................ ....... REDUCING rANg1CTCR;E16+1S0 Nnutr FLtl-pwN', ID6 t,aW.O:'d1YG19 Nnub FWitl-pu.[]20. 1.0.N 0:'d12A19 HIWLE: 302].8 INJECTgN V.W :2,@!.B SURFACE. 96.03.W A .,F.-Wdwa .. %6f0, SEE D', M1]R015 UESACKSTRING:R.1 ].Mi INTERMEDIATE, %38]435— .1,S.2— NJ;S,.2NIPPLE; .,A,., 10.0$89 LOGTQ2: USES. BFK lS5Y; l0.mS INTERMECIATE 2 SDL:1884 -11.8 LINER; 4� LINER, 11.340. operations Summary (with Timelog Lepths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start DepN StertT,me EnE Tune Dur (hr) Phase Op Code Activity Case Tene P -T -X Operation (flKB) ErA Depth (MB) 12/22/2018 12/22/2018 8.00 MIRU MOVE MOB P Spot MPD equipment in cellar. Move 0.0 0.0 00:00 08:00 sub over well. Skid rig floor. Spot pits & motors complex. 12/2212018 12122/2018 2.00 MIRU MOVE MOB P Connect service lines & spot 0117ill. 0.0 0.0 08:00 10:00 12122/2018 12/2212018 2.00 MIRU MOVE RURD P Accept rig & finalize rig acceptance 0.0 0.0 10:00 12:00 check list. 12/22/2018 12/2212018 5.00 MIRU MOVE RURD P Connect service lines. Rig on high line 0.0 0.0 12:00 17:00 @ 14:00 Hrs. N/U slip lock adaptor. NIU riser & flow line. Hook up bleeder & hole fill lines. Take on spud mud. 12/22/2018 12/22/2018 0.50 MIRU MOVE BHAH P Bring BHA tools & equipment to rig 0.0 0.0 17:00 17:30 floor. 12/22/2018 12/22/2018 3.00 MIRU MOVE BHAH P MIU & rack back NMFC. M/U mud 0.0 115.0 1730 20:30 molar, MWD, & UBHO & scribe as per Baker reps. M/U 1 stand of HWDP. 12/22/2018 12/22/2018 0.50 MIRU MOVE SFTY P Pre -Spud Meeting 115.0 115.0 20:30 21:00 12/22/2018 12122/2018 0.50 MIRU MOVE RURD P Make final lap around rig. Double 115.0 115.0 21:00 21:30 check rig up. Install 4" valve on conductor. 12/22/2018 12/22/2018 0.25 MIRU MOVE SEQP P Fill riser w/spud mud & check for 115.0 115.0 21:30 21:45 leaks. Test surface equipment to 3500 psi (good) 12/22/2018 12/22/2018 0.25 MIRU MOVE REAM P W&R to base of conductor @ 115' 115.0 115.0 21:45 22:00 1 jw/525 gpm, 650 psi, 40 rpm, 2 k trq. 1212212018 12/23/2018 2.00 SURFAC DRILL DDRL P Drill ahead f/115'to 184' MD 1184' 115.0 184.0 22:00 00:00 TVD, ADT .7 Hrs, 525 gpm, 700 psi, PU wt 77 k, SO wt 74 k, ROT wt 75 k, 40 rpm, Trq On/Off 3/2 k fUlbs 12/23/2018 12123/2018 12.00 SURFAC DRILL DDRL P Drill ahead 11184'to 1,320' MD / 1,308' 184.0 1,320.0 00:00 12:00 TVD, ADT 8.6 Hrs, ECD 10.48 ppg, 750 gpm, 2080 psi, PU wt 107 k, SO wt 107 k, ROT wt 107 k, 60 rpm, Trq On/Off 3/1.5 k ftAbs 12/23/2018 12/23/2018 8.50 SURFAC DRILL DDRL P Drill ahead f/1,320'to TO of 2,090' 1,320.0 2,090.0 12:00 20:30 MD / 2,029' TVD, ADT 7.5 Hrs, ECD 10.8 ppg, 900 gpm, 2750 psi, PU wt 117 k, SO wt 112 k, ROT wt 115 k, 60 rpm, Trq On/Off 311.5 k Nlbs 1212312018 12/23/2018 0.25 SURFAC CASING CIRC P Pump sweep & circ hole clean for 1 2,090.0 2,090.0 20:30 20:45 BAl w/900 gpm, 2670 psi, 40 rpm, 2 k trq 12/23/2018 12/2312018 0.25 SURFAC CASING OWFF P F/C (static) 2,090.0 2,090.0 20:45 21:00 12/23/2018 12/24/2018 3.00 SURFAC CASING BKRM P BROOH f/2,090'to 1,203'w/900-525 2,090.0 1,203.0 21:00 00:00 gpm, 2620 - 970 psi, 40 rpm. 3 k trq. Steady flow of cuttings on shakers. Pumped sweep @ 1,500' 12/24/2018 12/2412018 1.75 SURFAC CASING BKRM P BROOH f/1,203'to 547'w/525 gpm, 1,203.0 547.0 00:00 01:45 900 psi, 40 rpm. 1.5 k trq. Steady flow of cuttings on shakers. 12/24/2018 12124/2018 1.25 SURFAC CASING PMPO P Pump OOH f/547'to 180' w/300 gpm, 547.0 180.0 01:45 03:00 1420 psi (Rack back HWDP & Jars) 12/24/2018 12/24/2018 0.50 SURFAC CASING BHAH P Rack Back NMFC's (retrieve gyro tool) 180.0 91.0 03:00 03:30 f/180' to 91' 12/24/2018 12/24/2018 0.50 SURFAC CASING CIRC P Pump 30 bbl nut plug drill zone sweep 91.0 5-10- 03:30 04:00 to clean up BHA 12/24/2018 12/2412018 1.75 SURFAC CASING BHAH P UD BHA as per Baker reps f/91' 91.0 0.0 04:00 05:45 12/24/2018 12/24/2018 1.25 SURFAC CASING BHAH P Clean & clear floor of BHA tools & 0.0 0.0 05:45 07:00 1 1 equipment. Page 1129 Report Printed: 2119/2019 Uperations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Shit Depth Start Time End Time Dur (hr) Phase Op Code Ac[Mty Code Time P -T -X Opembon (W8) End Depm (fiKB) 12/24/2018 12/24/2018 3.00 SURFAC CASING RURD P Mobilize casing tools & equipment to 0.0 0.0 07:00 10:00 rig floor. R/U to run casing. R/U Volant & casing tongs, slips & elevators. 12/24/2018 12/24/2018 6.00 SURFAC CASING PUTB P M/U shoe track & check floats (good). 0.0 1,262.0 10:00 16:00 RIH w/13-3/8" 68# L-80 BTC/TXP casing to 1,262'. 12/24/2018 12/2472018 0.50 SURFAC CASING CIRC P Break circ @ base of perfafrost w/6 1,262.0 1,262.0 16:00 16:30 1 1 bpm, 100 psi. 12/24/2018 12/24/2018 2.00 SURFAC CASING PUTB P RIH w/13-3/8" 68# L-80 BTC/TXP 1,262.0 2,042.0 16:30 18:30 1 casing f/1,262'to 2,042' 12/24/2018 12/24/2018 0.50 SURFAC CASING HOSO P M/U landing jt & land casing on 2,042.0 2,080.0 18:30 19:00 hanger @ 2,080. PU wt 185 k / SO wt 150 k 12/24/2018 12/24/2018 2.00 SURFAC CEMENT CIRC P Circ & cond mud for cement job w/8 2,080.0 2,080.0 19:00 21:00 bpm 1130 psi. Reciprocate pipe. (PU wt 170 k / SO wt 155 k) 12/24/2018 12/24/2018 0.50 SURFAC CEMENT RURD P BID top drive. R/U thru cement lines. 2,080.0 2,080.0 21:00 21:30 Clean suction screens on mud pump. 12/24/2018 12/24/2018 0.50 SURFAC CEMENT CIRC P Break circ thru cement lines w/8 bpm, 2,080.0 2,080.0 21:30 22:00 1300 psi. PJSM on cementing. 12/24/2018 12/25/2018 2.00 SURFAC CEMENT CMNT P Dowell pump 2.1 bbls H2O & PT to 2,080.0 2,080.0 22:00 00:00 3500 psi (good). Dowell pump 100.1 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 300 bbls 11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement w/5 bpm, 250 psi at report time 12/25/2018 12/25/2018 1.50 SURFAC CEMENT CMNT P Dowell cont. to pump total of 382.5 2,080.0 2,080.0 00:00 01:30 bbls 11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement and 72.7 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 279.6 bbls 12,798 stks 10 ppg DrillPlex with 8 bpm / 700 psi. Reduce pumps to 3 bpm / 400 psi. last 10 bbls. Bump plug, pressure 500 psi over to 900 psi for 5 min. Check floats. FIC good. CIP @ 1:29 Hrs. Calculate 150 bbls good cement to surface. Full returns & reciprocated pipe during cement job. 12/25/2018 12/25/2018 2.00 SURFAC CEMENT RURD P Flush riser w/blackwater. RID Volant 0.0 0.0 01:30 03:30 & casing running tools & equipment. VD landing jt. 12/25/2018 12/25/2018 2.50 SURFAC CEMENT NUND P RID bleeder & hole fill lines. RID 0.0 0.0 03:30 06:00 surface riser asst' SIMOPS - clean pits. 12/25/2018 12/25/2018 2.50 SURFAC WHDBOP NUND P NIU speed lock head adaptor.. N/U 0.0 0.0 06:00 08:30 well head & test to 1000 psi for 10 min (good). SIMOPS - clean pits. 12/25/2018 12/25/2018 3.50 SURFAC WHDBOP NUND P NIU BOPE & N/U choke/kill lines. 0.0 0.0 08:30 12:00 1 1 SIMOPS - clean pits. 12/25/2018 12/25/2018 4.00 SURFAC WHDBOP MPDA P NIU RCD clamps & orbit valve. N/U 0.0 0.0 12:00 16:00 flow line & flow box. Install annulus valves. Obtain RKB's. Install trip nipple. Install KatchKan. 12/25/2018 12/25/2018 2.00 SURFAC WHDBOP MPDA P R/U test equipment. Test MPD 0.0 0.0 16:00 18:00 equipment 250/1500 psi. RID testing equipment & in stall trip nipple. SIMOPS - M/U choke & flare lines. 12/25/2018 12/25/2018 1.50 SURFAC WHDBOP RURD P R/U to test BOPE. Install test plug. Fill 0.0 0.0 18:00 19:30 1 1 1 1 stack w/H2O. Purge air from system. Page 2/29 ReportPrinted: 2119/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log scan Depth Start Time End Time Dur (tic) Phase op cme AchAy CWe Time P-T-X Operation(ftKB) End Depth (WS) 12/25/2018 12/26/2018 4.50 SURFAC WHDBOP BOPE P Test BOPE w/5 test joint. Annular 250 0.0 0.0 19:30 00:00 psi for 5 min 12500 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 3-1/2" X 6" VBR's, 5" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 2,950 psi, final 1,500 psi, list 200 psi recharge = 31 sec's, full recharge = 162 seconds. Nitrogen Bottles x4 = 2,175 psi. Gas alarms and PVT alarms tested. 12/26/2018 12/26/2018 0.50 SURFAC WHDBOP BOPE P Test blind rams. Perform poorboy gas 0.0 0.0 00:00 00:30 buster flush. Draw down on chokes 01100 psi. AOGCC Lou Laubenstein & BLM Mutasim Elganzcory waived witness. 12/26/2018 12/26/2018 1.50 SURFAC WHDBOP RURD P B/D choke, kill lines & mud lines. R/D 0.0 0.0 00:30 02:00 BOPE testing equipment. Retrieve test plug. Install wear ring. UD running tools. 12/26/2018 12/26/2018 2.00 SURFAC CEMENT BHAH P M/U 12-1/4" Intermediate#1 BHA as 0.0 620.0 02:00 04:00 1 1 1 per Baker reps. (up-Load MWD) 12/26/2018 12/26/2018 2.00 SURFAC CEMENT TRIP P RIH f/620'to 1,743' 620.0 1,743.0 04:00 06:00 12/26/2018 12/26/2018 1.00 SURFAC CEMENT CIRC P Circ B/U w/250 gpm, 200 psi, Thick 1,743.0 1,743.0 06:00 07:00 cement contaminated mud. SIMOPS - PJSM on slip & cut. 12/26/2018 12/26/2018 1.00 SURFAC CEMENT SLPC P Slip &cut drill line 1,743.0 1,743.0 07:00 08:00 12126/2018 12126/2018 0.50 SURFAC CEMENT SVRG P Service rig & drawworks. 1,743.0 1,743.0 08:00 08:30 12/26/2018 12/26/2018 0.25 SURFAC CEMENT DHEO P Shallow hole test MWD w/800 gpm, 1,743.0 1,743.0 08:30 08:45 j 1640 psi 12/26/2018 12/26/2018 2.00 SURFAC CEMENT PRTS P R/U to test casing. Pressure test lines 1,743.0 1,743.0 08:45 10:45 to 2700 psi. Test casing to 2500 psi & 1 chart for 30 min (good). R/D testing equip. 12/26/2018 12126/2018 0.25 SURFAC CEMENT TRIP P RIH f/1,743'to 1,932' 1,743.0 1,932.0 10:45 11:00 12/2612018 12/26/2018 5.00 SURFAC CEMENT DRLG P Drill float collar, shoe track, & rat hole 1,932.0 2,090.0 11:00 16:00 to 2,090'w/500 gpm, 720 psi, 50 rpm, 3 - 6 k trq. Circ out thick contaminated mud. Float collar & shoe track on depth. 12/26/2018 12/26/2018 0.25 SURFAC CEMENT DDRL P Drill 20' new formation f/2,090'to 2,090.0 2,110.0 16:00 16:15 2,110' MD / 2,047' TVD, ADT. 25 Hrs. Start displacing to new 9.5 ppg LSND 12/26/2018 12/26/2018 0.75 SURFAC CEMENT DISP P Cont. to displace to new 9.5 ppg 2,110.0 2,027.0 16:15 17:00 LSND w/550 gpm, 800 psi, 60 rpm, 5 k trq. BROOH f/2, 11V to inside 13-3/8" casing shoe at 2,027' 12/26/2018 12/2612018 0.75 SURFAC CEMENT FIT P F/C. R/U testing equipment. FIT to 2,027.0 2,027.0 17:00 17:45 18.5 ppg. (957 psi Q 2,046' TVD w/9.5 ppg mud) R/D /eking equipment 12/26/2018 12/26/2018 0.50 INTRMI DRILL REAM P Install 5.57' ghost reamer in stand #16 2,027.0 2,110.0 17:45 18:15 @ 2,062' behind bit. SPR's W&R f/2,027' to 2,110' 12/2612018 12/27/2018 5.75 INTRMI DRILL DDRL P Drill ahead f/2, 11V to 2745' MD / 2,110.0 2,745.0 18:15 00:00 2,598' TVD, ADT 3.95 Hrs, ECD 10.12 ppg, 850 gpm, 1370 psi, PU wt 130 k, SO wt 120 k, ROT wt 125 k, 140 rpm, Trq On/Off 5/2 k fUlbs, 5/10 k wob. Page 3/29 Report Printed: 2119/2019 Uperations Summary (with Timelog Depths) t MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Amoy Code Time P-T-X Operation (") End Dept (flK8) 12/27/2018 12/27/2018 9.75 INTRMI DRILL DDRL P Drill ahead f/2745'to 4,103' MD / 2,745.0 4,103.0 00:00 09:45 3,729' TVD, ADT 7.6 Hrs, ECD 10.4 ppg, 920 gpm, 2000 psi, PU wt 154 k, SO wt 135 k, ROT wt 140 k, 150 rpm, Trq On/Off 8/3.5 k ft/Ibs, 10 k wob. 12/27/2018 12/27/2018 0.75 INTRMI DRILL CIRC P Circ B/U w/920 gpm, 2050 psi, 50 4,103.0 4,103.0 09:45 10:30 rpm, 3.5 k lrq. (Install 7.32' ghost reamer in stand #37 @ 4,044" behind bit). 12/27/2018 12/27/2018 1.50 INTRMI DRILL DDRL P Drill ahead f/4,103'to 4,172' MD / 4,103.0 4,172.0 10:30 12:00 3,782' TVD, ADT 1.0 Hrs, ECD 10.2 ppg, 920 gpm, 2000 psi, PU wt 154 k, SO wt 135 k, ROT wt 140 k, 150 rpm, Trq On/Off 8/3.5 k fUlbs, 10 k wob. 12/27/2018 12/28/2018 12.00 INTRMI DRILL DDRL P Drill ahaed F/ 4172' To 5764'md / 4928 4,172.0 5,764.0 12:00 00:00 TVD, ADT 9.2 hrs, ecd 10.5 ppg, 922 gpm 2280 spp, P/u wt 190, SIO 150, rot wt 155, rpm 150, lorq on 10.5k torq off 618 k, wob 15k, 12/28/2018 12/28/2018 12.00 INTRMI DRILL DDRL P Drill ahead f/5,764' to 7,057' MD / 5,764.0 7,057.0 00:00 12:00 5,857' TVD, ADT 9.1 Hrs, ECD 10.54 ppg, 925 gpm, 2360 psi, PU wt 200 k, SO wt 160 k, ROT wt 165 k, 150 rpm, Trq OnfOff 15/7 k f flbs, 25 k wob. 12/28/2018 12/28/2018 10.50 INTRMI DRILL DDRL P Drill ahaed F/ 7057'to 8162' MD / 7,057.0 8,162.0 12:00 22:30 6,653' TVD, ADT8.5 hrs, ECD 10.37 ppg, 955 gpm, 2560 psi, FILM 225 k, SIO wt 200 k, ROT wt 175 k, 150 Fpm, Trq On/Off 18/8 k/fUlbs, 25 k wob 12/28/2018 12/29/2018 1.50 INTRMI DRILL CIRC P Circ & cond mud while waiting up to 8,162.0 8,162.0 22:30 00:00 10.5 ppg w/spike fluid w/950 gpm, 2560 psi 12/29/2018 1212912018 6.00 INTRMI DRILL CIRC P Cond to circ & cond mud while waiting 8,162.0 8,162.0 00:00 06:00 up to 10.5 ppg w/spike fluid w/Initial 950 gpm, 2500 psi, Final 850 gpm, 2550 psi. 12/29/2018 12/29/2018 0.50 INTRMI DRILL MPDA P F/C. PJSM. Remove trip nipple & 8,162.0 8,162.0 06:00 06:30 install RCD bearing. Break in bearing as per MPD advisor. 12/29/2o18 12/29/2018 5.50 INTRMI DRILL DDRL P Drill ahead f/8,162'to 8,556" MD / 8,162.0 8,556.0 06:30 12:00 6,937' TVD, ADT 3.7 Hrs, ECD 11.3 ppg, 950 gpm, 3200 psi, PU wt 260 k, SO wt 160 k, ROT wt 200 k, 150 rpm, Trq On/Off 14113 k fl/lbs, 25 k wob. MPD connections 12129/2018 12/29/2018 7.50 INTRMI DRILL DDRL P Drill ahead f/8,556' to 9026" MD / 8,556.0 9,026.0 12:00 19:30 7261' TVD, ADT 5.4 Hrs, ECD 11.06 ppg, 960 gpm, 3270 psi, PU wt 275 k, SO wt 170 k, ROT wt 200 k, 150 rpm, Trq On/Off 18/13 k ft/lbs, 25 k wob. MPD connections 12/2912018 1212912018 3.00 INTRMI CASING CIRC P Pump sweep & circ hole clean for 2 9,026.0 9,026.0 19:30 22:30 B/U w/950 gpm, 2370 psi, 150 rpm, 13 k trq. 12/29/2018 12/29/2018 0.25 INTRMI CASING OWFF P FIC (static) 9,026.0 9,026.0 22:30 22:45 12129/2018 12/29/2018 0.75 INTRMI CASING CIRC P Spot 135 bbis 11.2 ppg across HRZ, 9,026.0 9,026.0 22:45 23:30 and 10 bbls in drill pipe. SIMOPS - Line up MPD equipment to strip out of hole. 12/29/2018 12/30/2018 0.50 INTRMI CASING SMPD P StripOOH f/9,026'to 8,917' as per 9,026.0 8,917.0 23:30 00:00 1 MPD schedule Page 4129 Report Printed: 2119/2019 operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log sten Depth Stan Tune End Time our (hr) Phase Op Cafe Activity Cade Time P-T-X Operation (ftKB) End Depth (ftKB) 12/3012018 12/302018 4.50 INTRMI CASING SMPD P StripOOH f/8,917'to 6,184'as per 8,917.0 6,184.0 00:00 04:30 MPD schedule. Work tight hole with no improvement. 12/30/2018 12/30/2018 0.25 INTRMI CASING TRIP T RIH f/6,184'to 6,277' 6,184.0 6,277.0 04:30 04:45 121302018 12/30/2018 1.75 INTRMI CASING CIRC T Circ 2X B1U w/950 gpm, 2670 psi, 120 6,277.0 6,277.0 04:45 06:30 rpm, 9.5 k trq. Start to observe psi increase & MPD chokes were packed off with cuttings. 12/30/2018 12/30/2018 0.25 INTRMI CASING OWFF P FIC (static). Mobilize trip nipple to rig 6,277.0 6,184.0 06:30 06:45 1 1 ifloor. 12/30/2018 12/3012018 0.75 INTRMI CASING MPDA P Pull RCD bearing & install trip nipple. 6,277.0 6,184.0 06:45 07:30 1 Rack back 1 stand f/6,277' to 6,184' 12/30/2018 12/30/2018 4.50 INTRMI CASING BKRM P BROOH f/6,184'to 3,444'w/900 gpm, 6,184.0 3,444.0 07:30 12:00 2390 psi, 120 rpm, 9 k trq. 12130/2018 12130/2018 7.25 INTRMI CASING BKRM P BROOH fl3,444't0708' w/950-925 3,444.0 708.0 12:00 19:15 gpm, 2390 - 2025 psi, 120 - 60 rpm, 9 - 5 k trq. Once BHA was at 2,800' started having issues with hole packing off and caving's across shakers. Once BHA was inside casing shoe hole un-loaded softball size caving's & continued all the way to the BHA. 12/302018 12/30/2018 0.25 INTRMI CASING CIRC P Pump nut plug sweep & circ casing & 708.0 708.0 19:15 19:30 BHA clean. Hole un-loaded medium size cuttings & day. 12130/2018 12/30/2018 0.25 INTRMI CASING OWFF P F/C (static). SIMOPS - function rams 708.0 708.0 19:30 19:45 12/30/2018 12/3012018 1.50 INTRMI CASING TRIP P POOH f/708'to 160'. Racked back 708.0 160.0 19:45 21:15 HWDP & Jars. UD 2 its HWDP not needed for next hole section. 12/30/2018 12/30/2018 1.00 INTRMI CASING BHAH P UD BHA as per Baker reps. 160.0 0.0 21:15 22:15 12/30/2018 12130/2018 0.50 INTRMI CASING SHAH P Clean & clear floor of BHA tools & 0.0 0.0 22:15 22:45 equipment. 12/30/2018 12/30/2018 0.75 INTRMI CASING WWWH P Pull wear ring &M/U Johnny Wacker 0.0 0.0 22:45 23:30 & flush slack. 12/30/2018 12/31/2018 0.50 INTRMI CASING RURD P Drain stack. Close blind rams. Prep to 0.0 0.0 23:30 00:00 C/O rams. 12/31/2018 12/31/2018 1.00 INTRMI CASING BOPE P PJSM-Change out upper pipe rams to 0.0 0.0 00:00 01:00 9 5/8". Set test plug & R/U to test BOPE. SIMOPS - Clean & clear floor. Mobilize casing running tools to rig floor. 12/31/2018 12/312018 1.50 INTRMI CASING BOPE P Test BOPE w/9-5/8" test it. Annular 0.0 0.0 01:00 02:30 preventer to 250 for 5 min / /2500 psi for 10 min. Test upper pipe rams to 250 for 5 min 113500 psi for 10 min. 12131/2018 12131/2018 0.50 INTRMI CASING BOPE P R/D testing equipment. Set 13.125" 0.0 0.0 02:30 03:00 wear ring. 12/31/2018 12131/2018 2.00 INTRMI CASING RURD P R/U to min casing. R/U Volant, spider's 0.0 0.0 03:00 05:00 & elevators. 12/31/2018 12/31/2018 7.00 INTRMI CASING PUTS P RIH 9-518"40#TN-80 TXP casing 0.0 2,442.0 05:00 12:00 RIH T/ 2442' s/o 125k, @ 2080 (shoe) observed 20k s/o loss, establish circ @ 160 gpm, 3000 psi was through shoe 12/31/2018 12/31/2018 8.50 INTRMI CASING PUTB P RIH 9-5/8" 40# TN-80 TXP casing 2,442.0 8,314.0 12:00 20:30 f/2,442'to 8,314'. 2131/2018 12/31/2018 2.25 INTRMI CASING PUTB T Wash down 9-5/8" 40# TN-80 TXP 8,314.0 8,717.0 :20:30 22:45 f/8,317 to 8,719'w/3 bpm, 510 psi. Hole attempting to pack off Page 5129 Report Printed: 2/19/2019 Uperations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log SWn Depth Stert Time End Time our mr) Phase Op Code Activity Cade Time P-T-X Operation (ftKB) End Depth (MS) 12/3112018 1/112019 1.25 INTRMI CASING PUTB T Work tight hole & casing packing off. 8,717.0 8,717.0 22:45 00:00 Stage rate to 3.5 bpm, 400 psi. PU wt 390k/SO wt 220k 1/1/2019 1/1/2019 6.00 INTRMI CASING PUTB T Work tight hole & rasing packing off. 8,717.0 8,739.0 00:00 06:00 Stage rate to 3.5 bpm, 400 psi. PU wt 390 k / SO wt 220 k, continue working with tight hole & casing packing off to 8739' 1/1/2019 1/1/2019 1.00 INTRMI CASING CIRC T Circulate and get pump rate up to 8,739.0 8,739.0 06:00 07:00 8bbl/min, circulate bottoms up 1/1/2019 1/1/2019 5.00 INTRMI CASING PUTB T Continue working with tight hole & 8,739.0 8,739.0 07:00 12:00 casing packing off to 8739' pump rates - 1 bbl/min 190/240 psi, 2 bbl/min 260 psi, 3bbl/min 320 psi, 4.5 bbl/min =380 5bbl/min 350/380, 6.5 bbl/min 360 psi 8 bbl/ min 420 psi, 1/1/2019 1/1/2019 4.00 INTRMI CEMENT PUTB T Continue working with tight hole & 8,739.0 8,742.0 12:00 1600 casing packing off , work with clean up hole f/ 8739 U 8751', circ.and regain rates, 336 gpm, 400 psi, 410/235k p/u 225 s/o, attempt to was down casing. ICP - 84 gpm, 105 psi, FCP 135 gpm, 210 psi, MW 10.5+ in, 10.6 out final depth 8742 1/1/2019 1/1/2019 1.00 INTRMI CEMENT CMNT P PJSM, rig up cement equip. test 8,742.0 8,742.0 16:00 17:00 cement lines @ 3900 psi. 1/1/2019 1/112019 2.00 INTRMI CEMENT CMNT P Mix and pump 60 bbls 12.5 ppg Mud 8,742.0 8,742.0 17:00 19:00 Push II, drop bottom plug, mix and pump 98 bbls Gass G 12.2 ppg lead cement, mix and pump 48.8 bbls, 15.8 tail cement, drop top plugs. (two plugs, regular NRP and HEWP) pump 20 bbls H2O 1/1/2019 1/1/2019 4.00 INTRMI CEMENT CMNT P Displace with dg pumps, pump 628 8,742.0 8,742.0 19:00 23:00 bbls mud @ 4bbls/min. 7 % returns, bottom plug bumped @ 4858 stks, sheared @ 460 psi, pump psi increased to 1850 psi @ 4984 stks pump @ 5002 stks pump rate reduced to 112 bbl/min 2030 psi. no returns. Notify drilling engineer, continue displacing cement, @ 1 bpm-3 bpm, 2500-3100 psi, no returns. Bumped plug @ 6380 stks, 110 bbls total lost ( pit strap). Pressure up to 3500 psi and hold 5 minutes. Cement in place @ 22:55 hrs 11112019. 1/1/2019 1/1/2019 0.50 INTRMI CEMENT OWFF P Bleed off psi check floats, float 8,742.0 8,742.0 23:00 23:30 holding, rig down cementing equipment. 1/1/2019 1/2/2019 0.50 INTRM1 CEMENT RURD P Rig down and blow down cement 8,742.0 8,742.0 23:30 00:00 lines. 1/2/2019 1/2/2019 2.75 INTRMI CEMENT WOC T Waiting on cement to cure to 500 psi 8,742.0 8,742.0 00:00 02:45 compressive strength. SIMOPS-Load pipe shed with 84jts XT 39 4" 14# DP, Perform MP2's on rig equipment, Prep tools, equipment and review procedure for emergency slips, 1/2/2019 1/2/2019 4.25 INTRMI CEMENT WOC T Continue WOC. 8,742.0 8,742.0 02:45 07:00 SIMOPS - PIU and rack back 28 stds 4" 14# DP in derrick , contingency for SDL inner string. Page 6/29 Report Printed: 2119/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time EM Time Dur hr ( ) Phew Op CaEa Activity Cotle Time P -T -X Operetion (flK8) Eno Depth (flKB) 1/2/2019 1/2/2019 4.00 INTRMI CEMENT WAIT T WOO from office regarding path 8,742.0 8,742.0 07:00 11:00 forward. SIMOPS- Continue to moblize tools and equipment for setting emergency slips, MP2'S, rig maintenance, clean work areas, monitor well on trip tank. Recieve orders to continue with setting slips on 9-5/8" casing. 1/2/2019 1/2/2019 0.25 INTRMI CEMENT OWFF T OWFF- Static, slight drop. 8,742.0 8,742.0 11:00 11:15 1/2/2019 1/2/2019 0.75 INTRMI CEMENT RURD T Drain stack, unsling Volant CRT F/ 8,742.0 8,742.0 11:15 12:00 casing, dg dwn trip nipple, prep stack for picking up. Total static loss 12 bbl for 12 hr. 1/2/2019 1/2/2019 1.75 INTRMI CEMENT RURD T Monitor annulus, (i bbl loss) continue 8,742.0 8,742.0 12:00 13:45 preping stack F/ removal 1/2/2019 1/2/2019 2.25 INTRMI CEMENT CPBO T PJSM- Break well head install 8,742.0 0.0 13:45 16:00 emergency slips, (set 50k on slips) cul CSG, pull cut joint to floor, make final cut on mg per FMC, lay down cut joint (17.34' of joint #217), remove elevators, and bail extensions. 1/2/2019 1/2/2019 1.25 INTRMI CEMENT WWSP P Set stack down, pull wear bushing, set 0.0 0.0 16:00 17:15 9-5/8" pack off, run in lock down screws. 1/2/2019 1/2/2019 2.25 INTRMI CEMENT NUND P PJSM - nipple down flow box, pick up 0.0 0.0 17:15 19:30 slack, install 7" well head spool, set stack down, & align tubing outlet to production flow line. 1/2/2019 1/2/2019 1.25 INTRM1 CEMENT PRTS P Torque lower wellhead flange bolts, 0.0 0.0 19:30 20:45 Test packoff to 250 / 2500 psi F/ 10 min. CPAI witnessed (test good). 1/2/2019 1/2/2019 2.00 INTRMI CEMENT MPDA P Continue torque up bolts, Install flow 0.0 0.0 20:45 22:45 line, flow box, tum buckles, trip nipple and obtain new RKB's. SIMOPS- Clean casing equip. continue monitoring annulus, I bbl/hr loss 1/2/2019 1/3/2019 1.25 INTRMI WHDBOP RURD P Change out upper rams to 4%" x 7" 0.0 0.0 22:45 00:00 VBR's. SIMOPS- Rig down Volant CRT. Continue monitoring annulus. Total loss for tour -7 bbl static loss, total for day 19 bbl via 13-3/8"x9-5/8" annulus. 1/3/2019 1/3/2019 3.00 INTRMI WHDBOP RURD P Install 4.5 X 7" Upper VBR's, cln/clr rig 0.0 0.0 00:00 03:00 floor excess tools/equip., install m/h and trip nipple, tighten choke line connection, gtrease IBOP, B/D lines confirm clr, install Iwr test plug, fill bop's and choke. monitor annulus - 3 bbis loss in 12 hr 1/3/2019 1/3/2019 4.00 INTRMI WHDBOP BOPE P Test BOPE with 3.5", 5" & 7" lest jts. 0.0 0.0 03:00 07:00 AOGCC Brian Bixby waived witness. With 5" TJ, test annular preventer to 250/2500 psi for 5/10 min, 4%d' x 7" Upper VBR's, 3W' x 6" lower VBR's to 250/3500 psi for 5/10 min.Test 4" Demco Kill valve, Auto and manual IBOP valves, HCR and Manual Choke and Kill valves, floor safety valves 2- XT39 and I-NC50, Dart Valves 1- XT39 and 1- NC50, Choke Valves 1- 14 and Needle valve to 250/3500 psi for 5/10 min. Test gas alarms, Flow paddle and High level pit alarms Page 7129 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Time our(hn Phase Op Code Adivity Code Time P -T -X Operation ptKB) End Depth h1KIs) 1/3/2019 1/3/2019 0.50 INTRMI WHDBOP DOPE P Peform accumulator test, System 0.0 0.0 07:00 07:30 Pressure=2900 psi, Pressure after functioning all rams, annular and HCR's=1500 psi, 200 psi attained=36 sec, Full System Recovery=169 sec. 4 bottle Nitrigen average=2150 psi. 1/3/2019 1/3/2019 3.25 INTRMI WHDBOP BOPE P Change to 7" test joint, test annular to 0.0 0.0 07:30 10:45 250/2500 psi for 5/10 min, Upper VBR's to 250/3500 psi for 5/10 min. Swap to 3'/:" test joint, test annular to 250/2500 and lower VBR's to 250/3500 psi for 5/10 min. Test blind rams to 250/3500 5/5 min. Test Manual and Super Auto chokes to 1100 psi. 1/3/2019 1/3/2019 0.50 INTRMI WHDBOP RURD P Pull lower test plug, drain stack, B/D 0.0 0.0 10:45 11:15 choke, kill & HCR lines, RID test equip. set 8.875" wear bushing as per FMC, LID test joint. /3/20191/312019 0.75 INTRMI CEMENT ELOG T P/U and mobilize E -line tools to rig 0.0 0.0 11:15 12:00 1 floor 1/3/2019 1/3/2019 1.00 INTRMI CEMENT ELOG T PJSM - rig up E- Line cable, sheaves, 0.0 0.0 12:00 13:00 M/U E -Line Tools, in mouse hole, 1/3/2019 1/3/2019 2.00 INTRMI CEMENT ELOG T Test E- Line tools, weight indacator 0.0 0.0 13:00 15:00 not working on E -Line, order parts for E Line unit. 1/3/2019 1/3/2019 1.75 INTRM1 CEMENT TRIP T M/U BHA#3 & bit, RIH T/ 2,063' while 0.0 2,063.0 1500 16:45 waiting for E Line parts. 1/3/2019 1/3/2019 1.00 INTRMI CEMENT CIRC T Circulate @ 900 gpm, SPP 1900 psi to 2,063.0 2,063.0 16:45 17:45 warm annular fluids while waiting F/ E Line parts. 1/3/2019 1/3/2019 3.75 INTRMI CEMENT SVRG T Work on MP2, test MPD chokes, P/U 2,063.0 0.0 1745 21:30 & stand back 3stds of 14# - 4" dp while waiting on E line parts and epairs. 1/3/2019 1/3/2019 0.50 INTRMI CEMENT ELOG T Rig up wire line sheaves, P/U CBL log 0.0 0.0 21:30 22:00 tools 1/3/2019 1/4/2019 2.00 INTRMI CEMENT FLOG T RIH with CBL tools on E line. Work 0.0 0.0 2200 00:00 through one obstruction @ 7,055' MD. RIH to 8,660' MD. Correlate with Gamma. Begin logging up. SIMOPS- Test MPD chokes, clean rig, MP2's. 1/4/2019 1/4/2019 1.00 INTRMI CEMENT ELOG T Continue running CBL, to 8660', 0.0 0.0 0000 01:00 1 1/4/2019 1/4/2019 0.50 INTRMI CEMENT ELOG 7 R/D CBL tools, and E -Line equip. 0.0 0.0 01:00 01:30 1/4/2019 1/4/2019 1.00 INTRM1 CEMENT PULD F7- P/U 2 aids 4" DP and std in derrick F/ 0.0 0.0 01:30 02:30 1 133 stds total, 1/4/2019 1/4/2019 2.25 INTRMI CEMENT BHAH P P/U clean out BHA#4 per Baker rep to 0.0 541.0 02:30 04:45 541' MD. 1/4/2019 1/4/2019 5.75 INTRMI CEMENT TRIP P Trip in hole T/ 8447, fill pipe every 20 541.0 8,447.0 04:45 10:30 stds, shallow test MWD @ 2387', 1/4/2019 1/4/2019 0.75 INTRMI CEMENT COCF P Trip in hole F/ 8447 T/ 8512', circ. and 8,447.0 8,447.0 10:30 11:15 condition mud, wash dwn @ 450 gpm, 1450 psi, 10.5 MW 10.5 in, & out. @ 8512' observe psi increase. no S/O observed, pick up to 8447' & std back 1 std in derrick. 1/4/2019 1/4/2019 0.75 INTRMI CEMENT SLPC P Hang blocks, cut & slip 60' drlg line. 8,447.0 8,447.0 11:15 12:00 1 1/4/2019 1/4/2019 0.50 INTRMI CEMENT SVRG P Service rig, blocks, drawworks, T/D, 8,447.0 8,447.0 1200 1230 Dynamatic, MP'S Page 8129 Report Printed: 211 912 01 9 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sean Depth Stan Time End Time our (hr) Phase Op Cade Activity Code Time P -T -X Operation (VIR) End Depth (eKa) 1/4/2019 1/4/2019 1.50 INTRMI CEMENT PRTS P Rig up and test 9 5/8 casing @ 3500 8,447.0 8,447.0 12:30 14:00 psi, 7.6 bbls pumped chart test for 30 min, test good, B/D lines & test equip. 1/4/2019 1/4/2019 2.25 INTRMI CEMENT COCF P Wash down F/ 8447 T/ 8635', ddg 8,447.0 8,635.0 14:00 16:15 stringer @ 8510', 540 gpm, 1950 psi, 40 rpm, 13115 torq 1/4/2019 1/4/2019 0.50 INTRMI CEMENT EORP T B/D top drive, change out Baker 8,635.0 8,635.0 16:15 16:45 MWD encoder on drawworks, & cal. block height. 1/4/2019 1/4/2019 0.50 INTRMI CEMENT COCF P Wash and ream down to float collar 8,635.0 8,661.0 16:45 17:15 from 8,635' MD to 8,661' MD tag up on plugs. 1/4/2019 1/4/2019 1.75 INTRMI CEMENT DRLG P Drill out plugs, Float equipment, shoe 8,661.0 8,665.0 17:15 19:00 track and shoe to 8,742' MD @ 540 gpm, 2015 psi, 40 rpm, 13.5k TO. 1/4/2019 1/4/2019 0.25 INTRMI CEMENT DRLG P Drill / clean rathole to 8,762' MD @ 8,742.0 8,762.0 19:00 19:15 540 gpm, 1990 psi, 40 rpm, 13.5k Tq. 1/4/2019 1/4/2019 0.75 INTRMI CEMENT BKRM P BROOH from 8,762' MD to 8,730' MD, 8,762.0 8.730.0 19:15 20:00 working through shoe twice to clean up. 1/4/2019 1/4/2019 0.25 INTRMI CEMENT RURD P Blow down topdrive and R/U for FIT. 8,730.0 8,730.0 20:00 20:15 1/4/2019 1/4/2019 0.50 INTRMI CEMENT FIT P Perform'preliminary' FIT to 14.0 ppg 8,730.0 8,730.0 20:15 20:45 EMW, pumped 3.3 bbl to 1290 psi, 1/4/2019 1/4/2019 0.25 INTRM2 DRILL OWFF P OWFF static and PJSM on installing 8,730.0 8,730.0 20:45 21:00 RCD. 1/4/2019 1/4/2019 0.75 INTRM2 DRILL MPDA T Pull trip nipple and install RCD 8,730.0 8,730.0 21:00 21:45 element. 1/4/2019 1/5/2019 2.25 INTRM2 DRILL WASH T Wash down, cleaning out rathole from 8,730.0 8,919.0 21:45 00:00 8,730' MD to 8,919' MD, 540 gpm, 1990 psi, 60 rpm, 14.5k Tq, .3-1k WOB, Minor torque and pressure events at 8745', 8,775', 8,810' MD. 1/5/2019 1/5/2019 1.25 INTRMI DRILL WASH T Wash / Ream F/ 8919'T/ 9026', 540 8,919.0 9,026.0 00:00 01:15 gpm, 1920 spp. ROT= 195k, 14k Tq, rpm 60, continue with 550 bbl dilution with 10.5 ppg LSND. 1/5/2019 1/5/2019 0.75 INTRMI DRILL DDRL T Drlg F 9026 T/ 9046', 540 gpm, 1920 9,026.0 9,046.0 01:15 02:00 spp. ROT=195k, trq 14k, rpm 60, 1/5/2019 1/5/2019 0.50 INTRMI DRILL CIRC T Circulate bottoms up, 550 gpm, 1870 9,046.0 9,016.0 02:00 02:30 spp. ROT=195k, trq 14k, rpm 60, MW 10.5 ppg, condition for FIT, 10.5 ppg in/out. 1/5/2019 1/5/2019 1.50 INTRMI DRILL BKRM T BROOH F/ 9016'T/ 8923% holding 9,016.0 8,923.0 02:30 04:00 11.3 ppg with MPD, 550 gpm, 1910 psi,12k trq, Pack oft @ @ 8923'. Open chokes, work string, 72k overpull, 51 k s/o, U/D wt 253k/151 K,. UD double, work free. Attempt to continue backreaming, packing off. 1/5/2019 1/5/2019 1.00 INTRM2 DRILL PMPO T Pump out to 8661'. Circ/recip @ 550 8,923.0 8,734.0 04:00 05:00 gpm, 1870 psi, 14k Tq, rpm 60, Shakers unloaded shale then cleaned up after BU. 1/5/2019 1/5/2019 0.25 INTRM2 DRILL CIRC T OWFF ( static) R/U for FIT. 8,734.0 8,734.0 05:00 05:15 1/5/2019 1/5/2019 0.50 INTRM2 DRILL FIT T Perform FIT to 14.0 ppg EMW. Drillers 8,734.0 8,734.0 05:15 05:45 TD @ 9,046' MD/ 7,273' TVD. Pumped 3.4 bbl 10.5 ppg mud to 1300 psi. Good test, bleed off, rig down and blow down. Page 9129 ReportPrinted: 2/1912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Slant Depth Stan Time End Time our (hr) Phase op Code Activity Code Time P-T-X operation (MB) End! Depth (I(ka) 1/5/2019 1/5/2019 1.00 INTRM2 DRILL WAIT T Prepare to SOOH while waiting on 8,734.0 8,734.0 05:45 06:45 decision regarding plan forward due to hole conditions Clean and clear rig floor. 1/5/2019 1/5/2019 3.25 INTRM2 CSGDRL REAM T Wash and ream F/ 8734 T/ 9046, 550 8,734.0 9,046.0 06:45 10:00 gpm, 1850 spp. rpt 1951k, trq 14k, rpm 60, P/U 238k, S/O 167k, MW 10.5 ppg, holding 11.3 EMW via MPD, 1/5/2019 1/5/2019 1.00 INTRM2 CSGDRL BKRM T BROOH F/ 9046 T/ 9014', CBU, 550 9,046.0 9,014.0 10:00 11:00 gpm, 1820 spp, 12.5k trq, 60 rpm, weight up F/ 10.5 T/ 10.8 1/5/2019 1/5/2019 1.00 INTRM2 CSGDRL PMPO T Continue pump out of hole F/ 9014' T/ 9,014.0 8,730.0 11:00 12:00 8730', hold 11.4 EMW with MPD, 90 gpm/ 400 psi 1/5/2019 1/5/2019 2.00 INTRM2 CSGDRL CIRC T Continue circulate and weight mud up 8,730.0 8,730.0 12:00 14:00 to 10.8 ppg @ 8730'. 1/5/2019 1/5/2019 0.50 INTRM2 CSGDRL TRIP P OWFF, B/D top drive, line up MPD to 8,730.0 8,730.0 14:00 14:30 SOON. Obtains SPR's. SIMOPS- Annular LOT to 16.0 ppg EMW, flush and freeze protect annulus with 300 bbl water and 84 bbl diesel. 1/5/2019 1/5/2019 5.00 INTRM2 CSGDRL SMPD P Strip out of hole with MPD from 8,730' 8,730.0 1,005.0 14:30 19:30 MD to 1,005' MD per stripping schedule, holding 180 psi in slips, 270 psi pulling. Maintaining 11.3 ppg CBHP. 1/5/2019 115/2019 0.50 INTRM2 CSGDRL OWFF P Observe well for flow, static. 1,005.0 1,005.0 19:30 20:00 Function upper and lower rams. 1/5/2019 1/5/2019 0.75 INTRM2 CSGDRL MPDA P Pull RCD and install trip nipple 1,005.0 1,005.0 20:00 20:45 1/5/2019 1/5/2019 1.75 INTRM2 CSGDRL FULD P POOH on trip tank from 1,005' MD to 1,005.0 203.0 20:45 22:30 203' MD, laying down HWDP to pipe shed. 1/5/2019 1/612019 1.50 INTRM2 CSGDRL BHAH P PJSM and lay down BHA # 4 per 203.0 0.0 22:30 00:00 Baker DD / MWD. Function blind rams. Total trip Calc Fill=87 bbl, Acual Fill= 100.5 bbl. 1/6/2019 1/6/2019 1.75 INTRM2 CSGDRL SHAH P UD BHA tools/ equip. clean and clear 0.0 0.0 00:00 01:45 RF, P/U SOL BHA tools / Equip. 1/612019 1/6/2019 5.00 INTRM2 CSGDRL BHAH P PJSM, P/U SDL inner string. BHA, M/U 0.0 0.0 01:45 06:45 flow DIV - N- slab F/SDL ddg string. M/U back up str head assy. W/ 6" PDC bit UD in shed. P/U -N- M/U primarry SDL inner string BHA per Baker rep. Plug in BHA and test (good), STD back in DIRK M/U shod kick std. w? 4" FOSV, P/U SDL false table tools and equip. 1/6/2019 1/6/2019 1.75 INTRM2 CSGDRL RURD P R/U 7" SDL liner running tools/ equip., 0.0 0.0 06:45 08:30 trq turn equip. DBL stack tongs, bail esten. 7" elevators, handling equip. PJSM F/ RIH with 7" 26# casing. 1/6/2019 1/6/2019 3.50 INTRM2 CSGDRL PUTB P M/U 8-1/2" EZ Reamer shoe, M/U and 0.0 1,519.0 08:30 12:00 RIH with 7" 26# L-80 TN Blue casing to 1,519' MD, torque turning to 15k ft/lbs per program. 1/6/2019 1/6/2019 2.50 INTRM2 CSGDRL PUTB P Continue Running in hole W/ 7" 26# L- 1,519.0 3,140.0 12:00 14:30 80 Ten. Blue liner F 1519'T/ 3140'. Cal disp = 30, ACT 28bbls, S/0 113k 1/6/2019 1/6/2019 0.50 INTRM2 CSGDRL RUHL)P R/D 7"I inner handling equip. 3,140.0 3,140.0 14:30 15:00 Page 10129 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X operation (fIKB) End Depth Moo) 1/6/2019 1/6/2019 2.50 INTRM2 CSGDRL BHAH P PJSM, R/U & RIH with AutoTrak inner 3,140.0 3,140.0 15:00 17:30 string BHA T/ 50'( load sources) 1/6/2019 1/6/2019 1.25 INTRM2 CSGDRL BHAH P Cont. T/ M/U inner BHA F/ 50'T/ 180' 3,140.0 3,140.0 17:30 18:45 1/6/2019 1/6/2019 0.25 INTRM2 CSGDRL TRIP P RIH F/ 180'T/ 465' w/4" tip inner strg, 3,140.0 3,140.0 18:45 19:00 1/6/2019 1/6/2019 0.25 INTRM2 CSGDRL SFTV P Perform SDL kick while tripping drill 3,140.0 3,140.0 19:00 19:15 1 1 with long kick stand. 1/6/2019 1/6/2019 1.75 INTRM2 CSGDRL TRIP P Continue RIH F/465' T/ 3040' p/u wt 3,140.0 3,140.0 19:15 21:00 90k, SIO wt 87k. 1/6/2019 1/6/2019 1.00 INTRM2 CSGDRL HOSO P M/U stcl 4" dp & tag up 2' in on joint 3,140.0 3,140.0 21:00 22:00 #97, set 10k dwn. POOH & RIB std #97, M/U space out pups 1/6/2019 1/6/2019 1.00 INTRM2 CSGDRL BHAH P MIN HRDE liner running tools, Baker 3,140.0 3,258.0 22:00 23:00 flow diverter, stab & float sub, rig down false table & work platform. 1/6/2019 1/8/2019 0.50 INTRM2 CSGDRL TRIP P RIH w/ SDL on 5" dp F/ 3258' T/ 3,258.0 3,723.0 23:00 23:30 1 13258' ( new BHA depth 3723) 1/612019 1/7/2019 0.50 INTRM2 CSGDRL DHEQ P Shallow hole test SDL dirAssy. W/ 3,723.0 3,723.0 23:30 00:00 1 225 gpm, 1200 psi 1/712019 1/7/2019 0.50 INTRM2 CSGDRL DHEQ P Shallow test MWD 225 gpm, 3,723.0 3,723.0 00:00 00:30 TRPM=3450. Increase to 350 gpm, TRPM=5538. Rotate 50 rpm, 5k, R0T=160k. Attempt to open diverter, loo shallow. Blow down top drive. 117/2019 117/2019 1.00 INTRM2 CSGDRL TRIP P RIH F/ 3723'T/ 5138' with SDL BHA 3,723.0 5,138.0 00:30 01:30 #5. 1/7/2019 117/2019 0.25 INTRM2 CSGDRL DHEQ P Verify flow diverter open@ 5138', 5,138.0 5,138.0 01:30 01:45 300 / 600 gpm, 2150/ 3300 psi, 50 rpm, ROT=180k, torq. 7k, 600 gpm, TRPM - 5313 psi 1/7/2019 1/7/2019 2.50 INTRM2 CSGDRL TRIP P Cont. RIH F/ 5138'T/ 8620', 5,138.0 8,620.0 01:45 04:15 1/7/2019 1!7/2019 0.50 INTRM2 CSGDRL OWFF P OWFF, @ 8620', pull T/N install MPD 8,620.0 8,620.0 04:15 04:45 RCD. PIU 252k, S/O 196k. 1/7/2019 177/2019 1.75 INTRM2 CSGDRL TRIP P Cont. RIH F/ 8620' T/ 8880' with SDL 8,620.0 8,880.0 04:45 06:30 liner DRLG Assy. ( no s/o loss working through shoe Irk. w/ str head assy, 7" reamer shoe. P/U 295, S/O 194k, ROT=252k, 16.5k Tq, 30 rpm 30, Calc disp= 47.28 bbls, Actual Disp= 44 bbls 1/7/2019 1!7/2019 2.00 INTRM2 CSGDRL REAM P Wash/ ream F/8880' T/ 9033', circ, 8,880.0 9,033.0 06:30 08:30 spm 80, gpm 225, 630/1610 psi, rot 226, trq 13.5k, rpm 10, ( flow diverter opened 2X, cycle pump T/ close. pressure indicated possible packoff, PIU 30k, S/O to 175k, hole packing off, attempt to work strg free pump rates 401275 gpm, PIU=291 k, S/0=188k, ROT=232k. 1/7/2019 1/7/2019 2.00 INTRM2 CSGDRL CIRC P Work string free F/ 9028 T/ 9008', est. 9,033.0 9,028.0 08:30 10:30 circ, rot/ recip SDL liner volume @ 40- 275 gpm, 460-1860 psi, rot wt 227k, trq 15k, rpm 15, circ btms up 17/2019 1/7/2019 1.50 INTRM2 CSGDRL REAM P FI 9028' T/ 9037' cont. wash/ ream w/ 9,028.0 9,037.0 10:30 12:00 SDL liner drig easy. 550 gpm, 2430 psi, rot 230k, trq 16.2k, 17/2019 1/7/2019 0.50 INTRM2 CSGDRL REAM P Continue washing down to bottom 9,037.0 9,046.0 12:00 12:30 9,046' MD @ 570 gpm, 2450 psi, diverter open, 30 rpm 16.6k Tq. Page 11129 ReportPrinted: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log rt De Start Depth start Time End Time our (hr) Phase Op Coca A vi Coae ty Time P-T-X OparaOon Enc Depth (flKB) 1/7/2019 1/8/2019 11.50 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8'/." SOL 9,046.0 9,330.0 12:30 00:00 assembly from 9,046' MD to 9,330' MD, 7,444' TVD @ 575 gpm, 2485 psi, 45 rpm, 13.5k Tq. Under-reamer open @ 9,117' MD pilot depth, 9,049' reamer depth. ADT=10.7 hrs, 1/8/2019 1/8/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8'/." SDL 9,330.0 9,705.0 00:00 12:00 assembly from 9,330' MD to 9,705' MD, 7,626' TVD @ 575 gpm, 2485 psi, 45 rpm, ECD=11.61 ppg, Tq on/off= 13.5k/12.4k, 5-7k WOB, ROT=227k, ADT=11.0 his. 1/8/2019 1/9/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8W SDL 9,705.0 10,046.0 12:00 00:00 assembly from 9,705' MD to 10,046' MD, 7,710' TVD @ 575 gpm, 2470 psi, 45 rpm, ECD=11.60 ppg, Tq on/off= 13.5k/12.4k, 5-7k WOB, ROT=230k, ADT=10.5 hrs. 1/9/2019 1/9/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8'/." SDL 10,046.0 10,390.0 00:00 12:00 assembly from 10,046' MD to 10,390' MD, 7,833' TVD @ 575 gpm, 2580 psi, 45 rpm, ECD=11.50 ppg, Tq on/off= 13k/14.5k, 5-7k WOB, ROT=235k, ADT=11.1 his. 1/9/2019 1/10/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8'/." SDL 10,390.0 10,699.0 12:00 00:00 assembly from 10,390' MD to 10,699' MD, 7,858' TVD @ 575 gpm, 2550 psi, 45 rpm, ECD=11.54 ppg, Tq on/off-- n/off=13.7k/14.7k, 13.7k/14.7k.5-7k WOB, ROT=2261k, ADT=10.5 his. 1/10/2019 1/10/2019 12.00 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8%" SDL 10,699.0 11,020.0 00:00 12:00 assembly from 10,699' MD to 11,020' MD, 7,899' TVD @ 575 gpm, 2480 psi, 45 rpm, ECD=11.43 ppg, Tq on/off= 15.3k/13.1k, 5-7k WOB, ROT=226k, ADT=11.0 hrs. Note: Alpine C Top 10,999' MD 7,897' TVD. 1/10/2019 1/10/2019 4.50 INTRM2 CSGDRL DCSG P Directional drill with 6 x 8'/." SDL 11,020.0 11,132.0 12:00 16:30 assembly from 11,020' MD to 11,118' MD, Down link and close 8-3/4" under reamer, Continue drilling from 11,118' MD to section TO at 11,132' MD 7909' TVD, Observed static reamer land on ledge @ 11,132' bit depth, 11,050' MD 7901.9' TVD 7" shoe depth. 7" TOL 7,863' MD 6'438.7' TVD. 575 gpm, 2480 psi, 45 rpm, ECD=11.34 ppg, Tq on/off= 15.3k/l 3.1 k, 5-7k WOB, ROT=226k, ADT=4.5 hrs. Max gas 2985 units. 1/10/2019 1/10/2019 7.00 INTRM2 CEMENT CIRC P Final TO survey, Down link and close 11,132.0 11,132.0 16:30 23:30 ribs. ROT =228k, PUW =275k, SOW =165k. Continue circulate and weight up in stages from 10.3 ppg to 11.0 ppg. 585 gpm, 2480 psi, ECD=11.34 ppg. Final circulation 245 gpm, 1150 psi. ECD= 11.7 ppg. 1/10/2019 1/11/2019 0.50 INTRM2 CEMENT OTHR P Shut down, break out tool joint and 11,132.0 11,132.0 23:30 00:00 drop 1.75" Bronze release ball per BOT rep. Slack off string from 228K to 140K, Continue to circulate ball down at 84 gpm 1450 psi. Ball landed on seat @ 317 strokes, continue pressure up to 3440 psi to blow ball seat and release from 7" liner. Page 12129 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log stent Depth Stan Time EM Time Dar(hn Phase Op Corte Activity Code Time P -T -X Operation (RKB) End Depih(flKB) 1/11/2019 1/11/2019 0.75 INTRM2 CEMENT PMPO P Continue pump 126 gpm 745 psi. P/U 11,132.0 10,975.0 00:00 00:45 string from 11,132'to 10,975' bit depth and verify release @ 212k per BOT 7" liner reamer shoe @ 11,050' MD 7,901 TVD. TOL 7863' MD 6,438.9' TVD. 1/11/2019 1/11/2019 1.00 INTRM2 CEMENT CIRC P Continue pump out hole from 10,975' 10,975.0 10,882.0 00:45 01:45 MD to 10,882' MD @ 100 fph circulate btms up @ 370 gpm 1240 psi. ROT = 190k, Torque 7k with 30 rpm. ECD =11.65 ppg. 1/11/2019 1111/2019 0.50 INTRM2 CEMENT OWFF P Flow check well static, Blow down top 10,882.0 10,882.0 01:45 02:15 drive. Line up MPD. 1/11/2019 1/1112019 5.00 INTRM2 CEMENT SMPD P Strip out of hole with MPD per 10,882.0 3,543.0 02:15 07:15 schedule from 10,882' MD to 3,543' MD, maintaining 11.7 ppg with 200 psi in slips, 345 psi pulling. (No drag observed SOOH with SDL BHA through 7" liner top) 1/11/2019 1/11/2019 0.25 INTRM2 CEMENT OWFF P Flow check well static, PJSM for MPD, 3,543.0 3,543.0 07:15 07:30 RCD/Tnp nipple, Prep tools and equipment. 1/11/2019 1/11/2019 0.50 INTRM2 CEMENT MPDA P Pull MPD bearing and install trip 3,543.0 3,543.0 07:30 08:00 nipple. P/U and SIO 107k. 1/11/2019 1/11/2019 1.25 INTRM2 CEMENT BHAH P POOH from 3,543' MD to 3,215' MD. 3,543.0 3,215.0 08:00 09:15 P/U and SIO 101 k. Lay down flow diverter assembly, stabilizer and liner running tool. 1/11/2019 1/11/2019 2.25 INTRM2 CEMENT TRIP P POOH from 3,215' MD to 272' MD. 3,215.0 272.0 09:15 11:30 1/11/2019 1/11/2019 0.25 INTRM2 CEMENT OWFF P Monitor for flow, static 272.0 272.0 11:30 11:45 Function test annular, upper and lower rams. (weekly) 1/11/2019 1111/2019 3.25 INTRM2 CEMENT BHAH P Lay down BHAand unload/secure 272.0 0.0 11:45 15:00 sources from MWD from 272' MD. Function test blind rams. 1/11/2019 1/11/2019 1.00 INTRM2 CEMENT BHAH P Clean and clear dg floor. P/U tools and 0.0 0.0 15:00 16:00 equipment for cement retainer / liner hanger and packer run. 1/11/2019 1/11/2019 2.50 INTRM2 CEMENT TRIP P Make up K-1 Cement retainer as per 0.0 3,055.0 16:00 18:30 BOT rep. RIH with 4" DP to 3,055' MD 1/11/2019 1/11/2019 1.25 INTRM2 CEMENT PUTS P Rig up double stack tongs, change to 3,055.0 3,055.0 18:30 19:45 5" handling equipment. P/U SLZXP, make up 10.62' pup on bottom. Make up latching seal assy to packer, Torque tum to 12k. Make up to inner string. PIU and SIO 95k. 1/11/2019 1/11/2019 0.25 INTRM2 CEMENT TRIP P RIH from 3,055' MD to 3,228' MD. 3,055.0 3,228.0 19:45 20:00 1/11/2019 1/11/2019 0.25 INTRM2 CEMENT CIRC P At 3,228' MD fill pipe and circulate 3,228.0 3,228.0 20:00 20:15 string volume at 189 gpm 300 psi. PIU and SIO 95k. 1/11/2019 1/12/2019 3.75 INTRM2 CEMENT TRIP P RIH with assembly from 3,228' MD to 3,228.0 7,843.0 20:15 00:00 7,843' MD on 5" DP. Fill pipe every 20 stands. S/0=150k. 1/12/2019 1112/2019 0.50 INTRM2 CEMENT CIRC P Make up to top drive, establish 7,898.0 7,898.0 00:00 00:30 circulation and wash through TOL @ 7,898' MD with retainer. 2 bpm @ 250 psi. Observed no loss of S/0 weight I going into TOL. Blow down top drive. 1/12/2019 1/12/2019 4.25 INTRM2 CEMENT TRIP P Continue RIH to 10,951' MD. P/U 7,898.0 10,951.0 00:30 04:45 1 I =218k S/0=175k. Page 13129 Report Printed: 2/1 912 01 9 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -x Operation (ftKB) End Depth (ftKB) 1/12/2019 1/1212019 0.75 INTRM2 CEMENT WASH P Make up tag stand, Break circulation 10,951.0 10,999.0 04:45 05:30 42-84 gpm 300-430 psi. PIU=218k S/O 1751k, Wash down slow at 42 gpm 300 psi. Noticed 30psi increase from 300 psi to 330 psi and seals intered TOL. at 7,863' MD. K-1 at 10,999' MD. Rack back tag stand and Blow down top drive. 1/12/2019 1112/2019 1.00 INTRM2 CEMENT RURD P Space out, Make up single 5" drill pipe 10,999.0 10,999.0 05:30 06:30 and two 5" pup joints with cement swivel. 1/12/2019 1/12/2019 0.25 INTRM2 CEMENT WASH P Break circulation at .8 bpm 300 psi, 10,999.0 10.999.0 06:30 06:45 Wash in and noticed 30 psi increase from 300 - 330 psi as seals intered TOL at 7,898'(K-1 @ 10,999') Continue to slack off to 11,004.95' as Nogo lands and latch seal easy. Bleed off string pressure and Pull test to 250k, SIO to 175k to confirm latch. 1/12/2019 1/12/2019 2.25 INTRM2 CEMENT CIRC P Break circulation at .5 bpm 270 psi, 10,999.0 10,999.0 06:45 09:00 stange pumps up in .5 bbl increments to 2.5 bpm 450 psi. Observed no mud losses. 1/12/2019 1112/2019 0.50 INTRM2 CEMENT CIRC P Drop 1.75" bronze release ball, pump 10,999.0 11,004.0 09:00 09:30 down @ 2 bpm, 400 psi. Ball on seat @ 287 silks. Pressure up to 4000 psi, bleed down to 500, Observed pressure drop to 0 psi in 5 minutes for DOSS to open. 1/1212019 1/12/2019 0.50 INTRM2 CEMENT MPSP P P/U from 11004.95 MD to 10,988' MD 11,004.0 10,988.0 09:30 10:00 and set cement retainer with RH rotation per Baker rep. Un -sting from retainer. P/U=240k, S/0=145k. 1/12/2019 1/12/2019 1.00 INTRM2 CEMENT CIRC P Break circulation with 3 bpm 500 psi, 10,988.0 10,988.0 10:00 11:00 stage up pumps to 7 bpm 1070 psi, (SIMOPS- PJSM on cementing) 1/12/2019 1/12/2019 2.50 INTRM2 CEMENT CMNT P Monitor well for flow (static) Pump 2 10,988.0 10,988.0 11:00 13:30 bbls water, Test lines to 3,000 psi. Pump 38.4 bbls 11.5 ppg mud push II, Mix and pump 55.1 bbls 15.8 ppg cement, Pump 20 bola water. Sting in and displace with 142 bbls 10.9 ppg LSND mud. Final circulation pressure at 2 bpm 720 psi. 300 psi lift pressure. Cement in place at 13:30 hrs. Observed no mud losses. 1/12/2019 1/12/2019 0.25 INTRM2 CEMENT CIRC P P/U 20'to expose rotating dog sub. 10,988.0 10,965.0 13:30 13:45 S/0=125k. Set 60k down to set liner hanger/ packer assy, observe shear @ 160k, P/U, rotate 20 rpm (ROT =200k) 6.5K torque and repeat to confirm as per BOT Rep. 1/12/2019 1/12/2019 0.75 INTRM2 CEMENT CIRC P Circulate out 20 bbls water and 2.7 10,965.0 10,965.0 13:45 14:30 bbls cement at 10,965' 13 bpm 2700 psi. 1/12/2019 1/1212019 1.00 INTRM2 CEMENT RURD P Pump 20 bbls water surface/surface at 10,965.0 10,965.0 14:30 15:30 15.5 bpm 3640 psi. 1112/2019 1112/2019 1.25 INTRM2 CEMENT RURD P Blow down mud system, Flush and 10,965.0 10,965.0 15:30 16:45 UD cement swivel and 5" pup joints. 1112/2019 1/12/2019 5.50 INTRM2 CEMENT PULD P PJSM, POOH UD 5" drill pipe from 10,965.0 7,933.0 16:45 22:15 10,965' to 7,933'. Cleaning out cement rings from tool joints. Page 14/29 Report Printed: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sbrl Time End Time Our (hr)Phase Op Gods Activity GDde Time P-T-X Operation start Depth (MB) End Depth (WB) 1/12/2019 1/12/2019 1.25 INTRM2 CEMENT CIRC P Wash accross 7" liner top from 7,933' 7,933.0 7,841.0 22:15 23:30 to 7,841'@ 15.5 bpm 2200 psi. Pump 22 bbls 12.9 ppg slug. Blow down top 1drive. 1/12/2019 1/13/2019 0.50 INTRM2 CEMENT PULD P POOH UD 5" drill pipe from 7,841'to 7,841.0 7,748.0 23:30 00:00 7, 748'. Cleaning out cement rings from tool joints. 1/13/2019 1/1312019 4.75 INTRM2 CEMENT PULD P Continue POOH with liner running 7,748.0 3,139.0 00:00 04:45 tools and cement stinger, laying down 5" drill pipe from 7,748' MD to 3,139' MD. Cleaning out cement rings from tool joints. 1/13/2019 1/13/2019 1.00 INTRM2 CEMENT BHAH P Lay down Baker liner running tools 3,139.0 3,055.0 04:45 05:45 from 3,139' MD to 3,055' MD. Observe dog sub sheared. Change out to 4" running tools. 1/13/2019 1/13/2019 1.50 INTRM2 CEMENT TRIP P POOH from 3,055' MD, racking back 3,055.0 0.0 05:45 07:15 4" DP. 1/13/2019 1/13/2019 0.50 INTRM2 CEMENT SHAH P Lay down cement retainer running tool 0.0 0.0 07:15 07:45 and stinger, 1/13/2019 1/13/2019 0.50 INTRM2 CEMENT '(5-LEN P Clean and clear rig floor. UD excess 0.0 0.0 07:45 08:15 1 1 1 tools and equipment. 1/13/2019 1/13/2019 1.00 INTRM2 CEMENT RURD P Make up test joint, FMC pull 8.812" ID 0.0 0.0 08:15 09:15 wear ring. 1113/2019 1/13/2019 1.00 INTRM2 CEMENT PRTS P Rig up and test liner top packer and 0.0 0.0 09:15 10:15 retainer to 1000 psi for 10 minutes charted, (good test.) RID test equipment. Blow down lines. 1/13/2019 1/13/2019 2.50 INTRM2 CEMENT RURD P Mobilize 7" casing handling equipment 0.0 0.0 10:15 12:45 to rig floor, R/U to run tie-back. M/U Volant CRT. 1/13/2019 1/13/2019 0.25 INTRM2 CEMENT PUTB P Make up seal assembly, X/O and 7" 0.0 0.0 12:45 13:00 29#, H563 Dopeless 1/1312019 1/13/2019 6.25 INTRM2 CEMENT PUTB P Continue P/U and RIH with 7" 29# TN- 0.0 4,884.0 13:00 19:15 110 563 dopeless Torque to 12, 10011- lbs. to 4,884' MD. 1/13/2019 1/13/2019 1.50 INTRM2 CEMENT RURD P R/U torque turn equipment, test same 4,884.0 4,884.0 19:15 20:45 while clen and clear rig floor. 1/13/2019 1/14/2019 3.25 INTRM2 CEMENT PUTB P Continue P/U and RIH with 7" 26# L- 4,884.0 6,165.0 20:45 00:00 80 TSH- Blue, Torque to 9,010ft-lbs. From 4,884' MD to 6,165' MD. 5,259' joint #132 improper torque, Back out and clean connection (no issues) retorqued same. 1/14/2019 1/14/2019 1.50 INTRM2 CEMENT PUTB P Continue P/U and RIH with 7" 26# L- 6,165.0 6,708.0 00:00 01:30 80 TSH- Blue, Torque to 9,01 Oft-lbs. From 6,165' MD to 6,708' MD. 1/14/2019 1/14/2019 1.00 INTRM2 CEMENT PULD T Attempt to makeup joint #168. Unable 6,768.0 6,708.0 01:30 02:30 to achieve proper torque after cleaning and redressing threads. Lay down joint #168 and replace with joint #206. Change out collar on joint #167. 1/1412019 1/14/2019 0.75 INTRM2 CEMENT PUTB P Continue P/U and RIH with 7" 26# L- 6,708.0 6,992.0 02:30 03:15 80 TSH- Blue, Torque to 9,010ft-lbs. From 6,708' MD to 6,992' MD. 1/14/2019 1/14/2019 0.50 INTRM2 CEMENT PULD T Attempt to makeup joint#174. Unable 6,992.0 6,992.0 03:15 03:45 to achieve proper torque after cleaning and redressing threads. Lay down joint #174 and replace with joint #196. Change out collar on joint #173. Page 15129 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur(hn Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth h1KB) 1/14/2019 1/14/2019 4.25 INTRM2 CEMENT PUTB T Continue P/U and RIH with 7" 26# L- 6,992.0 7,861.0 03:45 08:00 80 TSH- Blue, Torque to 9,010ft-lbs. From 6,992' MD to 7,861' MD. Polishing each connection to achieve proper torque. 1/14/2019 1/14/2019 1.00 INTRM2 CEMENT HOSO P Establish circulation on joint #195 with 7,861.0 7,892.0 08:00 0900 Volant CRT @ 1 bpm, 270 psi. PU= 220k SO=185k. Wash down to locate TOL. Locate seals @ 7,872.12' via pressure increase. Shut down and bleed off, slack off to no-go @ 7,892'. (TOL=7,872.12' MD 6,444.7 TVD, Shoe 11,059.93' MD 7,902.7 TVD corrected.) 1/14/2019 1/14/2019 0.50 INTRM2 CEMENT PRTS P Rig up and pressure test seal 7,892.0 7,892.0 09:00 0930 assembly via 9-5/8" X 7" annulus to 1000 psi for 10 minutes, with bleeder open on casing side. Good test. 1/14/2019 1/14/2019 0.25 INTRM2 CEMENT HOSO P Sting out and LID 7" singles from 7,892.0 7,820.0 09:30 09:45 7,892' MD to 7,820' MD. 1/14/2019 1/14/2019 0.75 INTRM2 CEMENT WAIT P Make up 7" space out pups (4.98' and 7,820.0 7,820.0 09:45 10:30 3.85') Observed 19' pup joint was 7 5/8". Decision made to LID pups and wait on pup joint to arrive. 1/14/2019 1/14/2019 2.25 INTRM2 CEMENT CIRC T Clean and clear rig Floor, while waiting 7,820.0 7,820.0 10:30 12:45 1 on 7" 26 ppf L-80 TSH Blue pup joint. 1/14/2019 1/14/2019 3.00 INTRM2 CEMENT HOSO P Make up 18.15' pup, X/O from TSH 7,820.0 7,873.0 12:45 15:45 Blue to H563, M/U 1.8' space out pups. M/U hanger and landing joint. R/U lines to Volant tool to pump. Pump down casing string @ 4 bpm 480 psi (SIMOPS PJSM spot inhibitor and diesel.) 1/14/2019 1/14/2019 1.50 INTRM2 CEMENT CRIH P Reverse in 40 bbl Hi Vis spacer, 180.7 7,873.0 7,873.0 15:45 17:15 bbl corrosion inhibited seawater into 9.625" x 7" annulus. @3.5 bpm 650 psi. 1/14/2019 1/14/2019 1.00 INTRM2 CEMENT FRZP P Line up Ball mill and PT lines to 2500 7,873.0 7,873.0 17:15 1815 psi. 40.5 bbl diesel pumped by Ball Mill into 9.625" x 7" annulus @ 3 bpm, 834 psi. 1/14/2019 1/14/2019 0.25 INTRM2 CEMENT HOSO P Shut down, strip in landing joint until 7,873.0 7,892.0 18:15 1830 seals entered TOL, Bleed pressure to 0, open annular and continue slacking off until landed @ 7,892' seal assy depth, spaced 7.13' off fully located. 1/14/2019 1/14/2019 1.00 INTRM2 CEMENT RURD P Rig down reverse circulating 0.0 0.0 18:30 1930 equipment, back out and lay down landing joint. RID Volant tools and equipment. 1/14/2019 1/14/2019 1.00 INTRM2 CEMENT WWSP P Make up packoff running tool, Install 0.0 0.0 19:30 2030 13"W" Packoff. Run in lock downs and packoff, torque to 450 ft -lbs. Pressure test void to 250/5000 psi, 5min/10min. Good test witnessed 1/14/2019 1/14/2019 1.00 INTRM2 CEMENT PRTS P Pressure test 9-5/8" x 7" annulus to 0.0 0.0 20:30 21:30 2500 psi for 30 minutes charted, good. Used Ball Mill pump and diesel for test. Bleed annulus to 0 psi, close in valves. Clear lines of diesel. Install PT sensor I gauge on annulus @ wing valve. Page 16129 ReportPrinted: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Siert Depth St in Time End Time Dur (hr) Phase Op Code Acwdy Code Time P -T -X Opetatlon (ftKB) End Depth (/11<13) 1/14/2019 1/15/2019 2.50 INTRM2 CEMENT BOPE P Change out upper rams from 4-1/2" x 0.0 0.0 21:30 00:00 7" VBR to 3W x 6" VBR. SIMOPS- Change out saver sub on top drive from NC50 to XT39. 1/15/2019 1/15/2019 0.75 INTRM2 CEMENT SEQP P Continue change out saver sub on top 0.0 0.0 00:00 00:45 drive from NC50 to XT39. 1/15/2019 1/15/2019 1.25 INTRM2 CEMENT BOPE P Rig up and test upper 3.5" X 6" VBR 0.0 0.0 00:45 02:00 to 250/3500 for 5/10 minutes with 4" lest joint. 7" annulus vented for leak path, Monitor same. 1/15/2019 1/15/2019 0.50 INTRM2 CEMENT RURD P Pull test plug, R/D test equipment. 0.0 0.0 02:00 02:30 Install 6.25" ID wear bushing. 1/15/2019 1/15/2019 0.50 INTRM2 CEMENT RURD P Clean and clear rig floor and install 4" 0.0 0.0 02:30 03:00 elevators. 1/15/2019 1/15/2019 2.25 INTRM2 CEMENT BHAH P P/U and RIH with BHA#6 to 294' MD. 0.0 294.0 03:00 05:15 BHA weight 12k 1/15/2019 1/15/2019 5.25 INTRM2 CEMENT PULD P RIH with clean out BHA#6, picking up 294.0 4,279.0 05:15 10:30 4" DP singles from pipe shed to 4,279' MD. 1/15/2019 1115/2019 9.25 INTRM2 CEMENT WAIT T Phase III weather conditions, Shut 4,279.0 4,279.0 10:30 19:45 down operations at 1030 hrs. Break Circulation at 4,279' MD 100 gpm 320 psi. every 6 him while WOW. 1/15/2019 1115/2019 0.25 INTRM2 CEMENT SFTY P Received Phase II weather conditions 4,279.0 4,279.0 19:45 20:00 at 1945 hrs to resume operations, PJSM P/U and continue RIH with 4" singles. 1/15/2019 1/16/2019 4.00 INTRM2 CEMENT PULD P RIH with clean out BHA#6, picking up 4,279.0 4,708.0 20:00 00:00 4" DP singles from pipe shed from 4,279' MD. to 7,408' MD. 1/16/2019 1/16/2019 1.00 INTRM2 CEMENT PULD P Continue to single in the hole with 6" 4,708.0 8,269.0 00:00 01:00 clean out assembly on 4" 14# Drill pipe 1/16/2019 1/16/2019 1.50 INTRM2 CEMENT TRIP P RIH w/6" clean out assembly on 4" 8,269.0 10,740.0 01:00 02:30 14# drill pipe from the derrick. 1/16/2019 1/16/2019 1.25 INTRM2 CEMENT SLPC P Slip and cut 75' of drill line. 10,740.0 10,740.0 02:30 03:45 Circulate at 2bpm 750psi while slipping and cutting. Cut MW back to a 10.2ppg 1/16/2019 1/1612019 0.50 INTRM2 CEMENT SVRG P Service Top Drive and Drawworks. 10,740.0 10,740.0 03:45 04:15 Circulate at 2bpm 750psi while slipping and cutting. Cut MW back to a 10.2ppg 1/16/2019 1/16/2019 1.25 INTRM2 CEMENT CIRC P Circulate and condition mud to a 10,740.0 10,740.0 04:15 05:30 10.2ppg 280 gpm 1580 psi. 1116/2019 1/16/2019 0.25 INTRM2 CEMENT RURD P Rig up for casing test, rig up surface 10,740.0 10,740.0 05:30 05:45 lines and establish circulation kill line. 1116/2019 1/16/2019 1.25 INTRM2 CEMENT PRTS P Test 7" casing string to 3500 psi for 30 10,740.0 10,740.0 05:45 07.00 minutes charted, good. 1/16/2019 1/16/2019 0.50 INTRM2 CEMENT RURD P Rig down test equipment, blow down 10,740.0 10,740.0 07:00 07:30 kill line. 1/16/2019 1/16/2019 1.00 INTRM2 CEMENT COCF P Wash and ream down from 10,740' 10,740.0 10,991.0 07:30 08:30 MD to 10,991' MD tag up on cement I cement retainer. 200 gpm, 1060 psi, 40 rpm, 4k. 1/16/2019 1/16/2019 2.00 INTRM2 CEMENT DRLG P Continue drill cement retainer and 10,991.0 11,025.0 08:30 10:30 cement from 10,991' MD to 11,025' MD. 200-300 gpm 1150-1650 psi. 15k WOB. 1/16/2019 1116/2019 1.25 PRODi CEMENT CIRC P Pump 29 bbls 11 ppg Hi -Vis sweep at 11,025.0 11.025.0 10:30 11:45 11,025' MD, Continue circulate sweep out at 11,025' MD @ 300 gpm 1650 psi. 50 rpm 4k torque. Page 17129 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log SWTime End Time Dur(m) Phase op Code AdN@/Code Time P-T-X Operation Start Depth mKB) End Deph(nKB) 1/1612019 1/16/2019 0.50 PROD1 CEMENT OWFF P Observe well for flow @ 11,025'MD. 11,025.0 11,025.0 11:45 12:15 Sialic 1/16/2019 1/16/2019 4.25 PROD1 CEMENT TRIP P POOH on elevators from 11,025' MD 11,025.0 4,564.0 12:15 16:30 to 4,564' MD. 1/16/2019 1/16/2019 0.25 PROD1 CEMENT CIRC P Pump 21 bbls 11 ppg slug. Blow down 4,564.0 4,564.0 16:30 16:45 top drive. 1/16/2019 1/1612019 1.75 PROD1 CEMENT TRIP P POOH on elevators from 4,564' MD to 4,564.0 112.0 16:45 18:30 1 1 1112'MD. 1/16/2019 1/16/2019 0.75 PROD1 CEMENT OWFF P Observe well for flow @ 116' MD. 112.0 112.0 18:30 19:15 Static (SIMOPS) R(D mud bucket and air slips. PIU tools to handle BHA. 1/1612019 1/16/2019 2.00 PROD1 CEMENT BHAH P UD BHAfrom 112' MD. Clean and 112.0 0.0 19:15 21:15 clear rig floor from spare tools and equipment. ****Recover 75lbs of metal debris from magnets'*** 1116/2019 1/1612019 0.75 PROD1 CEMENT W W WH P Flush stack @ 9 bpm. Blow down lop 0.0 0.0 21:15 22:00 1 drive. 1/16/2019 1/16/2019 0.50 PROD1 WHDBOP RURD P R/U test joint and wear bushing 0.0 0.0 22:00 22:30 retrieving tool. Pull wear bushing. ( ID 6.25" No wear) 1/1612019 1/16/2019 0.25 PROD1 WHDBOP WWWH P Flush stack @ 10 bpm 330 psi.. Blow 0.0 0.0 22:30 22:45 down lop drive. 1/16/2019 1/17/2019 1.25 PROD1 WHDBOP RURD P Drain stack and set test plug. R/U to 0.0 0.0 22:45 00:00 test BOPE. Fill stack and manifold with water, purge air from system. Shell test to 2500 psi (good test) 1/17/2019 1/17/2019 7.25 PROD1 WHDBOP BOPE P Test BOPE with 3.5" and 4.5" test jts. 0.0 0.0 00:00 07:15 AOGCC rep Austin McLoud witness test. BLM rep Quinn Sawyer waived witness on 1-13-19 at 1108 hrs. With 4.5" TJ, test annular preventer to 250/2500 psi for 5110 min, 3Yz' x 6" Upper VBR's, 31/." x 6" lower VBR's to 250/3500 psi for 5/10 min.Test 4" Demco Kill valve, Auto and manual IBOP valves, HCR and Manual Choke and Kill valves, floor safety valves 1- XT39 and, Dart Valves 1-XT39, Choke Valves 1-14 and Needle valve to 250/3500 psi for 5/10 min. Test gas alarms, Flow paddle and High level pit alarms. Perform accumulator test, System Pressure=3000 psi, Pressure after functioning all rams, annular and HCR's=1700 psi, 200 psi attained=26 sec, Full System Recovery=111 sec. 4 bottle Nitrogen average=2100 psi. Change to 3.5" test joint, test annular to 250/2500 and lower VBR's to 250/3500 psi for 5110 min. Test blind rams to 250/3500 5/5 min. Test Manual and Super Auto chokes to 1100 psi. 1/1712019 1/17/2019 0.50 PROD1 WHDBOP RURD P R/D test equipment. Blow down choke 0.0 0.0 07:15 07:45 and kill lines. 1/17/2019 1/1712019 0.50 PROD1 WHDBOP RURD P Pull test plug and install 6.25" wear 0.0 0.0 07:45 08:15 1 I I ring. 1/17/2019 1/1712019 0.25 PROD1 CEMENT RURD P P/U RCD bearing and R/U BPA 0.0 0.0 08:15 08:30 I I I manifold. Page 18129 Report Printed: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log sten Depm StartTime End Time our(hr) Phaae op Code AdMty Code Time P -T -X Operaon (ftKB) End Depth(ftKB) 1/17/2019 1/17/2019 3.50 PROD? CEMENT SHAH P PJSM, M/U BHA#7 to 135' MD per 0.0 135.0 08:30 12:00 Baker DD/MWD, Upload MWD/Perfom teslrak function test with 200 gpm 770 psi. Blow down top drive. 1/17/2019 1/17/2019 1.00 PROD1 CEMENT BHAH P PJSM, P/U BHA#7 and load nukes 135.0 355.0 12:00 13:00 from 135' MD to 355' MD per Baker DD/MWD, Belowjar 11.5k Total 14.8k. 1/17/2019 1/17/2019 6.25 PROD1 CEMENT TRIP P Trip in hole with BHA#7 from 355' to 355.0 10,991.0 13:00 19:15 10991' MD from derrick. Fill pipe every 20 stands. Trip displacement (Calculated: 69 bbls, ACT: 61 bbls.) 1/17/2019 1/17/2019 0.50 PROD? CEMENT COCF P Wash and ream down from 10,991' 10,991.0 11,025.0 19:15 19:45 MD to 11,025' MD @ 200 gpm, 1600 psi, 60 rpm @ 5-61k Tq. Continue cutting mud weight to 10.2 ppg. 1/17/2019 1/17/2019 2.00 PROD1 CEMENT DRLG P Drill cement out shoe track from 11,025.0 11,132.0 19:45 21:45 11,025' MD to 11,059' MD. Clean out rat hole from 11,059' MD to 11,132' MD. @ 200 gpm, 1670 psi, 60 rpm @ 7-8k Tq. 1/17/2019 1/17/2019 0.50 PRODt CEMENT DDRL P Drill new formation from 11,132' MD to 11,132.0 11,152.0 21:45 22:15 11,152' MD. @ 215 gpm @ 1630 psi, 11.05 ppg ECD. P/U=170k, 8/0=145k, ROT=160k, 60 rpm. Tq on/off-7k. 1/17/2019 1/17/2019 1.25 PROD1 CEMENT CIRC P Back ream from 11,152' MD to 11,022' 11,152.0 11,022.0 22:15 23:30 MD @ 215 gpm, 1630 psi, 60 rpm 7.71k Tq. Work string inside the casing without rotation 4x. Rack back stand to 9,457' MD. 1/17/2019 1/18/2019 0.50 PROD1 CEMENT FIT P R/U and perform FIT to 12.5 ppg, 985 11,022.0 11,022.0 23:30 00:00 psi with 10.1 ppg mud in hole, no leak off. 1.4 bbl pumped and bled back. Shut in pressure 850 psi after ten minutes. 1/18/2019 1/18/2019 0.25 PROW CEMENT FIT P Finish monitor shut in pressure from 11,022.0 11,022.0 00:00 00:15 FIT & RID testing equipment. 1/18/2019 1/18/2019 0.50 PROD1 DRILL MPDA P Remove trip nipple & install RCD 11,022.0 11,022.0 00:15 00:45 bearing. 1/18/2019 1/18/2019 0.50 PROD1 DRILL REAM P W&R f/11,022'to 11, 152'w/200, 1440 11,022.0 11,152.0 00:45 01:15 psi, 60 rpm, 8 k trq 1/18/2019 1/18/2019 1.75 PROD1 DRILL DISP P Pump 26 bbls Hi -Vis spacer and 11,152.0 11,152.0 01:15 03:00 displace 10.1 ppg mud with 8.8 ppg FloPro @200 gpm 1200 gpm, 60 rpm while reaming from 11,152' MD to 11,086' MD. Take SCR's 1/18/2019 1/18/2019 0.75 PROD1 DRILL OWFF P Perform MPD draw down test with 8.8 11,152.0 11,152.0 03:00 03:45 ppg FloPro (25 psi increase) Well static 1/18/2019 1/18/2019 0.25 PROD1 DRILL REAM P Wash and ream from 11,086' MD to 11,152.0 11,152.0 03:45 04:00 11,152' MD @ 200 gpm 1010 psi 80 rpm 5k torque. 1/18/2019 1/18/2019 8.00 PROD1 DRILL DDRL P Directional drill from 11, 152' MD to 11,152.0 11,805.0 04:00 12:00 11,805' MD, 7,922' TVD @ 226 gpm, 1560 psi, 140 rpm, 8k ftlbs Tq. P/U wt 183k, SIO wt 139k, ROT wt 1591k. ADT= 6.4 hm ECD: 10.03 ppg Max gas 4788 units. 1/18/2019 1/19/2019 12.00 PROD1 DRILL DDRL P Directional drill from 11,805' MD to 11,805.0 13,178.0 12:00 00:00 13,178' MD, 7,896' TVD @ 230 gpm, 1870 psi, 140 rpm, 8k ftlbs Tq. PIU wt 185k, S/O wt 140k, ROT wt 156k ADT= 9.4 hrs ECD: 10.36 ppg Max gas 7833 units. Page 19129 Report Printed: 2119/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log StartTime End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (MB) 1/19/2019 1/19/2019 12.00 PROD1 DRILL DDRL P Directional drill from 13,178' MD to 13,178.0 13,870.0 00:00 12:00 13,870' MD, 7,896' TVD (oj 230 gpm, 2070 psi, 150 rpm, 9k - 12 ftlbs Tq. P/U wt 180k, S/O wt 130k, ROT wt 150k ADT= 9.9 hrs ECD: 10.48 ppg Max gas 6500 units @ 13,450' MD. 1/19/2019 1/20/2019 12.00 PROD1 DRILL DDRL P Directional drill from 13,870' MD to 13,870.0 14,978.0 12:00 00:00 14,978' MD, 7,898' TVD @ 230 gpm, 2110 psi, 140 rpm, 7.5k Ribs Tq. P/U wt 185k, S/O wt 130k, ROT wt 155k ADT= 9.9 hrs ECD: 10.16 ppg Max gas 8500 units @ 14660' MD. 1/20/2019 1/20/2019 12.00 PROD1 DRILL DDRL P Directional drill from 14,978' MD to 14,978.0 15,654.0 00:00 12:00 15,654' MD, 7,922' TVD @ 230 gpm, 2190 psi, 140 rpm, 5 / 8.7k ftlbs Tq. PIU wt 190k, S/O wt 125k, ROT wt 155k ADT= 10.4 hrs ECD: 10.62 ppg Max gas 9000 units @ 15,150' MD. 1/20/2019 1/21/2019 12.00 PROW DRILL DDRL P Directional drill from 15,654' MD to 15,654.0 16,615.0 12:00 00:00 16,615' MD, 7,944' TVD @ 230 gpm, 2070 psi, 140 rpm, 6.5 / 8.5k ftlbs Tq. P/U wt 210k, S/O wt 115k, ROT wt 152k ADT= 9.8 hrs ECD: 10.26 ppg Max gas 5300 units @ 16,490' MD. 1/21/2019 1/21/2019 12.00 PROD? DRILL DDRL P Directional drill from 16,615' MD to 16,615.0 17,042.0 00:00 1200 17,042' MD, 7,940' TVD @ 230 gpm, 2300 psi, 150 rpm, 9 / 6.5k ftlbs Tq. P/U wt 21 Ok, S/O wt 115k, ROT wt 152k ADT= 10.4 hrs ECD: 10.47 ppg Max gas 9020 units @ 16,650' MD. 1/21/2019 1/22/2019 12.00 PRODi DRILL DDRL P Directional drill from 17,042' MD to 17,042.0 18,001.0 12:00 00:00 18,001' MD, 7,957' TVD @ 230 gpm, 2300 psi, 140 rpm, 11 / 7k ftlbs Tq. P/U wt 216k, SIO wt 115k, ROT wt 158k ADT= 10 hrs ECD: 10.81 ppg Max gas 9980 units @ 17,450' MD. 1/22/2019 1/22/2019 12.00 PROD1 DRILL DDRL P Directional drill from 18,001' MD to 18,001.0 18,580.0 00:00 12:00 18,850' MD, 7,933' TVD @ 230 gpm, 2370 psi, 140 rpm, 11.6 / 7k Us Tq. PIU wt 21 Ok, S/O wt N/Ak, ROT wt 162k ADT= 10.1 hrs ECD: 10.50 ppg Max gas 4570 units @ 18,210' MD. 1/22/2019 1/23/2019 12.00 PROD1 DRILL DDRL P Directional drill from 18,850' MD to 18,580.0 19,529.0 12:00 00:00 19,529' MD, 7907' TVD @ 230 gpm, 2370 psi, 150 rpm, 12.3/9 ftlbs Tq. PIU wt 223k, S/O wt N/Ak, ROT wt 158k ADT= 8.1 hrs ECD: 10.85 ppg Max gas 8776 units @ 18,704' MD. 1/23/2019 1/23/2019 12.00 PROD1 DRILL DDRL P Directional drill from 19,529' MD to 19,529.0 20,608.0 00:00 12:00 20,608' MD, 7858' TVD @ 230 gpm, 2100 psi, 150 rpm, 14.5/10 ftlbs Tq. P/U wt 245k, S/O wt N/Ak, ROT wt 160k ADT= 9.4 hrs ECD: 10.72 ppg Max gas 8086 units @ 20,570' MD. 1/23/2019 1/23/2019 PROD1 DRILL DDRL P Directional drill from 20,608' MD to 20,608.0 21,704.0 12:00 12:00 21.704' MD, 7847' TVD @ 230 gpm, 2100 psi, 150 rpm, 15/10 Ribs Tq. P/U wt 245k, S/O wt N/Ak, ROT wt 160k ADT= 9.5 hrs ECD: 10.84 ppg Max gas 8328 units @ 20,733' MD. Page 20129 ReportPrinted: 211912019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth start rime End Time our (hr) Phew Op Code Adivey Cade Time Pd -X Opemdon (fiK8) End DoW (MB) 1/24/2019 1/24/2019 6.50 PROD1 DRILL DDRL P Directional drill from 21,704' MD to 21,704.0 22,228.0 00:00 06:30 22,228' MD, 7834' ND @ 230 gpm, 2670 psi, 150 rpm, 17.5/10.5 fllbs Tq. P/U wt 2501k, SIO wl N/Ak, ROT wt 160k ADT= 5.2 him ECD: 11.4 ppg Max gas 6000 units @ 21,920' MD. 1/24/2019 1/24/2019 3.00 PROD1 CASING CIRC P Circ 2 B/U w/230 gpm, 2650 psi, 80 22,228.0 22,133.0 06:30 09:30 rpm, 12 k trq. Rack back 1 stand to 22,133' 1/24/2019 1/24/2019 0.50 PROD1 CASING OWFF P B/D top drive. Shut in MPD chokes. 22,133.0 22,133.0 0930 10:00 Perform formation draw down test w/8.9 ppg mud. Build 140 psi in 10 min. Bleed off pressure. Build 130 psi in 10 min. Calculate 0.33 ppg under balance. Decision made to weight up to 9.4 ppg 1/24/2019 1/24/2019 0.50 PROD1 CASING BKRM P BROOH f/22,133'to 22,038'w/225 22,133.0 22,038.0 10:00 10:30 gpm, 2520 psi, 30 rpm, 10 k trq. Weight up on the fly to 9.4ppg 1/24/2019 1/24/2019 1.50 PROD1 CASING PMPO P Pump OOH w/225 gpm, 2050 psi. 22,038.0 21,948.0 10:30 12:00 f/22,038'to 21,948'laking Test Track pressure samples as per Baker reps. (Continue to weight up to 9.4ppg). 1/24/2019 1/24/2019 2.00 PROD1 CASING DLOG P Test station 1: 21,948' MD, 3 attempts 21,948.0 21,948.0 12:00 14:00 to obtain sample no success. (continue to weight up to 9.4ppg). 1/24/2019 1/24/2019 1.00 PROD1 CASING BKRM P Backream f/ 21948'to 21,840' 21,948.0 21,840.0 14:00 15:00 225gpm, 2230psi, 100 rpm, 12.51k ft/lbs tq. (continue weighting up to 9.4ppg). Decision made to go back to bottom and finish weighting up. 1/24/2019 1/24/2019 1.50 PROD1 CASING WASH T Wash/ream 21,840'to 22,226' 21,840.0 22,226.0 15:00 16:30 225gpm, 2350psi, 80-120 rpm, 12- 12.5k f Ilbs tq. (continue weighting up to 9.4ppg) 1/24/2019 1124/2019 2.00 PRODt CASING CIRC T Circulate and condition mud. Finish 22,226.0 22,226.0 16:30 18:30 weighting up to 9.4ppg. 1/24/2019 1/24/2019 0.50 PRODt CASING OWFF T Perform 30 minute Flow check. Static. 22,226.0 22,226.0 18:30 19:00 1/24/2019 1/24/2019 1.50 PRODt CASING BKRM T Backream f/ 22,226'to 21,851' 22,226.0 21,851.0 19:00 20:30 1 1 1225gpm, 2400psi, 80rpm, 12k fUlbs tq, 1/24/2019 1/25/2019 3.50 PROD1 CASING DLOG P Log 21,851' to 21,654' for corrrelation. 21,851.0 21,654.0 20:30 00:00 Get on depth for test station #2: bit depth 21,727'sample depth 21,643.37'. 1/25/2019 1/25/2019 10.50 PROD1 CASING DLOG P Pump& BROOH while taking 21,654.0 20,028.0 00:00 10:30 formation pressure samples f/21,654 to 20,028'w/225 gpm, 2350 psi, 50 rpm, 11 k trq (Bit depths for samples; 21,646, 21,566, 21,377, 21,251, 21,163, 20,985, 20,907, 20,495, 20,291, 20,028) 1/25/2019 1/252019 10.00 PROD1 CASING BKRM P BROOH to next sample depth 20,028.0 17,455.0 10:30 20:30 f/20,028' to 17,454 w/225 gpm, 2350 psi, 80 - 30 rpm, 11 - 14 k trq. (Had significant trouble back reaming thru Kingak f/18,385' - 18,100' hole packing off & stalling out top drive). 1/25/2019 1/25/2019 1.00 PRODi CASING DLOG P Take formation pressure sample @ 17,455.0 17,455.0 20:30 21:30 17,454' MD bit depth. 1/252019 1/26/2019 2.50 PROD1 CASING REAM P Wash/ Ream f/ 17,454'to 18,130'. 17,455.0 18,130.0 21:30 00:00 220k PU/ 158k Rol Wt. 200 GPM/ 1870 PSI/ 9k FVLbs TO. Losses @10 bph slowed rate to 200gpm. Page 21129 Report Printed: 2119/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth start Time End Time our (M) Phase Op code Activity Code Time P-T-X Ope2fion (flKB) End Depth (ftKB) 1/26/2019 1/26/2019 13.50 PROD1 CASING REAM P Wash/ Ream f/18,130'to 22,228' 18,130.0 22,228.0 00:00 13:30 w/200 - 220gpm, 1880 - 2000 psi, 80 rpm, 11.5 k trq, PU wt 230 k, ROT wt 159 k. No issues reaming back thru Kingak 1/26/2019 1/26/2019 0.50 PROD1 CASING SVRG P Service rig, top drive & draw works. 22,228.0 22,228.0 13:30 14:00 Circ w/200 gpm, 2000 psi 1/26/2019 1/26/2019 0.50 PROD1 CASING CIRC P Circ & cond w/200 gpm, 2000 psi, 80 22,228.0 22,228.0 14:00 14:30 rpm, 12 k trq. SIMOPS - PJSM & prep for displacemt. 1/26/2019 1/26/2019 2.50 PROD1 CASING DISP P Displace well to 9.6 ppg vis brine 22,228.0 22,228.0 14:30 17:00 w/225 gpm, 2300 psi, 80 rpm, 12 k trq 1/26/2019 1/26/2019 0.50 PROD1 CASING OWFF P FIC (static) SIMOPS - line up MPD to 22,228.0 22,228.0 17:00 17:30 stdpOOH 1/26/2019 1/27/2019 6.50 PROD1 CASING SMPD P StripOOH as per MPD schedule 22,228.0 18,080.0 17:30 00:00 f/22,228' to 18.080'. (18,874'15k drag/ 18,204' 15k drag /18,174' 12k drag) 1/27/2019 1/27/2019 7.25 PROD1 CASING SMPD P StripOOH as per MPD schedule 18,080.0 11,342.0 00:00 07:15 f/18,080' to 11,342' as per MPD schedule. Took wt w/ 25 k wob @ 11,342' and not able to make forward process. Decision made to back ream 1/27/2019 1/27/2019 1.25 PROD1 CASING BKRM T BROOH f/11,342'to 10,992'w/225 11,342.0 10,992.0 07:15 08:30 gpm, 1140 psi, 40 rpm, 6 k trq 1/27/2019 1/27/2019 1.25 PROD1 CASING CIRC P Pump high vis sweep & circ casing 10,992.0 10,992.0 08:30 09:45 clean w/225 gpm, 1300 psi, 40 rpm, 5.6 k trq 1/27/2019 1/27/2019 0.25 PROD1 CASING OWFF P F/C (static) SIMOPS - B/D top drive, 10,992.0 10,992.0 09:45 10:00 function rams, PJSM on C/O RCD bearing. Mobilize tools & equipment. 1/27/2019 1/27/2019 0.50 PRODI CASING MPDA P C/O RCD bearing 10,992.0 10,992.0 10:00 10:30 1/27/2019 1/27/2019 1.00 PRODI CASING SLPC P Slip & cut drill line 75' drill line. 10,992.0 10,992.0 10:30 11:30 Calibrate block height. 1/27/2019 1/27/2019 0.50 PRODI CASING SVRG P Service dg, top drive, draw works. 10,992.0 10,992.0 11:30 12:00 1/27/2019 1/27/2019 0.50 PRODI CASING MPDA P Line up MPD equipment 10,992.0 10,992.0 12:00 12:30 1/27/2019 1/27/2019 7.50 PROD1 CASING SMPD P StripOOH as per MPD schedule 10,992.0 1,020.0 12:30 20:00 f/10,992' to 1,0201. 1/27/2019 1/27/2019 1.00 PROD1 CASING MPDA P Flow check (Static). Retrieve RCD 1,020.0 1,020.0 20:00 21:00 bearing and install trip nipple. 1/27/2019 1/27/2019 1.25 PRODI CASING TRIP P POOH f/ 1020'to 266' 1,020.0 266.0 21:00 22:15 1/27/2019 1/27/2019 1.50 PROD1 CASING BHAH P PJSM. Remove source and UD BHA. 266.0 0.0 22:15 23:45 127/2019 1/28/2019 0.25 PRODI CASING BHAH P Clean & dear floor of BHA tools & 0.0 0.0 23:45 00:00 equipment. 128/2019 128/2019 1.00 COMPZN CASING RURD P Clean rig floor from wet trip. SIMOPS - 0.0 0.0 00:00 01:00 Mobilize liner running tools & equipment. 1/28/2019 1/28/2019 2.00 COMPZN CASING PULD P P/U & rack back in derrick 17 stands 0.0 0.0 01:00 03:00 of 4" HWDP for liner run. 1/28/2019 128/2019 1.00 COMPZN CASING RURD P R/U to run 4-1/2" liner. Power tongs, 0.0 0.0 03:00 04:00 slips & elevators. 1/28/2019 1/28/2019 6.00 COMPZN CASING PUTS P Pick up & RIH 4-1/2" 12.6# L-80 TXP 0.0 5,983.0 04:00 10:00 liner with perf pups to 5,983' (150 jls & 22 pert pups) Page 22129 ReportPrinted: 211912019 Operations Summary (with Timelog Depths) MT6-02 I& Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Siert Time EM lime our (hr) Phase Op Code Activity Cone Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/28/2019 1/28/2019 1.00 COMPZN CASING PUTB P C/O Handle equipment & M/U HRDE 5,893.0 6,018.0 10:00 11:00 liner setting sleeve as per Baker rep. Break circ & confirm fluid path clean w/1 bpm @ 60 psi, PU wt 120 k / SO wt 110 k 1/28/2019 1/28/2019 0.75 COMPZN CASING TURD P RID liner running tools & equipment. 6,018.0 6,018.0 11:00 11:45 Clean & clear floor. 1/28/2019 1/29/2019 12.25 COMPZN CASING RUJNL P7- RIH w/TXP liner on DP f/6,018'to 6,018.0 16,972.0 11:45 00:00 16,972'. Parameters @ 11,047': 165k PU, 140k SO, 152k Rot, 3 bpm @ 370psi, 3.5k fl/Ibs TO @ 10/20/30 rpm. Parameters @ 16,972': 205k PU, 125k SO, 165k Rot, 3 bpm @ 370psi, 8k fUlbs TO @ 10/20/30 rpm. 1/29/2019 1/29/2019 12.00 COMPZ1 CASING RUNL P RIH w/TXP liner on DP f/16,972'to 16,972.0 20.448.0 00:00 12:00 20,448'. PU wt 210 k, SO wt N/A, ROT wt 170 k, 30 rpm, 8.8 - 10 k trq. Washing down @ 1.5 bpm, 150 - 200 psi. Had to rotate liner f/17,900'. Had trouble washing & reaming f/19,695' to 19,715'. 1/29/2019 1/29/2019 1.50 COMPZI CASING RUNL P Tont. W&R-liner f/20,448'to set depth 20,448.0 20,905.0 12:00 13:30 of 20,905'w/1.5 gpm, 200 psi, 30 rpm, 9.7 k trq. Dropped ball on last stand. PU wt 215 k, SO wt N/A, ROT wt 175 k 1/29/2019 1/29/2019 0.75 COMPZ1 CASING CIRC P Circ down ball w/5 bpm, 930 psi. Slow 20,905.0 14,831.0 13:30 1415 pumps to 2 bpm, 240 psi @ 900 stks. Ball on seat 1400 slks. Pressure up to 3000 psi & release from liner. PU with 200 k & confirm free. SO & confirm dogs are out. POOH 1 stand to 14,831' (Shoe @ 20,905'& TOL 14,896') 1/29/2019 1/29/2019 0.25 COMPZ1 CASING OWFF P B/D top drive. FIC (static) 14,831.0 14,831.0 14:15 14:30 1/29/2019 1/30/2019 9.50 COMPZ1 WELLPR TRIP P POOH f/14,831'to 1270'. 14,831.0 1,270.0 14:30 00:00 1/30/2019 1/30/2019 0.50 COMPZI WELLPR TRIP P POOH f/1270'tp 36' 1,270.0 36.0 00:00 00:30 1/30/2019 1/30/2619 0.50 50MPZ1 WELLPR SHAH P UD Baker liner running tools. 36.0 0.0 00:30 01:00 1/30/2019 1/3012019 0.50 COMPZ1 WELLPR CLEN P Clean & clear floor of BHA tools & 0.0 0.0 01:00 01:30 equip, 730/2019 1/30/2019 1.75 COMPZ1 WELLPR PULD P RIH 15 stands of HWDP needed for 0.0 0.0 01:30 03:15 liner run to 1,351'. POOH & UD same. 1/30/2019 1/30/2019 3.00 COMPZ1 WELLPR RGRP P C/O saver sub on lop drive. 0.0 0.0 03:15 06:15 1/30/2019 1/30/2619 0.50 COMPZI WHDBOP WWWH P M/U Johnny wacker&flush stack. 0.0 0.0 06:15 06:45 1/30/2019 1/3012019 2.75 COMPZt WHDBOP RURD P FMC pull wear ring & set test plug. 0.0 0.0 06:45 09:30 R/U to test BOPE. Fill stack with H2O & purge. Flood lines & purge air from system. Shell test BOPE. SIMOPS - C/O valve paddle & seat on 4" Demco Page 23129 Report Printed: 2 /1 912 01 9 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Time End Time Dur (hr) Phase Dp code At%�dy Code Mme P -T -X Operation Start Depth (kKB) End Depth(flKB) 1/30/2019 1/30/2019 5.50 COMPZI WHDBOP BOPE P Test BOPE w/4" & 4-1/2" test joints. 0.0 0.0 09:30 15:00 Annular 250 psi for 5 min 12500 psi for 5 min, Remaining test 250 psi for 5 min! 3500 psi for 5 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper/lower 3-1/2" X 6" VBR's & blind rams, 4" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 2950 psi, final 1450 psi, 1st 200 psi recharge = 31 sec's, full recharge = 160 seconds. Nitrogen Bottles x4 = 2100 psi. Gas alarms and PVT alarms tested. Draw down on chokes U1100 psi. AOGCC Guy Cook waived witness. 1/30/2019 1/30/2019 1.00 COMPZI WHDBOP RURD P R/D testing equipment. Pull test plug & 0.0 0.0 15:00 16:00 set wear ring. 1/30/2019 1/30/2019 3.75 PROD2 DRILL BHAH X PJSM. M/U 6"AutoTrak BHA as per 0.0 344.0 16:00 19:45 Baker reps to 344'. (Load sources) 1/30/2019 1130/2019 2.00 PROD2 DRILL PULD X RIH w/BHA picking up 66 jts 4" DP 344.0 2,200.0 19:45 21:45 f/344' to 2200' 1/30/2019 1/30/2019 0.25 PROD2 DRILL DHEA X Shallow Test MWD tools w/200 gpm, 2,200.0 2,200.0 21:45 22:00 650 psi 1/30/2019 113112019 2.00 PROD2 DRILL TRIP X RIH w/ BHA, culling As w/ worn 2,200.0 2,526.0 22:00 00:00 hardbanding and UD same f/2,200' to 2,526' 1/31/2019 1/31/2019 8.00 PROD2 DRILL TRIP X RIH w/ BHA, culling Jts w/ worn 2,526.0 10,982.0 00:00 08:00 hardbanding and UD same f/2,526'to 10,982' 1/31/2019 1/31/2019 1.00 PROD2 DRILL SLPC X Slip & cut 60' drill line 10,982.0 10,982.0 08:00 09:00 1/31/2019 1/31/2019 0.50 PROD2 DRILL SVRG X Service rig, top drive & draw works. 10,982.0 10,982.0 09:00 09:30 1/31/2019 1/31/2019 1.00 PROD2 DRILL MPDA X Pull trip nipple & install RCD bearing. 10,982.0 10,982.0 09:30 10:30 Break in bearing as per MPD rep. 1/31/2019 1/31/2019 1.00 PROD2 DRILL TRIP X Cont. to RIH 1/10,982'to 11,728' 10,982.0 11,728.0 10:30 11:30 1/31/2019 2/1/2019 12.50 PROD2 DRILL DDRL X Trough, time drill & open hole side 11,728.0 11,735.0 11:30 00:00 track w/230 gpm, 1300 psi, 100 rpm, 6 k trq. f/11,728 to 11,735' (Displace 9.6 ppg vis brine to 8.8 ppg FloPro on thre fly) 2!1/2019 2/1/2019 12.00 PROD2 DRILL DDRL X Time drill f/11,735'to 11,752'MD! 11,735.0 11,752.0 00:00 12:00 7,933' TVD, ADT 12.0 Hrs, ECD 9.73 ppg, 230 gpm, 1390 psi, ROT wt 167 k, 120 rpm, 3.5 k trq. 2/1/2019 2/1/2019 7.50 PROD2 DRILL DDRL X Drill f/11,735'to 11,837' MD / 7,229' 11,752.0 11,837.0 12:00 19:30 TVD, ECD 9.73 ppg, 230 gpm, 1390 psi, ROT wt 167 k, 120 rpm, 3.5 k trq. 2/1/2019 2/1/2019 2.00 PROD2 DRILL DHEQ XT MWD tools stopped working. 11,837.0 11,847.0 19:30 21:30 Troubleshoot tools. Recycle pumps, different flow rates, drilled 10'to 11,847'. Several attempts with no success. After discussion with town decision made to POOH. 2/1/2019 2/2/2019 2.50 PROD2 DRILL BKRM XT Backream OOH f/ 11,B47'to 11,361', 11,847.0 11,361.0 21:30 00:00 Simops Prep to displace to 9.6ppg vis brine. 22/2019 2/212019 2.00 PROD2 DRILL BKRM XT BROOH 0111,361' to 10,981'. No 11,361.0 10,981.0 00:00 02:00 rotation while pulling thru shoe. SIMOPS - Prep to displace to 9.6ppg vis brine. 2/2/2019 2/2/2019 1.75 PROD2 DRILL DISP XT Displace to 9.6 ppg Vis Brine w/225 10,981.0 10,981.0 02:00 03:45 gpm, 1130 psi, 10 rpm, 3.2 k trq. Page 24/29 Report Printed: 2!19(2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (rtKB) End Depth htKB) 2/2/2019 2/2/2019 0.50 PROD2 DRILL OWFF XT F/C (static) 10,981.0 10,981.0 03:45 04:15 2/2/2019 2/2/2019 5.75 PROD2 DRILL SMPD XT StripOOH as per MPD schedule 10,981.0 911.0 04:15 1000 -2 f/10,981' to 2/2/2019 2/2/2019 0.25 15-R-0-5 DRILL OW FF XT F/C (static). SIMOPS - PJSM on 911.0 911.0 10:00 10:15 pulling RCD bearing. 2/2/2019 2/2/2019 0.50 PROD2 DRILL MPDA XT Pull RCD bearing & install trip nipple. 911.0 911.0 10:15 10:45 2/2/2019 2/2/2019 0.25 PROD2 DRILL TRIP XT POOH f/911'to 344' 911.0 344.0 10:45 11:00 2/2/2019 2/2/2019 3.50 PROD2 DRILL BHAH XT Rack back HWDP & jars. Remove 344.0 0.0 11:00 14:30 sources. Plug into tools & determine failure. Bad BCPM & AziTrak. L/D Same. 2/2/2019 2/2/2019 2.50 PROD2 DRILL SHAH XT M/U new BHA as per Baker reps. 0.0 344.0 14:30 1700 Inspect bit graded 1-1. Plug into tools. Load sources. RIH Jars & HWDP. 2/2/2019 2/2/2019 0.75 PROD2 DRILL TRIP XT RIH to 2,243'. 344.0 2,241.0 17:00 17:45 2/2/2019 2/2/2019 0.75 PROD2 DRILL DHEQ XT Shallow hole lest MWD tools @ 2,241.0 2,241.0 17:45 18:30 2,241'. 215 gpm, 775 psi, 30 rpm. 2/2/2019 2/3/2019 5.50 PROD2 DRILL TRIP XT RIH f/ 2,243'to 10,917' Filling pipe 2,241.0 10,917.0 18:30 00:00 every 20 stills. 2/3/2019 2/3/2019 0.50 PROD2 DRILL MPDA XT Pull trip nipple & install RCD bearing 10,917.0 10,917.0 00:00 00:30 2/3/2019 2/3/2019 0.25 PROD2 DRILL DHEQ XT Pulse test MWD/LWD tools w/200 10,917.0 10,917.0 00:30 00:45 gpm, 1030 psi, 30 rpm, 4.7 k trq, 2/3/2019 2/3/2019 1.75 PROD2 DRILL DISP XT Displace to 8.8 ppg FloPro w/225 10,917.0 10,917.0 00:45 02:30 gpm, 1450 psi 2/3/2019 2/3/2019 1.00 PROD2 DRILL TRIP XT RIH f/10,917'to 11,745 10,917.0 11,745.0 02:30 03:30 2/3/2019 2/3/2019 0.75 PROD2 DRILL REAM XT W&R f/11,745 to 11,847'w/225 gpm, 11,745.0 11,847.0 03:30 04:15 1430 psi, 120 rpm, 5.2 k trq. No issues getting into sidetrack. 2/3/2019 2/3/2019 7.75 PROD2 DRILL DDRL X Drill ahead f/11,847' to 12,428' MD / 11,847.0 12,428.0 04:15 12:00 7,937' TVD, ADT 6.6 Hrs, ECD 10.42 ppg, 225 gpm, 1660 psi, PU wt 183 k, SO wt 138 k, ROT wt 161 k, 130 rpm, Trq On/Off 6/4 k ft/lbs, 10/13 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/3/2019 2/4/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/12,428' to 13,503' MDI 12,428.0 13,503.0 12:00 00:00 7,917' TVD, ADT 9.9 Hrs, ECD 10.75 ppg, 225 gpm, 1860 psi, PU wt 183 k, SO wt 138 k, ROT wt 161 k, 130 rpm, Trq On/Off 6/4 k fUlbs, 10/13 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/4/2019 2/4/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/l3,503'to 14,732' MD / 13,503.0 14,732.0 00:00 12:00 7,940' TVD, ADT 9.6 Hrs, ECD 10.91 ppg, 225 gpm, 2010 psi, PU wt 200 k, SO wt 125 k, ROT wt 158 k, 130 rpm, Trq On/Off 8.5/5 k fUlbs, 8/12 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/4/2019 2/5/2019 12.00 PROD2 DRILL DDRL X Drill ahead U14,732'to 15,710' MD / 14,732.0 15,710.0 12:00 00:00 7933' TVD, ADT 10.1 Hrs, ECD 10.69 ppg, 225 gpm, 2140 psi, PU wt 203 It, SO wt 113 k, ROT wt 157 k, 130 rpm, Trq On/Off 11/6 k fUlbs, 5/14 k WOB. Closing MPD chokes on connections & monitoring pressure. Page 25129 Report Printed: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stat, Time End Time our (hr) Phase Op Cotle Activily Cotle Tme P -T-% Operation Start Depth (ftKB) End Dept (XKB) 2/5/2019 2/5/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/15,710' to 16,800' MD / 15,710.0 16,800.0 00:00 12:00 7926' TVD, ADT 9.3 Hrs, ECD 10.98 ppg, 230 gpm, 2270 psi, PU wt 210 k, SO wt n/a, ROT wt 163 k, 130 rpm, Trq On/Off 10.7/6.2 k ft/lbs, 8/10 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/5/2019 2/6/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/16,800'to 17,730' MDI 16,800.0 17,730.0 12:00 0000 7910' TVD, ADT 10.3 Hrs, ECD 10.74 ppg, 230 gpm, 2270 psi, PU wt 225 k, SO wt n/a, ROT wt 155 k, 130 rpm, Trq On/Off 12/8.4 k ft/Ibs, 9/11 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/6/2019 2/6/2019 12.00 PROD2 DRILL DDRL X Drill ahead f/17,730'to 18,796' MD / 17,730.0 18,796.0 00:00 12:00 7,915' TVD, ADT 9.2 Hrs, ECD 11.09 ppg, 230 gpm, 2250 psi, PU Al 240 k, SO wt n/a, ROT wt 163 k, 130 rpm, Trq On/Off 13.9/9.8 k ft/lbs, 7/9 k WOB. Closing MPD chokes on connections & monitoring pressure. 2/6/2019 2/6/2019 11.75 PROD2 DRILL DDRL X Drill ahead f/18,796'to 19,930' MD / 18,796.0 19,930.0 12:00 2345 7,867' TVD, ADT 9.7 Hrs, ECD 11.2 ppg, 230 gpm, 2600 psi, PU wt 240 k, SO Al n/a, ROT wt 163 k, 130 rpm, Trq On/Off 13.9/9.8 k ft/lbs, 10/12 k WOB. Closing MPD chokes on connections & monitoring pressure. 2I6I2019 2/7/2019 0.25 PROD2 DRILL CIRC X Circulate hole clean. 230 gpm, 19,930.0 19,930.0 23:45 0000 2600psi, 130 rpm, 13k ft/lbs tq. 2/7/2019 2/7/2019 4.75 PROD2 CASING CIRC X Circulate hole clean. Racking back std 19,930.0 19,740.0 00:00 0445 after each bottoms up. 225 gpm. 2410 psi. 80 rpm. Ilk ft/lbs tq. 2/7/2019 2/7/2019 5.25 PROD2 CASING DISP X Displace to 9.6 ppg vis brine. 230 19,740.0 19,740.0 04:45 1000 gpm. 2410 psi. 80 rpm. 2/7/2019 2/7/2019 1.25 PROD2 CASING OWFF X Fingerprint well. Flow check static. 19,740.0 19,740.0 10:00 11:15 Take slow pump rales. Drop 2.09 hollow drift w/ tail. 2/7/2019 2/7/2019 0.75 PROD2 CASING SMPD X SOOH f/ 19,740'to 19,104' per 19,740.0 19,104,0- 11:15 12:00 stripping schedule. 40/80 psi in/out slips. 20k OP at 19,104' 2/7/2019 2/7/2019 3.00 PROD2 CASING BKRM X RIH to 19,263'. Backream It 19,263'to 19,104.0 18,500.0 12:00 15:00 18,500'. 230 gpm. 1790 psi. 100 rpm. 9.7k ft/Ibs tq. 2/7/2019 2/7/2019 1.50 PROD2 CASING CIRC X Circulate BU 230 qpm. 1800 psi. 100 18,500.0 18,500.0 15:00 16:30 rpm. 9.7k ft/lbs tq. minimal cuttings across shakers. 2/7/2019 2/7/2019 6.25 PROD2 CASING SMPD X SOON f/ 18,500'to 10,981' per 18,500.0 10.981.0 16:30 22 4! 1 stripping schedule. 2/7/2019 2/8/2019 1.25 PROD2 CASING CIRC X Pump 30 bbl hi vis sweep. 230 gpm. 10,981.0 10,981.0 22:45 00:00 1300 psi. 20 rpm 4.2k ft/lbs tq. reciprocating std. 2/8/2019 2/8/2019 0.25 PROD2 CASING CIRC X Circulating BU. 10,981.0 10,981.0 00:00 0015 2/8/2019 2/8/2019 0.50 PROD2 CASING OWFF X Flow check. Static 10,981.0 10,981.0 00:15 0045 2/8/2019 2/8/2019 3.25 PROD2 CASING SMPD X SOOH f/ 10,981' to 5,755' per 10,981.0 5,755.0 00:45 0400 stripping schedule. 2/8/2019 2/8/2019 5.50 PROD2 CASING SMPD X SOON If 5,755' to 1,007' UD DP per 5,755.0 1,007.0 04:00 0930 stripping schedule. 2/8/2019 2/8/2019 0.25 15ROD2 CASING OWFF X Flow check. Static 1,007.0 1,007.0 09:30 09:45 Page 26129 ReportPrinted: 2/19/2019 Operations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start T Eno Tune urime O(hd Phase Op Code Activity COtla Time P -T-% Operation Start Depth (RKB) End Depth hK8) 2/8/2019 218/2019 0.25 PROD2 CASING MPDA X deve RCD bearing assembly. 1,007.0 1,007.0 09:45 10:00 Install trip nipple. 2/8/2019 2/8/2019 2.00 PROD2 CASING PULD X POOH f/ 1,007- to 344' UD DP 1,007.0 344.0 10:00 12:00 2/8/2019 2/8/2019 2.25 PROD2 CASING BHAH X POOH UD BHA 344.0 0.0 12:00 14:15 2/8/2019 2/8/2019 1.25 PROD2 CASING TEEN X Clean and clear rig Floor. 0.0 0.0 14:15 15:30 2/8/2019 2/8/2019 2.50 COMPZN CASING PULD X PIU and rack back 15 stds HWDP. 0.0 0.0 15:30 18:00 1 2/8/2019 2/8/2019 1.00 COMPZN CASING RURD X RU to run 4 1/2" lower completion. 0.0 0.0 18:00 19:00 2/8/2019 2/9/2019 5.00 COMPZN CASING PUTS X RIH w/ 4 1/2" lower completion to 0.0 3,798.0 19:00 00:00 3,7981. 2/9/2019 2/9/2019 7.25 COMPZN CASING PUTB X RIH w/ 4 1/2" lower completion f/ 3,798.0 8,455.0 00:00 07:15 3,798'to 8,455' 2/9/2019 2/9/2019 2.25 COMPZN CASING OTHR X M/U ZXP liner hanger packer 8,455.0 8,608.0 07:15 09:30 assembly. RIH to 8,608'. Break circulation. 120 gpm. 110 psi. PU 162k. DN 133k. ROT 148k. 20 rpm 4k ft/lbs tq. 219/2019 2/9/2019 2.00 COMPZN CASING RUNL X RIH w/ liner on DP f/ 8,608'to 10,983'. 8,608.0 10,983.0 09:30 11:30 Parameters 0 shoe: UP 162k. DN 133k. ROT 148k. 10/20 rpm 3.7k/4k ft/lbs tq. 2/9/2019 2/9/2019 10.25 COMPZN CASING -FU NL X RIH w/ liner on DP f/ 10,983' to set 10,983.0 19,394.0 11:30 21:45 1 depth 019,394'. PU 225k. D 125k. 2/9/2019 2/912019 1.25 COMPZN CASING CIRC X Circulate BU. 4 bpm. 620 psi. 19,394.0 19,394.0 21:45 23:00 2/9/2019 2/9/2019 0.25 COMPZN CASING OWFF X Flow check. Static 19,394.0 19,394.0 23:00 23:15 2/9/2019 2/10-/2019 0.75 COMPZN CASING PACK X Drop 1.625" ball and pump down 0 3 19,394.0 19,394.0 23:15 00:00 bpm. Pressure up to 650 hold 1 minute. Pressure up to 2500 psi. Set down 75k and confirm hanger set. Pressure up to 3500 psi to release running tool. P/U and expose slips. Set down w/ 15 rpm and 70k. Observe shear 0 125k hookload. Shoe depth 19,394'. TOL 10,900'. 2/10/2019 2/10/2019 1.00 COMPZN CASING PRTS X Test packer to 3300 psi for 10 19,394.0 19,394.0 00:00 01:00 minutes. Good test. 2/10/2019 2/1012019 0.25 COMPZN WELLPR TRIP X POOH f/ 11,051 to 10,890'. 11,051.0 10,890.0 01:00 01:15 2/10/2019 2/10/2019 1.50 COMPZN WELLPR CIRC X Circulate BU. 4 bpm. 440 psi. 10,890.0 10,890.0 01:15 02:45 2/10/2019 2110/2019 0.25 COMPZN WELLPR OWFF X Flow check. STatic 7,612.0 7,612.0 02:45 03:00 2/10/2019 2/10/2019 4.00 COMPZN WELLPR QEVL X POOH f/ 10,890 to 7612' 0 1500 ft/hr 10,890.0 7,612.0 03:00 07:00 logging w/ SCMT tool. Observed 200k OP 0 7" liner top. Rotate 0 5 rpm to pull through. 2/10/2019 2/10/2019 1.00 COMPZN WELLPR SLPC X Slip/cut 80' ddll line. 7,612.0 7,612.0 07:00 08:00 2/10/2019 2/10/2019 0.50 COMPZN WELLPR SVRG X Service dg. 7,612.0 7,612.0 08:00 08:30 2/10/2019 2/10/2019 8.25 COMPZN WELLPR 750 ULD X POOH UD DP N 7612' to 100' 7,612.0 100.0 08:30 16:45 2/10/2019 2/10/2019 1.50 COMPZN WELLPR SHAH X UD running tool and SMT tool. 100.0 0.0 16:45 1815 Page 27/29 Report Printed: 2/1912019 Uperations Summary (with Timelog Depths) MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) phase CD Code A vft Code Time P -T -X operapan Start Depen (WS) End Depth (IIKB) 2/10/2019 2/10/2019 1.00 COMPZN RPCOMP W W WH X Jet stack w/ 15 bpm 60 psi. Pull wear 0.0 0.0 18:15 19:15 bushing. Jet stack again w/ 15 bpm 60 psi. 2/10/2019 2/10/2019 1.25 COMPZN RPCOMP RURD P RU to run upper completion. 0.0 0.0 19:15 20:30 2/10/2019 2/11/2019 3.50 COMPZN RPCOMP PUTB P RIH w/4 1/2 TSH Blue upper 0.0 2,291.0 20:30 00:00 completion to 2,291'. 2/11/2019 2/11/2019 2.50 COMPZN RPCOMP PUTB P RIH w/ 4 1/2" TSH Blue upper 2,291.0 3,956.0 00:00 02:30 completion f/ 2,291'to 3,956' 2/11/2019 2/11/2019 0.50 COMPZN RPCOMP SVRG P Service rig 3,956.0 3,956.0 02:30 03:00 2/11/2019 2/11/2019 0.75 COMPZN RPCOMP RGRP T Troubleshoot power tongs. 3,956.0 3,956.0 03:00 03:45 2/11/2019 2/11/2019 0.75 COMPZN RPCOMP PUTB P RIH w/41/2'TSH Blueupper 3,956.0 4,526.0 03:45 04:30 completion f/ 3,956'to 4,526'. 2/11/2019 2/11/2019 3.25 COMPZN RPCOMP WAIT T Phase III weather. Secure well and 4,526.0 4,526.0 04:30 07:45 monitor on TT. 2/11/2019 2/11/2019 0.75 COMPZN RPCOMP WAIT T Perform derrick inspection after 4,526.0 4,526.0 07:45 08:30 inclement weather. 2/11/2019 2/11/2019 6.00 COMPZN RPCOMP PUTB P RIH w/ 4 1/2" TSH Blue upper 4,526.0 10,807.0 08:30 16:30 completion f/ 4,526' to 10,807'. 2/11/2019 2/11/2019 1.50 COMPZN RPCOMP HOSO P MU 3 its and pump in sub. Wash down 10,807.0 10,900.0 16:30 18:00 @ 1 bpm. Locate top of liner@ 10,900'. (Observed pressure increase). SO and locate no-go @ 10,914'. POOH w/ extra joints. 2/1112019 2111/2019 1.50 COMPZN RPCOMP THGR P MU 3 pup joints, full joint, tbg hanger, 10,900.0 10,900.0 18:00 19:30 and landing joint A. Wash dawn 1 bpm U locate TOL. (Observed pressure increase). Pull tbg tbg hanger up to trip nipple to displace. 2/11/2019 2/11/2019 2.25 COMPZN RPCOMP CRIH P Pump 210 bbls 9.6 ppg Cl Clr brine, 10,900.0 10,900.0 19:30 21:45 153 bbls 9.6 ppg clear brine. 211112019 2/11/2019 0.75 COMPZN WPCOMP P7— Flow check. Static. Blow down surface 10,900.0 10,900.0 21:45 22:30 lines. 2/11/2019 2/11/2019 1.00 COMPZN RPCOMP THGR P Land tubing on hanger @ 10,912'. (3' 10,900.0 10,912.0 22:30 23:30 from fully located. 2/11/2019 2/12/2019 0.50 COMPZN RPCOMP THGR P Run in lockdown screws. RU to test. 10,912.0 10,912.0 23:30 0000 2/12/2019 2/12/2019 1.00 COMPZN RPCOMP THGR P Finish running in lockdown screws. 10,912.0 10,912.0 00:00 01:00 RU to test. Test hanger seals 250/5000 psi it 5/10 min. Good test. Charted 2/12/2019 2/12/2019 1.00 COMPZN RPCOMP PRTS P Drop ball and rod and let fall to seat. 10,912.0 10,912.0 01:00 02:00 2/12/2019 2/12/2019 1.00 COMPZN RPCOMP PRTS T Attempt to pressure test tubing. 10,912.0 10,912.0 02:00 0300 Surface valve leaks. Troubleshoot. 2/12/2019 2/12/2019 3.75 COMPZN RPCOMP PRTS P Test 4 1/2" tubing to 4200 psi f/ 30 10,912.0 10,912.0 03:00 0645 min. good test. Bleed off tbg to 2000 psi. Line up and test 4 1/2" x 7" annulus to 3300psi f/ 30 min. good test. All charted, Bleed off annulus then tbg to 0 psi. Pressure up annulus to shear out SOV. Sheared @ 2600 psi. Break circulation @ 1 bpm/ 500psi. 2/12/2019 2/12/2019 2.25 COMPZN WHDBOP MPSP P landingjt A. Install HP-BPV. 10,912.0 10,912.0 06:45 09:00 Install landing jt B. test BPV to 2500 I IUD psi f/ 15 min in direction of Flow. Good test, UD landing it B. 2/12/2019 2/12/2019 3.00 COMPZN WHDBOP MPDA P PJSM. UD MH, TN,. R/D MPD 10,912.0 10,912.0 09:00 12:00 I package. Page 28129 Report Printed: 2/19/2019 . Operations Summary (with Timelog Depths) �� a+ MT6-02 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur ft) Phase Op Code Activity Code Time P -T -X Operabon start Depth (fiKB) End Depth(bKB) 2/12/2019 2/12/2019 3.75 COMPZN WHDBOP NUND P PJSM. N/D BOPE. 10,912.0 10,912.0 12:00 15:45 2/12/2019 2/12/2019 1.50 COMPZN WHDBOP NUND P Install Smooth Bore Metal Seal, install 10,912.0 10,912.0 15:45 17:15 plug off tool in HP-BPV profile per FMC.N/U Prod tree. 2/12/2019 2/12/2019 0.25 COMPZN WHDBOP PRTS P Test adapter flange to 5000 psi. good. 10,912.0 10,912.0 17:15 17:30 2/12/2019 2/12/2019 2.50 COMPZN WHDBOP PRTS P Fill tree w/diesel & RR/U to test. Test 10,912.0 10,912.0 17:30 2000 tree to 250 psi low, 5000 psi hi for 10 minutes each charted. 2/12/2019 2/12/2019 1.00 COMPZN WHDBOP MPSP P FMC remove HP-BPV SIMOPS- R/U 10,912.0 10,912.0 20:00 21:00 circulating lines to freeze protect. 2/12/2019 2/12/2019 2.25 COMPZN WHDBOP FRZP P Fill tree w/ diesel. flood lines and 10,912.0 10,912.0 21:00 23:15 pressure test to 2300psi. good test.Ball mill pump @ 1 bpm 48 bbls diesel down IA w/ GIS. FCP 460 psi. Line up and let well u -tube for 1 hr, 2 19 2/13/2019 0.75 COMPZN WHDBOP PSP P TD lines to prod tree. R/U to test 10,912.0 10,912.0 233:15:15 00:00 BPV. Tbg pressure 0 psi. 2/13/2019 2/13/2019 0.50 COMPZN WHDBOP MPSP P Install HP-BPV. 0.0 0.0 00:00 00:30 2/13/2019 2/13/2019 0.50 COMPZN WHDBOP PRTS P Test BPV to 2500psi (in direction of 0.0 0.0 00:30 01:00 flow) good test. Bleed off to 100psi. Secure well. 2/73/2019 2/13/2019 1.75 (TO MPZN WHDBOP KURD P Clear lines. Clean cellar area. Install 0.0 0.0 01:00 0245 flanges on tree. Secure cellar area. final pressures I/A100psi.OA Opsi.Tbg 100psi. 2/13/2019 2/13/2019 5.25 DEMOB MOVE RURD P PJSM. Swap out T transducer on 0.0 0.0 02:45 0800 gooseneck.SimOps: prep cellar/Metz area f/ rig move. 2/1312079 2/73/2019 14.00 DEMOB MOVE PULD P PJSM. Install MH. UD DP from 0.0 0.6- 08:00 2200 derrick. 2/7312019 2/14/2019 2.00 DEMOB MOVE RURD P R/D lines and wiring. Prep f/ move. 0.0 0.0 22:00 00:00 Release rig @ 00:00 furs 2/14/19 Page 29129 Report Printed: 2/19/2019 ConocoPhillips ConocoPhillips Alaska Inc WNS Western North Slope GMT1 Lookout Pad MT6-02L1 50-103-20792-60 Baker Hughes INTEQ Definitive Survey Report 08 March, 2019 BA <ER UGHES " 6R o 70° 15'23.180 N 151°28'41.3NW 3730 us9 Field Strength (-T) 57,384 W!01911. 1133AM Page 2 COMPASS SOW 14 Bead 90 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhi9ips Alaska mi WNS Local Coordinate Reference: MIN WITS -02 ProlecL Western NOM Slope ND Reference: Plan MT6-02 C 99.30usft(Dayon 19 Planned) sire: GMT1 Lookout Pad MO Reference: Plan MT642®89.30usft(Doyonl9 Planned) Well: MT6-02 North ReMrence: True Wellborn: M11`6-0211 Survey Calculation Method: Minimum Curvature Design: MT6-02L1 Database: EDT 14 Alaska Production Protect Western NOM Slope, North Slope Alaska. United States Map System: US State Plane 1927 (Erect solution) System Datum: Mean Sea Level Gee Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone W Using geodetic scala factor Weft MT6-02 Well Position -NIS 000 usft Would.: 5.945.564.39usft Lathade: +V -W 0.00 .,it Easgng: 317,116.39usft Longitude: Position Uncenainty 0.00 usft Wellhead Elevation: sell Ground Level: Wellbore MT6-021.1 Magnetics Model Name Sample Dab Declination Dip Angle 3GGM2018 12/2212018 16 25 8666 Design MT6-021.1 Audit Notes: Version: 1.0 PM1ase: ACTUAL Te On Depth: 1172309 Vertical South: Depth From (No) +WS aE14V Direction (usR) (uan) (usR) 1•) 37.10 0.00 600 345.55 6R o 70° 15'23.180 N 151°28'41.3NW 3730 us9 Field Strength (-T) 57,384 W!01911. 1133AM Page 2 COMPASS SOW 14 Bead 90 ConocoPhillips % 0 ConocoPhillips Definitive Survey Report Company. ConaccPhilitps AMska lnc ANS Local Coordinate Refere.: Mil MT6-02 Project: Mstem North !bps TVC Reference: Plain MT642 ® 69.30ush (Doyan19 Planned) SHe: GMT1 Laokaul Pad MD Reference: Plan MT642®89.30ush(Doyan19 Planned) Well: MT6-02 Nohh Remrence: True Welmore: MT6-0211 Survey Calculation Method: Minimum Curvature Deslgn: MT6-021-1 Database. EDT 14 Alaska Pmduchon Survey Pmgmm Date From To Samy Survey (ush) Iaeh) Sumy(Welhadal Tool Name Deseriptlon SMIt WM End Date 75.53 356.00 1. Gymdata GymSS IV(MT6-02) GYDCT-DMS GynWaM cont.drillpipe mls 12/192018 12/1N2018 393.46 2,027.27 2. BHGE MAO+IFR+MBA 16"(MT6-02) MWD+IFR-AK-CAZSC MA IFR AK CAZ SCG 12232018 12Y132018 2,115.67 8,972.41 3-BHGE MMATK+IFR+MSA 1211P(M MWD+IFRAK-CAZSC MA IFR AK CAZ SCC 12262018 12292018 9,065.23 11,105.67 4, BHGE MWD+IFR+MSA 631V(MT6-0 MWD+IFRAK-CAZSC MA IFRAKCAZSCC 11102019 1/1712019 11,152.00 11,723.09 5. BHGE MW IFR+MSA41W(MT6-0 MWD+IFRAK-CAZSC MA FR AK CAZ SCC IIIW2019 112412019 11,728.00 19,901.57 6. BHGE MM+IFR+MSA41W(MT6-0 MWD+IFRAK-CAZSC MAD+IFRAKCAZSCC 12812019 2012019 Survey Map Map Vertical MD Inc Aad TVD TVDSS +NIS +V -W Northing Easting DU Section Survey Tool Name Annotation lush) (°I (°I (ush) (ush) (uanj loan) Ihl IDI 32.10 DO 000 37.10 5320 000 n00 5945564.39 317116.39 0.00 000 UNDEFINED 75.53 021 259.42 25.53 -13.72 401 -0.07 594556430 31711631 0.55 000 GYDCT-OMS (1) 1863 044 232.20 12200 0270 -0.27 -0.54 5,945.564,13 312,115.85 0.28 D13 GYDCT-0MS(1) 25922 020 51.82 2%M 169.92 -0.51 -101 5945.563.91 312.115.32 038 -0.24 GYD{T-0M6(1) 356.00 1.48 291 355.99 266.69 0.71 -1.16 5,945,555.12 317,115.5 161 0.% GYDCT-DM6(1) 393.48 236 A. 393.42 304.12 1.95 -104 5,945.563.32 312,11540 240 215 MW➢+11FR-P1(-CAZS0(2) 482.67 011 1092 482.49 3019 6.91 -0d6 5945,57130 31,116.40 1.92 65 MWDNFR-PK-CAZSO(2) 576.84 545 11.09 576.33 402.03 14,61 1.34 5,945,526.% 312,118.% 1.42 13.81 MWD+IFR-PHCA2SC(2) 44.30 0.29 11.89 632.31 520.01 23.28 3.21 5945588.08 312,120.18 002 22.22 MWDHFR-AKCA -SC (2) 762.46 2.40 10.65 260.29 621.49 34.85 5.40 5,945,639.63 312,122.64 1.22 3240 M +IFR- -C{ -6C(2) C ,70 353 979 654.19 2..09 227 723 5945,61i.% 312, 125.M 1.12 44.34 MWDNFR-PH-0AZSC (2) sea. %. 952 946.69 857.39 62.5 10.18 5,.5.62.35 317128.% 102 57,22 NNMDNFR.AN-C 2SC(2) 1,d4A1 10.50 0.27 1039.24 949.. 763. 12.7 5..5,642.37 312.13106 109 866 M +IFP-AKCA-$C(2) 1,13363 11.84 365 1,131.91 1,.2.61 %541 1554 5.945.663.39 312,134.22 1.42 8349 MND+IFR-AKICA C(2) I.M&A 1358 1007 1Y34.42 1.12.1 11397 19.10 5,.5.69006 317IM.M 1.90 10051 NKVDNFR-AN-CAZ£C (2) 1325.% 15.13 11,62 1.31360 1,Y4.M 139.38 2356 5,945.203.13 312,143.5 1,70 12900 NKMONFR-PH-CAZSC(2) 1.419.41 1652 11.10 140369 1,314.39 164.36 2359 5,.5.88.01 31148.95 1A9 15205 MND+IFR-AK-CAZSC(2) 1,51277 1T 62 1010 1492.94 1.40364 19132 3362 5.945.754.82 - 312,154.. 1R 126.88 MNDHFRr CA -$C(2) 32201911: 13 38A Gage 3- COMPASS 5000.14 Bm2d 850 Survey ConocoPhillips Co11oAkillips Definitive Survey Report Map Compim, ConocoPhillips Alaska Inc WINS Local Coordinate Reference: Wall MT6-02 Project: Western North Slope TVD Resonance: Plan MT6-02®89.30usf1(Oayonl9 Planned) She: GMT1 Lookout Pad MO Reference: Plan MTB -02 C 8930unt(Dayonl9 Planned) Well: MTB -02 None Reference: True Wellbore: MTB -021 Survey Calculation Method Minimum Curvature Design: MTSA2Ll Database: EDT 14 Alaska Production Survey �1!IG"ES ER 3782019 11: 13 38A Fags 4 COMF4SS 5000.14 Buk BSD Map Map Vannes( MD Me Aal TVD TVD58 4W.S .EIWJ No EasEked,Section DLS (-I"1q hl 19 luaf7 IuMI lusfry lusrtl 1°1100T Survey Tool Name Annotation Oft) Irtl IDI IRI 1,507.40 16.02 10.20 1,58282 1.4%.52 220.44 30x3 5,945,783.31 317,16.56 137 20378 MWD+IFR- CAZSC(2) 1 M 20,47 10.51 15726 1,587.20 25193 4459 5.90.5.015.15 317,167.09 1.74 23284 MWDNFR-AWG12SC(2) 1,797,10 2155 8,42 1/67,6 167139 285.29 5044 5,MSa8.35 317,17375 1.22 x369 MWONFR-AKLsZSC(2) 1.89164 MA4 994 1,84813 1750.83 3x74 55.35 5945883.55 39,18051 166 2%54 MWOOFR-AI(CAZSC(2) 1190578 No 9.39 1934.24 1,94.94 358.26 62.59 5,9459216 39.107,% 147 331.32 ~W FRAK-CAZSC(2) 2,027.27 2458 10.11 1971.0 1,882.68 37525 65.51 5,945,937,92 317,19099 075 34705 MWDrIFRJ CA Co) 2,11567 25.16 10.57 2,052.19 196289 41183 7218 5,948974.31 31719855 O.. Main MWDrIFRAKCA C(3) 2.181.31 26.12 11.04 2]11.36 2MG6 439.72 7751 5,9M,6207 317.24.55 189 46.48 MrV➢rIFR-N(-CA25L(3) 2.27541 WAS 1092 2,19536 2,1%06 451.36 8555 594.04,50 39.21364 183 44.79 MWTHIFR?HLALSL(3) 2,370.51 29.07 last 2,278.12 2189.82 5559 94.07 5,94,007.6 317,223.19 169 45.50 MNDrffR-PA-0KSO (3) 2.4483 3030 10% 2,4161.10 2,271.80 91.41 102.75 5,94133.10 317.232% Ix 527.71 MNDAFR- -CA (3) 2.5%44 31.70 11.17 2442.26 2,35290 61924 11196 5,9410069 317,243.37 1.6 57173 MM10+1FR-N(-CAZSC(3) 2,65178 326 lam 2520.35 2,431.06 66752 12127 5,94$28.72 317,25383 OW 616.16 MWD+IF&AI(4AZ 13) 2)46.27 no lan 2600.02 2510.72 79.47 two 59427843 317,261.4 0.07 652.19 MNONFRJ CAZSC(3) 2641.33 3249 9.40 2.680.18 25%.63 no" 139.6 594.32850 312274.6 0.75 706.67 M DHFR-M-CAZSC(3) 2,926.25 3268 8% 2.76022 2670.92 818.14 147,74 5,9x6.370.65 317283.94 am 755.42 MND+IFRAK-CAZSC(3) 3,030.02 32% 9.21 2,8x.26 2749.0 867.0 15570 5.94820.26 317,293.11 0.15 6t CS MNDHFRAK-CAZSL(3) 3,122.9 3251 9.6 2,91895 2627.65 916.85 16380 5,94.47694 317 am 033 847,6 MND+IFR.AK-CAL C13 3.216.78 32.61 BA4 2.996.69 2,907,39 %7,16 171.51 5,946.527.04 39,311@ 039 69378 M D+IFR-AK AZ-SC(3) 3,311% nee 0.02 3,076.57 298727 1,017,72 170]4 5,9,5724 39,319.70 005 940% MNDrIFR.AK-0AZSC(3) 3,405.4 326 0.94 3,10.41 306.11 1,67.54 IM17 5,94.6270.1 39,3x.41 053 9935 MWDNFRAK-CPZSC(31 3.499.93 no 10.07 3,2x.31 3,14.01 1,19.85 194.59 5,916,677.12 317,330.6 del 1,0339 MWDHFRA -6C(3) 3,592.8) 32.61 last 3.313.64 3,221.34 1,19.07 203.M 5,946)x.,0 31734035 as0 1078.35 MWD+IFRA-CA C(3) 3,67.4 32.47 1165 3,39326 3.W1.05 1,216.97 21365 5,94.27574 317359.52 045 1125.19 MWDHFR-AK-0PZSC(3) 3,780.% 34.13 12.04 3.4716 3.362.20 1,267.21 NA19 5,848025.70 39371A 1,79 1,91.21 MWO+IFRA CAZSC(3) 3074.92 356 12,5 3,54850 3.4%.20 1319.82 235.62 594.878.02 39,383.97 1.79 1319.32 MWO+IFR-AK-0AZSC(3) 3.%9.47 37.50 12.89 3,624.26 3,%5.05 1,374.89 248.OD 5,94,032.76 31739789 1.82 1,26 ISS MWD+IFRAK1AZSC(3) 4,071.4 39.31 13.6 3,704.26 3,514.0 1AW.56 262.47 5,948.994.06 31741355 let 1,32566 MWOHFRAK-CAZSC(3) 4,164.71 41.71 1391 3,77516 3.685.86 1.4%.41 276.62 5947,05254 317,420.4 2.59 1,37907 MWDOFR-AK-CAZSC(3) 425892 4.55 1409 334.47 375517 1,55732 292.26 5947,11/05 317.44.26 1.% 1435.9 MWTI+IFR-AK-0AZSC(3) 435165 44.02 lso 3911.% 382226 1.61962 308.16 5,847.175.95 317.43.76 060 14154 MNOdFR+ix-0AZSC(3) �1!IG"ES ER 3782019 11: 13 38A Fags 4 COMF4SS 5000.14 Buk BSD Survey ConocoPhillips ConocoPhiiiips Definitive Survey Report Map Company: ConowPMlllps Alaska lnc_WNS Local Coordinate Reference: Well MT642 Pm)ecC MSWM North Slope TVD Reference. Plan MT642 ® 89.30usn (Doyon1Q Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT642@ 89.30usn(Doyon19 Planned) Well: MT6-02 North Reference: Thus Wake. MT642L1 Survey Calculation Method: mshmum Curvature Design: MT64211 Database: EDT 14 Alaska Production Survey Annotation �ERRo 1 WES 3418019 11:13:38AM Page 5 COMPASS 5D00J4 Bud fIW Map Map Vertical MD Inc Act TVD WDSS +NI -S +E/ -W Nunn, Easting 13 B Section Survey Tool Name (.an) 19 C) lose) (unrt) lush) (urn) (n) (N (°a IIN 0.44505 44.07 15.45 3.979.13 3,869.63 1,60275 325.99 5,94].23864 317,482.20 069 1,540.45 MWD+IFR-AK-CA2SC(3) 4,54080 44.11 15.95 4047.39 3.959-09 1,74640 34395 594).301.84 317.50184 036 1,60563 MWDHFRA -CA 4tC(3) 4.63582 44.05 16,70 4,115.59 4,0W. 1,80910 36153 5,94)364.]5 317,521Ta 0.55 1,52.37 MWD+IFR-AK-CAZSC(3) 4,73027 44.02 1&0 4,103.40 4,094.19 1012.52 300.53 594]42711 317,542.25 0.19 1,71649 MWD+IFRJ-CAZSC(3) 4,02425 4393 1689 4251.12 4.161.82 1.93505 399.52 5.94],409 .05 317,562.75 011 1,72421 M IIFR-M-C3-S0(3) 49304 44.05 1591 4320,04 4,230.74 1.99000 418.31 5,94].66240 317,583.08 072 1,83123 MND+IFR-FK-CA ,SC (3) 501421 44.09 15.72 4387.71 4.296.41 ?061.89 436.15 5947,614.99 317.602.45 0.14 1,807.09 MND+IFR-lWCA2SC(3) 5,108.30 4413 155 445.32 4.365.02 2.124.95 453.61 5,947,677.59 317,62161 GAS 1,944.58 MND+IFR- -C{ -SC (3) 5, m,] 43.97 16]6 4523.10 4433.80 3.188.03 472.07 5947740.17 317.64142 0.91 2,00106 MN10+1FRJ -CcZSC(3) 6,29TIi1 4386 17.29 4,59150 450220 2,250.92 491.33 5,947.80259 317,6612.20 0.40 2,05749 M +IFR-PKCPZSC(3) 539016 43.92 17.20 4658.20 4.56090 231220 510.35 5,947,01337 317.602.70 009 2,111.78 MN1+IFR-P CAZSC(3) 5484.40 43.85 1662 4,726.12 4,636.82 Z.37o. 530.44 6,9479Y.02 317.704.29 105 2,106.96 MND+IFR-PH-CAZSC(3) 5.57093 43.70 1762 1794.33 4706.03 2436.56 55079 594],986.71 317726.15 074 2,222.4 MJUDNFR-AKLAL3C(3) 567ZM 43.5 16.95 4.862.11 47801 2490.68 570.13 5.948 048.14 317]45.96 051 2,277.46 MNDNFR-PX-0PZSC(3) 5.76760 43,w 16.29 4,930.42 4,041A2 Z551.5 660.0 5,940,11074 317,767,27 049 2.W3.99 MM)+IFR-AKCPZSC(3) 5.0078 1412 14.50 4.997.48 4,90.10 Z623.93 60608 6, 9461 h.67 317705.95 1.37 2,38978 Mrfl)+IFR-TK-0/550(3) 5.065.81 44.1s 15.05 5.065.71 4,97041 Z607,83 62295 5,940,23524 317,804.36 Al 2,447.54 MrVDHFR-PHLA2SC(3) 605053 K.00 16.60 5.133.74 5,944.44 275120 64056 5,948.299.13 317823.93 1.2(1 2,504.40 MWDMFRAK-CALBC(3) 614465 44.10 17.25 5,201.39 5.112.09 281380 50.06 5,940,361.24 317.04453 043 2,56025 MWD+IFR-AK{p SC(3) 6.23622 44.03 1092 5268.&1 5.17934 2,8MM 679.17 5,940.423.94 317,665.15 027 2,61570 MMs)+IFRAKGAZSC(3) 6.3325 44.03 16.79 5,339.67 5,24727 2,930.80 09.20 5946.485.27 317,88520 0.10 3.67170 MWD+IFR-AK-0AZSC(3) 6.427.7 44.03 150 5,404.52 5,31522 3,00189 71663 5940.647.01 317,QWaS 0j, 272921 MWD+IFR-AK-CAZSC(3) 6,5211.0 4412 1607 5,471.83 5,391.63 3064.52 734.5 5.916.609.98 317,925.5 023 2,78439 MWDNFR--CALSC(3) 6.616.32 44.12 1667 5,54038 5.451.08 3,120.32 753.21 5,940.67330 317.945.28 036 284151 MWDHFRJ -CAZSC(3) 6710.53 44.07 1676 5115.11 5,518.81 3,191.19 7814 5,918.735.0 317,966.62 0.15 Z89770 MWDNFRAWCAZSC(3) 6,00530 4409 17.15 5076.12 Uses. 3,254.10 79123 5948,796211 37,999.35 0.29 Z95691 MWDNFRJ-CAZSC(3) 6099.19 4413 17.0 574&53 5.65423 3.316.58 0100 5.946860.10 310,00729 0.22 3,009.49 MNDNFR-AI(-CAZSC(3) 6,99393 44.13 1629 5.81153 5.M23 3.373.36 830.0 594992237 310029.04 0.62 3.06524 MWDNFR-AK-CAZSG(3) 7,086.63 4384 1622 5,870.23 5.78193 3,440.0 851.06 5.91098300 318.050.5 032 34119.41 MND+IFRAK-CAZSC(31 7,181.62 43.79 17M 5,946.78 5,857.46 3,50303 87142 5,94904502 318,072.55 028 3,17489 MWD+IFRAK-CAZSC(3) 7,27621 4392 17.76 6,01499 6,925,69 3,5543 89145 SW9106,90 318'.. 0.15 3,23032 MWD+IFR-M-C ZSC(3I Annotation �ERRo 1 WES 3418019 11:13:38AM Page 5 COMPASS 5D00J4 Bud fIW �, ConoeoPhfiiips ConoeoPhilfips Definitive Survey Report Company: ConocoPhilips Alaska Inc_ MS Local Coardlnats Rehrence: Well MT6.02 Pro)eaf Westem North Slope TVD Remanca Plan MT"2 Q 89.30ush(Doyonl 9 Planned) She OMT1 Lookout Pad NO Reference: Plan MT642 ® 09.30us6 (Dayonl9 Planned) Well: MT"2 North Reference: TNG Wellbore: MT 021.1 Survey Calculation Method: Minimum Curvature Design MTS -021-1 Database: EDT 14 Alaska Pmduchan Survey Annotation �I�WlffS v 01911-13.38AM calls,6 COMPASS 500014&db 060 Map Map Vertical MD 100111 Inc Vl 4791 TVD NDSB NLS aH-W Northing said, OLS section Survey Tool Name 1-1 (Wm (Wm (aell( (-ft) (rtl 1-1106 (nt ].369]3 4394 16.40 6082.30 5883.04 3.62].11 eti58 5949,166.0] 318,18, 115]2 0.4 4 8 3.38502 MWD+IFRAK-0.2250(3( 7,464.13 4309 19.55 6"50.34 6.061." 3,63902 93207 5.949,229.45 318.1311,50 0.85 3.33967 MWDNFR-AWCPZSC(3) 7,55an 4383 20.01 6.216." 6,12930 3,]50]4 95507 5,949,280.61 318.162.19 034 3,333.90 IMD+IFR-AK-0.2 C(3) 7,85338 4367 2036 6,211674 6,19T.44 3812,M 9]].60 5,949.35t50 31818621 0.19 3,4279 MWDNFR-PH ,SC (3) ]]4653 ON 20.23 6,353.96 82".66 3,8]2." 999.97 5949411.5] 318,210." 0.02 3,50094 MWD+1FR-MN AZSC(3) ],84000 43. 20.35 6.421.98 6.332.69 3,93416 1,OII. 5,949AMM 316,23418 0.10 3,654.66 MWDHFR-M( AZSC(3) ],93538 44.M 1997 6450.06 6,414.76 3.99589 1,045,23 5,949.53328 310.250.26 033 3,60061 MWD+11FR-AK-CKSC(3) 0.020.45 43.94 18.50 6.557." 6,46]]4 4,06689 1,066.56 5,949,591.13 318,281.07 1X4 3.66236 MWDOFR-AK-CAZ43C(3) 6,12331 4389 ISM 6,625.37 6,536.07 4,11909 1.08749 5,948,655.61 318,303.41 0.10 3.219.59 iffl FR-AWCP23C(3) 8,21117 43113 18.57 6,693.05 6,60375 4,180.26 1.107.99 5.949,]16]0 318.325.50 0.17 3.]2.19 MV+IFR-P AZSC(3) 8,310.61 4365 1902. 6,26044 6.671.14 4,242.06 1,120.84 5.949]]14 310,347.83 0.34 3,826.33 MWD+IFR-14(-04250(3) 840636 4394 21.4 6029.37 6.740.07 4304.30 1151,71 5,949,8%.19 310,3820 1.67 3,80090 MWD+FR-AK-CPZSC(3) 6,50094 43.81 2155 6,897.62 goneN 4,366.39 1,1]569 5,949.099.67 318,39766 032 3,93407 MWD+IFR- K-CPZSC(3) 6.59694 44.20 129. 6966.67 6,82,3] 442776 1,19930 5,849,961.45 318422]] 1,2$ 3.98858 MWD+IFRAK-CPZ-SC (3) 8668.99 14,4 1629 TOMAS 6,94310 4 4885 1,22036 5,95002173 318,445.30 129 4,042.22 MWDAFR-AK{42.6[(3) 8)83.. 45.97 1641 7,09932 ].009.9] 455266 1.240.44 5,950.065.53 318.466.93 207 4,069,48 M .FR-PK-CAZ4C(3) 8,071M 47M 15X0 7,163.62 7,074.32 4.618W 1,258.98 6,950,15103 31848107 209 4,156,75 MAD+IFR-MH-0 4C (a) B,9R41 49.37 1485 7,226.25 7,136.95 4,687.27 132].21 5,950.21398 310,506.85 1.83 4,220,46 MWD+FRAK aZ 0(3) 9,065.23 4990 15.30 ],266.3] 7.197,07 4,75555 1,299.66 5,860.28678 318.52105 OR 4,2111X7 MWDHFRAK-0ALSC(4) 9,15915 4.92 13.12 1344.95 7,25.66 4,026,69 1,31359 5,950,35/.46 310,546.81 372 4.346.36 MW0+1FRAK-0AZ4C(4) 9.25360 55.28 1034 7,400.41 7,311.11 4,80165 1,32923 5950432.01 318584.18 343 4415.08 MMD+IFRfJ(-C42£C(4) %M.. as an 7.02 7,45323 7,363.93 4979.23 1,341.05 6,950,609.26 318,577.85 3.30 040725 MAD+1FR-cK-0AZSO(4) 9.443b 5902 5.83 75MM 7,414.39 5,059.30 1,350.06 5950.589.11 310,5..81 2.49 4,56255 MAD+IFRAK AZSC(4) 9,53].3] 61.14 4.36 7,5504 7.46137 5,140.44 1,35128 5,950.6]0." 31859i 2.50 4,639.32 MWD+IFR-AK-CPZSC(4) 9,631.10 6333 329 ],594.28 25",93 5.223.10 1362.00 5,950,74.4 318,605.53 255 4718.07 MWD4FRAWCPZSC(4) 9,]2590 65.54 OBt 7635.14 7,545.64 5,306,03 1,365.85 5,950,0].9] 318,610.64 3.32 4,800.06 MADNFRAKLAZ36(4) 9,821.37 67.61 359." ],6]309 7,5MM 5386.23 1,36572 5,9509X,53 318,84.64 276 4,Wel M D+1PR-AKC ,SC (4) 9.91450 69]3 355,32 7.766,97 7,61].6] 5,40295 136372 5.951X1227 3"06275 2.39 496939 MAD+IFRJHCPZSC(4) 10,008.4 ]1]9 356,34 7,2805 7.646.75 55]1.89 13%% 595"""29 318610]5 2.95 5,056,56 MWD+IFRAK-CAZSO(4) 10,103.47 7332 35660 7,765 42 ],67].4 5,662.02 1,354.00 5,95119151 31860730 1'. 6,14522 MWOHFRJa0-CAZSC(4) 10.19740 ]6.46 35559 ]]9166 7]02.30 5,7=7 1,34184 5951,261.M 318.603.41 252 5.23416 MWD+IFR-AK-CPZSC(4) Annotation �I�WlffS v 01911-13.38AM calls,6 COMPASS 500014&db 060 r, ConocoPhillips Conoco�ll��lp5 Definitive Survey Report Compal.. ConocoPMllips Alaska ac -M5 Local Coondlni Reference: Project: Western Nodh Slope TVD Reference: Sita Gli Lookout Pad MD Reference: Well MT6-02 Nertb Ralerence: We116ere: MT6-09L1 Survey Calculation Metbad: Desitin: MT6-02L1 Database: Survey Well MT6-02 Plan MT642 ® 89,30usR (Ooyon19 Planned) Plan MT6-02 ® 8930usR (Dayonl9 Planned) True Minimum Curvature EDT 14 Alaska Production Annotation X01911:13 3" Pepe 7 COMPASS 5000.14 Bead SSD Map Map Vertical MD ("1 Inc 1°) Aad (h TVD mops .5045 +E7 -W No EastinH OLS Section Survey Taal Name (deft) (.WQ (Nae) (.aft) (ft) (rtl N(.110w)let 10,291[3 ]74] 35483 7,613.8 7,70.42 5,043.56 134010 5,951,3]332 316.58]9] 226 5324.48 MWOHFR-AK-CKSC(4) 10.311 1 7ae1 354.11 ],832.13 ],]42.83 5,934.]] 1,33134 5.951,464,h 31859135 2.61 5415.01 No VD°IFRAK-0PZEC(41 j 10,48002 0193 353.50 ].04].19 7,757.89 6,027,93 1,32122 5.951$58.09 318,583.50 232 5,50)]4 NVVD+IFRrV(-CPZSC(4) 10$]301 83.85 $294 ].81 7,789,40 6,11955 1,31033 5,951 640.50 3105]4.03 285 Si MWDaIFR-PI(-04250(4) 10.&9.50 04.92 351.47 ],86].88 7,770.50 6,212.10 1,29766 5,951]42.76 31056441 193 5,691.97 "Di (4) 10765.69 85.04 350.00 ],8]8.53 7,787.23 6,30536 1.26349 5951.8,036 318,55161 0.69 5,78894 "D+1 JJf-CAZSC(4) 10,854-01 6492 35016 780433 7,7M.03 6,396,91 1 267Bt 5951,92824 318.539.05 073 5,078.39 NWD+IFRJJ -$C(4) 10949.60 04.69 34950 ],892.]5 7.80345 6,409.05 1,251,13 5,952021.54 318.52465 ¢fig 5,9]2.54 MMD°IFR-AKCAZSC(4) 11,044.11 84,76 348.97 7501.27 7,811.97 6.58231 123355 5,952,114.40 318.50332 OSB 6,05647 MN➢NFRAR-0PL6C(4) 11.10567 8416 348.46 7.506.89 7,09.59 6,64243 1,221,56 5952.1]4]9 31049879 0.82 5.12788 MWDHFR-PH-CA2SC(4) 11,152D0 6520 34810 7.91092 7,821.62 6,687.63 1312.21 5,9522200 31845055 127 6,1]3]8 VNVDUFR-746-04250(5) 11,0]34 Iii 3b,05 ],91].8, 7,828.10 8.780.61 1.192.67 5,952313 .0 318,4]32] 1.71 6,58]0 MWDHFR-AK-04250(5) 11,342.9 0683 34852 7,9MW 7,83320 6,0738, 1.17345 5,95240588 310.45633 0.46 836339 M 0+1FRAK-CAZ-SC(5) 1143725 BB45 ladled ]93634 7,837.04 6,96655 1,154.60 5,952,56042 316.439.73 160 645026 MND°FFR-AKCA SC(5) 53199 8869 34748 7,928.70 733940 7,05920 1,134.98 5,953,59352 310,42238 121 fi55200 MNDNFRrWCPLSC(5) 11,63761 M97 346.15 7,930.65 7,841.35 7,153.26 1,113.9 5,952,68).09 310,40282 1.42 6,64045 MWDH1(5) 11,72aw 89.12 34592 7,93224 7,842.94 7,24493 1,090.13 5,952.78026 31838204 029 6,743.91 MWDHFR✓J6-04250(5) 11,728,10 0928 34594 7,93231 7.84341 7,249.50 1,098.94 5,952.755,05 318380.96 3.20 6,74882 MWDNFRAK-CAZSC(6) 1170.61 8001 34818 7,93269 7,8,329 720.81 10094 5952,80126 318,37]35 3,18 5,]6543 NIVI R-AK-0PLSC(6) 11.800.31 00.19 345.63 7,934116 7,08,.96 ],3275] 1,50943 5,952116330 31836335 130 6.029,11 MND°1FRJJ4CPLBC(6) 1190211 88.38 34203 7,997.06 ],047]6 T.41779 1.04395 5952.95418 31034007 299 6,92283 VuVo -P14LAZS0(6) 11,990.16 09.13 o4am 7,939.15 784985 7,50898 1,01388 5.951M,07 31831222 239 7,018.64 MWD+1FP-PK-0AZSC(6) 12,052,04 0936 339.54 7,94039 7,851.09 7,596,95 98116 5953,134.81 318428165 2.27 7,112.00 MWDHFRJJ6LF2SC(6) 12,18725 90,14 335.20 7.94030 7.85150 7,684.03 950.52 5.953.2mm 318,247.16 259 720623 MVVD+IFR-AKZCP (6) 12,282.7 9091 33466 793893 7,850.63 ],]7169 904.01 5953,31134 318.4657 180 7,30026 ~+IFRAK,CLC(6) 12,3"32 9149 33258 7937.95 7,84885 ],8563] 80,81 5,953397.01 318,169.64 228 7,39274 M✓ N+IFR-AKCPLSC16f 1247255 9223 33016 7.934.85 7845.55 7,939.99 01716 5,953481.71 310126-04 265 ],485]0 MWDHFR-AK-0AZSC(6) 1256776 92]5 32759 7,930.72 7,84142 8.02133 76805 5,95356421 31007892 275 7,576.12 "Di (6) 12663.10 92.56 32439 7,92030 7837.00 8,15024 714.75 6a53,6i 318,027.55 3.42 7665.83 MWOHFRAK-OAZSC(6) 12757.79 91.14 319.78 792325 7,633.95 0,17485 BSBS7 595372030 317.971.20 5.03 7]52.60 MVVD+IFRAK-C -SC (6) 12,65334 9022 31569 7%oII 7.83261 0,24554 59232 5,95374260 317,908.70 4.39 7,837X0 WVD+IFR-AKLA-SC(6) Annotation X01911:13 3" Pepe 7 COMPASS 5000.14 Bead SSD Survey CortmoPhillipsR lH-iffS 4 ns CoocoPhilli p Definitive Survey Report "w°^ Company. ConocoPhiBips Alaska lnc_WNS Loeal Co�orBinate Reference; MR MTB52 Protect Mstem Nom Slope TVD Reference: Plan MT6.02®89.30usn(Dayonl 9 Planned) S. GMT1 Lockout Pad MD Reference: Plan MT"2@ 09.30usn(Doyonl9 Planned) Well: MTB52 North Reference; True Wellbore: MTB -021-1 Survey Lalculatlon Melh.d; Minimumeumbon Design: MT6521-1 Database: EDT 14 Alaska Proeudion Survey Map Map Vertical MD lusnl Inc Azi TVD MISSHU8 +FIiY North, Reading MS 3ectlon Survey Tool Name Annotation PI V) Wank) laanl (Ilsm (..to (n) OR) Oloo'1 Inl 1254629 9069 314.02 7,92136 3,832.08 0,31250 52502 5,953,861.18 317,64304 183 ],910]2 M IFRAKL4 (6) 13,43.34 9040 313.16 7,921142 ],03112 63]0.04 45510 5,953,92046 317,5.82 0,94 7,999.35 AWD-IFRAKLP (6) 13,139.48 9075 31199 7,919.42 2,03012 0,443,07 385.39 5,953,895.09 317706.63 t26 8.07999 MND+6R-AK-CAZSC(6) 13,23443 90.56 31140 2,91840 7829.04 0,505.16 314.52 5,954,069,88 317,637.37 O[5 8,158,25 MWD+IMAK-CAZSC(6) j 13,33009 NO 30B,93 T, 917.30 2,828.00 6562.92 241,40 5,954,12349 317,565.73 250 0,236-01, MWDHFR-AK-0AZSC(6) 13,42492 09.70 30646 7,916.99 7.827.69 8,625]3 IN5,18 5,954,18301 317,491.94 3,10 0,311.56 MWDHFR-W(-CAZSC(6) 13.51925 6905 3036) 7,81601 7,828.21 8,67964 0665 5,950238,7 312,41594 2.80 suo.95 MWWIFRAK-CPZ4C(6) 13.615.09 88,9 30280 7,91957 2,83022 8731.92 n7 5.954293W 317.336.97 IN 85053]5 MNDNFR-AKCAFS (6) 13}10.64 8921 3008 2.9d1Po 7.831.69 8,702.18 -72,70 5954,34520 312,25694 1,07 8.522.66 MNDHFRAK{' C(6) 13,808,09 8905 29143 2,92244 783414 8.82863 456.06 554,39365 312,174.74 156 0,56643 MWDNFR-M(1- C(6) 15900.92 89.21 8566 2,924.00 2.834.58 8,870.80 -240.5 5,954,43702 312,090.87 216 0,65045 MWDNFR-, AZSC(6) 13,NIsla N.N 29344 7,925.17 7,835.02 s.IolT 327.21 5.95447934 317.005]3 205 8,71021 MW0+IFR-AI(-CAZSC(6) 10.06120 08.%29279 ],926.63 7,837.33 8,947.50 41516 5.954 518.77 316,91661 D.73 0,768.18 MNo+IFRAK AZSD(6) 1048645 69,15 294.07 7.828.10 7,830,88 0,9530 50239 5.954,5%68 316,83244 145 8,82650 MNDNFR-Nf-0AZSC(6) 14.34203 BBR 29622 7,929.5 7,840 9,025.94 58090 5954.601,41 316,746.71 2.29 8,807`50 MND+IFRAKCAZSC(6) 14,316.92 8662 297. 2,93216 704286 9,069,5 573.47 5954,646.56 31666335 171 8.95033 MND+IFRJRCALSC(6) 10,4830 00.5 N... 7,930,48 7,845.10 9,14458 -756.11 5,954,6.407 316.581.85 214 9,01503 MWD+IFR-A AZSC(6) 14,556.: 00.44 301,5 7,936.90 7,047.68 9,1,6359 R e) 5954}45.05 316,50119 219 9,08291 MWDNFRAe-0AZSC(6) 14,66205 0m 302.92 7,930.93 7,049.63 9,21488 41639 5,950,75,06 316.48.06 1.31 8,152.45 MWDAFRAK AZSC(6) 14755.54 11930 305.5 7.94015 7,850,5 9,267.49 b9O8 5.954 B527 316,345. 2.26 9,223.14 MWD+IFRAKCPLBC(6) 14852.62 9035 30733 7,940,44 ].5114 9,32425 -1,074.31 5,950.911,39 31828885 261 9,297.45 ksM+IFR-AWCAZSC(6) 1480.51 9186 310.40 2.930.61 7Uo3l 9,38379 -1,148.09 51954,8871 316/9655 368 9,373.52 MWD -IFR -ML C(6) 15,442.68 9300 31303 2,93450 2,04526 944710 -1219.01 5,55,037.8 315127.10 293 9,452.52 MWDNFR-P AZSC(6) 15,13750 0.14 315.30 7,M49 7,800.19 9,513,12 -1,208.Po 595510547 316.060.84 239 9,53341 MWD+IFR-AK-0AZSC(6) 15,23211 91.60 31652 7925.50 7,83820 9,58096 -1,352.70 5,55174.77 31,5,985,06 2.00 9,61550 MWDHFRAK QSC(6) 15 32795 50.59 318.40 ],823]5 7,830.45 9,651.56 -1017A0 5,955,246.@ 31,5.933,75 2.23 9,700.02 M IFRAK-CAZSC do 15,42324 00.56 31637 7,924.46 7,83516 9)8.79 -1,480.76 5,955,31966 315,8822 21,3 9,784.79 M .IFR-AK-0AZSC(6) 15,51665 88.8 32150 7,9Z6,72 7,83702 9,75.3 -154209 5,955390.16 315,01266 337 9,070.82 MW DHFR-AK-0PZSC(6) 15,61339 88,16 324.70 7,98.33 7&0.06 9,0863 -1,598.84 5,955.0131 31525779 343 9956b MWDNFR-AK AZSC(6) 15.m8.. 8715 322.03 2.933.10 7,84300 9,949.90 -1,651,69 5,955.55D.92 315,70668 Zen 111042A8 MWD+IFR-N(-CA2SC(6) 1580225 8768 330.06 7932.45 711.15 10.03065 -1.20t8 5,955632]6 315,659.34 320 10,13791 MWD+IFRAK A25C(6) 3B 1-01911:13:30,44 Page 8 COMPASS 5000.14 Bodd 85D �. ConocoPhillips cAnoci3 (i ip5 Definitive Survey Report points., ConocoPhi8lps Alaska Ine_WNS Local CooNlnate Rehrence: W lk MT&02 'Ptojeel: Western NoMh Slope ND Reference: Plan MT6-02@ 89.30us)(Doyoml 9 Planned) Bib: GMT] Lookout Pad MD Rehrence: Plan MT6-02 ® 89.30uafi (Doyonl9 Planned) �4Vell: MT6-02 Notes Reference: Tme W4114os: MT6-021-1 Survey CalcuMthm Metbe9t Minimum Curvature DaMpn: MT6-021.1 Database: EDT 14 Alaska PmEucfien -Survey .. _. Map Map Vertical MD (IaN) Ice P) A61TVD NOsS +N/5 ♦F/ -W No Ea 01.8 section survey Too] Name P) tusR) (usn) (usDl Ideas) i) IDRI Its) (•1199.1 IRI i 15,298.20 9523 330.97 ],939.19 7,84909 10.113]3 -1,748.15 &955.]16.95 31561442 283 1(1.2300] MWOHFR-AK-CAZSC(6 15%4.33 91.43 332. ],93].80 7,848,50 ig190.M -1].41.00 5965,80257 315 57C176 179 10,32334 MfN+IFRJ AZSC(6) 1&%854 91.51 332.. 7,935.35 7,&605 10,28251 -1,030.18 5,965,807.86 315,520.52 0.16 10,41597 MND+IFR- AZSC(6) 16.184.% 90.19 33152 ],9..95 ],044.65 10,35591 -0,802.66 S,955,BM.31 315.48&00 197 10,60].84 MND+IFR-AK-0PLSC(6) 16.2]9.12 i 90.01 333.25 9,93379 7,844.49 tg450.12 -1.926.72 5,956057.55 315.444.00 1&t 10,600.38 M DAFR-AK-0PZSC(6) 16.375.T1 80.25 Mrs ].9335] 7844.27 10,536.93 -1%9.M 595614537 315,403.87 1.57 10,69501 MWD+11FR-AK-0AZSC(6) 16.471.20 90.53 334.10 7932.92 7.04362 10,623.06 -201038 5,966,232.47 315.39715 0.74 10708,70 M IFRr AZSC(6) $56525 89.58 333.53 ],932.83 ],843.53 10,707.91 -2,052.00 5,966,318.30 315,325.10 1.17 10,891.2] MND+IFRJ AZSC(6) j 16,971.49 9183 34.23 7.93165 7.042.35 10]93811 -209114 5,956,406.24 315.28586 2.46 10.975.01 MWDHFRJO AZSC(6) 16.757.11 0.49 334.63 7,92721 7,837.91 10.080.02 -213537 5,955,49237 315345.94 179 11,05823 MND+IFR-AK-CAZSC(6) 16,851.23 0.57 334.52 7,921.42 7,832.12 10,984.86 -2,175.70 5,956,57a.t6 315.207.69 0.14 11160.95 MD+IFR-AK-CALSC(6) 16,947.54 9354 334.49 7915.44 7,826.14 11051,63 -2,217.08 5,954%5% 315,168.43 004 11,25530 MWD+IFR-AK-CPZSC(6) 1],94272 9272 33370 7,91021 TS2091 fl,137AI 1,05869 5:956752.36 315.1..97 1.16 11340.44 MVEHFR-A AZSC(6) 17,138.57 92.74 333.53 7,905.60 7,416.30 11,222.80 -2,30197 5,956,83913 315097.55 0.18 11,44211 MNDHFR-AK-0AZSC(6) 17,234.09 90.61 33011 7,902.81 7,813.51 11,307.02 -2,346.22 5,956,92434 31501553 451 11,534.84 MN0+IFR-W(-CAZSC(6) 1],328.3] 89.33 331.72 7.142.% 7,013.59 11,3a941 -239205 5,957,00781 315,001.72 2.18 11,6S.W MNDHFR-FK-0AZSC(6) 17,Q3.85 8909 332.76 7,603.51 781431 11,473.89 -243552 5,957,093.35 314,959.32 114 11]18.% MWD+IFR-AK-CAZSC(6) 17,51&90 00.16 33197 7.00512 ],41602 11,5&M -2480.76 5957P&59 314,917.14 206 1181153 MWD+IFRrll AZSC(61 li 17,61429 8051 33227 7,907.89 7,a1059 11,642X -252544 5.%].263.79 31407452 061 11.90116 MWDHFR✓J! -SC (6) 1],]0804 8&94 33337 7,910.00 7,82070 1176.50 -2 Sal 5%7.149.07 314.833.31 125 11,995.55 MND+IFR-W(-0AZSC(6) 17.85.89 90.05 334.57 7.910.10 7,821.88 H,012a0 -2810.85 5,957,436.. 314,793.28 2.35 12090.97 MNpHFR-FK-0AZSC(6) 17.899]4 9055 332.91 7,909.01 7,019.71 11,897..67 3652]3 5,95],522.22 314,75340 128 12,103.26 MN04FR--CAZSC(6) 17,99410 09.12 333.23 7,909.28 7,819.90 11,981.87 8,69550 5,95],60].43 31471277 166 12.27540 MWDHFRAKSTZSC(6) 10,09.24 8829 332.4] 7,911.42 7,82212 12.066.43 -2730.86 5.957,693.01 314,6]14] 118 12360.19 MND+IFRAK-0A2S0(6) 18,10526 Saw 33291 7,91370 7.924.40 12.15173 -2,782.90 5,957,779.35 314.629.52 0,87 12,461.7] MND+IFRJJ({'A2SC(6) 18,2]9.85 9063 33399 7, 914.00 ],824.]0 12236.34 -2,825.10 59S].86495 31450931 307 1255425 MNDNFR-A14CAZSC(6) 18,375.0 91.84 334.45 7,91210 7,822.80 1232285 -2,05.97 5,957,95245 31454964 1.15 12,64&40 MNDHFR-A AZSC(6) 18.470.85 9154 334.09 7.909.46 ],82(1.16 1240831 -ZIM15 5,958 won, 314.51054 039 1274149 "DHFR-AKLAZSC(6) 18,5533 89.29 332.24 7.&1.°.78 7,019.48 12,492.61 -295080 5.950,124.18 314,469.% IN 12,833.76 WNVNIFRAKCAZSC(6) 18,861.11 08.35 335. 7,910.76 7821.45 12,57&47 -2993.17 5950.211.04 314 4A 327 12927.4] MNDHFRAK-0AZSC(6) 10768.. Mel 336.91 ],913]0 7824.48 12,W50 -303130 595&230.% 314,393.20 160 13,021.37 MWDHFR-AH-0A250(6) 3 e01911:13:31LAa1 P89e 9 9 AnnClaOCn COMPASS 5000.14 Sa4E 650 ConocoPhillips FJi 0 s ConocoPhilli P Definitive Survey Report Company: ConowPhilips Alaska lnc WNB Pmlecb Wesiem North Slope She : OMT1 Lookout Pad Well'. MT6-02 Wellborn,: MT6-0211 0.".: MT6-021.1 surrey Local Coordinate Reference: NMI MT602 TVD Reference: Plan 141`6-02®89.30usn(DoWnl 9 Planned) MO Reference: Plan MTB-02®89.30us0(Doyonl9 Planned) North Reference: Tma Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Phoduclion MD heat Ado TVD TVDSS eWS .0m Map Map D45 VeNicel (-am (°) PI load) (uan) (usft) (Man) No Fasting ey section SuryToci Maine(g) (ft) (n) 1°Wore) (11110,051.63 8].6] 314,48 791],3] ].0260] 1275220 070AS 5,9503&1.60 314.356.14 257 1311516 MWD,IFRA K!-clC(6) 10,147.20 87.83 3332] 7,921.12 783182 12,&17.90 1,11301 5958AM,37 314.316.19 128 13.20060 MNDNFR- -C-0 SC(6) 19,04270 8&82 33281 7,92391 7,814.61 12,923.06 -3.15.29 5 9158 659.47 314,274.99 114 13.301.87 MWDNFR-AI(-0pL6C(61 19,138.27 90.85 33320 ],9N19 7,834.89 1tlW&21 -3,199.87 5,958,645.65 314,23369 216 13,39515 M%M)AFRAK-0 C(6) 1923395 W,23 33362 7,921.82 7,032.32 13.09374 1,24248 5958,73218 314192.98 1.51 13,45&5 M IIFRr CFZSC(6) 19,329.09 93.3 3N.N ],91]20 ],82].90 13,178.14 4,28417 5,959.81&57 314,153.37 1.18 13,50176 M DOFR-W(-CVZ C(6) 19425W 936,1 330.07 ],911.5] ],822.2] 13265]0 -3,32526 5,950,95.9 314,114,40 0.80 13,675.83 MWD+lFRAK-0AZSC(6) 19,520,5 93.57 334.58 7.lK 9 7,816.28 13,35145 4,35]5 5,959925 314,076.01 0.31 13,76897 MWDaIFRAH-0A24C(6) 19515.8 93.54 334,38 16%68 7.81036 13,437.58 4466,89 5.959,0]9.89 314.05.98 023 13,862.63 MWOHFR-rWLAZ4IC(6) 19710.73 9623 334.71 ],891.5] 7,80227 13,523.04 4,447,58 5,959,15,31 313,9INK37 2.85 13.95554 MWDHFRo(-0AZSC(6) 19.56.48 96.19 33510 7.88122 7,,791.92 13,60]25 -3,41488 5959.253.4] 313.96017 049 8049.03 MWD+lFRAX-CQSC(6) 19,90157 95.97 314.67 70]1 14 7.78184 13,684.91 .,52]9] 5,959,34007 313,5)Vui 050 14,14204 MJUDHFRAKC C(6) 19930.0 9597 334.67 7,868,19 ],7]8.89 13]20.4] 4,540.06 595936591 313,91011 0.00 14.10980 PROJECTED to TD Annotation 318/2019 11 13 38A Pape 10 COMPASS 500014 Beat 8W e Cement Detail Report MT6-02 String: Conductor Cement Job: DRILLING ORIGINAL, 12/22/2018 00:00 Cement Details Description Conductor Cement 12/51201 Cementing Start Date 8 0800 Cementing End Date 2/5/2018 1000 Wellbore Name MT6-02 Comment Cement Stages Stage # 1 Description Conductor Cement Objective Cement Conductor Top Depth (ftKB) 36.8 Bottom Depth (ftKB) 115.0 Full Return? No Vol Cement... Top Plug? No 8tm Plug? No Q Pump Init (bbl/m... O Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) I Recip? 1 No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & 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 (Iblgal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr t (psi) Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 3/18/2019 Cement Detail Report MT6-02 String: Surface Casing Cement Job: DRILLING ORIGINAL, 12/22/201800:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 12/24/2018 22:30 12/25/2018 01:30 MT6-02 Comment Dowell pump 2.1 bbls H2O & PT to 3500 psi (good). Dowell pump 100.1 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 382.5 bbls 11.0 ppg 1.95 113/sx yield LiteCRETE lead cement and 72.7 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 279.6 bola 12,798 stks 10 ppg DriIlPlex with 8 bpm / 700 psi. Reduce pumps to 3 bpm 1400 psi. last 10 bbls. Bump plug, pressure 500 psi over to 900 psi for 5 min. Check floats. F/C good. CIP @ 1:29 Hrs. Calculate 150 bbis good cement to surface. Full returns & reciprocated pipe during cement job. Cement Stages Stage # 1 Description ObjectiveTop Depth IRKS) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? atm Plug? Surface Casing Cement Cement Surface Casing 37.0 2,080.4 Yes 150.0 1 Yes O Pump InR (bbgm... O Pump Final (boll... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (R) Rotated? Pipe RPM (rpm) 8 3 5 400.0 900.0 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Dowell pump 2.1 MIS H2O & PT to 3500 psi (good). Dowell pump 100.1 bbls 10.3 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 382.5 bbls 11.0 ppg 1.95 Max yield LiteCRETE lead cement and 72.7 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 279.6 bbls / 2,798 stks 10 ppg DriIlPlex with 8 bpm / 700 psi. Reduce pumps to 3 bpm / 400 psi. last 10 bbls. Bump plug, pressure 500 psi over to 900 psi for 5 min. Check floats. FIC good. CIP @ 1:29 Hrs. Calculate 150 bbls good cement to surface. Full returns & reciprocated pipe during cement job. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bim IRKS) Amount (sacks) Class Volume Pumped (bbl) Surface Cement 1 37.0 1,580.0 1,101 B 1382.5 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water Density (ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.95 7.0 1 4.80 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) I Est Btm (ftKB) Amount (sacks)Class Volume Pumped (bbl) Tail Cement 1,580.0 2,080.4 352 G 72.7 Yield (tVisack) Mix H2O Ratio (Sallee... Free Water (°h) Density (lb(gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.08 1 15.80 5.00 Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 3/18/2019 Cement Detail Report MT6-02 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 12/22/2018 00:00 Cement Details DescriptionCementing Intermediate Casing Cement Start Date 1/11201916:00 Cementing End Date 1/1/201923:00 Wellbore Name MT6-02 Comment SLB pumped 60 bbl Mud Push, 98 bbl 12.2 ppg Lead cement, 48.8 bbl 15.8 ppg Tail cement. Kicked out with 20 bbl water. Rig displaced with 638 bbl LSND. Bottom plug landed on time, @ 490 bbl into displacement, pressure built up to 3000 psi, packed off and lost returns. 110 bbl lost to formation. Cement Stages Stage # 7 Description Intermediate Casing Cement Objective Top Depth (ftK8) 1000 feet of cement for 8,504.0 I drilling ahead Bottom Depth (ftKB) 8,742.5 Full Return? No Vol Cement... Top Plug? Yes Bum Plug? Yes O Pump Init (bblim... 4 O Pump Final (bbU... 3 O Pump Avg (bbil... 3 P Pump Final (psi) 3,080.0 P Plug Bump (psi) 3,080.0 Recip? No Stroke (ft) I Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Lost returns at 490 bbl into displacement, packoff and pressure up to 3100 psi. Lost 110 bbl cement to formation. Cement Fluids 8 Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top IRKS) 7,742.5 Est Bon IRKS) 8,115.0 Amount (sacks) 239 Class G Volume Pumped (bbl) 98.0 Yield (Wisack) 2.30 Mix H2O Ratio (gal/aa... 13.23 Free Water (%) Density (lb/gal) 12.20 Plastic Viscosity (CP) 12.0 Thickening Time (hr) 5.00 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 8,115.0 Est Bum (ftKB) 8,742.5 Amount (sacks) 236 Class Volume G 48.8 Pumped (bbl) Yield (ft /sack) 1.16 Mix H2O Ratio (gallsa... 5.06 Free Water (%) 1 Density (Ib/gal) 15.80 Plastic Viscosity (CP) 124.0 Thickening Time (hr) CmprStr 5.50 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 3/18/20191 Cement MT6-02 Liner Cente Cement Details Description Liner Cement Cementing start Date 1/121201912:00 Cementing End Data 11121201913:30 Wellbore Name MT6-02 Comment Test lines to 3,000 psi. Pump 38.4 bbls 11.5 ppg mud push II, Ma and pump 55.1 bbls 15.8 ppg cement, Pump 20 bbis water. Sting in and displace with 142 this 10.9 ppg 1 -SND mud. Final circulation pressure at 2 bpm 720 psi. Cement in place at 13:30 his. Observed no mud losses. Cement Stages Stage # 1 Description Liner Cement Objective Top Depth (RKB) Cement 7" SDL Liner 9,551.0 Bottom Depth (RKB) 11,051.0 Full Return? Yes Vol Cement... Top Plug? 0.0 No Btm Plug? No O Pump Init (bblim... 3 O Pump Final (bbll... 2 D Pump Avg (boll... 2 P Pump Final (psi) 730.0 P Plug Bump (psi) Recip? No Stroke (R) Rotated? No Pipe RPM (rpm) Tagged Depth (RKB) Tag Mathod Depth Plug Drilled Out To (RKB) Drill Out Diameter (in) Comment Pumped via cement retainer @ 10,988' Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description I Estimated Top (RKB) 9,551.0 Est atm (RKB) 11,051.0 Amount (sacks) 263 Class C Volume Pumped (bbl) 55.3 Yield (tt'lsack) 1.16 Mix H2O Ratio (galisack) 5.02 Free Water (%) Density Qblgai) 15.80 Plastic Viscosity (CP) 115.0 Thickening Time (hr) 5.56 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 ReportPrinted: 111412019 BA ER Date: UGHES March 8, 2019 a GE company Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 21900 30441 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94`h Avenue Anchorage, Alaska 99515 se find enclosed the directional survey data for the following WON: MT6-02 MT6-02L1 MAR t 3 2019 �,QGGC (2) Total prints Enclosed for each weil(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.Soi)er(@BakerHughes.com 21900 30 44 1 ConocoPhillips ConocoPhillips Alaska Inc_WNS Western North Slope GMT1 Lookout Pad MT6-021-1 50-103-20792-60 Baker Hughes INTEQ BAi�`UGHES a U company Definitive Survey Report 08 March, 2019 ConocoPhillips ConocoPhillips Definitive Survey Report Bea Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 ` Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) MT6-0211 Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) 1.0 Well: MT6-02 North Reference: True Wellbore: MT6-0211 Survey Calculation Method: Minimum Curvature Design: MT6-0211 Database: EDT 14 Alaska Production Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MT6-02 Well Position +N/ -S 0.00 usft Northing: 5,945,564.39usft Latitude: 70° 15 23.180 N +El -W 0.00 usft Easting: 317,116.39usft Longitude: 151'28'41.304W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: i 37.20 usft did Wellbore MT6-0211 Magnetics Model Name BGGM2018 Design MT6-0211 Audit Notes: Version: 1.0 /ertical Section: Phase: ACTUAL Depth From (TVD) (usft) 37.10 Sample Date 12/22/2018 Declination f) 16.25 Tie On Depth: 11,723.09 +N/ -S +E/ -W (usft) (usft) 0.00 0.00 Direction (I 345.55 3/8/2019 11: 13: 38AM Page 2 COMPASS 5000.14 Build 85D ✓ ConocoPhillips Es ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-0211 Survey Calculation Method: Minimum Curvature Design: MT6-021-1 Database: EDT 14 Alaska Production Survey Program Date - From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date ; 75.53 356.00 1. Gyromna GyroSS 16" (MT6-02) GYD-CT-DMS Gyrodata cont.drillpipe m/s 12/19/2018 12/19/2018 393.46 2,027.27 2. BHGE MWD+IFR+MSA 16" (MT6-02) MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC 12/23/2018 12/23/2018 2,115.67 8,972.41 3. BHGE MWDATK+IFR+MSA 121/4"(M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/26/2018 12/29/2018 9,065.23 11,105.67 4. BHGE MWD+IFR+MSA6 3/4" (MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 1/10/2019 1/17/2019 j 11,152.00 11,723.09 5. BHGE MWD+IFR+MSA 4 1/8" (MT6-0 MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 1/18/2019 1/24/2019 11,728.00 19,901.57 6. BHGE MWD+IFR+MSA4 1/8" (MT6-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/28/2019 2/7/2019 i ...._ _. ,-�..-..-....�.._.�.e.....� .....«-n«vee-�....�e..�-.P.-.�Y..vA._..-e.-.s..y...--•--•-....-.a_...._e..nn Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section Survey Tool Name Annotation (usft) (°) 11 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 37.10 0.00 0.00 3].10 -52.20 0.00 0.00 5,945,564.39 317,116.39 0.00 0.00 UNDEFINED y 75.53 0.21 259.42 75.53 -13.77 -0.01 -0.07 5.945,564 38 317,116.33 0.55 0.00 GYD-CT-DMS (1) P 172.00 0.44 232.20 172.00 82.70 -0.27 .0.54 5,945,564.13 317,115.85 0.28 -0.13 GYD-CT-DMS(1) 259.22 028 261.87 259.22 169.92 -0.51 -1.01 5,945,563.91 317,115.37 0.28 .0.24 GYD-CT-DMS(1) ^( 356.00 1.48 2.91 355.99 266.69 0.71 -1.18 5,945,565.12 317,115.23 1.61 0.98 GYD-CT-DMS (1) 393.46 2.36 8.49 393.42 304.12 1.95 -1.04 5,945,566.37 317,115.40 2.40 2.15 MWD+IFR.AK-CAZ-SC(2) 482,67 4.11 10.97 482.49 393.19 6.91 .0.16 5,945,571.30 317,116.40 1.97 6.73 MWD+IFR-AK-CAZ-SC(2) 576.84 5.45 11.09 576.33 487.03 14.61 1.34 5,945,578.96 317,118.09 1.42 13.81 MWD+IFR.AK-CAZ-SC(2) 668.30 6.29 11.89 667.31 578.01 23.78 321 5,945,588.08 317,120.18 0.92 22.22 MWD+IFR-AK-CAZ-SC(2) 762.46 7.48 10.65 760.79 671.49 34.85 5.40 5,945,599.09 317,122.64 1.27 32.40 MWD+IFR.AK-CAZ.SC(2) 856,78 8.53 9.79 854.19 764.89 47.77 7.73 5,945,611.96 317,125.28 1.12 44.34 MWD+IFR-AK-CAZ-SC(2) 9 I 950.44 9.48 9.52 946.69 857.39 62.23 10.18 5,945,626.35 317,128.08 1.02 57.72 MWD+IFR.AK-CAZ.SC(2) 1,044.41 10.50 8.77 1,039.24 949.94 78.32 12.77 5,945,642.37 317,131.06 1.09 72.66 MWD+IFR-AK-CAZ.SC(2) 1,138.88 11.84 8.65 1,131.91 1,042.61 96.41 15.54 5,945,660.39 317,134.27 1.42 89.49 MWD+IFR-AK-CAZ.SC(2) VEII! 1,233.76 13.58 10.87 1,224.47 1,135.17 116.97 19.10 5,945,680.86 317,138.33 1.90 108.51 MWD+IFR-AK-CAZ-SC(2) 1,325.85 15.13 11.62 1,313.68 1,224.38 139.36 23.56 5,945,703.13 317,143.33 1.70 129.08 MWD+IFR-AK-CAZ.SC(2) I 1,419.41 16.52 11.10 1,403.69 1,314.39 164.38 28.58- 5,945,728.01 317,148.96 1.49 152.05 MWD+IFR-AK-CAZ.SC(2) 1,512.77 17.62 10.10 1,492.94 1,403.60 191 32 33.62 5,945,754.82 317,154.64 1.22 176.88 MWD-IFR-AK-CAZ-SC (2) 3/8/2019 11: 13:38AM Page 3 COMPASS 5000.14 Build 85D Survey W Elt ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Local Coordinate Reference: Well MT6-02 Project: Western North Slope ND Reference: Plan MTB -02 @ 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-02L1 Survey Calculation Method: Minimum Curvature Design: MT6-0211 Database: EDT 14 Alaska Production Survey W Elt 31WO19 11:13:38AM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi ND NDSS +N/ -S +E/ -W Northing Easting DES Section Survey Tool Name Annotation (usft) (°I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ftl 1607.40 18.82 10.20 1,582.82 1,493.52 220.44 38.83 5,945 783 81 317.160.56 1.27 203.78 MWD+IFR-AK-CAZ-SC(2) 1,702.63 20.47 10.51 1,672.50 1,583.20 251.93 44.59 5,945,815.15 317,167.09 1.74 232.84 MWD+IFR-AK-CAZ-SC (2) 1,797.10 21.55 9.42 1,760.69 1,671.39 285.29 50.44 5,945,848.35 317,173.75 1.22 263.69 MWD+IFR-AK-CAZ-SC(2) 1,891.64 23.14 9.50 1,848.13 1,758.83 320.74 56.35 5,945,883.65 317,180.51 1Sit 296.54 MWD+IFR-AK-CAZ-SC(2) 1,985.78 24.52 9.38 1,934.24 1,844.94 356.26 62.59 5,945,921.00 317,187.66 1.47 331.32 MWD+IFR-AK-CAZ-SC 12) 2,027.27 24.58 10.11 1,971.98 1,882.68 375.25 65.51 5,945,937.92 317,190.99 0.75 347.05 MWD+IFR-AK-CAZ-SC (2) 2,115.67 25.16 10.57 2,052.19 1,962.89 411.83 72.18 5,945,974.31 317.198.55 0.69 380.80 MWD+IFR-AK-CAZ-SC(3) 2,181.31 26.12 11.04 2,111.36 2,022.06 439.72 77.51 5,946,002.07 317,204.55 1.49 406.49 MWD+IFR-AK-CAZ-SC(3) 2,275.41 27.46 10.92 2,195.36 2,106.06 481.36 85.58 5,946,043.50 317,21364 1.43 444.79 MWD+IFR-AK-CAZ-SC(3) 2,370.51 29.07 10.81 2,279.12 2,189.82 525.59 94.07 -- 5,946,087.50 317,223.19 1.69 485.50 MWD+IFR-AK-CAZ-SC(3) 2,464.83 30.20 10.65 2,361.10 2,271.80 571.41 102.75 5,946,133.10 317,232.98 1.20 527.71 MWD+IFR-AK-CAZ-SC(3) 2,559.44 31.78 11.17 2,442.20 2,352.90 619.24 111.98 5,946.180.69 317,243.37 1.69 571.73 MWD+IFR-AK-CAZ-SC(3) 2,651.78 32.56 10.62 2,520.36 2,431.06 667.52 121.27 5,946,228.72 317,253.83 0.90 616.16 MWD+IFR-AK-CAZ-SC(3) 2,746.27 32.53 10.72 2,600.02 2,510.72 717.47 130.68 5,946,278.43 317,264.45 0.07 662.19 MWD+IFR-AK-CAZSC (3) 2,641.33 32.49 9.40 2,680.18 2,590.88 767.77 139.60 5,946,328.50 317,274.59 0.75 708.67 MWD+IFR-AK-CAZ-SC(3) 2,936.25 32.54 8.95 2,760.22 2,670.92 818.14 147.74 5,946,378.65 317,283.94 0.26 755.42 MWD+IFR-AK-CAZ-SC(3) 3,030.02 32.56 9.21 2,839.26 2,749.96 867.96 155.70 5,946,428.26 317,293.11 0.15 801.68 MWD+IFR-AK-CAZ-SC(3) 3,122.17 32.51 9.60 2,916.95 2,827.65 916.85 163.80 5,946,476.94 317,302.40 0.23 847.00 MWD+IFR-AK-CAZ-SC (3) 3,216.78 32.61 8.04 2,996.69 2,907.39 967.16 171.61 5,946,527.04 317,311.42 0.89 893.78 MWD+IFR-AK-CAZ-SC(3) 3,311.58 32.56 8.02 3,076.57 2,987.27 1,017.72 178.74 5,946,577.40 317,319.78 0.05 940.95 MWD+IFR-AK-CAZ-SC(3) 3,405.14 32.59 8.94 3,155.41 3,066.11 1,067.54 186.17 5,946,627.03 317,328.41 0.53 987.35 MWD+IFR-AK-CAZ-SC(3) 3,499.93 32.53 10.07 3,235.31 3,146.01 1,117.85 194.59 5,946,677.12 317,338.05 0.64 1,033.97 MWD+IFR-AK-CAZ-SC (3) 3,592.89 32.63 10.91 3,313.64 3,224.34 1,167.07 203.70 5,946,726.10 317,348.36 0.50 1,079.35 MWD+IFR-AK-CAZ-SC(3) 3,687.46 32.47 11.65 3,393.35 3,304.05 1,216.97 213.65 5,946,775.74 317,359.52 0.45 1,125.19 MWD+IFR-AK-CAZ-SC(3) 3,780.96 34.13 12.04 3,471.50 3,382.20 1,267.21 224.19 5,946,825.70 317,371.28 1.79 1,171.21 MWD+IFR-AK-CAZ-SC(3) 3,874.92 35.80 12.45 3,548.50 3,459.20 1,319.82 235.62 5,946,878.02 317,383.97 1.79 1,219.32 MWD+IFR-AK-CAZ-SC(3) 3,969.47 37.50 12.89 3,624.35 3,535.05 1,374.89 248.00 5,946,932.76 317,397.69 1.82 1,269.55 MWD+IFR-AK-CAZ-SC(3) 4,071.45 39.31 13.50 3,704.26 3,614.96 1,436.56 262.47 5,946,994.06 317,41365 1.81 1,325.66 MWD+IFR-AK-CAZ-SC(3) 4,164.71 41.71 13.91 3,775.16 3,685.86 1,495.41 276.82 5,947,052.54 317,429.43 2.59 1,379.07 MWD+IFR-AK-CAZSC(3) 4,258.92 43.55 14.09 3,844.47 3,755.17 1,557.32 292.26 5,947,114.05 317,446.36 1.96 1,435.17 MWD+IFR-AK-CAZ.SC(3) 4,351.85 44.02 14.53 3,911.56 3,822.26 1.619.62 308.16 5,947,175.95 317,463.76 0.60 149154 MWD+1FR-AK-CAZ-SC(3) 31WO19 11:13:38AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BAd(E RES ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc WINS Local Coordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @) 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-0211 Survey Calculation Method: Minimum Curvature Design: MT6-0211 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +E/-W Northing Eastin 9 DLS Section Survey Tool Name Annotation (usft) V) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) 4.445.85 44.07 15.46 3,979.13 3,889.83 1,682.75 325.06 5,947,238.64 317,462.20 0.69 1,548.45 MWD+IFR-AK-CAZ-SC(31 4,540.88 44.11 15.95 4,047.39 3,958.09 1,746.40 342.96 5,947,301.84 317,501.64 0.36 1,605.63 MWD+IFR-AK-CAZ-SC(3) 4,635.82 44.05 16.70 4,115.59 4,026.29 1,809.78 361.53 5,947,364.75 317,521.73 0.55 1,662.37 MWD+IFR-AK-CAZ-SC(3) 4,730.27 44.02 16.95 4,183.49 4,094.19 1,872.62 380.53 5,947,427.11 317,542.25 0.19 1,718.49 MWD+IFR-AK-CA7-SC(3) f 4,824.25 43.93 16.89 4,251.12 4,161.82 1,935.05 399.52 5,947,489.05 317,562.75 0.11 1,77421 MWD+IFR-AK-CAZSC(3) 4,920.04 44.06 15.91 4,320.04 4,230.74 1,998.88 418.31 5,947,552.40 317,583.08 0.72 1,831.33 MWD+IFR-AK-CAZ-SC (3) 5,014.21 44.06 15.72 4,387.71 4,298.41 2,061.89 436.15 5,947,614.95 317,602.45 0.14 1,887.89 MWD+IFR-AK-CAZ-SC(3) 5,108.36 44.13 15.55 4,455.32 4,366.02 2,124.98 453.81 5,947,677.59 317,621.63 0.15 1,944.58 MWD+IFR-AK-CAZ.SC(3) 5,202.77 43.97 16.76 4,523.18 4,433.88 2,188.03 472.07 5,947,740.17 317,64142 0.91 2,001.08 MWD+IFR-AK-CAZ.SC 13) 5,297.61 43.86 17.29 4,591.50 4,502.20 2250.92 491.33 5,947,802.56 317,662.20 0.40 2,057.19 MWD+IFR-AK-CAZ-SC (3) 5,390.16 43.92 17.20 4,658.20 4,568.90 2,312.20 510.35 5,947,863.37 317,682.70 0.09 2,111.78 MWD+IFR-AK-CAZ-SC(3) 5,484.40 43.85 18.62 4,726.12 4,636.82 2,374.36 530.44 5,947,925.02 317,704.29 1.05 2,166.96 MWD+IFR-AK-CAZ.SC(3) f Ii 5,578.93 43.78 17.62 4,794.33 4,705.03 2,436.56 550.79 5,947,986.71 317,726.15 0.74 2,222.12 MWD+IFR-AK-CAZ-SC (3) 5,672.88 43.68 16.95 4,862.11 4,772.81 2,498.68 570.13 - 5,948,048.34 317,746.98 0.51 2,277.46 MWD+IFR-AK-CAZ-SC (3) 5,767.60 43.82 16.29 4,930.42 4,841.12 2,561.56 588.89 5,948,110.74 317.767.27 0.49 2,333.66 MWD+IFR-AK-CAZ-SC(3) 5,860.78 44.12 14.50 4,997.48 4,908.18 2,623.93 606.06 5,948,172.67 317,785.95 1.37 2,389.78 MWD+IFR-AK-CAZ-SC(3) - 5,955.84 44.15 15.06 5,065.71 4,976.41 2,687.93 622.95 5,948,236.24 317,804.38 0.41 2,447.54 MWD+IFR-AK-CAZ.SC(3) .� 6,050.53 44.00 16+68 5,133.74 5,044.44 2,751.28 640.96 5,948,299.13 317,823.93 1.20 2,504.40 MWD+IFR-AK-CAZ-SC (3) 6,144.65 44.10 17.25 5,201.39 5,112.09 2,813.88 660.06 5,948,361.24 317,844.53 0.43 2,560.25 MWD+IFR-AK-CAZ-SC(3) 6,238.22 44.00 16.92 5,268.64 5,179.34 2,876.06 679.17 5,948,422.94 317,865.15 0.27 2,615.70 MWD+IFR-AK-CAZ-SC(3) 6,332.68 44.03 16.79 5,336.57 5,247.27 2,938.88 698.20 5,948,485.27 317,885.70 0.10 2,671.78 MWD+IFR-AK-CAZ-SC(3) 6,427.17 44.00 15.82 5,404.52 5,315.22 3,001.89 716.63 5,948,547.81 317,905.65 0.71 2,72821 MWD+IFR-AK-CAZ-SC(3) 6,520.83 44.12 16.07 5,471.83 5,382.53 3,064.52 734.53 5.948.609.98 317,925.06 0.23 2,784.39 MWD+IFR-AK-CAZ-SC(3) 6,616.32 44.12 16.57 5,540.38 5,451.08 3,128.32 753.21 5,948,673.30 317,945.28 0.36 2,841.51 MWD+IFR-AK-CAZ-SC(3) 6,710.63 44.07 16.76 5,608.11 5,518.81 3,191.19 772.03 5,948,735.69 317,965.62 0.15 2,897.70 MWD+IFR-AK-CAZ-SC(3) 6,805.30 44.09 17.15 5,676.12 5,586.82 3,254.18 791.23 5,941 317,986.35 0.29 2,953.91 MWD+IFR-AK-CAZ-SC (3) 6,899.19 44.13 17.44 5,743.53 5,654.23 3,316.58 810.66 5,948,860.10 318,007.29 0.22 3,009.49 MWD+IFR-AK-CAZ-SC(3) 6,993.93 44.13 18.29 5,811.53 5,722.23 3,379.36 830.90 5,948,922.37 318,029.04 0.62 3,065.24 MWD+IFR-AK-CAZ-SC(3) 7,086.63 43.84 18.22 5,878.23 5,788.93 3,440.50 851.06 5,948,983.00 318,050.68 0.32 3,119.41 MWD+IFR-AK-CAZ-SC (3) 7,181.62 43.79 17.84 5,946.78 5,857.48 3,503.03 871.42 5,949,045.02 318,072.55 0.28 3,174.89 MWD+IFR-AK-CAZ-SC (3) 7,276.21 43.92 17.76 6,014.99 5,925.69 3,565.43 891.45 5,949,106.90 318,094.09 0.15 3,230.32 MWD+IFR-AK-CAZ-SC (3) Page 5 COMPASS 5000.14 Build 85D 3/8/2019 11:13:38AM ConocoPhillips HrR ConocoPhllllps Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope ND Reference: Plan. MT6-02 @ 89.30usft (Doyonl9 Planned) Site: GMTI Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: "True Wellbore: MT6-0211 Survey Calculation Method: Minimum Curvature Design: MT6-02L1 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi ND NDSS +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting' (°/100-) Section Survey Tool Name Annotation (ft) (ft) (ft) 7,369.73 43.94 18.40 6,082.34 5,993.04 3627.11 911.59 5,949,168.07 318,115.72 048 3,285.02 MWD+IFR-AK-CAZ-SC(3) 7,464.13 43.89 19.55 6,150.34 6,061.04 3,689.02 932.87 5,949,229.45 318,138.50 0.85 3,339.67 MWD+IFR-AK-CAZ-SC(3) 7,558.79 43.83 20.01 6,218.60 6,129.30 3,750.74 955.07 5,949,290.61 318,162,19 0.34 3,393.90 MWD+IFR-AK-CAZ-SC(3) 7,653.28 43.87 20.26 6,286.74 6,197.44 3,812.20 977.60 5,949,351.50 318.186+21 0.19 3,447.79 MWD+IFR-AK-CAZ-SC(3) 7,746.53 43.88 20.23 6,353.96 6,264.66 3,872.84 999.97 5,949,411.57 318,210.04 0.02 3,500.94 MWD+IFR-AK-CAZ-SC(3) 7,840.88 43.84 20.35 6,421.99 6,332.69 3,934.16 1,022.64 5,949,472.32 318,234.19 0.10 3,554.66 MWD+IFR-AK-CAZ-SC(3) 7,935.38 44.00 19.97 6,490.06 6,400.76 3,995.69 1,045.23 5,949,533.28 318,258.26 0.33 3,608.61 MWD+IFR-AK-CAZ-SC(3) 8,02645 43.94 18.58 6,557.04 6,467.74 4,056.69 1,066.56 5,949,593.73 318,281.07 1.04 3,662.36 MWD+IFR-AK-CAZ-SC(3) 8,123.31 43.89 18.35 6,625.37 6,536.07 4,119.09 1,087.40 5,949,655.61 318,303.41 0.18 3,717.59 MWD+IFR-AK-CAZ-SC (3) 8,217.17 43.83 18.57 6,693.05 6,603.75 4,180.78 1,107.99 5,949,716.78 318,325.50 0.17 3,772.19 MWD+IFR-AK-CAZ-SC(3) j 8,310.61 43.86 19.02 6,760.44 6,671.14 4,242.06 1,128.84 5,949,777.52 318,347.83 0.34 3.826.33 MWD+IFR-AK-CAZ-SC(3) 8,406.26 43.94 21.32 6,829.37 6,740.07 4,304.30 1,151.71 5,949,839.19 318,372.20 1.67 3,880.90 ()j MWD+IFR-AK-CAZ-SC(3) 8,500.94 43.81 21.55 6,897.62 6,808.32 4,365.39 1,175.69 5,949,899.67 318,397.66 0.22 3,934.07 MWD+IFR-AK-CAZ-SC(3) 8,596.94 44.20 19.92 6,966.67 6,877.37 4,427.76 1,199.30 5,949,961.45 318,422.77 1.25 3,988.58 MWD+IFR-AK-CAZ-SC(3) 8,688.99 44.53 18.29 7,032.48 6,943.16 4,488.57 1,220.36 5,950,021.73 318,445.30 1.29 4,042.22 MWD+IFR-AK-CAZ-SC(3) 8,783.86 45.97 16.41 7,099.27 7,009.97 4,552.88 1,240.44 5,950,085.53 318,466.93 2.07 4,099.48 MWD+IFR-AK-CAZ-SC (3) i 8,877.88 47.64 15.00 7.163.62 7,074.32 4,618.86 1,258.98 5,950,151.03 318,487.07 2.09 4,158.75 MWD+IFR-AK-CAZSC (3) --� 8,972.41 49.37 14.85 7,226.25 7,136.95 4,687.27 1,277.21 -- 5,950,218.98 318,506.96 1.83 4,220.46 MWD+IFR-AK-CAZ-SC (3) 9,065.23 49.90 15.38 7,286.37 7,197.07 4,755.55 1,295.66 5,950,286.78 318,527.05 0.72 4,281.97 MWD+IFR-AK-CAZ-SC(4) 9,159.15 52.92 13.12 7,344.95 7,255.65 4.826.69 1,313.69 5,950,357.46 318,546.81 3.72 4,346.36 MWD+IFR-AK-CAZ-SC(4) 9,253.69 55.25 10.34 7,400.41 7,311.11 4,901.65 1,329.23 5,950,432.01 318,564.16 3.43 4,415.08 MWD+IFR-AK-CAZ-SC(4) 9,348.30 56.88 7.02 7,453.23 7,363.93 4,979.23 1,341.05 5,950,509.28 318,577.e6 3.38 4,487.25 MWD+IFR-AK-CAZ-SC(4) 9,443.38 59.02 5.83 7,503.69 7,414.39 5,059.30 1,350.06 5,950,589.11 318,588.81 2.49 4,562.55 MWD+IFR-AK-CAZ-SC(4) 9,537.37 61.14 4.36 7,550.57 7,461.27 5,140.44 1,357.28 5,950,670.04 318,598.00 2.63 4,639.32 MWD+IFR-AK-CAZ-SC(4) 9,631.10 63.33 3.29 7,594.23 7,504.93 5,223.18 1,362.80 5,950,752.62 318,605.53 2.55 4,718.07 MWD+IFR-AK-CAZ-SC (4) 1 9,725.90 65.54 0.81 7,635.14 7,545.84 5,308.63 1,365.85 5,950,837.97 318,610.64 3.32 4,800.06 MWD+IFR-AK-CAZ-SC (4) 9,821.37 67.61 359.04 7,673.09 7,583.79 5,396.23 1,365.72 5,950,925.53 318.612.64 2.76 4,884.91 MWD+IFR-AK-CAZ-SC(4) 9,914.50 69.73 358.32 7,706.97 7,617.67 5,482.95 1,363.72 5,951,012.27 318,612.75 2.39 4,969.39 MWD+IFR-AK-CAZ-SC(4) 10,008.82 71.79 356.34 7,738.05 7.648,75 5,571.89 1,359.56 5,951,101.29 318.610+75 2.95 5,056.56 MWD+IFR-AK-CAZ-SC(4) 10,103.47 7332 356.60 7,766.42 7,677.12 5,662.02 1,354.00 5,951,191.51 318,607.38 164 5,145.22 MWD+IFR-AK-CAZ-SC(4) _10,197.40 75.48 35559 7,791.68 7,702.38 5,752.27 1,34184 5,951,281.88 318,603.41 2.52 5,234.16 MWD+IFR-AK-CAZ-SC(4) 3/8/2019 11:13:38AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips 1IMP44ima ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Local Coordinate Reference: Well MT6-02 Project: Western North Slope ND Reference: Plan MT6-02 Q 89.30usft (Doyonl9 Planned) Site: GMT7 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wetlbore: MT6-021-1 Survey Calculation Method: Minimum Curvature Design: MT6-0211 Database: EDT 14 Alaska Production Survey j Map Map Vertical ' MD Inc Azi ND NDSS +N/-5 +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°ry00.) Section Survey Tool Name Annotation (ft) (ft) (ft) 10,291.63 77.47 354.82 7.813.72 7,724.42 5,843.56 1,340.18 5,951,373.32 318,597.97 2.26 5,324.48 MWD+IFR-AK-CAZ-SC(4) 10,385.11 79.81 354.11 7,832.13 7,742.83 5,934.77 1,331.34 5,951,464.72 318,591.35 261 5,415.01 yy MWD+IFR-AK-CAZ.SC 14) p 10,480.02 81.93 353.50 7,847.19 7,757.89 6,027.93 1,321.22 5,951,558.09 318,583.50 2.32 5,507.74 MWD+IFR-AK-CAZ-SC(4) (i( 10,573.01 83.85 352.94 7,858.70 7,769.40 6,119.55 1,310.33 5,951,649.94 318,574.83 2.15 5,599.19 MWD+IFR.AK-CAZ.SC(4) 10,666.87 84.92 351.47 7,867.88 7,778.58 6,212.10 1,297.66 5,951,742.76 318,564.41 1.93 5,691.97 MWD+IFR-AK-CAZ.SC(4) 10,765.69 85.04 350.80 7,876.53 7,787.23 6,309.36 1,282.49 5,951,840.36 318,551.61 069 5,789.94 MWD+IFR.AK-CAZ-SC(4) 10,854.81 84.92 350.16 7,884.33 7,795.03 6,396.91 1,267.81 5,951,928.24 318,539.06 0.73 5,878.39 MWD+IFR-AK-CAZ-SC(4) 10,949.60 84.89 349.50 7,892.75 7,803.45 6,489.85 1,251.13 5,952,021.54 318,524.65 0.69 5,972.54 MWD+IFR-AK.CAZ-SC(4) 11,044.11 84.76 348.97 7,901.27 7,811.97 6,582.31 1,233.55 5,952,114.40 318,509.32 0.58 6,066.47 MWD+IFR-AK-CAZ-SC(4) E 11,105.67 84.76 348.46 7,906.89 7,817.59 6,642.43 1,221.56 5,952,174.79 318,498.79 0.82 6,12768 MWD+IFR-AK-CAZ-SC(4) 11,152.00 85.28 348.18 7,910.92 7,821.62 6,687.63 1,212.21 5,952,220.20 318,490.55 1.27 6,173.78 MWD+IFR-AK-CAZ-SC (5) 11,247.24 86.91 348.08 7,917.40 7,828.10 6,780.61 1,192.67 5,952,313.63 318,473.27 1.71 6,268.70 MWD+IFR-AK-CAZSC(5) 11,342.17 86.93 348.52 7,922.50 7,833.20 6,873.44 1,173.45 5,952,406.88 318,456.30 0.46 6,363.39 MWD+IFR-AK-CAZ-SC (5) 11,437.25 88.45 348.60 7,926.34 7,837.04 6,966.55 1,154.60 5,952,500.42 318,439.73 1.60 6,458.26 MWD+IFR-AK-CAZ.SC(5) 11,531.99 88.69 347.48 7,928.70 7,83940 7,059.20 1,134.98 5,952,593.52 318,422.36 1.21 6,552.88 MWD+IFR-AK-CAZ-SC(5) 11,627.61 88.97 346.15 7,930.65 7,841.35 7,152.28 1,113.17 5,952.687.09 318,402.82 1.42 6,648.45 MWD+IFR-AK-CAZ.SC(5) J 11,723.09 89.12 345.92 7,932.24 7,842.94 7,244.93 1,090.13 5,952,780.26 318,382.04 0.29 6,743.91 MWD+IFR-AK-CAZ-SC(5) 11,728.00 89.28 345.94 7,932.31 7,843.01 7,249.69 1,088.94 5,952,785.05 318,380.96 3.28 6,748.82 MWD+IFR-AK-CAZ-SC(6) 11,744.61 88.81 346.18 7,932.59 7,843.29 7,265.81 1,084.94 5,952,801.26 318,377.35 3.18 6,765.43 MWD+IFR.AK-CAZ-SC(6) i i 11,808.31 88.79 345.133 7,934.26 7,844.96 7,327.57 1,0139.43 5,952,863.38 318,363.35 1.30 6,829.11 MWD+IFR-AK-CAZ-SC (6) 11,902.11 88.38 342.83 7,937.06 7,847.76 7,417.79 1,043.95 5,952,954.18 318,340.07 2.99 6,922.83 MWD+IFR-AK-CAZ-SC (6) 11,998.16 89.13 340.66 7,939.15 7,849.85 7,508.98 _ 1,013.88 5,953,046.07 318,312.22 2.39 7,018.64 114 MWD+IFR-AK-CAZ-SC (6) l 12,092.04 89.36 338.54 7,940.39 7,851.09 7,596.95 981.16 5,953,134.81 318,281.65 2.27 7,112.00 MWD+IFR-AK-CAZ.SC(6) 12,187.25 90.14 336.20 7,940.80 7,851.50 7.684.83 944.52 5,953,223.54 318,247.16 2.59 7,206.23 MWD+IFR-AK-CAZ-SC(6) 12,282.77 90.91 334.66 7,939.93 7,850.63 7,771.69 904,81 5,953,311.34 318,209.57 1.80 7,300.26 MWD+IFR.AK-CAZ.SC(6) j 12,377.32 91.49 332.58 7,937.95 7,848.65 7,856.37 8132.81 5,953,397.01 318,169.64 228 7,392.74 MWD+IFR-AK-CAZ-SC(6) r 12,472.65 92.23 330.16 7,934.85 7,845.55 7,939.99 817.16 5,953,481.71 318,126.04 2.65 7,485.10 MWD+IFR-AK-CAZ-SC(6) 12,567.76 92.75 327.59 7,930.72 7,841.42 6,021.33 768.05 5,953,564.21 318,078.92 2.75 7,576.12 MWD+IFR.AK-CAZ-SC(6) i 12,663.10 92.56 324.33 7,926.30 7,837.00 8,100.24 714.75 5,953.644.38 318,027.55 3.42 7,665.83 MWD+IFR-AK-CAZ-SC(6) 12,757.79 91.14 319.78 7,923.25 7,833.95 8,174.85 656.57 5,953,720.38 317,971.20 5.03 7,75260 MWD+IFR-AK-CAZ-SC(6) 12,853.34 9022 315.69 7,922.11 7,832.81 8,245.54 592.32 5,953,792.60 317,908.70 4.39 7,837.08 MWD+IFR.AK-CAZ-SC(6) 3/8/2019 11:13:38AM Page 7 COMPASS 5000.14 Build 85D ®, ConocoPhillips 9AF Rt EConOCOPl1II1 5 Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS - Local Cc -ordinate Reference: Well MT6-02 Project: Western North Slope ND Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-021_1 Survey Calculation Method: Minimum Curvature Design: MT6-021_1 Database: EDT 14 Alaska Production Survey MD Inc Azi ND N +N/ -S +E/.W Map Map DLS VerticalDSS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Se Section cti Survey Tool Name (ft) (ft) 12,94829 90.69 314.02 7,921.36 7,832.06 8,312.50 525.02 5,953,861.18 317,843.04 1.83 7,918.72 MWD+IFR-AK-CAZ-SC(6) 13,043.34 90.44 313.16 7,920.42 7,831.12 8,378.04 456.18 5,953,928.36 317,775.82 0.94 7,999.35 MWD+IFR-AK-CAZ-SC(6) 13,139.48 90.75 311.99 7,919.42 7,830.12 8,443.07 385.39 5,953,995.09 317,706.63 1.26 8,079.99 MWD+IFR-AK-CAZ-SC(6) 13,234.33 90.56 311.40 7,918.34 7,829.04 8,506.16 314.57 5,954,059.88 317,637.37 0.65 8,158.75 MWD+IFR-AK-CAZ-SC(6) 13,330.09 90.68 308.93 7,917.30 7,828.00 8,567.92 241.40 5,954,123.39 317,565.73 2.58 8,236.81 MWD+IFR-AK-CAZ-SC(6) 13,424.97 89.70 306.16 7,916.99 7,827.69 8,625.73 166.18 5,954,183.01 317,491.94 3.10 8511.56 MWD+IFR-AK-CAZ-SC (6) 13,519.25 89.05 303.60 7,918.01 7,828.71 8,679.64 88.85 5,954,238.77 317,415.94 2.80 8,383.05 MWD+IFR-AK-CAZ-SC (6) 13,615.09 89.09 302.60 7,919.57 7,830.27 8,731.97 8.57 5,954,293.03 317,336.97 1.04 8,453.75 MWD+IFR-AK-CAZ-SC (6) 13,710.64 89.21 300.82 7,920.99 7,831.69 8,782.18 -72.70 5,954,345.20 317.256.94 1.87 8,522.66 MWD+IFR-AK-CAZ-SC(6) 13,806.09 89.05 297.43 7,922.44 7,833.14 8,828.63 -156.06 5,954,393.65 317,174.74 3.56 8,588.43 MWD+IFR-AK-CA7-SC(6) 13,900.92 89.21 295.39 7,923.88 7,834.58 8,870.80 -240.98 5,954,437.87 317,090.87 2.16 8,650.45 MWD-HFR-AK-CAZ-SC(6) 13,996.18 89.24 293.44 7,925.17 7,835.87 8,910.17 -327.71 5,954,479.34 317,005.13 2.05 8,710.21 MWD+IFR-AK-CAZ-SC(6) 14,091.28 88.99 292.79 7,926.63 7,837.33 8,947.50 415.16 5,954,518.77 316918.61 0.73 8,768.18 MWD+IFR-AK-CAZ-SC(6) 14,186.36 89.15 294.07 7,928.18 7,838.88 8,985.30 -502.39 5.954.558.68 316,832.34 1.36 8,826.54 MWD+IFR-AK-CAZ-SC (6) 14,282.03 88.72 296.22 7,929.96 7,840.66 9,025.94 -588.98 5,954,601.41 316,746.77 2.29 8,887.50 MWD+IFR-AK-CAZ-SC(6) 14.376,92 88.62 297.84 7,932.16 7,842.86 9,069.05 -673.47 5,954,646.56 316.663+35 1.71 8,950.33 MWD+1FR-AK-CA7-SC(6) 14,471.30 88.56 299.86 7,934.48 7,845.18 9,114.58 -766.11 5,954,694.07 316,581.85 2.14 9,015.03 MWD+IFR-AK-CAZ-SC(6) 14,566.76 88.44 301.95 7,936.98 7,847.68 9,163.59 -837.99 5,954,745.05 316,501.19 2.19 9,082.91 MWD+IFR-AK-CAZ-SC(6) 14.662.05 89.22 302.92 7,938.93 7,849.63 9,214.68 -918.39 5,954,798.08 316,422.05 1.31 9,152.45 MWD+IFR-AK-CAZ-SC(6) 14,756.54 69.30 305.05 7,940.15 7,850.85 9,267.49 -996.73 5,954,852.77 316345.03 2.26 9,223.14 MWD+IFR-AK-CAZ-SC(6) 14,852.67 90.35 307.33 7,940.44 7,851.14 9,324.25 -1,074.31 5,954,911.39 316,268.85 2.61 9,29]45 MWD+IFR-AK-CAZ-SC(6) 14,947.51 91.86 310.48 7,938.61 7,849.31 9,383.79 -1,148.09 5,954,972.71 316,196.55 3.68 9,373.52 MWD+IFR-AK-CAZSC(6) 15,042.68 93.00 313.03 7,934.58 7,845.28 9,447.10 -1,219.01 5,955,037.72 316,127.18 2.93 9,452.52 MWD+IFR-AK-CAZ-SC(6) 15,137.58 93.14 315.30 7,929.49 7,840.19 9,513.12 -1,286.99 5,955,105.37 316,060.84 2.39 9,533.41 MWD+IFR-AK-CAZ-SC(6) 15,232.11 91.60 316.52 7,925.58 7,836.28 9,580.96 -1,352.70 __ 5,955,174.77 315,99680 2.08 9,615.50 MWD+IFR-AK-CAZ-SC(6) 15,327.95 90.59 318.40 7,923.75 7,834.45 9,651.56 -1,417.48 5,955,246.92 315,933.75 2.23 9,700.02 MWD+IFR-AK-CAZ-SC(6) 15,423.24 88.56 318.37 7,924.46 7,835.16 9,722.79 -1.480.76 5,955,319.66 315,872.22 2.13 9,784.79 MWD+IFR-AK-CAZ-SC(6) 15.518.65 88.72 321.58 7,926.72 7,837.42 9,795.83 -1,542.09 5,955,394.16 315,812.68 3.37 9,870.82 MWD+IFR-AK-CAZ-SC(6) 15,613.39 88.16 324.78 7,929.30 7,840.00 9,871 63 -1,598.84 5,955,471.31 315,757.79 3.43 9,958.38 MWD+IFR-AK-CAZ-SC (6) 15,708.09 87.15 327.03 7,933.18 7,843.88 9,94998 -1,651.88 5,955,550.92 315,70668 2.60 10,047.48 MWD+IFR-AK-CAZ-SC(6) 15,802.75 87.68 330.09 7,937.45 7,848.15 10,030.65 -1,701.20 5,955,632.76 315,659.34 3.28 10,137.91 MWD+IFR-AK-CAZ-SC(6) 3/82019 11:13:38AM Page 8 Annotation COMPASS 5000.14 Build 85D ConocoPhillips RA ER yq'ME. ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-02 Wellbore: MT6-0211 Design: MT6-0211 Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MT6-02 ,. _°......-..�. _ Plan MT6-02 Q 89.30usft (Doyon19 Planned) Plan MT6-02 Q 89.30usft (Doyonl9 Planned) i True Minimum Curvature EDT 14 Alaska Production Annotation 3/82019 11:13:38AM Page 9 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +EI -W Northing East) DLS Section Survey Tool Name (usft) (°) (°) (usft) (usft) (usft) (usft) (k) (ft) (°/100') Iftl 15,898.20 90.23 330.97 7,939.19 7,849.89 10,113.73 -1,748.15 5,955,716.95 315,61442 2.83 10,230.07 MWD+IFR-AK-CAZ-SC(6) 15,994.33 91.43 332.20 7,937.80 7,848.50 10,198.26 -1,793.88 5,955,802.57 315,570.76 1.79 10,323.34 MWD+IFR-AK-CAZ-SC (6) 16,089.54 91.51 332.33 7,935.35 7,846.05 10,282.51 -1,838.18 5,955,887.86 315,528.52 0.16 10,415.97 MWD+IFR-AK-CAZ-SC(6) 16,184.08 90.19 331.52 7,933.95 7,844.65 10,365.91 -1,882.66 5.955,972 31 315,486.08 1.64 10,507.84 MWD+IFR-AK-CAZ-SC(6) 16,279.12 90.01 333.25 7,933.79 7,844.49 10,450.12 -1,926.72 5,956,057.56 315,444.08 1.83 10.600.38 MWD+IFR-AK-CAZ-SC(6) 16,375.71 90.25 334.75 7,933.57 7,844.27 10,536.93 -1.969.06 5,956,145.37 315,403.87 1.57 10,695.01 MWD+IFR-AK-CAZ-SC(6) 16,471.20 90.53 334.10 7,932.92 7,843.62 10,623.06 -2,010.28 5,956,232.47 315,364.75 0.74 10,788.70 MWD+IFR-AK-CAZ-SC(6) 16,565.75 89.58 333.53 7,932.83 7,843.53 10,707.91 -2,052.00 5,956,318.30 315,325.10 1.17 10,881.27 MWD+IFR-AK-CAZ-SC(6) 16,661.49 91.83 334.23 7,931.65 7,842.35 10,793.86 -2,094.14 5,956,405.24 315,285.06 2.46 10,975.01 MWD+IFR-AK-CAZ-SC(6) 16,757.11 93.49 334.63 7,927.21 7,837.91 10,880.02 -2,135.37 5,956,492.37 315,245.94 1.79 11,068.73 MWD+IFR-AK-CAZ-SC (6) 16,851.23 93.57 334.52 7,921.42 7,832.12 10,964.86 -2,175.70 5,956,578.16 315,207.69 0.14 11,160.95 MWD+IFR-AK-CAZ-SC 16) 16,947.54 93.54 334.49 7,915.44 7,826.14 11,051.63 -2,217.08 5,956,665.90 315,168.43 0.04 11,255.30 MWD+IFR-AK-CAZ-SC(6) 17,042.72 92.77 333.70 7,910.21 7,820.91 11,137.11 -2,258.59 5,956,752.36 315,129.00 1.16 11,348.44 MWD+IFR-AK-CAZ-SC(6) 17,138.57 92.74 333.53 7,905.60 7,816.30 11,222.88 -2,301.14 5,956.839.13 315,088.55 0.18 11,442.11 MWD+IFR-AK-CAZ-SC(6) 17,234.09 90.61 330.11 7,902.81 7,813.51 11,307.02 -2,34622 5,956,924.34 315,045.53 4.22 11,534.84 MWD+IFR-AK-CAZ-SC(6) 17,328.37 89.33 331.72 7,902.86 7,813.56 11,389.41 -2,392.05 5,957,007.81 315,001.72 2.18 11,626.05 MWD+IFR-AK-CAZ-SC(6) 17,423.85 89.89 332.76 7,903.51 7,814.21 11,473.89 -2,436.52 5,957,093.35 314,959.32 1.24 11,718.96 MWD+IFR-AK-CAZ-SC(6) 17,518.98 88.16 331.80 7,905.12 7,815.82 11,558.09 -2,480.76 5,957,178.59 314,917.14 2.08 11,811.53 MWD+IFR-AK-CAZ-SC(6) 17,614.29 88.51 332.27 7,907.89 7,818.59 11,642.24 -2,525.44 5,957,263.79 314,874.52 0.61 11,904.16 MWD+IFR-AK-CAZ-SC (6) 17,709.04 88.94 333.37 7,910.00 7,820.70 11,726.50 -2,568.71 5,957,349.07 314,833.31 1.25 11,996.55 MWD+IFR-AK-CAZ-SC (6) 17,805.09 90.85 334.57 7,910.18 7,820.88 11,812.80 -2,610.85 5,957,436.36 314,793.28 2.35 12,090.64 MWD+IFR-AK-CAZ-SC (6) 17,899.74 90.56 332.91 7,909.01 7,819.71 11,897.67 -2,652.73 5,957,522.22 314,753.48 1.78 12,183.28 MWD+IFR-AK-CAZ-SC(6) 17,994.18 89.12 333.23 7,909.28 7,819.98 11,981.87 -2,695.50 5,957,607.43 314,712.77 1.56 12,275.48 MWD+IFR-AK-CAZ-SC(6) 18,089.24 88.29 332.47 7,911.42 7,822.12 12,066.43 -2,738.86 5,957,693.01 314,671.47 1.18 12,368.19 MWD+IFR-AK-CAZ-SC(6) 18,185.26 89.00 332.91 7,913.70 7,824.40 12,151.73 -2,782.90 5,957,779.35 314.629.52 0.87 12,461.77 MWD+IFR-AK-CAZ-SC(6) 18,279.85 90.63 333.99 7,914.00 7,824.70 12,236.34 -2,825.18 5,957,864.95 314,589.31 2.07 12,554.25 MWD+IFR-AK-CAZ-SC(6) 18,375.95 91.64 334.45 7,912.10 7,822.80 12,322.85 -2,866.97 5,957,952.45 314.549.64 1.15 12,648.46 MWD+IFR-AK-CAZ-SC (6) 18,470.85 91.54 334.09 7,909.46 7,820.16 12,408.31 -2,908.15 5,958,038.88 314,510.54 0.39 12,741.49 MWD+IFR-AK-CAZSC (6) 18,565.33 89.29 332.24 7,908.78 7,819.48 12,492.61 -2.950.80 -- 5,958,124.18 314,469.96 3.08 12,833.76 MWD+IFR-AK-CAZ-SC (6) 18,661.11 88.35 335.23 7,910.75 7,821.45 12,57647 -2,993.17 5,958,211.04 314,429.69 3.27 12,927.47 MWD+IFR-AK-CAZ-SC(6) 18,756.36 88.01 336.91 7,913.78 7.824.48 12,665.48 -3,031.78 5.958,298.96 314,393.20 1.80 13.021.37 MWD+1FR-AK-CAZ-SC (6) Annotation 3/82019 11:13:38AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips BqMR ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 Q 89.30usft (Doyon 19 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-0211 Survey Calculation Method: Minimum Curvature Design: MT6-0211 Database: EDT 14 Alaska Production Survey 3/&2019 11: 13 38A Page 10 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El -W Northing Easting DLS Section (usft) (°I (I (usft) (usft) (usft) (usft) (°1100') Survey Tool Name Annotation (ft) (ft) (ft) 18,851.63 87.67 334.48 7,917.37 7,828.07 12,752.24 -3,070.96 5,958,386.64 314,356.14 2.57 13,115.16 MWD+IFR-AK-CAZ-SC(6) 18,947.20 87.83 333.27 7,921.12 7,831.82 12,837.98 -3,113.01 5,958,473.37 314,316.19 1.28 13,208.68 MWD+IFR-AK-CAZ-SC(6) 19,042.70 88.82 332.81 7,923.91 7,834.61 12,923.06 -3,156.29 5,958,559.47 314,274.99 1.14 13,301.87 MWD+IFR-AK-CAZ-SC(6) 19,138.27 90.85 333.20 7,924.19 7,834.89 13,008.21 -3,199.67 5,958,645.65 314,233.69 2.16 13,395.15 MWD+IFR-AK-CAZ-SC(6) 19,233.95 92.23 333.62 7,921.62 7,832.32 13,093.74 -3,242.48 5,958,732.18 314,192.98 1.51 13,488.65 MWD+IFR-AK-CAZ-SC(6) 19,329.09 93.09 334.34 7,917.20 7,827.90 13,179.14 -3,284.17 5,958,818.57 314,153.37 1.18 13,581.76 MWD+IFR-AK-CAZ-SC(6) 19,425.07 93.64 334.87 7,911.57 7,822.27 13,265.70 -3,325.26 5,958,906.09 314,114.40 0.80 13,675.83 MWD+IFR-AK-CAZ-SC(6) 19,520.09 93.57 334.58 7,905.59 7,816.29 13,351.45 -3,365.75 5,958,992.80 314,076.01 0.31 13,768.97 MWD+IFR-AK-CAZ-SC(6) 19,615.72 93.54 334.36 7,899.66 7,610.36 13,437.56 -3,406.89.- 5,959,079.89 314,036.98 0.23 13,862.63 MWD+IFR-AK-CAZ-SC(6) 19,710.73 96.23 334.71 7,891.57 7,802.27 13.523.04 -3.447.58 5,959,166.31 313,998.37 2.85 13,955.54 MWD+IFR-AK-CAZ-SC(6) 19,806.46 96.19 335.18 7,881.22 7,791.92 13,609.25 -3,487.89 5,959,253.47 313,960.17 0.49 14,049.09 MWD+IFR-AK-CAZ-SC(6) 19,901.57 95.97 334.67 7,871.14 7,781.84 13,694.91 -3,527.97 5,959,340.07 313,922.18 0.56 14,142.04 MWD+IFR-AK-CAZ-SC(6) 19,930.00 95.97 334.67 7,868.19 7,778.89 13,720.47 -3,540.06 5,959,365.91 313,910.71 0.00 14,169.80 PROJECTED to TD 3/&2019 11: 13 38A Page 10 COMPASS 5000.14 Build 85D l THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Graham Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Greater Moose's Tooth Field, Lookout Pool, MT6-02L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-009 Surface Location: 239' FNL, 3115' FEL, SEC. 6, TI ON, R3E, UM Bottomhole Location: 4950' FNL, 2896' FEL, SEC. 13, TI IN, R2E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aloska.gov Enclosed is the approved application for the permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 218-160, API No. 50-103-20792-00- 00. Production should continue to be reported as a function of the original API number stated above. 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, Daniel T. Seamount, Jr. Commissioner DATED this day of January, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 � `�IVED JAN 2 0 2013 1a. Type of Work: Drill Q Lateral ❑ RednII ❑ Reentry ❑ 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG 0 Service - Disp ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zone ❑� Exploratory - Oil ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑ ic. Specify if p ed for: Coalbed Gas as Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket Q Single Well ❑ Bond No. 5952180 11. Well Name and Number: MT6-02L1 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 22920 TVD: 7887 12. Field/Pool(s): Greater Mooses Tooth Unit ' Lookout Pool ' 4a. Location of Well (Governmental Section): Surface: 239' FNL, 3115' FEL, Sec. 6, TION, R3E, UM Top of Productive Horizon: 4079' FNL, 1861' FEL, Sec. 30, T11 N, R3E, UM Total Depth: 4950' FNL, 2896' FEL, Sec. 13, T11 N, R2E, UM 7. Property Designation: i b,,, of L tQ (AA)81818, 92346, 81798, 9V5, 81743 8. DNR Approval Number: Not i% L'. 932553, 340761, 932533, 340760 13. Approximate Spud Date: 4,422/2018" 01 /3011!3 9. Acres in Property: 1208, 600, 607, 3837, 640 14. Distance to Nearest PrWerty: 2289' to AA092340 FF��-- 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x-317115 y- 5945564 Zone -4 10. KB Elevation above MSL (ft): 89.3 ' GL / BF Elevation above MSL (ft): 52.1 15. Distance to Nearest Well Open to Same Pool: 1350' to MT6-03 16. Deviated wells: Kickoff depth: 318 feet Maximum Hole Angle: 90 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3810 Surface: 3015 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 6" 45' 12.6 L-80 Blue 12011 10909 22920 7887 uncemented perf pup liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 22228 None 22228 None Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20 10 yds 115 115 Surface 2046 13.375 To Surface 2080 2020 Intermediate 1 8708 9.625 8504' MD TOC (CBL logged) 8742 7070 Intermediate 2 11025 7 55.1 bbl of 15.8# Class G 11059 7902 Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A Hydraulic Fracture planned? Yes No E ' 20. Attachments: Property Plat D �BOP Sketch ivertter Sketch e ing Program DSleabed Report Shallow Hazard Dril ngeFlV. u d Prog Pot atm 20 AAC 25.050 requi emlentse✓ 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: Andrew Beat Authorized Name: Graham Alvord (265-6120) Contact Email: andrew.t.beat CO .com Authorized Title: Drilling Manager Contact Phone: 907 265-6341 Authorized Signature: Date: (12429( Commission Use Only Permit to Drill Number: — API Number: 50- _ Permit Approval Date: ' G I I See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: 2 Other: 06P f C$ f .fo 3 ObQ� i r Samples req'd: Yes ❑ No[g/ Mud log mq'd: Yes ❑ No[g-' 4yamnV 1 G! ✓ ,O✓✓ t, ysI � ✓ ft t fa z SCC p5, 'H2S measures: Yes EJNo[[R" Directional svy aq'd: Yes YNo❑ r'I�t t ✓t f I'C Spaclngckception req'd: Yes ❑ N,[7/ Inclination -only svy req'd: Yes❑ NoW / V /- 7� " S -N �- N s r/ d ' r f )-,:5 v ( tS Postinitial injection MIT req'd: Yes ffNo❑ 10 /9-0,97 CC R.5 Q,$ ef VO r l ct b � e �o � ct�JJ/J ✓ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date VT's." '14/111i,%Submit Form and � 0-401 Revised 5/2017 his p rvalid for 4 �n hA from h to,�f proval per 20 AAC 25.005(g) Attachments in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 25th, 2019 Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT6-02L1 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill to add a lateral to the current well (MT6-02 / 218-160). This submission is in conjunction with the already approved PTD for MT6-02. After drilling the MT6-02 lateral as planned, it was determined that the rock quality did not meet one of the two primary well objectives and a sidetrack would be needed. The sidetrack will be performed in the open hole at the heel of the well and will drill to the west of the original plan in order to locate better rock for injecting into MT6-03. The current lateral will have a short section of liner installed before performing the sidetrack. The MT6-02L1 production interval will be a 6" horizontal that will be geo-steered in the Alpine sand. The same mud system used for MT6-02 will be used for MT6-021-1. The well will be completed as an injector with a 4.5" pre -perforated liner and tied back to surface with a 4.5" tubing string. An estimate of the remaining operations for the well are as follows: 1. POOH with lateral BHA and run `Plop and Drop' liner into MT6-02 lateral. Release liner. 2. BOPE test to 250/3500 psi. 3. with lateral BHA. Sidetrack well and drill MT6-02L1 to TD. POOH with BHA. 4. Run liner into MT6-02L1 with liner top packer set inside 7" casing (SCMT in liner tool to log 7" cement) a -- 5. Run upper completion. Conduct integrity tests as described in MT6-0 PTD. 6. Prepare well for rig release. Release rig from MT6-02. Please find attached the information for your review. Pertinent information attached to this application includes the following: 1. Form 10401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed completion diagram 3. Directional drilling/ collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Andrew Beat at 265-6341 (andrew.t.beat@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, cc: MT6-02 Well File / Ann Haggerty -Sherrod ATO 1530 Johnson Njoku ATO 1720 Chip Alvord ATO 1570 Andrew eat John Cookson ATO 1750 Drilling Engineer MT6-02/MT6-02L1, Well Schematic TOC at least 300' MD above Packer & 500' MD above Alpine C. Planned to Liner Top. - Top Alpine C 10,999' MD / 7,897' TVD 4-%" 12.6# L-80 TS Blue With Per' Pups Sidetrack Point 11,723' MD / 7,932' TVD 0 0 0 0 0 0 MT6-02L1 22,920' MD / 7,887' TVD 7" 26 ppf L-80 \ ° ° MT6-02 TD 22,228' MD / 7,834' TVD January 2019—ATB 20" 79 ppf H-40 Insulated Conductor 80 feet, cemented to surface 13-3/8" 68 ppf L-80 TXP/BTCM Surface Casing 4-1/2" 12.6 ppf L-80 Tenaris Blue 9 5/8" 40 ppf L-80 UP (to —4,960' MD) 9 5/8" 40 ppf TN -80 HS TXP (to TD) TOC at least 300' MD above Packer & 500' MD above Alpine C. Planned to Liner Top. - Top Alpine C 10,999' MD / 7,897' TVD 4-%" 12.6# L-80 TS Blue With Per' Pups Sidetrack Point 11,723' MD / 7,932' TVD 0 0 0 0 0 0 MT6-02L1 22,920' MD / 7,887' TVD 7" 26 ppf L-80 \ ° ° MT6-02 TD 22,228' MD / 7,834' TVD January 2019—ATB Applicatic Permit to Drill, Well MTU MT6-02L1 Saved: 28 -Jan -19 MT6-02L1 Application for Permit to Drill Document Table of Contents 1. Well Name (Requirements of 20 AA 25.005 (f))............................................................ 3 2. Location Summary (Requirements of 20 AA 25.005(c)(2)) ............................................ 3 Requirements of20AAC25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of20AAC25.005 (c)(4)) ........................4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 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 gf20AAC25.005(c)(8))....................................6 9. Abnormally Pressured Formation Information (Requirements of 20AAC 25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ......................................... 7 11. Seabed Condition Analysis (Requirements of20AAC 25.005 (c)(11)) ........................7 12. Evidence of Bonding (Requirements of20AAC 25.005 (c)(12)) ...................................7 13. Proposed Drilling Program (Requirements of20AAC25.005 (c)(13)) .........................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 (Requirements of 20 AAC 25.005 (c) (14))............................................................................. 7 15. Attachments............................................................................................................... 8 Attachment t Cement Summary ................................................................................................................. 8 MT6-02L1 PTD Page 1 of 14 Printed.' 28 -Jan -19 Attachment 2 Drilling Hazards Summary ..... Attachment Completion Schematic............ Attachment 4 Area ojReview....................... Attachment 5 Directional Plan ....................... Applicatid : Permit to Drill, Well MTU MT6-02L1 Saved: 28 -Jan -19 ............................................................................................ 8 ............................................................................................. 8 ............................................................................................. 8 ....................................................................................................... S MT6-02L1 PTD Page 2 of 14 Printed: 28 -Jan -19 ApplicatiC Permit to Drill, Well MTU MT6-02L1 Saved: 28 -Jan -19 1. Well Name (Requirements of20AAC25.005 (9) The well for which this application is submitted will be designated as MTU MT6-021-1. 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 239' FNL, 3115' FEL, Sec. 6 TION, RIE, UM NAD 1927 Northings: 5,945,564 Eastings: 317,115 RKB Elevation 89.3' AMSL Pad Elevation 52.1' AMSL . Top of Productive Horizon eel 4079' FNL 1861' FEL, Sec. 30 TI 1N, ME, UM NAD 1927 Northings: 5,952,252 Eastings: 318,505 Measured De th, RKB: 1 11,159' Total Vertical Depth, RKB71 7,847' Total Vertical Depth, SS: I7,758' Total Depth Toe 4950' FNL 2896' FEL, Sec. 13, TI 1N, R2E, UM NAD 1927 Northings: 5,962,085 Eastings: 312,723 Measured De th, RKB.. 22,920' Total Vertical Depth, RKB: 7,887' Total Vertical Depth, SS: 7,798' Requirements of 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. MT6-021-1 PTD Page 3 of 14 Printed: 28 -Jan -19 Applicatic 4. Drilling Hazards Information (Requirements of20AAC25.005(c)(4)) Permit to Drill, Well MTU MT6-021-1 Saved: 28 -Jan -19 The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 1151115 10.9 52 54 13.375 2080/2020 14.5 918 1321 9.625 8742/7070 13.5 3356 2835 7 11059/7902 12.5 3625 2816 4.5 22920/7887 12.5 3605 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP= [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from lb/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 (20") ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052) -0.1]x 115=54 psi OR ASP = FPP - (0.1 x D) = 918 - (0.1 x 2020) = 716 psi 2. Drilling below surface casing (13-3/8") ASP = [(FG x 0.052) - 0.11 D = [(14.5 x 0.052) - 0.1] x 2020' = 1321 psi OR ASP= FPP - (0.1 x D) = 3356 - (0.1 x 7070') = 2649 psi Drilling below intermediate casing (9-5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(13.5 x 0.052) - 0.11 x 7070 = 4256 psi OR ASP = FPP - (0.1 x D) = 3625- (0.1 x 7902') = 2835 psi G¢(C- g.:7Lt M w Mur.;' pvo vu, O P --Vg - 9.L--10_0 IP v'v 9 Gu �L g.� z 10.0 -II-C MT6-02L1 PTD Page 4 of 14 Printed: 28 -Jan -19 4. Drilling below production liner (7) IUs Applicatic Permit to Drill, Well MTU MT6-02L1 Saved: 28 -Jan -19 ASP = [(FG x 0.052) —0.1] D = [(12.5 x 0.052)-0.1] x 7902 = 4350 psi ASP =FPP—(0.1 xD) = 3605 — (0.1 x 7887) = 2816 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. cu !c._ Prue^ vJ f M P fl (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 Cementing Program Csg/Tbg Hole size yyeight eig Grade Conn. Length Top MD?VD Star MD/TVD Cement Program OD (in) (it) (h) (h) Cemented to surface with 20 42 94 H-40 Welded 80 Surf 115/115 10 yds slurry Cement to Surface with 13-3/8 16 68 L-80 H 563/ 563 2,047 Surf 2,080 / 2,020 964 sx DeepCrete Lead at 11.0 ppg, TXP330 sx Class G Tail Slurry at 15.8 pog lXP/ 9-5/8 12-1/4 40 L-80 TN -80 8,705 Surf 8,742 / 7,070 218 sx Class G Tail at 15.8 ppg HC 7 63/4 26 L-80 Blue/ 11,012 Surf 11,059 / 7,902 230 sx Class G Tail at 15.8 ppg 4-1/2 n/a 12.6 L-80 TSH Blue 10,872 Surf 10,909 / 7,889 n/a Uncemeneted open hole liner w/ pre - 4 1/2 6 12.6 L-80 UP 6,009 15,930 / 7,935 21,939 / 7,849 perforated pup joints Uncemeperfoted open hole liner w/ pre - 4 E/2 (Ll) 6 12.6 L-80 TXP 12,011 10,909 / 7,889 22,920 / 7,887 perforated pup joints 7. Diverter System Information (Requirements of20AAC25.005(c)(7)) It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. MT6-02L1 PTD Page 5 of 14 Printed., 28 -Jan -19 Applicatior! ?ermit to Drill, Well MTU MT6-021_1 Saved: 28 -Jan -19 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 <_10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. d 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. MT6-02L1 PTD Page 6 of 14 Printed. 28 -Jan -19 Surface Intermediate Intermediate Production #1 #2 Hole Size in. 16 12.25 6.0 x 8.75 6.0 Casing Size in. 13.375 9.625 7 4.5 Density PPG 9.0-10.0 9.4-10.0 10.0-11.0 8.8 PV cP 13 10 10 15 YP Ib./100 35-50 20-28 20-28 15-20 Funnel s/qt. 200 40-50 40-50 60-80 Viscosity Initial Gels Ib./100 50 10 10 10 30 Minute Ib./100 60 15 20 15 Gels ft2 API Fluid cc/30 N.C. — 15.0 5.0 5.0 4.0 Loss min. HPHT Fluid cc/30 12.0 8.0-12.0 10.0 Loss min. 1 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 <_10.0 ppg by use of solids control system and dilutions where necessary. Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight from 9.4-10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Intermediate #2: Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. d 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. MT6-02L1 PTD Page 6 of 14 Printed. 28 -Jan -19 Application ?ermit to Drill, Well MTU MT6-021_1 Saved: 28 -Jan -19 9. Abnormally Pressured Formation Information (Requirements of20AAC25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(1 1)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of20AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. End MT6-02 PTD and begin MT6-02L1 PTD. 2. Perform open hole sidetrack from MT6-02. 3. Drill 6" horizontal hole to section TD (LWD Program: GR/ Azimuthal RES). 4. Circulate the hole clean and POOH with drilling BHA. 5. Run in hole with 4.5" liner with pre -perforated pup joints on 4" drill pipe (CBL 7" Liner on way out of hole). 6. Set liner top packer and release from liner. 7. Displace well to kill weight brine. 8. Run 4.5" upper completion. Space out and land hanger. 9. Install HP back pressure valve and pressure test hanger seals to 5000 psi. Nipple down BOP. 10. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove back pressure valve. 11. Test tubing to 3500 psi/ 30 min and chart. Test tubing -casing annulus separately to 3300 psi / 30 mins and chart. 12. Shear circulation valve in GLM. Circulate tubing to diesel and install freeze protection in the annulus. 13. Set BPV and secure well. RDMO. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) incidental fluids developed from drilling operations on well MT6-02LI will be injected into a permitted surface casing x production casing annulus on MT6/CDI. The MT6-02 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1200' TVD. Significant hydrocarbon zones include only the Alpine sand based on pre -drill interpretations. There will be 500' MD, or 250' TVD, whichever is greater, of cement placed above the top of the Alpine reservoir. Once MT6-02 has been drilled and completed, consideration may be given to permit this well for annular injection. MT6-02L1 PTD Page 7 of 14 Printed.., 28 -Jan -19 Application Permit to Drill, Well MTU MT6-021-1 Saved: 28 -Jan -19 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) * (2,033') + 1,500 psi = 2767 psi Pore Pressure = 910 psi Therefore Differential = 2767 — 910 = 1857 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (Wt Grade Range Connection Type Collapse 85% of Collapse Burst 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 15. Attachments Attachment I Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan MT6-021-1 PTD Page 8 of 14 Printed: 28 -Jan -19 Application Permit to Drill, Well MTU MT6-02L1 Saved: 28 -Jan -19 Attachment 1 — Cement Summary GMTU MT6.02/MT6-02L1 COpu�MK MT6-020 PTD Page 9 of 14 Printed: 28 -Jan -19 Application ?ermit to Drill, Well MTU MT6-02L1 Saved: 28 -Jan -19 13-3/8" Surface Casing run to 2,080' MD / 2,020' TVD. Cement from 2,080' MD to 1,580'(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1,580' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1,106' MD), zero excess in 20" conductor. Lead slurry from 1,580' MD to surface with DeepCrete @ 11.0 ppg Conductor (115'— 371 X 1.0190 ft3/ft X 1.0 (0% excess) = 79 ft3 Permafrost to Conductor (1,106'-1151 X 0.4206 ft3/ft X 3.5 (250% excess) = 1,459 ft3 Top of Tail to Permafrost (1,580'— 1,106 X 0.4206 ft3/ft X 1.5 (50% excess) =312W Total Volume= 79 + 1,459 + 312 = 1850 ft3 => 964 sx of 11.0 ppg DeepCrete @ 1.92 ft3 /sk Tail slurry from 2,080' MD to 1,580' MD with 15.8 ppg Class G + additives Shoe to Top of Tail 2,080'-1,5801 X 0.4206 ft3/ft X 1.50 (50% excess) =315W Shoe Joint (801 X 0.8407 ft3/ft X 1.0 (0% excess) = 68 ft3 Total Volume = 315 + 68 = 383 ft3 => 330 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk 9-5/8" Intermediate easing to 8,742' MD / 7,070' TVD Cement 500' up from 9-5/8" casing shoe from 8,742' MD to 8,242' MD. Assume 40% excess annular volume. Tail slurry from 8,742' MD to 8,242' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (8,742'-8,242 X 0.3132 ft3/ft X 1.40 (40% excess) = 219 ft3 Shoe Joint (80) X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft3 Total Volume = 219 + 34 = 253 ft3 => 218 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk 7" Intermediate liner run to 11,059' MD / 7,902' TVD Top of sluny is designed to be — 250' TVD up from the 7" liner shoe. Assume 30% excess annular volume. 6" x 8-3/4" underreamer to be 100ft behind the drill bit. Tail slurry from 11,059' MD to 9,767' MD with 15.8 ppg Class G + additives (250'tvd) 8-3/4" Hole to Top of Tail (11,059'-9,7671 X 0.1503 ft3/ft X 1.30 (30% excess) =251W Shoe Joint (80) X 0.2148 ft3/ft X 1.0 (0% excess) = 17 ft3 Total Volume = 250 + 17 = 267 ft3 => 230 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk MT6-02L1 PTD Page 10 of 14 Printed. 28.1an-19 Applicatior( Permit to Drill, Well MTU MT6-021-1 Saved: 28 -Jan -19 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 iticlation 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 Medium Reduce trip speeds, condition mud properties, circulating time reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, monitoring, MPD stripping ractices Increase mud weight, use weighted sweeps, Low Well control drills, check for flow during reduce fluid viscosity, control ROP Abnormal Pressure in Low Diverter drills, increased mud weight. Shallow Surface Formations study noted minimal risk hazard stud noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost Abnormal Reservoir and use best hole cleaning radices circulation material, use of low density cement Pressure slurries ort collar, control pipe running seeds 12-1/4" Hole 9 -bits" Lam intervai Risk Level Event Risk Level Mitigation 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 Lost circulation proper hole filling, pump out of hole, real time ECD 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 Hole swabbing on trips connections, increase mud weight. Shallow hazard 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 Abnormal Reservoir and use best hole cleaning radices 6" x 8-3/4" Hole / 7" Liner - Casina Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight High MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Low Well control drills, check for flow during Pressure connections increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices mud scavengers MT6-02L1 PTD Page 11 of 14 Printed: 28 -Jan -19 Applicatiod 3ermit to Drill, Well MTU MT6-021-1 Saved: 28 -Jan -19 6" Hole / 4-1/2" Pre -Perforated Liner - Horizontal Production HnIP 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 monitorin Abnormal Reservoir Low Well control drills, check for Flow during Pressure connections increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low 1-12S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT6-02L 1 will be the seventh well drilled on the pad. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach in the pilot and intermediate #2 hole sections will require higher mud weights than historically used to enhance wellbore stability. Steerable Drilling Liner and Managed Pressure Drilling will be used in conjunction with a 4 -string casing design to mitigate shale instability. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT6-021-1 PTD Page 12 of 14 Printed: 28 -Jan -19 Application 'errnit to Drill, Well MTU MT6-021_1 Saved. 28 -Jan -19 Attachment 3 —Completion Schematic MT6-02/MT6-02L1, Well Schematic TOC w least 300 MD above Packer 8 500' MO above Alpine C. Planned to Liner Top. Top Alpine C 10.999' MD f 7,897' TVD 7" 26 ppt L-80 12.66 L-80 TS Blue With Perf Pups Sidetrack Point MT6-02L1 11,723' MD 17,932' TVD 22,929 MD 17,887' TVD 0 0 0 0 0 0 0 0 0 0 0 0 MT6-02 TD 22,228' MD 17,834' TVD January 2019 - ATB MT6-02L1 PTD Page 13 of 14 Printed: 28 -Jan -19 20" 79 ppf H-40 Insulated A Ilk Conductor 80 feet, cemented to swface 13-3J8" 69 ppf L-0 TXPJBTCM Surface Casing 4412" 12-6 ppf L-80 Tenads Blue 9 SW 40 ppf L-80 TXP (t0 -4,960' MO) 9 676" 40 ppf TN -80 HS TXP (to TO) TOC w least 300 MD above Packer 8 500' MO above Alpine C. Planned to Liner Top. Top Alpine C 10.999' MD f 7,897' TVD 7" 26 ppt L-80 12.66 L-80 TS Blue With Perf Pups Sidetrack Point MT6-02L1 11,723' MD 17,932' TVD 22,929 MD 17,887' TVD 0 0 0 0 0 0 0 0 0 0 0 0 MT6-02 TD 22,228' MD 17,834' TVD January 2019 - ATB MT6-02L1 PTD Page 13 of 14 Printed: 28 -Jan -19 Applicatiotl 2ermit to Drill, Well MTU MT6-02L1 Saved: 28-Jan-19 Attachment 4 —Area of Review MT6-02L1 Area of Review: This Area of Review is required as MT6-02 is being permitted as an Alpine C Sand Injector. There are currently not any wells or planned wells that fall within % mile of the well's entry point into the Alpine C sand. Attachment 5 — Directional Plan MT6-O2L1 MT6-02L1 PTD Page 14 of 14 Printed: 28 -Jan -19 ConocoPhillips ConocoPhillips Alaska Inc_WNS Western North Slope GMT1 Lookout Pad MT6-02 MT6-021-1 Plan: MT6-02L1_wp02 Drilling Summary Report 28 January, 2019 BT�aGanHES GEcom company �. ConocoPhillips BAT ConocoPhillips Drilling Summary Report 5,945,571.14 usft UGHES From: Map Easting: 317,134.52 usft a GE<ompany Company: ConocoPhillips Alaska Inc_WNS Slot Radius: Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope 151° 28'41.304 W TVD Reference: Plan MT6-02 ® 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad usft MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-021-1 Survey Calculation Method: Minimum Curvature Design: MT6-02L1_wp02 Database: EDT 14 Alaska Production Project Western North Slope, North Slope Alaska. United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site GMT1 Lookout Pad MT6-02L1 wp02 Site Position: Northing: 5,945,571.14 usft Latitude; 70° 15'23.251 N From: Map Easting: 317,134.52 usft Longitude: 151'28'40.782W Position Uncertainty: 0.00 Usti Slot Radius: 0.000 in Grid Convergence: -1.39 Well MT6-02 MT6-02L1 wp02 Audit Notes: Well Position +NI -S 0.00 usft Northing: 5.945,564.39 usft Latitude: 70° 15'23.180 N +E/ -W 0.00 usft Easting: 317,116.39 usft Longitude: 151° 28'41.304 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 37.20 usft Wellbore MT6-0211 Magnetic& Model Name Sample Date Declination Dip Angle Field Strength (1) V) (nT) BGGM2018 12/22/2018 16.25 80.68 57,384 Design MT6-02L1 wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 11,723.09 Vertical Section: Depth From (TVD) +NIS +EI -W Direction (usft) (usft) (usft) (1) 37.10 0.00 0.00 343.71 112 81201 9 10:32:36AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Drilling Summary Report BA. (CER IGHES BAT GEwmpany Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope TVD Reference: Plan MT6-02 ® 89.30usft (Doyonl9 Planned) Site: GMT1 Lookout Pad MD Reference: Plan MTS -02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 North Reference: True Wellbore: MT6-021-1 Survey Calculation Method: Minimum Curvature Design: MT6-02L1_wp02 Database: EDT 14 Alaska Production Survey Tool Program Date 1/28/2019 (usft) (') From To TIP Latitude (usft) (usft) Sumey (Wellbore) Tool Name Description 75.53 356.00 1. Gyrodata GyroSS 16" (MT6-02) GYD-CT-DMS Gyrodata cont.drillpipe m/s 393.46 2,027.272. BHGE MWD+IFR+MSA 16"(MT6-02) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 2,115.67 8,972.41 3. BHGE MWD ATK+IFR+MSA 121/4"(M MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,065.23 11,105.674. BHGE MWD+IFR+MSA 63/4"(MT6-02 MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 11,152.00 11,723.09 5. BHGE MWD+IFRMSA4 1/8" (MT6-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,723.09 22,920.38 MT6-02L1_wp02(MT6-021-1) MWD MWD -Standard 11,723.09 22,920.38 MT6-02L1 wp02(MT6-02L1) MWD+IFR.AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc (usft) (') 11,723.09 89.12 TIP Latitude 11,728.00 89.28 KOP (usft) 11,800.00 88.56 11,828.00 88.28 Start DLS 2.55 TFO.88.60 11,900.00 88.33 12,000.00 88.39 12,100.00 88.46 12,200.00 88.53 12,300.00 88.61 12,400.00 88.69 12,500.00 88.77 12,600.00 88.85 12,700.00 88.94 12,800.00 89.02 12,900.00 89.11 Azl (azimuth) TVD TVDSS DLeg V. Sec Northing Easting Latitude Longitude (I (usft) (usft) (1100usft) (usft) (usft) (usft) 345.92 7,932.24 7,842.94 0.00 6,648.04 5,952,780.26 318,382.04 70" 16'34.433 N 151'28' 9.560 W 345.94 7,932.31 7,843.01 3.28 6,652.95 5,952,785.05 318,380.96 70° 16'34.480 N 151° 28'9.595 W 345.94 7,933.67 7,844.37 1.00 6,724.88 5,952,855.28 318,365.18 70° 16' 35.166 N 151° 28' 10.104 W 345.94 7,934.44 7,845.14 1.00 6,752.85 5,952,882.59 318,359.04 70° 16'35.434 N 151° 28' 10.302 W 344.11 7,936.57 7,847.27 2.55 6,824.80 5,952,952.53 318,342.13 70° 16' 36.117 N 151° 2B' 10.843 W 341.56 7,939.44 7,850.14 2.55 6,924.74 5,953,048.71 318,314.96 70° 16'37.057 N 151° 28' 11.702 W 339.01 7,942.19 7,852.89 2.55 7,024.51 5,953,143.59 318,283.53 70° 16' 37.982 N 151° 28' 12.684 W 336.46 7,944.81 7,855.51 2.55 7,123.93 5,953,236.98 318,247.92 70" 16' 38.892 N 151"28' 13.786 W 333.91 7,947.30 7,858.00 2.55 7,222.78 5,953,328.70 318,208.19 70" 16' 39.784 N 151° 28' 15.008 W 331.37 7,949.66 7,860.36 2.55 7,320.89 5,953,418.57 318,164.42 70° 16' 40.657 N 151. 28' 16.345 W 328.82 7,951.89 7,862.59 2.55 7,418.05 5,953,506.40 318,116.69 70" 16' 41.510 N 151° 28' 17.796 W 326.27 7,953.97 7,864.67 2.55 7,514.07 5,953,592.03 318,065.11 70° 16'42.339 N 151° 28' 19.359 W 323.72 7,955.90 7,866.60 2.55 7,608.76 5,953,675.28 318,009.78 70" 16' 43.145 N 151"28' 21.028 W 321.18 7,957.68 7,868.38 2.55 7,701.93 5,953,756.00 317,950.79 70° 16' 43.924 N 151° 28'22.803 W 318.63 7,959.31 7,870.01 2.55 7,793.41 5,953,834.01 317,888.28 70° 16' 44.677 N 151° 28' 24.678 W 1/28/2019 10:32:36AM Page 3 COMPASS 5000.14 Build 850 ConocoPhillips Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-02 Wellbore: MT6-0211 Design: MT6-02L7_wp02 Planned Survey MD Inc (usft) (°) 13,000.00 89.20 13,100.00 89.30 13,200.00 89.39 13,300.00 89.48 13,400.00 89.58 13,500.00 89.68 13,600.00 89.78 13,700.00 89.87 13,800.00 89.97 13,828.00 90.00 Start DLS 2.05 TFO 57.50 13,900.00 90.84 13,941.83 91.33 13,948.89 91.33 Start 167.94 hold at 13948.89 MD 14,000.00 91.33 14,100.00 91.33 14,116.83 91.33 Start DLS 2.05 TFO 91.47 14,124.34 91.33 14,200.00 91.28 14,300.00 91.23 14,400.00 91.17 14,500.00 91.12 14,600.00 91.06 14,700.00 91.00 14,800.00 90.93 14,900.00 90.87 ConocoPhillips Drilling Summary Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: BA (ER F�UGHES a GEcomp., Well MT6-02 Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Tme Minimum Curvature EDT 14 Alaska Production Azl (azimuth) TVD TVDSS DLeg V. Sec Northing Fasting Latitude Longitude (°) (usft) (usft) (°1100usft) (usft) (usft) (usft) 5,954,452.72 317,061.51 316.08 7,960.78 7,871.48 2.55 7,883.00 5,953,909.18 317,822.36 70° 16' 45.400 N 151 ° 28'26,650 W 313.54 7,962.09 7,872.79 2.55 7,970.54 5,953,981.34 317,753.16 70° 16' 46.093 N 151° 28' 28.716 W 310.99 7,963.24 7,873.94 2.55 8,055.84 5,954,050.35 317,680.83 70° 16' 46.754 N 151° 28' 30.871 W 308.44 7,964.22 7,874.92 2.55 8,138.75 5,954,116.09 317,605.49 70" 16'47.383 N 151'28' 33.111 W 305.90 7,965.04 7,875.74 2.55 8,219.09 5,954,178.42 317,527.31 70° 16' 47.977 N 151° 28'35.431 W 303.35 7,965.68 7,876.38 2.55 8,296.71 5,954,237.21 317,446.44 70° 16'48.536 N 151° 28' 37.828 W 300.81 7,966.16 7,876.86 2.55 8,371.45 5,954,292.35 317,363.04 70° 16'49.058 N 151° 28' 40.295 W 298.26 7,966.46 7,877.16 2.55 8,443.16 5,954,343.73 317,277.26 70" 16'49.543 N 151.28' 42.829 W 295.71 7,966.60 7,877.30 2.55 8,511.72 5,954,391.25 317,189.29 70" 16'49.989 N 151° 28'45.424 W 295.00 7,966.61 7,877.31 2.55 8,530.32 5,954,403.85 317,164.29 70° 16' 50.107 N 151° 28' 46.161 W 293.79 7,966.08 7,876.78 2.05 8,577.26 5,954,435.17 317,099.47 70° 16' 50.399 N 151° 28'48.071 W 293.08 7,965.29 7,875.99 2.05 8,603.99 5,954,452.72 317,061.51 70° 16'50.563 N 151° 28' 49.189 W 293.08 7,965.13 7,875.83 0.00 8,608.47 5,954,455.64 317,055.09 70° 16' 50.590 N 151° 28' 49.378 W 293.08 7,963.94 7,874.64 0.00 8,640.88 5,954,476.81 317,008.58 70° 16' 50.787 N 151' 28' 50.747 W 293.08 7,961.63 7,872.33 0.00 8,704.30 5,954,518.22 316,917.60 70° 16'51.173 N 151° 28' 53.426 W 293.08 7,961.24 7,871.94 0.00 8,714.97 5,954,525.19 316,902.29 70° 16'51.237 N 151° 28'53.876 W 293.08 7,961.07 7,871.77 0.00 8,719.74 5,954,528.30 316,895.45 70° 16' 51.266 N 151° 28' 54.078 W 294.63 7,959.35 7,870.05 2.05 8,768.51 5,954,560.55 316,827.04 70" 16'51.567 N 151° 28'56.093 W 296.68 7,957.15 7,867.85 2.05 8,835.34 5,954,606.01 316,738.01 70° 16' 51.993 N 151° 28'58.717 W 298.73 7,955.05 7,865.75 2.05 8,904.78 5,954,654.62 316,650.66 70° 16'52.450 N 151° 29' 1.296 W 300.78 7,953.06 7,863.76 2.05 8,976.76 5,954,706.33 316,565.10 70° 16'52.938 N 151"29' 3.824 W 302.83 7,951.16 7,861.86 2.05 9,051.17 5,954,761.06 316,481.44 70° 16 53.456 N 151° 29' 6.299 W 304.88 7,949.37 7,860.07 2.05 9,127.92 5,954,818.75 316,399.79 70° 16' 54.003 N 151° 29' 8.717 W 306.93 7,947.69 7,858.39 2.05 9,206.92 5,954,879.32 316,320.26 70° 16' 54.580 N 151 ° 29' 11.076 W 308.98 7,946.11 7,856.81 2.05 9,288.06 5,954,942.71 316,242.94 70° 16'55.185 N 151- 29' 13.373 W 1/282019 10:32:36AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Drilling Summary Report BA ER FUGHES a GEcompany Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Local Co-ordinate Reference: Well MT6-02 Site: GMTMT6- Lookout Pad TVD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Well: MT6-0 2 MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) WellborNorth MT6-021-1 Reference: True Design: Design: MT6-02L1_ury02 Survey Calculation Method: Minimum Curvature (°)usft ( ) Database: PnT 1a elostra o.,.,r.,.11- Planned Survey MD (usft) Inc (°) Azi (azimuth) TVD TVDSS DLeg V. Sec Northing Fasting Latitude. Longitude (°)usft ( ) (usft) (°/100usft) (usft) (usft) (usft) 15,000.00 90.81 311.03 7,944.65 7,855.35 2.05 9,371.24 5,955,008.81 316,167.94 70' 16'55.817 N 151° 29' 15.604 W 15,100.00 90.74 313.07 7,943.30 7,854.00 2.05 9,456.35 5,955,077.56 316,095.35 70° 16' 56.475 N 151° 29' 17.767 W 15,200.00 90.67 315.12 7,942.07 7,852.77 2.05 9,543.28 5,955,146.86 316,025.26 70° 16' 57.159 N 151° 29' 19.859 W 15,300.00 90.61 317.17 7,940.95 7,851.65 2.05 9,631.93 5,955,222.62 315,957.76 70° 16'57.868 N 151'29' 21.877 W 15,400.00 90.54 319.22 7,939.95 7,850.65 2.05 9,722.17 5,955,298.75 315,892.95 70° 16' 58.601 N 151° 29' 23.819 W 15,500.00 90.47 321.27 7,939.07 7,849.77 2.05 9,813.90 5,955,377.15 315,830.89 70° 16'59.357 N 151° 29' 25.682 W 15,600.00 90.40 323.32 7,938.30 7,849.00 2.05 9,906.99 5,955,457.72 315,771.68 70° 17'0.135 N 151° 29' 27.464 W 15,700.00 90.33 325.37 7,937.66 7,848.36 2.05 10,001.33 5,955,540.35 315,715.39 70° 17'0.934 N 151° 29' 29.162 W 15,800.00 90.26 327.42 7,937.15 7,847.85 2.05 10,096.79 5,955,624.94 315,662.09 70" 17'1.753 N 151° 29' 30.775 W 15,900.00 90.19 329.47 7,936.75 7,847.45 2.05 10,193.26 5,955,711.39 315,611.84 70° 17' 2.591 N 151° 29'32.300 W 16,000.00 90.12 331.52 7,936.48 7,847.18 2.05 10,290,60 5,955,799.58 315,564.72 70° 17'3.447 N 151° 29' 33.735 W 16,100.00 90.05 333.56 7,936.33 7,847.03 2.05 10,388.70 5,955,889.39 315,520.78 70" 17' 4.319 N 151° 29' 35.079 W 16,170.09 90.00 335.00 7,936.30 7,847.00 2.05 10,457.85 5,955,953.26 315,491.91 70° 1T 4.940 N 151" 29' 35.966 W 16,170.85 90.00 335.00 7,936.30 7,847.00 0.00 10,458.60 5,955,953.95 315,491.60 70° 17'4.947 N 151' 29' 35,975 W Start DLS 0.22 TFO -59.09 16,200.00 90.03 334.94 7,936.29 7,846.99 0.23 10,487.41 5,955,980.65 315,479.91 70° 17'5.207 N 151" 29' 36.335 W 16,300.00 90.15 334.75 7,936.13 7,846.83 0.22 10,586.22 5,956,072.17 315,439.63 70° 17'6.097 N 151° 29' 37.573 W 16,400.00 90.26 334.56 7,935.77 7,846.47 0.22 10,684.97 5,956,163.56 315,399.04 70° 17'6.985 N 151° 29' 38.821 W 16,500.00 90.38 334.37 7,935.22 7,845.92 0.22 10,783.67 5,956,254.80 315,358.14 70° 17'7.873 N 151° 29' 40.077 W 16,600.00 90.49 334.18 7,934.46 7,845.16 0.22 10,882.32 5,956,345.91 315,316.95 70° 17' 8.759 N 151° 29' 41.342 W 16,700.00 90.60 333.99 7,933.51 7,844.21 0.22 10,980.91 5,956,436.89 315,275.45 70° 17'9.643 N 151° 29'42.616 W 16,800.00 90.72 333.81 7,932.35 7,843.05 0.22 11,079.44 5,956,527.72 315,233.66 70° 17' 10.526 N 151° 29' 43.898 W 16,900.00 90.83 333.62 7,931.00 7,841.70 0.22 11,177.92 5,956,618.41 315,191.56 70" 17' 11.408 N 151° 29' 45.189 W 17,000.00 90.95 333.43 7,929.45 7,840.15 0.22 11,276.33 5,956,708.96 315,149.17 70° 17' 12.288 N 151° 29' 46.489 W 17,100.00 91.06 333.24 7,927.70 7,838.40 0.22 11,374.68 5,956,799.37 315,106.48 70° 17' 13.166 N 151° 29'47.797 W 17,200.00 91.17 333.05 7,925.75 7,836.45 0.22 11,472.97 5,956,889.63 315,063.49 70° 17' 14.043 N 151° 29' 49.114 W 17,300.00 91.29 332.86 7,923.60 7,834.30 0.22 11,571.19 5,956,979.74 315,020.21 70° 17' 14.919 N 151" 29' 50.439 W 128/201910:32:36AM Page 5 COMPASS 5000.14 Build 85D ✓ ConocoPhillips ConocoPhillips SAT B A ER Drilling Summary Report F IGHES GE<om,, Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope Site: GMT11 Lookout Pad TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Wait: MT6-02 MD Reference: Plan MT6-02 (d) 89.30usft (Doyon19 Planned) North Reference: True Wellbore: MT6-021-1 Survey Calculation Method: Minimum Curvature Design: MT6-02L1_wp02 Database: EDT 14 Alaska Production Planned Survey MD Inc (usft) (°) Azi (azimuth) TVD TVDSS DLeg V. Sec Northing Easting Latitude Longitude (°) (usft) (usft) (°1100usft) (usft) (usft) (usft) 17,381.13 91.38 332.70 7,921.71 7,832.41 0.22 11,650.82 5,957,052.74 314,984.87 70' 17'15.628 N 151° 29' 51.521 W 17,400.00 91.38 332.70 7,921.26 7,831.96 0.00 11,669.34 5,957,069.71 314,976.63 70° 17' 15.793 N 151° 29' 51.773 W 17,407.49 91.38 332.70 7,921.08 7,831.78 0.00 11,676.69 5,957,076.44 314,973.36 70" 17' 15.859 N 151° 29' 51.873 W Start 244.57 hold at 17407.49 MD 17,500.00 91.38 332.70 7,918.85 7,829.55 0.00 11,767.48 5,957,159.63 314,932.95 70° 17'16.667 N 151° 29' 53.110 W 17,600.00 91.38 332.70 7,916.44 7,827.14 0.00 11,865.61 5,957,249.55 314,889.28 70° 17' 17.540 N 151° 29' 54.446 W 17,652.06 91.38 332.70 7,915.18 7,825.88 0.00 11,916.70 5,957,296.36 314,866.54 70` 17' 17.995 N 151"29' 55.142 W Start DLS 0.12 TFO 120.88 17,698.29 91.38 332.70 7,914.07 7,824.77 0.00 11,962.07 5,957,337.93 314,846.35 70° 17'18.399 N 151° 29'55.760 W 17,700.00 91.38 332.70 7,914.03 7,824.73 0.00 11,963.74 5,957,339.47 314,845.61 70° 17' 18.414 N 151° 29' 55.783 W 17,800.00 91.32 332.81 7,911.68 7,822.38 0.12 12,061.89 5,957,429.43 314,802.02 70° 17' 19.288 N 151° 29' 57.117 W 17,900.00 91.26 332.91 7,909.43 7,820.13 0.12 12,160.08 5,957,519.47 314,758.59 70° 1T 20.163 N 151" 29' 58.447 W 18,000.00 91.19 333.01 7,907.29 7,817.99 0.12 12,258.31 5,957,609.59 314,715.32 70° 17' 21.038 N 151° 29' 59.772 W 18,100.00 91.13 333.12 7,905.27 7,815.97 0.12 12,356.57 5,957,699.80 314,672.21 70° 17' 21.915 N 151° 30'1.093 W 18,200.00 91.07 333.22 7,903.35 7,814.05 0.12 12,454.87 5,957,790.08 314,629.27 70" 17'22.792 N 151° 30' 2.409 W 18,300.00 91.01 333.33 7,901.54 7,812.24 0.12 12,553.20 5,957,880.44 314,586.49 70° 17' 23.670 N 151" 30'3.720 W 18,400.00 90.94 333.43 7,899.83 7,810.53 0.12 12,651.56 5,957,970.88 314,543.87 70° 17' 24.549 N 151- 30'5.026 W 18,500.00 90.88 333.53 7,898.24 7,808.94 0.12 12,749.96 5,958,061.40 314,501.41 70° 17' 25.429 N 151° 30' 6.328 W 18,600.00 90.82 333.64 7,896.75 7,807.45 0.12 12,848.39 5,958,152.00 314,459.12 70° 17' 26.309 N 151° 30' 7.626 W 18,700.00 90.76 333.74 7,895.38 7,806.08 0.12 12,946.86 5,958,242.67 314,416.98 70' 17' 27.191 N 151` 30' 8.918 W 18,800.00 90.70 333.84 7,894.11 7,804.81 0.12 13,045.36 5,958,333.42 314,375.02 70° 17' 28.073 N 151° 30' 10.206 W 18,900.00 90.63 333.95 7,892.95 7,803.65 0.12 13,143.89 5,958,424.25 314,333.21 70° 17' 28.956 N 151° 30' 11.490 W 19,000.00 90.57 334.05 7,891.89 7,802.59 0.12 13,242.45 5,958,515.15 314,291.57 70° 17'29.839 N 151° 30' 12.768 W 19,100.00 90.51 334.15 7,890.95 7,801.65 0.12 13,341.04 5,958,606.13 314,250.09 70° 17' 30.724 N 151° 30' 14.042 W 19,200.00 90.45 334.26 7,890.11 7,800.81 0.12 13,439.67 5,958,697.19 314,208.78 70° 17'31.609 N 151° 30'15.311 W 19,300.00 90.39 334.36 7,889.39 7,800.09 0.12 13,538.32 5,958,788.32 314,167.63 70" 17'32.495 N 151" 30' 16.576 W 19,400.00 90.32 334.46 7,888.77 7,799.47 0.12 13,637.01 5,958,879.53 314,126.64 70° 17' 33.382 N 151° 30' 17.836 W 1/28/201910:32:36AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Drilling Summary Report BA <ER F�UGHES a GEcompa, Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Well MT6-02 Project: Western North Slope Site: GMT1 Lookout Pad TVD Reference: Plan MT6-02 @ 89.30us(t (Doyonl9 Planned) Well: MT6-02 MD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Wellbore: MT6-0211 North Reference: True Design: MT6-021-1_wp02 Survey Calculation Method: Minimum Curvature (`) (usR) Database: EDT 14 Alaska Prntlunfnn Planned Survey MD (usR) Inc M An (azimuth) TVD TVDSS DLeg V. Sec Northing Easing Latitude Longitude (`) (usR) (usR) (°1100us@) (usB) (ustt) Wall) 19,500.00 90.26 334.57 7,888.26 7,798.96 0.12 13,735.72 5,958,970.81 314,085.82 70° 17'34.270 N 151" 30' 19.091 W 19,600.00 90.20 334.67 7,887.86 7,798.56 0.12 13,834.47 5,959,062.16 314,045.16 70° 17' 35.158 N 151° 30' 20.341 W 19,700.00 90.14 334.77 7,887.56 7,798.26 0.12 13,933.24 5,959,153.59 314,004.67 70" 17'36.G47 N 151° 30' 21.587 W 19,800.00 90.07 334.88 7,887.38 7,798.08 0.12 14,032.04 5,959,245.09 313,964.34 70° 17'36.937 N 151° 30' 22.828 W 19,900.00 90.01 334.98 7,887.30 7,798.00 0.12 14,130.87 5,959,336.66 313,924.18 70" 17' 37.828 N 151° 30' 24.064 W 19,920.38 90.00 335.00 7,887.30 7,798.00 0.12 14,151.01 5,959,355.33 313,916.01 70° 17'38.009 N 151° 30' 24.316 W 19,921.12 90.00 335.00 7,887.30 7,798.00 0.00 14,151.74 5,959,356.01 313,915.72 70° 1T 38.016 N 151" 30' 24.325 W Start 5000.00 hold at 19921.12 MD 20,000.00 90.00 335.00 7,887.30 7,798.00 0.00 14,229.72 5,959,428.29 313,884.13 70" 17'38.719 N 151° 30' 25.297 W 20,100.00 90.00 335.00 7,887.30 7,798.00 0.00 14,328.57 5,959,519.91 313,844.08 70° 17'39.610 N 151° 30' 26.530 W 20,200.00 90.00 335.00 7,887.30 7,798.00 0.00 14,427.41 5,959,611.54 313,804.04 70° 17'40.501 N 151"30' 27.763 W 20,300.00 90.00 335.00 7,887.30 7,798.00 0.00 14,526.26 5,959,703.16 313,763.99 70" 17'41,392 N 151° 30' 28.997 W 20,400.00 90.00 335.00 7,887.30 7,798.00 0.00 14,625.11 5,959,794.78 313,723.94 70° 17'42.283 N 151° 30' 30.230 W 20,500.00 90.00 335.00 7,887.30 7,798.00 0.00 14,723.96 5,959,886.41 313,683.90 70" 17'43.174 N 151° 30' 31.463 W 20,600.00 90.00 335.00 7,887.30 7,798.00 0.00 14,822.81 5,959,978.03 313,643.85 70" 17'44,066 N 151° 30' 32.696 W 20,700.00 90.00 335.00 7,887.30 7,798.00 0.00 14,921.65 5,960,069.66 313,603.80 70" 17' 44.957 N 151° 30' 33.929 W 20,800.00 90.00 335.00 7,887.30 7,798.00 0.00 15,020.50 5,960,161.28 313,563.76 70° 17' 45.848 N 151° 30'35.162 W 20,900.00 90.00 335.00 7,887.30 7,798.00 0.00 15,119.35 5,960,252.91 313,523.71 70° 17' 46.739 N 151" 30'36.395 W 21,000.00 90.00 335.00 7,887.30 7,798.00 0.00 15,218.20 5,960,344.53 313,483.67 70° 17'47S30 N 151° 30' 37.629 W 21,100.00 90.00 335.00 7,887.30 7,798.00 0.00 15,317.05 5,960,436.16 313,443.62 70" 17'48.521 N 151° 30' 38.862 W 21,200.00 90.00 335.00 7,887.30 7,798.00 0.00 15,415.89 5,960,527.78 313,403.57 70° 17'49.412 N 151° 30'40.095 W 21,300.00 90.00 335.00 7,887.30 7,798.00 0.00 15,514.74 5,960,619.40 313,363.53 70° 17' 50.303 N 151" 30' 41.329 W 21,400.00 90.00 335.00 7,887.30 7,798.00 0.00 15,613.59 5,960,711.03 313,323.48 70° 17'51.195 N 151° 30' 42.562 W 21,500.00 90.00 335.00 7,887.30 7,798.00 0.00 15,712.44 5,960,802.65 313,283.43 70° 17' 52.086 N 151° 30' 43.795 W 21,600.00 90.00 335.00 7,887.30 7,798.00 0.00 15,811.28 5,960,894.28 313,243.39 70" 17'52.977 N 151° 30' 45.029 W 21,700.00 90.00 335.00 7,887.30 7,798.00 0.00 15,910.13 5,960,985.90 313,203.34 70` 17' 53.868 N 151° 30'46.262 W 21,800.00 90.00 335.00 7,887.30 7,798.00 0.00 16,008,98 5,961,077.53 313,163.29 70° 17'54.759 N 151" 30'47.496 W 12812019 f0:32:36AM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips Alaska lnc_WNS Project: Western North Slope Site: GMT1 Lookout Pad Well: MT6-02 Wellbore: MT6-0211 Design: MT6-0211_wp02 Planned Survey MD Inc (usft) (°) 21,900.00 22,000.00 22,100.00 22,200.00 22,300.00 22,400.00 22,500.00 22,600.00 22,700.00 22,800.00 22,900.00 22,920.38 Casing Points ConocoPhillips BAILER Drilling Summary Report IGHES BAT U company Local Co-ordinate Reference: Well MT6-D2 TVD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) North Reference: Title Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Measured Azl (azimuth) TVD TVDSS DLeg V. Sec Northing Easting Latitude Longitude (usft) (°) (usft) (usft) (°/100usft) (usft) (usft) (usft) 6.000 90.00 335.00 7,887.30 7,798.00 0.00 16,107.83 5,961,169.15 313,123.25 70" 17' 55.650 N 151° 30'48.729 W 90.00 335.00 7,887.30 7,798.00 0.00 16,206.68 5,961,260.78 313,083.20 70° 17'56.541 N 151° 30' 49.963 W 90.00 335.00 7,887.30 7,798.00 0.00 16,305.52 5,961,352.40 313,043.16 70° 17' 57.432 N 151'30' 51.196 W 90.00 335.00 7,887.30 7,798.00 0.00 16,404.37 5,961,444.03 313,003.11 70° 17'58.323 N 151° 30' 52.430 W 90.00 335.00 7,887.30 7,798.00 0.00 16,503.22 5,961,535.65 312,963.06 70° 17' 59.215 N 151° 30' 53.664 W 90.00 335.00 7,887.30 7,798.00 0.00 16,602.07 5,961,627.27 312,923.02 70" 18'0.106 N 151° 30' 54.897 W 90.00 335.00 7,887.30 7,798.00 0.00 16,700.92 5,961,718.90 312,882.97 70" 18'0.997 N 151 ° 30' 56.131 W 90.00 335.00 7,887.30 7,798.00 0.00 16,799.76 5,961,810.52 312,842.92 70° 18' 1.888 N 151° 30' 57.365 W 90.00 335.00 7,887.30 7,798.00 0.00 16,898.61 5,961,902.15 312,802.88 70° 18'2.779 N 151° 30' 58.599 W 90.00 335.00 7,887.30 7,798.00 0.00 16,997.46 5,961,993.77 312,762.83 70° 18' 3.670 N 151° 30' 59.832 W 90.00 335.00 7,887.30 7,798.00 0.00 17,096.31 5,962,085.40 312,722.79 70° 18'4.561 N 151° 31' 1.066 W 90.00 335.00 7,887.30 7,798.00 0.00 17,116.45 5,962,104.07 312,714.63 70° 18'4.743 N 151. 31' 1.318 W Measured Vertical Casing Hole Depth Depth (usft) (usft) Name Diameter (in) Diameter (in) 22,921.12 7,887.30 4-1/8"x 6" 4.125 6.000 1282019 10:32:36AM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips A ER ConocoPhillips B Drilling Summary Report BAT aGEcompany Company: ConocoPhillips Alaska Inc_WNS Depth Depth Project: Western North Slope Local Co-ordinate Reference: Well MT6-02 Site: GMT1 Lookout Pad TVD Reference: Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Well: MT6-02 MD Reference: Plan MT6-02 @ 89.30usft (Doyon19 Planned) Wellbore: MT6-0211 North Reference: True Design: MT6-021-1_wp02 Survey Calculation Method: Minimum Curvature 4,822.64 4,249.96 Database: EDT 14 Alaska Production Formations Albian 94 8,892.83 7,173.67 Measured Vertical Depth Depth Depth (usft) (usft) (usft) Name 3,715.92 3,417.30 K-3 8,365.12 6,799.73 Top Fill 11,350.79 7,922.95 Alpine C 4,453.12 3,984.35 Albian 97 9,374.87 7,467.63 LCU 4,822.64 4,249.96 Albian 96 7,279.35 6,017.25 Albian 94 8,892.83 7,173.67 HRZ Slump 2,192.05 2,121.00 C-30 2,607.60 2,483.05 C-10 5,633.24 4,833.53 Albian 95 7,855.51 6,432.54 Albian 93 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 11,723.09 7,932.24 11,728.00 7,932.31 11,828.00 7,934.44 13,828.00 7,966.61 13,948.89 7,965.13 14,116.83 7,961.24 16,170.85 7,936.30 17,407.49 7,921.08 17,652.06 7,915.18 19,921.12 7,887.30 22,921.12 -1,876.69 Checked By: Dip Dip Direction Lithology (') (`) Local Coordinates +N/ -S +FJ -W (usft) (usft) Comment 7,244.93 11090.13 TIP 7,249.69 1,088.94 KOP 7,346.67 1,064.65 Start DLS 2.55 TFC, -88.60 8,838.57 -166.75 Start DLS 2.05 TFO -57.50 8,887.70 -277.19 Start 167.94 hold at 13948.89 MD 8,953.51 -431.64 Start DLS 2.05 TFO 91.47 10,347.69 -1,876.69 Start DLS 0.22 TFO -59.09 11,457.33 -2,422.07 Start 244.57 hold at 17407.49 MD 11,674.61 -2,534.20 Start DLS 0.12 TFO 120.88 13,710.69 -3,534.82 Start 5000.00 hold at 19921.12 MD Planned TD at 22921.12 Approved By: Date: 112812019 10:32:36AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Alaska Inc WNS Western North Slope GMT1 Lookout Pad MT6-02 MT6-021-1 MT6-02L1_wp02 Anticollision Summary Report 28 January, 2019 BT�a GHES GEcomoanv ConocoPhillips BAKER ConocoPhillip5 Anticollision Summary Report BAT aGEmmpany Company: Conocc Phillips Alaska Inc WNS Project: Western North Slope Reference Site: GMT1 Lookout Pad Site Error: 0.00 usft Reference Well: MT6-02 Well Error: 0.00 usft Reference Wellbore MT6-021-1 Reference Design: MT6-02L1_wp02 Reference MT6-021-1 wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 100.00usft Error Model: Depth Range: Unlimited Scan Method: Results Limited by: Maximum center -center distance of 2,488.40 usft Error Surface: Levels Evaluated at: 2.79 Method: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyon19 Planned) Plan MT6-02 @ 89.30usft (Doyonl9 Planned) True Minimum Curvature 2.00 sigma OAKEOMPI Offset Datum ISCWSA Tmv. Cylinder North Combined Pedal Curve Added to Error Values Survey Tool Program Date 1/28/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 75.53 356.00 1. Gyrodata GyroSS 16" (MT6-02) GYD-CT-DMS Gyrodam contdrillpipe m/s 393.46 2,027.272. BHGE MWD+IFR+MSA 16"(MT6-02) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 2,115.67 8,972.41 3. BHGE MWD ATK+IFR+MSA 121/4"(MT MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,065.23 11,105.674. BHGE MWD+IFR+MSA 6 3/4" (MT6-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,152.00 11,723.095. BHGE MWD+IFRMSA41/8"(MT6-02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,723.09 22,921.12 MT6-021-1_wp02(MT6-021-1) MWD MWD- Standard 11,723.09 22,921.12 MT6-02L1_wp02(MT6-021.1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) GMT1 Lookout Pad Lookout 2 -Lookout 2- Lookout 2 16,020.91 7,900.00 1,751.88 1,516.07 7.429 CC, ES, SF MT6-01-MT6-01 -MT6-01_wp03 (Draft A) 37.20 36.90 19.92 18.69 16.265 CC MT6-01 - MT6-01 - MT6-01_wp03 (Draft A) 400.74 400.00 21.29 17.31 5.352 ES MT6.01 - MT6-01 - MT6-01_wp03 (Draft A) 601.29 600.00 23.43 18.90 5.172 SF MT6-02 - MT6-02 - MT6-02 J2 098 92 12,100.00 23.74 21.58 1 CC, ES MT6-02-MT6-02-MT6-02 13,284.60) 13,300.00 108.95 44.36 1.687 aution Monitor Closely, SF MT6-03 - MT6-03 - MT6-03 200.02 200.00 19.75 17.26 . 2 CC - MT6-03 - MT6-03 - MT6-03 299.81 300.00 20.12 16.82 6.084 ES MT6-03-M76-03-MT6-03 22,536.46 21,764.00 1,429.43 866.92 2.541 Noraml Operations, SF MT6-03 - MT6-03PH - MT6-03PH 200.02 200.00 19.75 17.26 7.942 CC' MT6-03 - MT6-03PH - MT6-03PH 299.81 300.00 20.12 16.82 6.084 ES MT6-03 - MT6-03PH - MT6-03PH 399.11 400.00 23.25 19.38 6.017 SF MT6-04 - MT6-04 - MT6-04 100.76 100.00 40.07 38.42 24.281 CC MT6-04 - MT6-04 - MT6-04 300.50 300.00 40.82 37.03 10.759 ES MT6-04 - MT6-04 - MT6-04 399.51 400.00 43.88 39.16 9.293 SF MTe-04 - MT6-04PB1 - MT6-04PB1 100.76 100.00 40.07 38.42 24.281 CC MT6-04 - MT6-04P81 - MT6-04PB7 300.50 300.00 40.82 37.03 10.759 ES MT6-04 - MT6-04P81 - MT6-04PB1 399.51 400.00 43.88 39.16 9.293 SF MT6-05 - MT6-05 - MT6-05 200.99 200.00 59.96 57.11 21.002 CC MT6-05 - MT6-05 - MT6-05 300.47 300.00 60.44 56.61 15.786 ES MT6-05 - MT6-05 - MT6-05 399.10 400.00 63.49 59.23 14.901 SF MT6-05 - MT6-0511 - MT6-0511 200.99 200.00 59.96 57.11 21.002 CC MT6-05 - MT6-0511 - MT6-0511 300.47 300.00 60.44 56.61 15.786 ES MT6-05 - MT6-051-1 - MT6-051-1 399.10 400.00 63.49 59.23 14.901 SF MT6-05-MT6-05PB1-MT6-05PB7 200.99 200.00 59.96 57.11 21.002 CC MT6-05-MT6-05P81-MT6-05PB1 300.47 300.00 60.44 56.61 15.786 ES MT6-05 - MT6-05PB1 - MT6-05PB1 399.10 400.00 63.49 59.23 14.901 SF MT6-05 - MT6-05PB2 - MT6-05PB2 200.99 200.00 59.96 57.11 21.002 CC MT6-05 - MT6-05PB2 - MT6-05PB2 300.47 300.00 60.44 56.61 15.786 ES MT6-05-MT6-05PB2-MT6-05PB2 399.10 400.00 63.49 59.23 14.901 SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11282019 10:04:22AM Page 2 COMPASS 5000.14 Build 65D ConocoPhillips BAT ConocoPhillips Anticollision Summary Report IGHES a GEcompany Company: ConocoPhillips Alaska lnc WNS Project: Western North Slope Reference Site: GMT1 Lookout Pad Site Error: 0.00 usft Reference Well: MT6-02 Well Error: 0.00 usft Reference Wellbore MT6-021.1 Reference Design: MT6-021.1 wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Plan MT6-02 @ 89.30usft (Doyonl9 Planned) True Minimum Curvature 2.00 sigma OAKEDMPI Offset Datum Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) GMT7 Lookout Pad MT6-06-MT6-06-MT6-06 200.67 200.00 79.48 76.77 29.336 CC MT6-06-MT6-06-MT6-06 299.99 300.00 79.63 75.85 21.038 ES MT6-06-MT6-06-MT6-06 693.02 700.00 105.64 99.09 16.144 SF MT6-06 - MT6-06PB7 - MT6-06 Pat 200.67 200.00 79.48 76.77 29.336 CC MT6-06 - MT6-06PB1 - MT6-06 Pat 299.99 300.00 79.63 75.85 21.038 ES MT6-06-MT6-06PB1-MT6-06 Pal 693.02 700.00 105.64 99.09 16.144 SF MT6-06-MT6-06PB2-MT6-06PB2 200.67 200.00 79.48 76.77 29.336 CC MT6-06-MT6-O6PB2-MT6-06PB2 299.99 300.00 79.63 75.85 21.038 ES MT6-06-MT6-06PB2-MT6-06PB2 693.02 700.00 105.64 99.09 16.144 SF MT6-07 - MT6-07 - MT6-07_wp07 300.13 300.00 98.87 95.58 30.078 CC, ES MT6-07-MT6-07-MT6-07 wp07 398.11 400.00 101.38 97.47 25.906 SF MT6-08 - MT6-08 Lower Let- MT6-08 300.22 300.00 115.91 112.56 34.654 CC MT6-00-MT6-08 Lower Let -MT6-08 397.86 400.00 116.00 112.11 29.822 ES MT6-08-MT6-08 Lower Let -MT6-08 495.35 500.00 119.36 115.35 29.773 SF MT6-08 - MT6-08PBI Lower Let- MT6-08PB1 300.22 300.00 115.91 112.56 34.654 CC MT6-08-MT6-08PB7 Lower Let - MT6-08PB1 397.86 400.00 116.00 112.11 29.822 ES MT6-08-MT6-08PB1 Lower Let - MT6-08PBl 495.35 500.00 119.36 115.35 29.773 SF MT6-09 - MT6-09 - MT6-09 201.26 200.00 139.38 136.56 49.343 CC MT6-09 - MT6-09 - MT6-09 300.07 300.00 139.42 135.52 35.728 ES MT6-09 - MT6-09 - MT6-09 784.54 800.00 194.82 187.40 26.243 SF WNS (Various) Lookout 2 -Lookout 2- Lookout 2 16,020.91 7,900.00 1,751.88 1,516.07 7.429 CC,ES,SF CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1/28@019 10:04r22AM Page 3 COMPASS 5000.14 Build 65D ConocoPhillips BA, KER ConocoPhillips Anticollision Summary Report �j IGHES BAT GEcompaW Company: ConowPhillips Alaska lnc WNS Project: Western North Slope Reference Site: GMT1 Lookout Pad Site Error: 0.00 usft Reference Well: MT6-02 Well Error: 0.00 usft Reference Wellbore MT6-021-7 Reference Design: MT6-021-1_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well MTB -02 Plan MT6-02 @ 89.30usft (Doyonl9 Planned) Plan MT6.02 @ 89.30usft (Doyon19 Planned) True Minimum Curvature 2.00 sigma OAKEOMPI Offset Datum Reference Depths are relative to Plan MT6-02 @ 89.30usf1(Doyon19 P Coordinates are relative to: MT6-02 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 Central Meridian is 150' 0' 0.000 W Grid Convergence at Surface is: -1.39° CC -Min centre to center distance or covergent point, SP - min separation factor, ES -min ellipse separati Ladder Plot- lot24001800a I I I I I I I 2400-- I I I I I I I 1 I I I 1 I I I I I I I I I I I I I I I I I I I I I 1 I I I I 1 I I I I I I 1 I I I I I I 1 I 1 I I 1 1 I I I I I I _J I I I I I I _J I I I I I I I I I I I I 1 I I I 1 I I I 1 I I I I 1 I I I 1 I I I 1 I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I 1 I I I I I I I I 1800— .0 N m d N Cn N d 1200 U 0 m U 600 Q 0 4000 8000 12000 16000 20000 24000 Measured Depth LEGEND CC -Min centre to center distance or covergent point, SP - min separation factor, ES -min ellipse separati I I I I I I I I I I I I I I I I I I I I I I 1 I I I 1 I I I I I I I I I I I I I I I I I I I I I 1 I I I I 1 I I I I I I 1 I I I I I I 1 I 1 I I 1 1 I I I I I I _J I I I I I I _J I I I I I I I I I I I I 1 I I I 1 I I I 1 I I I I 1 I I I 1 I I I 1 I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I 1 I I I I I I I I on 1/28/2019 10:04:22AM Page 4 COMPASS 5000.14 Build 850 �. ConocoPhillips BAER ConocoPhillips Anticollision Summary Report UGHES aGEcompany Company: ConocoPhillips Alaska Inc_WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Reference Site: GMT1 Lookout Pad MD Reference: Site Error: 0.00 usft North Reference: Reference Well: MT6-02 Survey Calculation Method: Well Error: 0.00 usft Output errors are at Reference Wellbore MT6-021-1 Database: Reference Design: MT6-02L1_wp02 Offset TVD Reference: Well MT6-02 Plan MT6-02 @ 89.30usft (Doyon19 Planned) Plan MT6-02 @ 89.30usft (Doyontg Planned) True Minimum Curvature 2.00 sigma OAKEDMPI Offset Datum Reference Depths are relative to Plan MT6-02 @ 89.30usft (Doyon19 P Coordinates are relative to: MT6-02 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4 Central Meridian is 150° 0'0.000 W Grid Convergence at Surface is: -1.39" CC - Min centre to center distance or covergent point, SP - min separation factor, ES - min ellipse separation 1/2WO19 10:04:22AM Page 5 COMPASS 5000.14 Build 85D Separation Factor Plot 9.00— I I I I I I 1 1 1 I 1 I I I I I I I I I I 1 I 1 1 1 1 1 1 1 I I 1 I I 1 I p ---------- I I I I 1 1 I I I I 1 I I I 1 1 I I I I 1 1 1 I LL I I I Q I I 1 I I I I I I _____ ____I____ _________ __I____ ___I__________I d 3J30 -- I 1 I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I Caution MonibrOosey I I 1 I STOPDnlling 1 1 I I i 1 I 0. 1 I I I I I 1 I I I I 0 4000 8" 12000 16000 20000 Measured Depth LEGEND CC - Min centre to center distance or covergent point, SP - min separation factor, ES - min ellipse separation 1/2WO19 10:04:22AM Page 5 COMPASS 5000.14 Build 85D From: Beat, Andrew T To: Boyer, David L (DOA) Cc: Loeoo, Victoria T (DOA); Davies. Steohen F (DOA) Subject: Re: [EXTERNAL]RE: MT6-0213 PTD Submission Date: Friday, January 25, 2019 2:28:46 PM Dave, You are correct on both. Hard copies will come in Monday morning and no H2S at GMT 1. Thanks, 0131770 From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Friday, January 25, 2019 2:13 PM To: Beat, Andrew T Cc: Loepp, Victoria T (DOA); Davies, Stephen F (DOA) Subject: [EXTERNAL]RE: MT6-0211 PTD Submission Hi Andrew, I am working on the electronic copy of the PTD for MT -6-021-1. We assume that ConocoPhillips will submit an official hard copy with proper signatures next week? Also, when I checked last summer, no H2S had been encountered in Mooses Tooth wells to date. Is this still the case? Thank you, Dave Boyer AOGCC From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 25, 2019 10:14 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>; Boyer, David L (DOA) <david.boyer2@alaska.gov>; Mcphee, Megan S (DOA) <megan.mcphee@alaska.gov> Subject: MT6-021-1 PTD Submission Importance: High Victoria, As discussed yesterday, we would like to add a lateral to the current well. Please see attached and let me know if any additional information is needed. Please note, the directional plan shows a TD of 24,920' MD but this is incorrect. We will only permit to "22,920' MD. Our well planning software is down right now for updates so a corrected well plan will be submitted Monday. I'm including this one now so you have an idea of the path for review purposes. We expect to be ready for sidetracking operations late Monday night so approval by close of business on Monday should work. I will keep you posted if that accelerates. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria loeppPalaska gov> Sent: Wednesday, January 23, 2019 2:57 PM To: Beat, Andrew T <Andrew T Beat@conocoohillips.com> Cc: Rixse, Melvin G (DOA) <melvin rixsy alaska.gov>; Boyer, David L (DOA) <david bover2Palaska gov>; Mcphee, Megan S (DOA) <megan m ohee(@alaska gov> Subject: [EXTERNAL]RE: MT6-02 (PTD 218-160) REVISION- Redrill open hole lateral Andrew, Please prepare a revised PTD for this well using the same PTD number. The submission should include revisions from the original PTD in red font. Include the new directional plan, traveling cylinder, new 10-401 form, descriptive cover letter, new schematic, anything else that has changed. Since you have actual completion data, complete the present well condition portion of the 10-401 form. Be sure and mark in red in the upper right hand corner of both copies, "REVISED". Let me know if you have questions. Submit as soon as possible for approval. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria LoeooCcilalaska.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 law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Vic.toria.i-oeoo@alaska.gov From: Beat, Andrew T <Andrew T Beat anconoco hillips com> Sent: Wednesday, January 23, 2019 2:01 PM To: Loepp, Victoria T (DOA) <victoria.loeooPalaska eov> Cc: Rixse, Melvin G (DOA) <melvin.rixse @alaska.gov> Subject: MT6-02 (218-160) Well Path Change Importance: High Victoria, We are close to TD and have not found sand that meets the objectives we had for the well. We would like to perform an open hole sidetrack and re -drill the lateral to the west. The new well path will be more than 500' from the permitted well path. Can you please let me know what information you need for this approval? I'm guessing a new PTD (10-401) as well as the new directional plan but what additional info would you like? We likely have another 24-48 hours of operations before we would be prepared to sidetrack so we have 'time' to put something together. Give me a call if that's easiest. Thanks, Andrew (303)378-8881 Loepp, Victoria T (DOA) From: Boyer, David L (DOA) Sent: Friday, January 25, 2019 10:52 AM To: Loepp, Victoria T (DOA) Subject: FW: MT6-021-1 PTD Submission Attachments: MT6-0211 Cover Letter AOGCC.pdf; MT6-0211 10-401.pdf; MT6-02L1 Completion Schematic_01.25.19.pdf; MT6-02L1_wp01 DSR - NAD27.pdf; MT6-021-1_wp01 TCR -G-100 - NAD27.pdf; MT6-02L1_wp01 Canvas - NAD27.txt Importance: High Follow Up Flag: Follow up Flag Status: Flagged Victoria, I will try to advance this as far as possible w/o the hard copy on the geo side. Megan lives in Wasilla so did not make it in to log any PTD's into the system. For this well, we only have electronic docs. Dave From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, January 25, 2019 10:14 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>; Boyer, Megan S (DOA) <megan.mcphee@alaska.gov> Subject: MT6-021-1 PTD Submission Importance: High Victoria, David L (DOA) <david.boyer2@alaska.gov>; Mcphee, As discussed yesterday, we would like to add a lateral to the current well. Please see attached and let me know if any additional information is needed. Please note, the directional plan shows a TO of 24,920' MD but this is incorrect. We will only permit to 22,920' MD. Our well planning software is down right now for updates so a corrected well plan will be submitted Monday. I'm including this one now so you have an idea of the path for review purposes. We expect to be ready for sidetracking operations late Monday night so approval by close of business on Monday should work. I will keep you posted if that accelerates. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, January 23, 2019 2:57 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips com> Cc: Rixse, Melvin G (DOA) <melvin.rixse0Dalaska.gov>; Boyer, David L (DOA) <dayid.boyer2CZDalaska.go >; Mcphee, Megan S (DOA) <megan.mcphee@alaska.aov> Subject: [EXTERNALjRE: MT6-02 (PTD 218-160) REVISION- Redrill open hole lateral Andrew, Please prepare a revised PTD for this well using the same PTD number. The submission should include revisions from the original PTD in red font. Include the new directional plan, traveling cylinder, new 10-401 form, descriptive cover letter, new schematic, anything else that has changed. Since you have actual completion data, complete the present well condition portion of the 10-401 form. Be sure and mark in red in the upper right hand corner of both copies, "REVISED". Let me know if you have questions. Submit as soon as possible for approval. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria LOeoD(&alaska.QOV CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loepp@alasko.Qoy From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Wednesday, January 23, 2019 2:01 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.f;ov> Subject: MT6-02 (218-160) Well Path Change Importance: High Victoria, We are close to TD and have not found sand that meets the objectives we had for the well. We would like to perform an open hole sidetrack and re -drill the lateral to the west. The new well path will be more than 500' from the permitted well path. Can you please let me know what information you need for this approval? I'm guessing a new PTD (10-401) as well as the new directional plan but what additional info would you like? We likely have another 24-48 hours of operations before we would be prepared to sidetrack so we have 'time' to put something together. Give me a call if that's easiest. Thanks, Andrew (303)378-8881 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, January 25, 2019 5:21 PM To: Rixse, Melvin G (DOA) Subject: Re: MT6-021_1 PTD Submission Thx Sent from my iPhone On Jan 25, 2019, at 4:46 PM, Rixse, Melvin G (DOA) <melvin.rixsePalaska.gov> wrote: Victoria, Dave Boyer told me to tell you that he placed his part of the paper work on your desk this afternoon. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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. I: 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 Mel Rixse at (907-793-1231) or (Melvin.Rixse(@alaska.govI. From: Beat, Andrew T <Andrew.T.Beat0conocophillios.com> Sent: Friday, January 25, 2019 10:14 AM To: Loepp, Victoria T (DOA) <victoria.loeooC&alaska.gov> Cc: Rixse, Melvin G (DOA) <melvin.rixse(@alaska.gov>; Boyer, David L (DOA) <david.bover2@alaska.aov>; Mcphee, Megan S (DOA) <megan.mcoheePalaska.eov> Subject: MT6-021_1 PTD Submission Importance: High Victoria, As discussed yesterday, we would like to add a lateral to the current well. Please see attached and let me know if any additional information is needed. Please note, the directional plan shows a TO of 24,920' MD but this is incorrect. We will only permit to 22,920' MD. Our well planning software is down right now for updates so a corrected well plan will be submitted Monday. I'm including this one now so you have an idea of the path for review purposes. We expect to be ready for sidetracking operations late Monday night so approval by close of business on Monday should work. I will keep you posted if that accelerates. Thanks, Andrew (303)378-8881 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Sent: Wednesday, January 23, 2019 2:57 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.izov>; Boyer, David L (DOA) <david.bover20i)alaska.gov>; Mcphee, Megan S (DOA) <megan.mcphee@alaska.aov> Subject: [EXTERNAL)RE: MT6-02 (PTD 218-160) REVISION- Redrill open hole lateral Andrew, Please prepare a revised PTD for this well using the same PTD number. The submission should include revisions from the original PTD in red font. Include the new directional plan, traveling cylinder, new 10- 401 form, descriptive cover letter, new schematic, anything else that has changed. Since you have actual completion data, complete the present well condition portion of the 10-401 form. Be sure and mark in red in the upper right hand corner of both copies, "REVISED". Let me know if you have questions. Submit as soon as possible for approval. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a)alaska.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 law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793- 1247 907)7931247 or Victoria Loepo®alaska.aov From: Beat, Andrew T <And rew.T. Beat conocophillips.com> Sent: Wednesday, January 23, 2019 2:01 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.tov> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.aov> Subject: MT6-02 (218-160) Well Path Change Importance: High Victoria, We are close to TD and have not found sand that meets the objectives we had for the well. We would like to perform an open hole sidetrack and re -drill the lateral to the west. The new well path will be more than 500' from the permitted well path. Can you please let me know what information you need for this approval? I'm guessing a new PTD (10-401) as well as the new directional plan but what additional info would you like? We likely have another 24-48 hours of operations before we would be prepared to sidetrack so we have 'time' to put something together. Give me a call if that's easiest. Thanks, Andrew (303) 378-8881 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, January 24, 2019 4:53 PM To: Boyer, David L (DOA) Subject: Re: MT6-02 (PTD 218-160) REVISION- Redrill open hole lateral Hi David, It will come tomorrow but they changed plans, it will be a new lateral. We have until Monday to get approval. So some relief. Thanx, Victoria Sent from my iPhone On Jan 24, 2019, at 4:45 PM, Boyer, David L (DOA) <david. bover2@a laska.gov> wrote: Hi Victoria, I got caught up today (after fighting computer spam attack this AM!) in anticipation of this PTD on a short fuse. Hopefully, it will arrive tomorrow. Dave B. From: Loepp, Victoria T (DOA) Sent: Wednesday, January 23, 2019 2:57 PM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>; Boyer, David L (DOA) <david.bover2@alaska.gov>; Mcphee, Megan S (DOA) <megan.mcphee@alaska.aov> Subject: RE: MT6-02 (PTD 218-160) REVISION- Redrill open hole lateral Andrew, Please prepare a revised PTD for this well using the same PTD number. The submission should include revisions from the original PTD in red font. Include the new directional plan, traveling cylinder, new 10- 401 form, descriptive cover letter, new schematic, anything else that has changed. Since you have actual completion data, complete the present well condition portion of the 10-401 form. Be sure and mark in red in the upper right hand corner of both copies, "REVISED". Let me know if you have questions. Submit as soon as possible for approval. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a).alaska.go CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793- 1247 or Victoria Loepo@alaska.aov From: Beat, Andrew T <Andrew.T.Beat@conocophiIIips.corn Sent: Wednesday, January 23, 2019 2:01 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: MT6-02 (218-160) Well Path Change Importance: High Victoria, We are close to TD and have not found sand that meets the objectives we had for the well. We would like to perform an open hole sidetrack and re -drill the lateral to the west. The new well path will be more than 500' from the permitted well path. Can you please let me know what information you need for this approval? I'm guessing a new PTD (10-401) as well as the new directional plan but what additional info would you like? We likely have another 24-48 hours of operations before we would be prepared to sidetrack so we have 'time' to put something together. Give me a call if that's easiest. Thanks, Andrew (303)378-8881 TRANSMITTAL LETTER CHECKLIST WELL NAME: 0—F6-- Q a 1 PTD: -a 1!9 — o o . Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: G i" t 7 W POOL: 400 k© + Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing well Permit JMULTI LATERAL No. *aI g—(60 API No. 50-103-aO,L Z -_go_- co. (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 ermit). The permit is approved subject to full compliance with 20 TO 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 v/ (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements ) / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, ✓ composite curves for well logs run must be submitted to the AOGCC within 90 davs after com let. sus ension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool GRTR MOOSES TOOTH, LOOKOUT OIL - 2821 PTD#:2190090 Company CONO_COLEHILLIPS ALASKA INC Initial Class/Type SER / Well Name: Mme( OSES TOOTH 6-021-1 Program SE3—. _ _ _ Well bore seg ❑� PEND GeoArea 890 Unit 10750 On/Off Shore On Annular Disposal ❑ Administration '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 ....... MI5 Well located proper distance from drilling unit. boundary Yes.. 6 _ Well located proper distance from other wells. _ _ _ _ ..... _ _ _ _ Yes 7 Sufficient acreage available in. drilling unit.. _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 8 If deviated, is wellbore plat included _ _ _ _ _ .. ... _ _ No _ _ Wellbore sketch is enclosed.. 9 Operator only affected party. _ _ _ _ - - - - - _ _ .. ... YeS ...... ... - - - _ _ ... 10 Operator has. appropriate bond in force _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . 11 Permit can be issued without conservation order _ _ _ _ _ _ _ _ _ Yes Appr Date 12 Permit can be issued without administrative approval _ _ _ Yes _ 13 Can permit be approved before 15-day wait _ _ _ _ Yes . DLB 1/2512019 14 Well located within area and strata authorized by Injection Order # (put. 10# in.comments) .(For Yes _ AIO 40 & CO 747 15 All wells within 1/4 mile area of review identified (For service well only) _ _ _ Yes _ 16 Pre-produced injector: duration of pre-production less than 3 months (For service well only) - Yes 17 Nonconven. gas conforms to AS31,05,030(J.1.A),Q.2.A-Dj _ _ _ _ _ _ _ _ _ NA. . 18 Conductor string_ provided _ _ _ _ .................... ...... . . NA _ _ _ _ Conductor set forMT6-02_ _ Engineering 19 Surface casing protects all known USDWs _ . . ........... . .. . . . . . NA....... _ Surface casing set in MT6-02 20 CMT. vol adequateto circulate on conductor & surf csg . . . . . . . . . . .............. NA Surface casing set and fully cemented 21 CMT. vol adequate to tie-in long string to surf rag______ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA 22 CMT. will cover all known productive horizons. . . . .......... . ... . ..... . . No Productive interval will be completed with uncemented pert pup liner 23 Casing designs adequate for C, T, B &_permafrost_ _ . . ................. Yes 24 Adequate tankage. or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ . Yes Rig has steel tanks; all waste. to approved disposal wells_ _ 25 If a_re-drill, has_a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ 26 Adequate wellbore separation proposed _ _ _ _ .. _ _ .... ........ . . . Yes Anti-collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations _ _ _ _ _ .... NA Appr Date 28 Drilling fluid_ program schematic & equip list adequate.... _ _ _ _ _ _ Yes .... Max formation pressure is 3810 paig(9.4 ppg EMW ); will drill w/ 9.4-11.0 ppg. EMW VTL 1/28/2019 29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes ... _ ... ... ... _ _ _ 30 BOPE_press rating appropriate; test to (put psig in comments) .. _ .. _ Yes _ _ MPSP is 3015 psig; BOP test to 3500 psig _ ... 31 Choke. manifold complies w/API. RP-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ - - Yes 32 Work will occur without operation shutdown. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 33 Is presence of H2S gas probable .. . .. .. ...... ..... . ..... . _ _ No 34 .Mechanical condition of wells within AOR verified (For service well only) . _ _ _ _ _ _ _ _ _ _ Yes !.. No wells in 114 mile radius 35 Permit can be issued w(o hydrogen_ sulfide measures . . ........... _ Yes Only MT6-03 has been flowed back to date but no 1-12S was encountered in that well. Geology 36 Data. presented on potential overpressure zones.. _ _ _ _ _ _ .. Yes ... ... _ Appr Date 37 Seismic analysis of shallow gas. zones..... .. _ _ _ _ _ _ _ _ .N.A.. DLB 1/25/2019 38 Seabed condition survey (if off-shore)...... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ 39 Contact name/phone for weekly. progress reports [exploratory only] ............... . . NA Geologic Date: EngineeringmmiDate Public Date Commissioner: Cossion r: Commissioner `/ 31,/7
