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Home My WebLink About222-076From:Heusser, Heather A (DNR) To:Guhl, Meredith D (OGC) Cc:Morgan, Kirk A (DNR) Subject:RE: Alkaid 2PH and Alkaid 2, Extended confidentiality? Date:Thursday, November 7, 2024 2:22:59 PM Hi Meredith, We have not received an extended confidentiality request for Alkaid 2PH (50-223-20037-00-00, PTD 222-076) or Alkaid 2 (50-223-20037-01-00, PTD 222-077). Thank you, Heather Ann Heusser Natural Resource Specialist IV State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage AK 99501-3560 heather.heusser@alaska.gov From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Thursday, November 7, 2024 9:48 AM To: Heusser, Heather A (DNR) <heather.heusser@alaska.gov> Cc: Morgan, Kirk A (DNR) <kirk.morgan@alaska.gov> Subject: Alkaid 2PH and Alkaid 2, Extended confidentiality? Hello Heather, Has Great Bear Pantheon requested extended confidentiality for Alkaid 2PH (50-223-20037- 00-00, PTD 222-076) and Alkaid 2 (50-223-20037-01-00, PTD 222-077) which were due for release after November 5, 2024? Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. Date: 12/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #13: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 MUD LOGS – HAL 4. END OF WELL REPORT SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/MUD LOGS_HAL/END OF WELL REPORT Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: By Meredith Guhl at 1:08 pm, Dec 09, 2022 222-076 T37365 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.09 13:09:01 -09'00' Date: 11/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #1: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 LWD LOGS – SLB 1. END OF WELL LETTER SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/LWD_SLB/EOW LETTER Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: By Meredith Guhl at 1:03 pm, Dec 09, 2022 222-076 T37364 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.09 13:07:37 -09'00' Date: 11/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #2: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 LWD LOGS – SLB 2. SURVEY DATA SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/LWD_SLB/SURVEY DATA Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37364 Date: 11/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #3: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 LWD LOGS – SLB 3. DRILLING MECHANICS DEPTH SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/LWD_SLB/DRILLING MECHANICS DEPTH Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37364 Date: 11/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #4: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 LWD LOGS – SLB 4. DRILLING MECHANICS TIME SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/LWD_SLB/DRILLING MECHANICS TIME Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37364 Date: 11/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #5: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 LWD LOGS – SLB 5. a. LWD RECORDED MODE SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/LWD_SLB/LWD RECORDED MODE/ECOSCOPE Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37364 Date: 11/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #6: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 LWD LOGS – SLB 5. b. LWD RECORDED MODE SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/LWD_SLB/LWD RECORDED MODE/MICROSCOPE Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37364 Date: 11/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #7: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 LWD LOGS – SLB 5. d. LWD RECORDED MODE SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/LWD_SLB/LWD RECORDED MODE/QUADCOMBO Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37364 Date: 11/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #8: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 LWD LOGS – SLB 5. c. LWD RECORDED MODE SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/LWD_SLB/LWD RECORDED MODE/SONICSCOPE675 Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37364 Date: 11/9/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #9: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 LWD LOGS – SLB 5. e. LWD RECORDED MODE SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/LWD_SLB/LWD RECORDED MODE/RM Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37364 Date: 11/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #10: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 MUD LOGS – HAL 1. DRILLING EVALUATION LOG SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/MUD LOGS_HAL/DRILLING EVALUATION LOG Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37365 Date: 11/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #11: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 MUD LOGS – HAL 2. FORMATION EVALUATION LOG SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/MUD LOGS_HAL/FORMATION EVALUATION LOG Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37365 Date: 11/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #12: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 MUD LOGS – HAL 3. GAS RATIO LOG SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/MUD LOGS_HAL/GAS RATIO LOG Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37365 Date: 11/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II Atten: Kayla Junke 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL #13: CONFIDENTIAL Well: Alkaid 2 PH PTD: 222-076 API: 50-223-20037-00-00 MUD LOGS – HAL 4. END OF WELL REPORT SHAREFILE – DATA FOLDER: ALKAID 2/ALKAID 2 PH/LOG(s)/MUD LOGS_HAL/END OF WELL REPORT Please include current contact information if there is a difference from above. Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: T37365 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 180' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 20" L80 105' 9-5/8" L80 3,375.00' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Exploration Oil-Bbl: Water-Bbl: 5,045' FSL, 128' FEL, S7 T7N, R14E UM Mud Logs; LWD Logs: MicroScope, QuadCombo, SonicScope, EcoScope Water-Bbl: PRODUCTION TEST Date of Test: Oil-Bbl: Flow Tubing Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 108# 40# 105' SIZE DEPTH SET (MD) PACKER SET (MD/TVD) CASING WT. PER FT.GRADE 7/25/2022 CEMENTING RECORD 5,844,984.08 959' SETTING DEPTH TVD 8,844,730.89 TOP HOLE SIZE AMOUNT PULLED 661,288.20 660,888.82 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, 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 only if necessary. 50-223-20037-00-00 Alkaid 2 PH ADL 391706 1,042.9’ FSL, 3,493.1’ FEL, S5 T7N R14E UM LONS 22-002 7/6/2022 8,950' MD/ 8,584' TVD 7,287' MD 212' 3705 Arctic Blvd., Ste 2324, Anchorage, AK 99503 662,778.31 5,846,047.62 11.5' FSL, 271.1 FWL, T7N R14E UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Great Bear Pantheon, LLC WAG Gas 8/4/2022 222-076; 322-449 BOTTOM 12.25"0 702 sks 25' 3,383.000 25' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD to production or injection? YesNo25. 26. Was hydraulic fracturing used during completion?YesNo SIZE DEPTH SET (MD)PACKER SET (MD/TVDst each interval open (MD/TVD of Top and Bottom; Perforation Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD Status:OilSPLUG OtherAbandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory WINJ WDSPLNo. of Completions: ____________________Service Stratigraphic Test tor Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: ss: 7. Date Spudded: 15. API Number: tion of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: roductive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 180' BF: pth: 10. Plug Back Depth MD/TVD: 18. Property Designation: tion of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: x- y Zone- 4 x- y- Zone- 4 12.SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD: pth: x-y- Zone- 4 onal or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore:21. Re-drill/Lateral Top Window MD/TVD it electronic information per 20 AAC 25.050 (ft MSL) Obtained: BOTTOM L80 105' L80 3,375.00' Exploration gs; LWD Logs: MicroScope, QuadCombo, SonicScope, EcoScope # WT. PER FT.GRADE 7/25/2022 CEMENTING RECORD 959' SETTING DEPTH TVD 8 8 30 89 TOP HOLE SIZE AMOUN PULLED 660 888 82 TOP SETTING DEPTH MD on, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mu taneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casin ator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. 50-223-20037-00-00 Alkaid 2 PH ADL 391706 1,042.9’ FSL, 3,493.1’ FEL, S5 T7N R14E UM LONS 22-002 7/6/2022 8,950' MD/ 8,584' TVD 7,287' MD tic Blvd., Ste 2324, Anchorage, AK 99503 y-y- 11.5' FSL, 271.1 FWL, T7N R14E UM ar Pantheon, LLC 8/4/2022 222-076; 322-449 BOTTOM 702 sks3,375.00'12.25" 5 , 5 CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 4:08 pm, Nov 09, 2022 xJSB Abandoned 8/4/2022 JSB RBDMS JSB 113022 GVTL 11/12/2024 CDW 11/12/2024 SFD 11/2/2023 DSR-12/8/22 AOGCC &RQYHQWLRQDO&RUHV <HV1R 6LGHZDOO&RUHV 0' 79' a C /RZHU6DJDYDQLUNWRN /RZHU6DJDYDQLUNWRN )RUPDWLRQ6WDLQHV7RQJXH 7RS8JQX 7:HVW6DN 7RS6FKUDGHU%OXII &DQQLQJ)RUPDWLRQ 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ore Data 8,435' MD/8,099' TVD; 8,444' MD/8,112' TVD; 8,486' MD/8,144' TVD; 8,503' MD/8,160' TVD; 8,515' MD/8,173' TVD [will supply photographs, analytic results, ect as they are provided] 29 MD TVD 7,338' 6,854' 7,457' 6,697' 7,460' 6,970' 8,367' 7,831' 8,950' 8,384'Middle Schrader Bluff/Canning (TD) GEOLOGIC MARKERS NAME MFS / Dkr D/ Mid Schrader Bluff Middle Schrader Bluff/Canning (TPI) T. SMD / K-10 Alkaid 22 Confidential Alkaid 2 PH Type of Log Depth Start Stop Format LWD Logs End of Well Letter pdf FinalDefinitiveSurvey Alkaid_2_PH ASP Final Survey - NAD27Z4 pdf Alkaid_2_PH ASP Final Survey - NAD27Z4 excel PrintSurvey Alkaid_2_PH_SurveyList excel Print Survey List pdf DrillingMechanicsDepth Alkaid_2_PH_PH_Drilling_Mechanics_300- 8950ft_RMRT 300' - 8,950' 8/17/2022 LAS Alkaid_2_PH_Drilling_Mechanics_300- 8950ft_2in_MD_RMRT 300' - 8,950' 7/7/2022 7/25/2022 pdf DrillingMechanicsTime Alkaid_2_PH_DrillingMechanic_Run01_Time_RMRT 7/7/2022 LAS Alkaid_2_PH_DrillingMechanic_Run02_Time_RMRT 7/19/2022 LAS Alkaid_2_PH_DrillingMechanic_Run03_Time_RMRT 7/22/2022 LAS Alkaid_2_PH_DrillingMechanic_Run01_Time_RMRT 300' - 3,383' 7/7/2022 7/10/2022 pdf Alkaid_2_PH_DrillingMechanic_Run02_Time_RMRT 3,383' - 5,203' 7/19/2022 7/22/2022 pdf Alkaid_2_PH_DrillingMechanic_Run03_Time_RMRT 5,203' - 8,950' 7/22/2022 7/25/2022 pdf LWDRecordedMode Alkaid_2_PH_MicroScope_Processed_Images_3340_ 8893_ft_MD 3,340' - 8,893' DLIS Alkaid_2_PH_QuadCombo_300-8950ft_RM 300' - 8,950' DLIS Alkaid_2_PH_QuadCombo_300-8950ft_RM_Custom 300' - 8,950' DLIS Alkaid_2_PH_R2R3_8.5in_SonicScope675_DRILL_D TCO_3271-8837ft_Processed 3,271' - 8,837' DLIS Alkaid_2_PH_R2R3_8.5in_SonicScope675_DRILL_Q P_3271-8837ft_Processed 3,271' - 8,837' DLIS Alkaid_2_PH_R2R3_8.5in_SonicScope675_DRILL_S onFrac_3275-8837ft_Processed 3,275' - 8,837' DLIS Alkaid_2_PH_Run01_Drill_RM DLIS Alkaid_2_PH_Run02_Drill_RM DLIS Alkaid_2_PH_Run03_Drill_RM DLIS Alk2PH_R2R3_8.5in_SonicScope675_SonFrac_3275- 8837ft_Proc 3,275' - 8,837' 7/22/2022 LAS Alkaid_2_PH_MicroScope_3340_8893_MD_Dips 3,340' - 8,893' 7/22/2022 LAS Alkaid_2_PH_QuadCombo_300-8950ft_RM 300' - 8,950' 8/17/2022 LAS Alkaid2PH_R2R3_8.5in_SonicScope675_DTCO_3271- 8837ft_Processed 3,271' - 8,837' 7/22/2022 LAS Alkaid2PH_R2R3_8.5in_SonicScope675_QP_3271- 8837ft_Processed 3,271' - 8,837' 7/22/2022 LAS Logs Obtained Alkaid_2_PH_EcoScope_300-8950ft_2in_MD_RM 300' - 8,950' 7/7/2022 7/25/2022 pdf Alkaid_2_PH_EcoScope_300-8950ft_2in_TVD_RM 300' - 8,950' 7/7/2022 7/25/2022 pdf Alkaid_2_PH_EcoScope_300-8950ft_5in_MD_RM 300' - 8,950' 7/7/2022 7/25/2022 pdf Alkaid_2_PH_EcoScope_300-8950ft_5in_TVD_RM 300' - 8,950' 7/7/2022 7/25/2022 pdf Alkaid_2_PH_MicroScope_Images_3340_8893_ft_MD _Summary 3,340' - 8,893' 8/4/2022 pdf Alkaid_2_PH_MicroScope_Images_interpretation_1_2 0_3340_8893_ft_MD 3,340' - 8,893' 7/20/2022 pdf Alkaid_2_PH_MicroScope_Images_interpretation_1_2 40_3340_8893_ft_MD 3,340' - 8,893' 7/20/2022 pdf Alkaid_2_PH_MicroScope_Processed_Images_1_20_ 3340_8893_ft_MD 3,340' - 8,893' 7/20/2022 pdf Alkaid_2_PH_MicroScope_Processed_Images_1_240 _3340_8893_ft_MD 3,340' - 8,893' 7/20/2022 pdf Alkaid_2_PH_QuadCombo_300-8950ft_2in_MD_RM 300' - 8,950' 7/7/2022 7/25/2022 pdf Alkaid_2_PH_QuadCombo_300-8950ft_2in_TVD_RM 300' - 8,950' 7/7/2022 7/25/2022 pdf Alkaid_2_PH_QuadCombo_300-8950ft_5in_MD_RM 300' - 8,950' 7/7/2022 7/25/2022 pdf Alkaid_2_PH_QuadCombo_300-8950ft_5in_TVD_RM 300' - 8,950' 7/7/2022 7/25/2022 pdf Alkaid_2_PH_R2R3_8.5in_SonicScope675_QP_3271- 8837ft_Processed 3,271' - 8,837' 7/22/2022 pdf Alkaid_2_PH_R2R3_8.5in_SonicScope675_SDTCO_ 3271-8837ft_Processed 3,271' - 8,837' 7/22/2022 pdf Alkaid_2_PH_R2R3_8.5in_SonicScope675_SonFrac_ 3275-8837ft_Processed 3,275' - 8,837' 7/22/2022 pdf Alkaid_2_PH_Sonfrac_Images_Integrated_Plot_5inch _3340-8893_ft_MD_Processed 3,340' - 8,893' 7/22/2022 pdf Alkaid_2_PH_Spectroscopy_RM_3350-8950ft 3,350' - 8,950' 7/7/2022 7/25/2022 pdf Wireline-Electric Logs NONE CementBondLog NONE Mud Logs Alkaid 2 PH_LAS_Prelim 0' - 8,952' 7/25/2022 las Alkaid 2 PH_FEL_2MD_100_8950 100' - 8,950' 8/23/2022 pdf Alkaid #2 Pilot Hole Wellbore schematic Surface Hole Surface Casing Weight Grade Connection 12 1/4" 9 5/8"40 lb/ft L-80 BTC TOC Depth Surface Bit ID WŝůŽƚ,ŽůĞͲdΛϴϵϱϬΖD ϯϯϴϯΖdD͖ϯϯϳϱΖds 8.5 Pilot Hole, 8.5" Gr e a t B e a r P A N T H E O N A l k a i d # 2 As - S t a k e d W e l l C o n d u c t o r L o c a t i o n Pe r m i t t o D r i l l IS S U E DA T E : RE V I S I O N : DA T E : 05 J u l y 2 0 2 2 Re v . 1 05 J u l y 2 0 2 2 DR A W N B Y : SH E E T : Sh a n e S t r a g i e r 1 o f 1 PO I N T N A M E ST A T E P L A N E CO O R D I N A T E S LA T I T T U D E ( D D ) LO N G I T U D E ( D D ) We l l C e n t e r Su r f a c e X = 6 6 2 , 7 7 8 . 3 0 7 Y = 5 , 8 4 6 , 0 4 7 . 6 2 0 LA T : 6 9 . 9 8 5 8 6 4 6 3 LO N : - 1 4 8 . 7 0 1 4 4 3 4 9 Bo t t o m H o l e (B H L ) X = 6 6 0 , 7 9 9 . 7 8 0 Y = 5 , 8 4 4 , 6 4 0 . 3 0 0 LA T : 6 9 . 9 8 2 1 3 4 7 8 LO N : - 1 4 8 . 7 1 7 4 5 8 2 0 AL K A I D # 2 P H NA D 2 7 A L A S K A S T A T E P L A N E Z O N E 4 SE C T I O N S 5 & 7 , T 7 N , R 1 4 E & UM I A T M E R I D I A N NA D 2 7 Al a s k a S t a t e P l a n e Z o n e 4 S T A T E O F ALA S K A 49 TH Pi e r r e M . S t r a g i e r NO . L S - 9 8 1 2 07 / 0 5 / 2 0 2 2 65 0 W 5 8 t h A v e n u e S u i t e E A n c h o r a g e , A l a s k a 9 9 5 1 8 Te l : 1 - 9 0 7 - 4 6 0 - 1 6 8 6 Depth Lithology Markers / Horizon MD TVDSS Prognosis 0 - 200' Surficial sands and gravels T. Sagavanirktok ~270' 69` 250'-510' V coarse sands and pebbles Base apparent Ice saturation 980' 779' 510'-1,525' Interbedded sands and clays Lower Sagavanirktok 2,760' 2,503' 1,525'-3,000' Interbedded sands and clays Middle Sagavanirktok Formation Franklin Bluffs Member (Eocene-Oligocene)2,940' 2,630' 3,000'-3,383' Interbedded lignite, clays, minor thin sands T-5 Coal 3,300' 3,021' 3,383'-4,500' Interbedded sands, clays, coal Mikkelsen Tongue Canning Formation 3,374' 3,089' 4,500'-4,700'Interbedded sands, clays, numerous coal beds Lower Sagavanirktok Formation Staines Tongue 3,545' 3,253' 4,700'-5,200'Thinly bedded sands and clays, with thin coalbeds Top Ugnu 4,727' 4,377' 5,200'-5,838'Thick sands and interbedded claystones T. West Sak 5,838' 5,430' 5,838'-6,114'Thicker Claystones and siltstone/sandstones Top Schrader Bluff 6,114' 5,692' 6,114'-7,338'Siltstones and Claystones Canning Formation 7,030' 6,563' 7,338'-7,460'Claystones and Siltstone/sandstone KOP 7250 6771 7,460'-8,367'Claystones and Siltstone/sandstone MFS / Dkr D/ Mid Schrader Bluff 7,338' 6,854' 8,367'-8,540'Predominantly siltstone/sandstone Middle Schrader Bluff/Canning (TPI)7,457' 6,697' 8,540'-8,950'Siltstones and Claystones T. SMD / K-10 7,460' 6,970' Alkaid 8,367' 7,831' Middle Schrader Bluff/Canning (TD)8,950' 8,384' TD Lateral Hole 14,300' 7,855' Tops in 2 PH section MFS / Dkr D/ Mid Schrader Bluff 7338 6854 T. SMD / K-10 7460 6970 Alkaid 8367 7831 Base Alkaid 8540 7995 TD of Pilot hole 8950 8384 ID# STK SPM 0 MODELPUMP RPM OUTER: JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid#2 JOB:Pilothole RKB: DOL: RIGSUPERV: Naborsdrilling CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: RigMoveIn TIMEBREAKDOWN MOBILIZATIONCONT:CLEANINGMUDTANKS,CLEANTROUGHS,CLEANOUTPARTSHOUSE,REPLACEFOOT VALVEONHOPPERSUCTION#4.MOBILIZATIONFINISHCLEANINGMUDTANKS,FUNCTIONTESTMIX PUMPS,HOOKUPDRESSERSLEEVESINMUD TANKINNERCONNECT,STRAIGHENUPTOPSOFMUDTANKS,GENERALHOUSEKEEPING SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms RigUp&TearDown DAILYRECEIVED(gal) DAILYUSED(gal) RigUp&TearDown MOBILIZATION:INSTALLTOPDRIVELINKS&BAILS,REMOVEBLOCKSF/SHIPPINGPINSͲPREP.SHAKERSͲ FUNCTION TESTMIXPUMPSͲCONT.T/SERVICEVALVESINPITSREBUILDINGASNEEDEDͲCLEANPITSMOBILIZATION CONT.WORKINPTISͲTUBOSCOPEMPITOPDRIVEQUILL,BAILSADDLESͲCONT.T/PRESSUREWASH RIGͲMISC.TROUBLESHOOTDEGASSERBLOWERTESTEDGOOD.VERIFYPOWERT/CENTRIFUGE&CORRECT ROTATION. REPACEDLINERWASHMOTORRECONNECTED&TESTEDGOOD.INSTALLNEWJUNCTIONBOXINCELLAR W/NEWH2S SENSOR.REPLACEDNEWH2SSENSORONRIGFLOOR&PITS.CONTW/RIGWELDINGREPAIRS FROM TO RigMoveIn HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 4 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Mobrig105fromNaborsDeadHorseyard commissionandprepformocetolocation GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST: BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: OTHER: AVDPEFF%GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PUMPS ECD BITHHP RP: 2 WELL/JOBINFORMATION RPTDATE:6/21/2022 RPTNUM.:1 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid#2 JOB:Pilothole RKB: DOL: RIGSUPERV: Naborsdrilling CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: RigMoveIn TIMEBREAKDOWN ContinueNabors105Emobilization.Installingconductorandcellar,REPLACEHOLEFILLPUMPͲCONT.VALVE REPLACEMENTINPITSͲTROUBLESHOOT&FUNC.TEST CENTRIFUGEͲCONT.T/PRESSUREWASHSUB.ͲWASHINGTONCRANEINSP.STARTUP&RUN:TOPDRIVE,DRAW WORKS,ST80,ROTARYTABLE,COBRAHEADS,HOLEFILL PUMP,CENTRIFUGE,SHAKERS#1&#2,MIX.MOVECHOKELINE&KILLLINEINTOPLACE,M/U&TORQUE,INSTALL 21/6"X31/16"10K DSATOCHOKE&KILLLINE.INSTALLSAFETYCLAMPSONCHOKET/KILLLINE&ATTACHSAFETYCABLES,INSTALL NEW3"VALVEONENDOFMUDPITS,GENERALHOUSEKEEPINGAROUNDRIG SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms RigUp&TearDown DAILYRECEIVED(gal) DAILYUSED(gal) RigUp&TearDown Naborsrig105mobilization:UPPERIBOPONTOPDRIVEͲCONT.T/SERVICEVALVESINPITSREBUILDINGAS NEEDEDͲPRESSUREWASH,CLEAN&ORGANIZERIG.REPAIRCOMMUNICATIONCABLEF/TOPDRIVE.TROUBLE SHOOT 120VOLTRECEPTACLESINMUDPITS.RESETAIRCOMPRESSOR,REMOVEELECTRICROUGHNECKHEATERF/ MOTORMANSROOM.TRANSPORTEQUIPF/TUBOSCOPET/FRONTIERPADPAINTBOTHSETSOFBAILS. MOBILIZATIONFUNCTIONTESTST80&ROTARYTABLEͲCONT.T/SERVICEVALVESINPITSREBUILDINGAS NEEDEDͲASSISTCATMECHANICCOMPLETEGEN#1#2#4REPAIRMAINTENANCEPRESSUREWASH,CLEAN& ORGANIZERIG,PERFORMDROPSINSPECTIONW/CENERGY. FROM TO RigMoveIn HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 5 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Commissioningrig105E.comingalong,gettingclosetoready90%.complete,cellarisinconductorisin Performloadtestongensetsandpumps,complete#3generatorrepair,startriggingdown,prepformovetolocation,craneforrigdownscheduledforFriday GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST: BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:6/22/2022 RPTNUM.:2 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid#2 JOB:Pilothole RKB: DOL: RIGSUPERV: Naborsdrilling $32,742 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: $32,742 TIMEBREAKDOWN Continuerig105EcommissioningperNaborsprocedure.TROUBLESHOOTMUDPUMPS/CENTRIFIGULS, RECIEVE200BBLSWATER,FLUIDPACKMUD.LINESANDCHOKEMANIFOLD,PESSURETESTMUDLINES, CHOKELINE,KILLLINE,ADNCHOKEMANIFOLD/REPAIRLEAKSONCHOKEMANIFOLD,STANDPIPE,AND HAMMERUPGOOSENECKINDERRICKX2.ATTEMPTTOTESTSTILLLEAKINGF/GOOSENECKINDERRICK, BREAKLOOSEKELLYHOSEANDCHANGEOUTSEAL,CHANGEOUTLOWERMANUALONTDͲLEAKINGOUT OFSTEM,TROUBLESHOOTTDͲNOTBREAKINGOUTOFLOWERMANUAL,ATTEMPTTOTESTͲGOOSENECK LEAKINGINDERRICKANDONTD SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms DAILYRECEIVED(gal) DAILYUSED(gal) Beginrig105EcommissioningperNaborsprocedure.Rigonmoveratepercontract.WELDINGWORKON PIPESHEDLANDINGS,ROOFSUPPORTS,&LADDERSͲCONT.WORKONVALVESINPITS,DERRICK INSPECTION/SERVICESHEAVESͲCONT.TOPRESSUREWASHRIGͲTROUBLESHOOTPIPESKATECONTROLS. MANLIFTTRAININGͲCONT.TOPRESSUREWASHRIGͲCONT.WELDINGWORKONPIPESHEDLANDINGS, ROOFSUPPORTS,&LADDERSͲREPAIRSTEAMSYSTEMPLUMBINGͲRUNREMOTECHOKECONTROLLINES FROM TO HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 6 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: FunctioningtestandcommissioningNaborsrig105EinNaborsyard. CompletefunctiontestsandperformloadtestsperNaborscommissioningprocedure.Plantobeginsettingoutrigloadstomorrow.ifpadreadywillhaulNaborsshoptolocationtoday. GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$32,742 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:6/23/2022 RPTNUM.:3 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: COMPONENT OD ID LENGTH# OPERATIONSCODE NPT TIME FV WL GELS(10s/10m/30m) MUD OILMf MANUFACTURER CAKEPH PfMW OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP WELL/JOBINFORMATION RPTDATE:6/24/2022 RPTNUM.:4 RIG:Rig105E DAILYDRILLINGREPORT BITHHP RP: 1 GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 GPSGPMLINER 6.000 AVDC GAUGE: 98 OTHER: LENGTH: 06:00 18:00 12.0 CONSUMABLES 12.0 PHASE 18:00 06:00 HRS.ONJARS: DAILYONHAND(gal) DULL: LOC: PSI AVDPEFF% ROPWOB TOTALHRS 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST: BOP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: RiggingdownandpreploadsfortransporttoAlkaid2location. Continuetorigdownrig,setoutloadsfortransport 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 7 EMAIL: INTYPE DRILLBITS LENGTHODCOMPONENT BHA DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 FROM TO RigMoveIn HRS CONSUMABLE DAILYRECEIVED(gal) DAILYUSED(gal) RigUp&TearDown COMPLETINGNABORSRIGCOMMISIONINGCHECKLIST.TAKEDOWNKELLYHOSE&TIGHTENFACTORY FITTINGS&RUͲPTMUDLINES&CHOKE(BODY)5000PSI5MIN.(CHARTED)ͲLOADTESTGENERATORS, MUDPUMPS,TOPDRIVEͲCONT.TOCLEAN&ORGANIZERIGͲPREPSHOPANDPIPESHEDFORRIGMOVE, LOADTESTGENERATORS,MUDPUMPS,TOPDRIVEͲCOMPLETERIGCOMMISIONINGCHECKLISTͲCONT.TO CLEAN&ORGANIZERIG,RIGDNRDCHOKE,KILLLINES,CHOKEMANIFOLD6WAYBLOCK&SPOOLͲCONT. TOCLEAN&ORGANIZERIGͲPREP.CHOKEHOUSE&P.IPESHEDFORRIGMOVE. RigUp&TearDown www.wellez.comWellEzOnDemandver_102920ms P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTIONCOORDINATES TORQUE: BHAWT.AIR: INCLINATION BHAWT.MUD: ROT.WT.: SURVEYDATA MD N/S TIMEBREAKDOWN RIGGINGDOWN,PREPFORRIGMOVETOLOCATION,RIGDOWNTIOGAS,CHOKEMANIFOLD,GASBUSTER, PULLSTABBINGBOARDOUTOFPIPESHED,PREPPIPESHEDFORR/D,POWERDOWNMUDTANK EQUIPMENTANDLO/TO.CONT.TOCLEAN&ORGANIZERIG. RigMoveIn $65,484 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: $65,484 GRADE WELLNAME:Alkaid#2 JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: 2 JETS TFASERNO. REͲRUN GardnerDenver PUMP RPM OUTER: MAKE MODEL PUMPS ECDSPM 0 98 # STK ID ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid#2 JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $144,376 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: $144,376 RigMoveIn TIMEBREAKDOWN MOBILIZATIONCONT,T/PREPRIGFORMOVE,REMOVECHOKE&KILLLINESF/CELLAR,PULLBOPCARTF/ CELLAR,REMOVEUPPER&LOWERKELLYHOSE&STANDPIPEFROMRIGDERRICK/RIGFLOOR,RAISE GOOSENECK&PININPLACE,LOWERHYDSERVICELOOP,INSTALLTOPDRIVETRAVELINGPINS,UNPIN BLOCKSF/TOPDRIVE,MT/CLEANPITSANDWATERTANK,R/D,LOADOUTTRAILERS,R/DPITS INTERCONNECT SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms RigUp&TearDown DAILYRECEIVED(gal) DAILYUSED(gal) RigUp&TearDown RIGDOWN&MOBILIZATION;PIPESHED,CATWALK,VACTRUCKSUCKINGOUTMUDTANKS,PREP MECH/ELECTSHOP,BUILDHOSESTOLAYOVERBEAVERSLIDE.PULLROOFPANELOFFCATWALKSKID,LAY OVERBEAVERSLIDE,PULLCHOKEMANIFOLDSKIDAND LAYOVER,STAGEPIPESHEDSANDCATWALKFORTRANSPORT,REMOVEALLLOOSEEQUIPMENTFROM PIPESHEDS. MobilizeCruzcranetolocationforrigdown. FROM TO RigMoveIn HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 8 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Riggingdownandcraningoutloadsfortransport, ContinuetorigdownandsetrigapartandtransportrigcomponentstoAlkaid2 GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$36,150 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:6/25/2022 RPTNUM.:5 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid#2 JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $178,371 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: $178,371 TIMEBREAKDOWN Scopedownandremove1stsectionofmast,removederrickboard,scopedownsecondmastsection,rest cranecrew(only1daycranecrew).Riggingdownanddisconnectingmudlinesinpit Unabletotakeloadstolocation,dirtworkandlevelingpad. SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms DAILYRECEIVED(gal) DAILYUSED(gal) Riggingdownrig105formovetoAlkaid2.;RiggingdownmoveshopandstageatCruzyard,Generalrig down,remove4sectionsofrigshopandstagefortransport,disconnectserviceloop,removepipehandler andtopdrivefromfloor,laydownwindwallsandremoveasnecessary. FROM TO HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 9 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$39,587 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:6/26/2022 RPTNUM.:6 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid#2 JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $217,958 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: $217,958 RigMoveIn TIMEBREAKDOWN DEMOBILIZATIONPJSMW/CRUZET/REMOVEAͲLEGANDDERRICKBASE,PERFORMRIGMOVECHECKLIST, UNPLUGVFDROLLUPELECTRICALLINES,CONT.PREPPINGRIGF/CRANEREMOVAL SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms RigUp&TearDown DAILYRECEIVED(gal) DAILYUSED(gal) RigUp&TearDown RIGDOWNPJSMW/CRUZ,CONTINUERIGGINGDOWNDERRICKͲFLYOUTBOARDSECTION,BRIDLEUP ANDSCOPEDOWNCROWNSECTION,FLYOUTCROWNSECTION,SECURELINESTOCROWNCLUSTERFOR REMOVAL,UNSTINGBLOCKSANDCROWN,FLYOUTCROWNSECTION,SETOUTSHAKERWALKAROUND, PULLPARTSHOUSEANDCENTRIFUGE,LOADOUTDERRICK,MATTINGBOARDS,STARTUNPLUGGINGBACK YARD,POWERDOWNRIG FROM TO RigMoveIn HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 10 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Riggingdownpullingandsecuringwiresandcontrolcables,preptosetrigapartandprepfortransport Scatterrigcomponents,pickupmattingboardsandlaypitlineronAlkaid2,beginmovingrigtodrillsite. GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$39,587 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:6/27/2022 RPTNUM.:7 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: COMPONENT OD ID LENGTH# OPERATIONSCODE NPT TIME FV WL GELS(10s/10m/30m) MUD OILMf MANUFACTURER CAKEPH PfMW OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP WELL/JOBINFORMATION RPTDATE:6/28/2022 RPTNUM.:8 RIG:Rig105E DAILYDRILLINGREPORT BITHHP RP: 1 GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 GPSGPMLINER 6.000 AVDC GAUGE: 98 OTHER: LENGTH: 06:00 18:00 12.0 CONSUMABLES 12.0 PHASE 18:00 06:00 HRS.ONJARS: DAILYONHAND(gal) DULL: LOC: PSI AVDPEFF% ROPWOB TOTALHRS 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$35,958 BOP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: transportrig105EsubstructuretoAlkaid2location Setsubandbeginsettinginrigcomponentsandriggingthemup. 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 11 EMAIL: INTYPE DRILLBITS LENGTHODCOMPONENT BHA DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 FROM TO RigMoveIn HRS CONSUMABLE DAILYRECEIVED(gal) DAILYUSED(gal) RigUp&TearDown RIGDOWNSTARTCRUZOPERATIONS@07:00AMFINISHSECURINGLOAD&PREPINGRIGF/TRANSPORT, FLYOUTDOGHOUSES,DRILLLINESKID,AIRCOMPRESSORSKID,ANDSTAIRS//PULLMOTORSHEDS,PUMP SKIDS,MUDMANIFOLD,PITS,WATERTANKSͲSTARTHAULINGLOADSTONEWLOCATION,WAITONCRUZ CRANEF/15:00LOADSUBBASEONTRAILERF/TRANSPORT//GENERALMAINTENANCE&HOUSEKEEPING NEWLOCATIONͲSTACKDIVERTERTEESONWELL,LAYOUTHERCULITE,SETSUBMATS ExecutionRigUp&TearDown www.wellez.comWellEzOnDemandver_102920ms P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTIONCOORDINATES TORQUE: BHAWT.AIR: INCLINATION BHAWT.MUD: ROT.WT.: SURVEYDATA MD N/S TIMEBREAKDOWN WAITINGONCRUZEFORSUBTRANSPORT,SETMATTS&HURCULITE,PRESSUREWASHRIG,PREP HANDLINGEQUIPF/PAINT RigMoveIn $253,916 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: $253,916 GRADE WELLNAME:Alkaid#2 JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: 2 JETS TFASERNO. REͲRUN GardnerDenver PUMP RPM OUTER: MAKE MODEL PUMPS ECDSPM 0 98 # STK ID ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid#2 JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $289,866 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: $289,866 TIMEBREAKDOWN RIGUPPJSMW/CRUZTRUCKING,OFFLOADSUBBASEFROMTRAILER,SETSUBANDCENTEROVERHOLE, RIGUPCONTINUESETTINGINRIG,INSTALLSUBOUTRIGGERS,SETͲFIRSTMUDTANK,DRILLLINESKID, WATERTANK/CONFERENCEROOM,HOOKUPTURNBUCKELS,CONTINUECHANGINGOUTBUTTERFLY VALVESONPITS,CONTINUEPRESSUREWASHINGRIGANDPERFORMINGGENERALMAINTENANCE MOBILIZATIONPJSMW/CRUZESETRIGSKIDS,FIRSTAIRCOMPROOM,PMP#1,WALKWAY,PMP#2, HOOKUP4"ELECTRICALT/DRAWWORKS,AIRCOMP,BOTHMUDPUMPS,STARTHOOKINGUPHARD LINESINPUMPROOMMUDLINES,SETBREEZEWAY,VFDHOUSE,2NDMUDTANKSKID,GEN#1/MOTOR ROOMSKID,RELEASECRANE23:30.HOOKUPELECTRICALT/DRAWWORKS,AIRCOMP,BOTHMUD PUMPS,STARTHOOKINGUPHARDLINESINPUMPROOM SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms DAILYRECEIVED(gal) DAILYUSED(gal) RIGUPWHILEWAITINGONSUBBASE,CLEANRIGMATS,STRINGLINEFORSUBBASE,INSTALL4"VALVESON CONDUCTOR,FIXLEAKINACCESSHATCHONMP#2,STARTCHANGINGBUTTERFLYVALVESONMUDTANKS, GENERALHOUSEKEEPINGANDMAINTENANCE, FROM TO HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 12 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Riggingup,prepforcontinuedaylightonlyequipmentoperations. Completesettinginrigcomponentsandriggingthemup,installmaststartinglegswithcraneraiseandassemblewhenpowertodrawworks GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$35,950 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 11:00 18:00 06:00 12.0 CONSUMABLES 5.006:00 18:00 11:00 7.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:6/29/2022 RPTNUM.:9 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid#2 JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $325,816 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: $325,816 TIMEBREAKDOWN MOBILIZATION,STRINGBOTHTUGGERSANDMANRIDERCABLES,N/USURFACEBAG,KNIFEVALVEAND ADAPTOR,INSTALLRISERSINPITS,PAINTHANDLINGEQUIPMENT,LOADTRAILERSFORTRANSPORT,P/U ANDCLEANRIG SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms DAILYRECEIVED(gal) DAILYUSED(gal) RIGUPCRANEANDTRUCKINGCREWONLOCATION@06:30,HOLDPJSW/ALLPERSONNEL,SETͲSHAKER TANK,CENTRIFUGESKID,GENSHED#2,#3&#4,ODSDOGHOUSE,WATERTANK,DOGHOUSE,STAIRS,SET AͲLEG,INSTALLCROWN,CLUSTER//CONTINUERIGGINGUPELECTRICALͲGENSHEDS,MUDTANKS,TEST DERRICKLIGHTS,TROUBLESHOOTDOGHOUSEPLC,INSTALLNEWBUTTERFLYVALVESANDCHANGE DRESSERSLEEVERUBBERONMUDTANKINNERCONNECTS,MAKEUPALLMUDLINESININNERCONNECT ANDONMUDMANIFOLDSKID,GENERALHOUSEKEEPINGANDMAINTENANCE. FROM TO HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 13 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Setrigproperinplace,settingandraisingmast,riggingup,firegenerators. Continueriggingup,raisemastsections,setshopandpipesheds, GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$35,950 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:6/30/2022 RPTNUM.:10 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid#2 JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $362,638 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST: $362,638 TIMEBREAKDOWN CONTINUEMOBILIZATION&R/ULOWERKELLYHOSEANDHARDLINE,HANGINNERSERVISE+HYDRALIC LOOP,FINISHRISERINSTALLINPITS,GOTHREWSUCTION+EQUALIZERVALVE,ORGANIZENEWLOCATION, LOADTRAILERSATNOC, PAINTHANDLINGEQUIPMENT,TAKEONRIGWATER,R/DBLOCKHANGINGBEAN,PINBLOCKST/TOP DRIVE&UNPINTOPDRIVEF/TQTUBES.TAKEONWATER,RIGGINGUPRIGUTILITIES,STEANAIRAND WATER. SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms DAILYRECEIVED(gal) DAILYUSED(gal) MOBILIZATION&RIGUP.SETMATSFORSHOP,SETANDRIGUPSHOP,TORQUEBOLTSONDIVERTER, CHANGEOUTBUTTERFLYVALVEONEQUALIZER//SPOOLUPCROWN,BLOCKSANDDRUM.PJSMW/CRUZ ANDWORLEYCRANE,P/UANDRAISEDERRICKͲA,B,&CSECTIONS,INSTALLSTͲ80,P/UANDHANGTD, MAKEUPTDTRACKSECUREMENTS,CONTINUELOADINGANDBACKHAULRENTALMATS. FROM TO HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 14 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Riggingup Completecranework,setboard,serviceloop,windwallsandpipesheds.Haultubularstosite,rigupcomsandsupportshacks. GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$36,822 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/1/2022 RPTNUM.:11 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $4,528,510 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/3/22 $4,528,510 TIMEBREAKDOWN RIGUP;SPOTPIPESHEDSECTIONS(X5)ͲRAISECATTLECHUTEͲINSTALLLANDINGS&LADDERSͲRUKELLY HOSEͲINSTALLSAFETYCABLES&CLAMPSͲTIEBACKSTANDPIPEJUMPERHOSEͲINSTALLSAFETYCABLES& CLAMPSRIGUPREMOVECROSSBRACESECT.F/SUB.ͲREMOVEBOPCARTͲINSTALLDIVERTERSECT.F/TEE T/P.SHEDSECT.ͲSTARTBERMINGRIGͲINSTALLSHAKERDUMPCHUTES&CUTTINGSBOXͲCLEAN& ORGANIZERIGͲTROUBLESHOOTWEIGHTEDBLOCKCROWNSAVER SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms DAILYRECEIVED(gal) DAILYUSED(gal) RIGUP;INSTALLOUTERTDSERVICELOOP,REARWINDWALL,FRONTWINDWALL,RAISEALLWINDWALL ANDTIGHTENTURNBUCKELS//LUGUPTDHYDANDELECTRICALSERVICELOOPS,ATTEMPTTOTESTTDͲ INVERTEROUT//TESTANDTROUBLESHOOTCAMERASYSTEM//SETRIGMATSFORPIPESHED,MAKEUP FLOWLINE,TESTACCUMULATORBOTTLEANDPULSATIONDAMPENERSONMPS,SERVICEGEN4,PAINT SHOPFLOOR,REPLACEPLATEINMUDTANKINNERCONNECT,GENERALHOUSEKEEPINGAND MAINTENACE FROM TO HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 15 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Riggingup,bermingrigpreptotakeonfluidsinpits, Lasttwocranepicks,1pipeshedandsetgasbuster,bermrigtakeonwaterandfunctiontestPVTandmudsystems. GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$36,822 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/2/2022 RPTNUM.:16 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $4,569,208 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/3/22 $4,569,208 TIMEBREAKDOWN RIGUP.BREAKUPPERKELLYHOSECONN.&INSTALLSLBSTANDPIPETRANSDUCER&WIREͲINSTALL& SECUREDIVERTERF/PIPESHEDOUTͲCONT.REMOVINGPIPESHEDROOFSUPPORTSͲLOAD3JTSDPINP. SHEDFORDIVERTERSTACKTEST&TAG,MEASURE&LAYOUTUPPERDIVERTERSTACKRISERTOBECUTͲ INSTALLBAILSONTOPRIVEͲPREP.STANDPIPEBLEEDOFFMANIFOLDFORINSTALLF/REWORKRIG BERMINGͲBEGINTOFILLPITS&CHECKFORLEAKS SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms DAILYRECEIVED(gal) DAILYUSED(gal) RIGUP.SETLASTPIPESHEDANDCHOKE/BUSTERSKID,INSATLLROOFHATCHOVERSKATE,RIGUPPIPE SHEDANDCATWALK,FUNCTIONTESTCATWALK,RIGUPCHOKE/BUSTERSKID,INSTALLCHOKEANDKILL HOSE,FUNTIONMUDPUMPS,CHANGEOUTTDINVERTERINVFD,FUNCTIONTESTTD,TROUBLESHOOT CROWNSAVERTWOBLOCKͲREPAIRCABLE,BUILDCONTAINMENTAROUNDRIG,REPAIRFLOORPLATEON RIGFLOOR,INSTALLNEWDOORONMOTORROOMBREEZEWAY,FOLDLANDINGONENDOFMUDTANKS ANDINSTALLSTAIRS,RIGUPCONTROLHOSESFORDIVERTERSYSTEM,CHECKANDFILLACCUMULATOR BOTTLES,SETIN3RDPARTYSUPPORTSHAKES,FINISHPAINT SHOPROOMFLOOR,GENERALHOUSEKEEPINGANDMAINTENANCE FROM TO HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 16 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Riggingupandfunctioningtestingrigequipment,prepfordivertertestandAOGCCriginspection.Troubleshootdrawworks. Functiontestrigcomponentsandelectronics,performAOGCCdivertertestandriginspection,pickup5"hwdpanddrillpipeforspud. GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$40,698 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/3/2022 RPTNUM.:17 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $5,320,385 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/3/22 $5,320,385 RigMoveIn TIMEBREAKDOWN RIGUP.CONTINUETROUBLESHOOTINGDRAWWORKS.ASSEMBLESTANDPIPEBLEEDOFFMANIFOLDͲ CROSSCHAINDIVERTERSTACKͲCONT.TOASSEMBLEHANDLINGEQUIP.ͲREPLACESLBTRANSDUCERON STANDPIPEGOOSENECKͲINSTALLSLBTRANSDUCERONSTANDPIPEONRIGFLOORͲREMOVEUPPER DIVERTERSTACKRISERANDINSTALLSPAREGASKETSͲINSTALLKILL/CEMENTLINEJUMPERHOSES. SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms RigUp&TearDown EquipmentFailure DAILYRECEIVED(gal) DAILYUSED(gal) RigUp&TearDown EquipmentFailure MOBILIZERIG105E.CONTINUETROUBLESHOOTINGDRAWWORKSͲBRAKESETTINGWHILERUNNING, FILLACCUMULATORANDPRESSUREUPSYSTEM,FUNTIONTESTDIVERTERSYSTEM,TIGHTENFOOTVALVE INPIT#1&2,PUTTOGETHERHANDLINGSYSTEMͲTONGSANDSLIPS,INSTALLCAMERASͲSHAKERS,DW, ANDMP,OFFLOAD5"HWDPANDLOADINPIPESHED,FINISHSETTING3RDPARTYSUPPORTSHACKSAND RIGUPPOWER,OFFLOADDIRECTIONALTOOLSANDSTAGEFORDD. FROM TO RigMoveIn HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 17 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Troubleshootdrawworksbrakesystemandaudiblegasalarms Repairdrawworks.Repairaudiblegasalarms.FunctiontestgasalarmsandPVTsystemtimeannularclosingtime(AOGCCtowitness)Pullwaterfrompitsandreceivedrillingmud. GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST: CUMDRILLCOST:$40,697 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 06:00 CONSUMABLES 12.006:00 18:00 12.0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/4/2022 RPTNUM.:18 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK SPM 0 MODELPUMP RPM OUTER: 2 JETS TFASERNO. REͲRUN PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid $5,358,385 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $5,358,385 SurfaceDrilling 0.5 TIMEBREAKDOWN ContinuetroubleshootdrawworksEbrakesystm.loadpipeshedwithspudBHA,mixingspudmud,rigup handlingtoolsforpickupBHA. Rackandstrapdrillpipeinpipeshed.calibrateandsetcrownsaverandfloorsaver.installingelevators discoveredincorrectIBOPwasinstalledwouldnotclearbales,removeactuator,setlinkextensionfor derrickboard. SURVEYDATA MD N/S BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms RepairRig RepairRig Other HolsPJSMandprespudmeetingwithbothcrews. EquipmentFailure Execution DAILYRECEIVED(gal) DAILYUSED(gal) RepairRig EquipmentFailure TroubleshootdrawworksEbrakesystem. FROM TO SurfaceDrilling HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 18 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: HoldingpreͲspudandPJSMwithbothcrewsfordrillingandoverviewofwellplaninpreparationtopickuppipeanddriling. CompletepreͲspudmeeting,pickupandrackbackinderrick86joints4"DP,20jts.5"HWDP.Pickupandmakeupbitandmotor,drillto350',POHpickupsmartBHAtoolscontinuedrilling GRADE 9075290737 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$38,000 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 SurfaceDrilling 01:00 05:30 06:00 4.5 SurfaceDrilling CONSUMABLES 12.006:00 01:00 18:00 7.0 05:30 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/5/2022 RPTNUM.:19 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID 12.25 # STK N 450 SPM 0milltooth rk4080 MODELPUMP 1 12.25 Smith RPM OUTER: 2 JETS TFASERNO. REͲRUN MarkBrouillet FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL: RIGSUPERV: NaborsAlaskaDrilling Alkaid Conductor 20.00 $7,491,373 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $7,491,373 SurfaceCasing SurfaceCasing 1.0 TIMEBREAKDOWN Pickingupandstandingback4"drillpipeinderrick.Adjustingserviceloopsandkellyhoseasneeded. ReplaceIBOPactuatorontopdrive. SURVEYDATA MD N/S BHAWT.MUD: Surfacemotor(shortassembly) ROT.WT.: 42.66 COORDINATES TORQUE: BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms Trips RepairRig Trips Trips CondMud&Circ Drilling Pickingupandstandingback4"drillpipeinderrick.Adjustingserviceloopsandkellyhoseasneeded. Pickup121/4"bitandmotordrillingassembly,BHA#1 Fluidpacksurfacelinesandchecksforleaks,fillconductor,pressuretestsurfacelinestop2,500psi Cleanout20"conductort/100KB',spudanddrillfrom100"to226' EquipmentFailure DAILYRECEIVED(gal) DAILYUSED(gal) RepairRig EquipmentFailure Continuetroubleshootingdrawworksbrakingsystem. FROM TO SurfaceCasing HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 1.1 9.000 BHA 3.81 30.84 6.91 COMPONENT 8 DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 19 4226 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Drillingahead12.25surfacehole@226 Drillto500,pohpickupMWDtoolsrIHcontinuedrilling GRADE 7/6/2022 9079920615 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$49,257 BOP 24.0 226FT/226FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS 8 DULL: LOC: PSI 8.13 3.25 12.13 3 HRS.ONJARS: 4.0 DAILYONHAND(gal) PHASE 08:00 SurfaceCasing 15:00 01:00 18:00 19:00 06:00 3.0 SurfaceCasing 1.002:00 CONSUMABLES 2.0 SurfaceCasing 02:00 6.0 SurfaceDrilling19:00 06:00 15:00 08:00 7.0 01:00 18:00 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver 500 GPSGPMLINER 450 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 500 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/6/2022 RPTNUM.:20 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) MUD OILMf # 1 2 3 OPERATIONSCODE NPT 4 DrillBitͲmilltooth MotorͲ12.1.5STAB StabilizerͲNM XͲOverͲBOTTLENECK COMPONENT OD ID LENGTH LENGTH: 32 40LENGTH: MotorͲ12.1.5STAB StabilizerͲNM LWDToolͲArcvision825 StabilizerͲsch 11 COMPONENT OD ID# 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲmilltooth TIME FV WL GELS(10s/10m/30m) MANUFACTURER 9.0 360.0 10.0 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/7/2022 RPTNUM.:1 RIG:Rig105E DAILYDRILLINGREPORT ECD BITHHP RP: GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 50 500 6.000 9.000 PUMPS GardnerDenver 50 500 GPSGPMLINER 450 98 OTHER: AVDPEFF% 08:00 MWDToolͲTrulink MonelCollarͲNMDC MonelCollarͲNMDC AVDC GAUGE: 17:30 06:00 07:30 06:30 1.0 18:00 2.756.75 CONSUMABLES 0.5 6 19:30 0.5 0.5 1.519:30 07:30 18:00 08:00 17:30 00:00 PHASE 06:30 29.71 8.25 3 12.13 3 40 HRS.ONJARS: 4.5 DAILYONHAND(gal) 29.96.25 DULL: LOC: PSI 7 HTHPPf 14 MW 27.51 OIL 2.756.75 ROPWOB TOTALHRS 18.0 503FT/503FT DAILYDRILLCOST: GRADE 7/6/2022 9079920615 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$48,055 BOP COSTDATA 7/4/22 MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: outholepickingupsmarttools makeupsmarttoolsRIHto503Ͳfootdrillaheadastoowellplan Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 277 EMAIL: 553857 0.6510.0 8 DRILLBITS 3.818.13 LENGTHODCOMPONENTLENGTH BHA 19.17 30.84 3.25 6.75 2.75 6.91 9 10 DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 1.1 9.000 FROM TO HRS CONSUMABLE DAILYRECEIVED(gal) DAILYUSED(gal) RotaryDrillingto226 Downtimetroubleshoottopdrivetorquesystem TIHwithHWDP Downtimetopdrive NPTwashandreamto226calurbratetopdrivetorquesystemduetoinstallofnewmotherboard RotaryDrillingfrom226to www.wellez.comWellEzOnDemandver_102920ms 29,400P.U.WT.:40S.O.WT.: AZIMUTH TVD E/W DLSV.SECTIONCOORDINATES TORQUE: BHAWT.AIR: INCLINATION 7.75 BHAWT.MUD: Surfacemotor(shortassembly) ROT.WT.:40 835.18 6.75 5 2.75 312 DrillPipeͲ5HWDP 4.25 4.79 27.88 40 SURVEYDATA MD N/S 00:00 9.5 TIMEBREAKDOWN Poohtoconductor ServiceRig $7,562,873 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $7,562,873 Conductor 20.00 108 WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL:1 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/jerryOtto FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUNTYPE MAKE MODELPUMP 1 12.25 Smith MonelCollarͲNMDC 42 98450 SPM 0.15 0milltooth rk4080 STK N ID 12.25 91.8 8.25 8.25 3SubͲFILTERSUB 8 # XͲOverͲBottleneck 32 LENGTH: MotorͲ12.1.5STAB StabilizerͲNM LWDToolͲArcvision825 StabilizerͲsch 11 COMPONENT OD ID# 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲmilltooth TIME FV WL GELS(10s/10m/30m) MANUFACTURER 9.3 250.0 10.0 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/8/2022 RPTNUM.:2 RIG:Rig105E DAILYDRILLINGREPORT ECD BITHHP RP: GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 50 500 6.000 9.000 PUMPS GardnerDenver 50 500 GPSGPMLINER 250 98 OTHER: AVDPEFF% 08:30 MWDToolͲTrulink MonelCollarͲNMDC MonelCollarͲNMDC AVDC GAUGE: 12:30 06:00 08:00 07:00 1.0 15:30 6.000:00 06:00 2.756.75 CONSUMABLES 1.0 6 SurfaceDrilling 16:00 3.0 SurfaceDrilling 0.5 SurfaceDrilling 4.0 0.516:00 08:00 15:30 08:30 12:30 20:00 00:00 PHASE 07:00 29.71 8.25 3 12.13 3 HRS.ONJARS: 4.0 DAILYONHAND(gal) 29.96.25 DULL: LOC: PSI 7 HTHPPf 14 MW 20:00 27.51 OIL 10.00 2.756.75 ROPWOB TOTALHRS 24.0 930FT/930FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$48,055 BOP COSTDATA 7/4/22 MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: RepairRig RepairRigTIHDrillsurface Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 1 13.5427 EMAIL: 55385 0.65 20010.0 8 DRILLBITS 600 3.818.13 LENGTHODCOMPONENTLENGTH BHA 19.17 30.84 3.25 6.75 2.75 6.91 9 10 DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 1.1 9.000 FROM TO SurfaceDrilling HRS CONSUMABLE DAILYRECEIVED(gal) DAILYUSED(gal) Drilling POOHforBHApickup SurfaceDrilling PickupSmartToolsFrompipeshed TIHholetesttools Changesaversub Drillfrom503to930 Backreamoutofhole Troubletopdrivetorqueproblem Drilling Drilling Drilling Drilling RigService Drilling RepairRig RepairRig www.wellez.comWellEzOnDemandver_102920ms P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTIONCOORDINATES TORQUE: BHAWT.AIR: INCLINATION 7.75 BHAWT.MUD: Surfacemotor(shortassembly) ROT.WT.: 835.18 6.75 5 2.75 312 DrillPipeͲ5HWDP 4.25 4.79 27.88 SURVEYDATA MD N/S 20:00 4.0 TIMEBREAKDOWN TIHwithremainingHWDPPOOhSame SafetymeetingPickingupBHA SurfaceDrilling SurfaceDrilling SurfaceDrilling SurfaceDrilling $7,610,927 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $7,610,927 Conductor 20.00 108 WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL:2 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/jerryOtto FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUNTYPE MAKE MODELPUMP 1 12.25 Smith MonelCollarͲNMDC 42 98250 SPM 0.25 0milltooth rk4080 STK N ID 12.25 91.8 8.25 8.25 3SubͲFILTERSUB 8 # XͲOverͲBottleneck 23 LENGTH: MotorͲ12.1.5STAB StabilizerͲNM LWDToolͲArcvision825 StabilizerͲsch 11 COMPONENT OD ID# 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲmilltooth TIME FV WL GELS(10s/10m/30m) MANUFACTURER 9.5 250.0 8.0 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/9/2022 RPTNUM.:6 RIG:Rig105E DAILYDRILLINGREPORT ECD BITHHP RP: GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 80 1500 6.000 9.000 PUMPS GardnerDenver 80 1500 GPSGPMLINER 250 98 OTHER: AVDPEFF% MWDToolͲTrulink MonelCollarͲNMDC MonelCollarͲNMDC AVDC GAUGE: 06:00 22:00 20:30 1.5 2.756.75 CONSUMABLES 14.5 6 8.0 22:00 06:00 PHASE 20:30 29.71 8.25 3 12.13 3 HRS.ONJARS: DAILYONHAND(gal) 29.96.25 DULL: LOC: PSI 7 HTHPPf 30 MW 21:00 27.51 OIL 8.00 2.75 7.31 6.75 ROPWOB TOTALHRS 24.0 835FT/0FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$48,640 BOP COSTDATA 7/4/22 MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: DirectionalDrilling DirectionalDrillingto2215maintainINCtoͲ+35009Ͳ5/8CSGpoint Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 5 EMAIL: 52312/0.30 200 8 DRILLBITS 3.818.13 LENGTHODCOMPONENTLENGTH BHA 19.17 30.84 3.25 6.75 2.75 6.91 9 10 DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 1.1 9.000 FROM TO HRS CONSUMABLE 305.0 DAILYRECEIVED(gal) DAILYUSED(gal) EquipmentFailure DOWNTIMETopDriveovertorqueduetobadsoftwareupdatedowndownloadplusmisotherelectrical problems,changeoutsaversubfrom4Ͳ1/2to4HT Ͳ1.6 0.7 www.wellez.comWellEzOnDemandver_102920ms P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTIONCOORDINATES TORQUE: 4.11,138 1.51 226.94 BHAWT.AIR: INCLINATION 7.75 1,040 BHAWT.MUD: Surfacemotor(shortassembly) ROT.WT.: 835.18 6.75 5 2.75 312 DrillPipeͲ5HWDP4.25 4.79 27.88 SURVEYDATA MD N/S TIMEBREAKDOWN RotaryDrillingfrom930to1000ft DirectionalDrillfrom1000to1525 $8,983,247 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $8,983,247 Conductor 20.00 108 WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL:3 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/jerryOtto FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUNTYPE MAKE MODELPUMP 1 12.25 Smith MonelCollarͲNMDC 37 98250 SPM 0.30 0milltooth rk4080 STK N ID 12.25 91.8 8.25 8.25 3SubͲFILTERSUB 8 # XͲOverͲBottleneck 17 57LENGTH: MotorͲ12.1.5STAB StabilizerͲNM LWDToolͲArcvision825 StabilizerͲsch 11 COMPONENT OD ID# 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲmilltooth TIME FV WL GELS(10s/10m/30m) MANUFACTURER 9.8 188.0 8.0 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/10/2022 RPTNUM.:7 RIG:Rig105E DAILYDRILLINGREPORT ECD BITHHP RP: GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 96 1200 6.000 9.000 PUMPS GardnerDenver 96 1200 GPSGPMLINER 301 98 OTHER: AVDPEFF% 05:00 MWDToolͲTrulink MonelCollarͲNMDC MonelCollarͲNMDC AVDC GAUGE: 06:00 00:00 13:30 10.5 2.756.75 CONSUMABLES 7.5 6 5.0 SurfaceDrilling 00:00 05:00 06:00 PHASE 13:30 29.71 8.25 3 12.13 3 49 HRS.ONJARS: DAILYONHAND(gal) 29.96.25 DULL: LOC: PSI 7 HTHPPf 29 MW 21:00 27.51 OIL 8.00 2.75 3.87 6.75 ROPWOB TOTALHRS 24.0 3383FT/3299FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$48,640 BOP COSTDATA 7/4/22 MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Circulateandconditionmud Circulateandconditionmud,POOH.LDBHA,RUCsgequipmentRun9Ͳ5/8csg Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 6 15.52547.82 EMAIL: 49242 0.75 1809.6 8 DRILLBITS 700 3.818.13 LENGTHODCOMPONENTLENGTH BHA 19.17 30.84 3.25 6.75 2.75 6.91 9 10 DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 1.1 9.000 FROM TO SurfaceDrilling 222.1 295.79 3,159 2,854 HRS CONSUMABLE 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) DirWork DirectionalDrillingfrom1526to2200 392.8 0.6 SurfaceDrilling 96.7 1.6 233.8 0.52,377 19.22 233.82 2,349 129.4 Circulateandconditionmud Drilling Drilling CondMud&Circ www.wellez.comWellEzOnDemandver_102920ms 4,600P.U.WT.:84S.O.WT.: AZIMUTH TVD E/W DLSV.SECTIONCOORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION 7.75 3,236 323.0 1,894 BHAWT.MUD: Surfacemotor(shortassembly) ROT.WT.:90 835.18 6.75 5 2.75 312 DrillPipeͲ5HWDP 18.75 232.97 2,798 4.25 4.79 27.88 60 SURVEYDATA MD N/S 1.0 TIMEBREAKDOWN RotaryDrillingfrom2200to3140 ControlRotaryDrillingfrom3140to3383(9Ͳ5/8Casingpoint) SurfaceDrilling 0.818.32 296.1 516.1423.4 $9,059,940 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $9,059,940 Conductor 20.00 108 WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL:4 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/jerryOtto FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUNTYPE MAKE MODELPUMP 1 12.25 Smith MonelCollarͲNMDC 35 98301 SPM 0.35 0milltooth rk4080 STK N ID 12.25 91.8 8.25 8.25 3SubͲFILTERSUB 8 # XͲOverͲBottleneck 13 RunCsg&Cement RunCsg&Cement LENGTH: Makeupshoetracktestfloatsokay Run9Ͳ5/8csgastoprogram MotorͲ12.1.5STAB StabilizerͲNM LWDToolͲArcvision825 StabilizerͲsch 11 COMPONENT OD ID# 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲmilltooth TIME FV WL GELS(10s/10m/30m) MANUFACTURER 10.0 177.0 6.5 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/11/2022 RPTNUM.:8 RIG:Rig105E DAILYDRILLINGREPORT ECD BITHHP RP: GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 96 1200 6.000 9.000 PUMPS GardnerDenver 96 1200 GPSGPMLINER 301 98 OTHER: AVDPEFF% 12:30 MWDToolͲTrulink MonelCollarͲNMDC MonelCollarͲNMDC AVDC GAUGE: 13:00 06:00 12:00 06:30 5.5 13:30 0.500:00 00:30 2.756.75 CONSUMABLES 0.5 6 SurfaceCasing 17:30 0.5 SurfaceCasing 0.5 SurfaceCasing 3.5 4.017:30 12:00 13:30 06:00 12:30 13:00 20:30 00:00 3.0 PHASE 2.503:00 06:30 29.71 8.25 3 12.13 3 HRS.ONJARS: 3.0 DAILYONHAND(gal) 29.96.25 DULL: LOC: PSI 7 HTHPPf 27 MW 21:00 27.51 OIL 6.50 2.75 7.44 6.75 ROPWOB TOTALHRS 24.0 3383FT/3227FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$48,640 BOP COSTDATA 7/4/22 MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 7 EMAIL: 35212 0.90 1209.5 8 DRILLBITS 600 3.818.13 LENGTHODCOMPONENT SurfaceCasing LENGTH BHA 19.17 30.84 3.25 6.75 2.75 6.91 9 10 DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 1.1 9.000 FROM TO SurfaceCasing 222.1 295.79 3,159 2,854 HRS CONSUMABLE 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) CondMud&Circ Circulateandconditionmud 392.8 0.6 SurfaceCasing 96.7 1.6 233.8 0.52,377 19.22 233.82 2,349 129.4 Poohworktightspotsasneeded ChangeoutsaversubfromHTͲ40to4Ͳ1/2IF L/DBHA Clearandcleanfloorclearoutpipeshed MakeupandDummyrunhanger(noGo)spiceinflownipplehadasmallerIDpulllflownipplemakedummy run(RKB=23.90)rigupGBRvalonttoolR?UCasingtongsandbellextensionlaydownlandingjt.cutand installnewflownippleID=19Ͳ1/8crewchange 03:00 PreͲjobsafetymeetingonpickingupandrunningcsg Trips Other Other Trips Other Other RunCsg&Cement www.wellez.comWellEzOnDemandver_102920ms SurfaceCasing P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION 36.8 COORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION 7.75 3,236 323.0 1,894 BHAWT.MUD: Surfacemotor(shortassembly) ROT.WT.: 835.18 6.75 5 2.75 312 DrillPipeͲ5HWDP 18.75 232.97 2,798 4.25 4.79 27.88 SURVEYDATA MD N/S 20:30 00:30 0.5 TIMEBREAKDOWN POOHfrom3383to1121onelevatorsworktightholeasneededoverpullfrom40kto150k FillpipewithH2OtocleanoutBHA SurfaceCasing 0.818.32 296.1 SurfaceCasing SurfaceCasing SurfaceCasing 516.1423.4 $9,108,580 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $9,108,580 Conductor 20.00 108 WELLNAME:Alkaid2PH JOB:Mobilizerig105toAlkaid2 RKB: DOL:5 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/jerryOtto FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUNTYPE MAKE MODELPUMP 1 12.25 Smith MonelCollarͲNMDC 40 98301 SPM 0.35 0milltooth rk4080 STK N ID 12.25 91.8 8.25 8.25 3SubͲFILTERSUB 8 # XͲOverͲBottleneck StuckPipe/Fishing LENGTH: MotorͲ12.1.5STAB StabilizerͲNM LWDToolͲArcvision825 StabilizerͲsch 11 COMPONENT OD ID# 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲmilltooth TIME FV WL GELS(10s/10m/30m) MANUFACTURER 10.0 135.0 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/12/2022 RPTNUM.:9 RIG:Rig105E DAILYDRILLINGREPORT ECD BITHHP RP: GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 50 1200 6.000 9.000 PUMPS GardnerDenver 50 1200 GPSGPMLINER 200 98 OTHER: AVDPEFF% 00:00 MWDToolͲTrulink MonelCollarͲNMDC MonelCollarͲNMDC AVDC GAUGE: 06:00 12:00 11:30 0.5 2.756.75 CONSUMABLES 5.5 6 12.0 SurfaceCasing 12:00 00:00 06:00 PHASE 11:30 29.71 8.25 3 12.13 3 HRS.ONJARS: DAILYONHAND(gal) 29.96.25 DULL: LOC: PSI 7 HTHPPfMW 21:00 27.51 OIL 2.756.75 ROPWOB TOTALHRS 24.0 3383FT/3300FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$53,365 BOP COSTDATA 7/4/22 MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: workingstuckcasing Poohcasing,cleanoutrunwithdumbiron Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 8 EMAIL: 2 8 DRILLBITS 3.818.13 LENGTHODCOMPONENTLENGTH BHA 19.17 30.84 3.25 6.75 2.75 6.91 9 10 DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 1.1 9.000 FROM TO SurfaceDrilling 222.1 295.79 3,159 2,854 HRS CONSUMABLE 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) RunCsg&Cement Runcasing(shoeTrackcheckfloatsokay.rihwith9Ͳ5/8csg1558worktightspotsasneeded 392.8 0.6 SurfaceCasing 96.7 1.6 233.8 0.52,377 19.22 233.82 2,349 129.4 POOHwithCasingworkpipe(pipebecamestucknorotation,nocirculation,overpullsto300knodown movementat1800 RunCsg&Cement RunCsg&Cement www.wellez.comWellEzOnDemandver_102920ms P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION 36.8 COORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION 7.75 3,236 323.0 1,894 BHAWT.MUD: Surfacemotor(shortassembly) ROT.WT.: 835.18 6.75 5 2.75 312 DrillPipeͲ5HWDP 18.75 232.97 2,798 4.25 4.79 27.88 SURVEYDATA MD N/S 6.0 TIMEBREAKDOWN Circulatewell RIHwith9Ͳ5/8csgfrom1558to1842worktightpipe SurfaceCasing 0.818.32 296.1 516.1423.4 $9,438,069 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $9,438,069 Conductor 20.00 108 WELLNAME:Alkaid2PH JOB:Alkaid2OHsurfacehoke RKB: DOL:6 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/jerryOtto FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUNTYPE MAKE MODELPUMP 1 12.25 Smith MonelCollarͲNMDC 98200 SPM 0milltooth rk4080 STK N ID 12.25 91.8 8.25 8.25 3SubͲFILTERSUB 8 # XͲOverͲBottleneck 12 LENGTH: StabilizerͲNMWPORTEDFLOAT COMPONENT OD ID# 1 2 OPERATIONSCODE NPT DrillBitͲXRͲCPS TIME FV WL GELS(10s/10m/30m) MANUFACTURER 9.9 127.0 6.0 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/13/2022 RPTNUM.:10 RIG:Rig105E DAILYDRILLINGREPORT ECD BITHHP RP: GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 96 1200 6.000 9.000 PUMPS GardnerDenver 96 1200 GPSGPMLINER 301 98 OTHER: AVDPEFF% 01:00 0 AVDC GAUGE: 04:00 06:00 20:30 18:00 2.5 CONSUMABLES 12.0 2.0 SurfaceCasing 4.5 SurfaceDrilling 20:30 06:00 01:00 04:00 PHASE 18:00 HRS.ONJARS: DAILYONHAND(gal) 4.75 DULL: LOC: PSI HTHPPf 29 MW 9:00 OIL ROPWOB TOTALHRS 24.0 0FT/0FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$53,365 BOP COSTDATA 7/4/22 MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Cuttingandslippingdrillingline@720' slipandcutdrillingline,servicerig,changesaversubto4",RIHwith4"DPandcleanoutasnecessarytorunsurfacecasing Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 9 EMAIL: 30172/0.70 5009.6 8.42 DRILLBITS LENGTHODCOMPONENTLENGTH BHA 7.05 DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 1.08 9.000 FROM TO SurfaceCasing 222.1 295.79 3,159 2,854 HRS CONSUMABLE 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) RunCsg&Cement POHlayingdown95/8"surfacecasing. 392.8 0.6 SurfaceDrilling 96.7 1.6 233.8 0.52,377 19.22 233.82 2,349 129.4 Makeupbit#2andcleanout121/4"steelDCBHA. RIHwithbit#2cleanoutassemblyT720'. RunCsg&Cement RunCsg&Cement Trips Trips www.wellez.comWellEzOnDemandver_102920ms P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTIONCOORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION 3,236 323.0 1,894 BHAWT.MUD: 12.25"dumbcleanoutassembly ROT.WT.: 8.13 18.75 232.97 2,798 SURVEYDATA MD N/S 3.0 TIMEBREAKDOWN ContinuePOHlayingdown95/8"surfacecasingtoshoetrack. **Leftshoebullnoseandbowspringsfromjt#14 Breakandlaydown95/8"shoetrack,heatingbakerlockjointstobreak. SurfaceCasing 0.818.32 296.1 516.1423.4 $9,491,434 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $9,491,434 Conductor 20.00 108 WELLNAME:Alkaid2PH JOB:Alkaid2OHsurfacehoke RKB: DOL:7 RIGSUPERV: NaborsAlaskaDrilling Alkaid JerryOtto/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUN 12.251 TYPE MAKE MODELPUMP 2 12.25 smith Smith 27 98301 SPM 0.30 0milltooth milltooth RK4045 rk4080 STK N N 4x15 0.690 ID 12.25 # 13 DrillPipeͲHWDP ID 12.25 8.11 8.13 2.75 8 # STK N N 4x15 301 SPM 0.35 0milltooth milltooth RK4045 rk4080 0.690 MODELPUMP 2 12.25 smith Smith RPM OUTER: 2 JETS TFASERNO. REͲRUN 12.251 JerryOtto/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:8 RIGSUPERV: NaborsAlaskaDrilling Alkaid Conductor 20.00 108 $9,575,691 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $9,575,691 SurfaceDrilling 0.818.32 296.1 SurfaceDrilling 516.1423.4 3.0 TIMEBREAKDOWN Cleanout121/4"holewithcleanoutBHA#3f/720'to2,250.20rpmdown60rpmreamup,2,100psi @602gpm,torque3to6Kmax ContinuecleanoutwithdumbcleanoutBHA#3.f/2,250'tobottomtag@3,384',bottomclean,nofill observed.washandream121/4"hole@20rpmdownream60rpmupream,2,300psi@602gpm, torque3to6Kmax 18.75 232.97 2,798 3.25 29.46 3.81 SURVEYDATA MD N/S 3,236 323.0 1,894 BHAWT.MUD: 12.25"dumbcleanoutassembly ROT.WT.: 722.83 COORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms Reaming Reaming CondMud&Circ Trips Reaming Trips Circulateandcleanholefor95/8"casingrun. POHonelevatorsfrom3,384'to1,890' Encountertighthole@1,890',washandbackreamspotto1,887'cleanandworkareauntilclean.40rpm, 400gpm@1,000psi,75Kupwt.,70Krot,70Kdn.3to10Ktorque. ContinuePOHwithBHA#3onelevators,workstandsfrom1,900to1,505untilclean.downweightgood, upweightoverpullreducedf/20Koverto5to10Kover.ContinuePOHto722'. 233.8 0.52,377 19.22 233.82 2,349 129.4 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) RigService Cutandslipdrillingline,longcutduetohardoverpullspullswithcasingrun.Rigservice 392.8 0.6 96.7 1.6 FROM TO SurfaceDrilling 222.1 295.79 3,159 2,854 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 1.08 9.000 BHA 6.91 7.05 3 52.75 28.71 9 10 JarͲHYDRAͲJAR COMPONENT 10.6 8.42 DRILLBITS 600 91.8 LENGTHOD 37212 0.80 INTYPE 28 HRSDRLG: drillingsupervisor@greatbearpetro.com 10 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: POH@HWDP Standback5"HWDP,laydownBHA#3,rigupandrun95/8"surfacecasing. GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$54,074 BOP 24.0 3383FT/3383FT DAILYDRILLCOST: COSTDATA 7/4/22 5 ROPWOB TOTALHRS 9:00 1.14 3 31.654.75 DULL: LOC: PSI 7 521.22 83 8.13 2.81 HRS.ONJARS: 2.0 DAILYONHAND(gal) PHASE 08:30 SurfaceDrilling 18:00 03:00 22:00 01:00 06:00 4.0 SurfaceDrilling 1.004:00 35 CONSUMABLES 2.5 6 SurfaceCasing 04:00 2.0 SurfaceCasing01:00 06:00 18:00 08:30 9.5 03:00 22:00 XͲOverͲBOTTLENECK DrillPipeͲHWDP XͲOverͲBOTTLENECK 177 0 AVDC GAUGE: 98 10.3 681 OTHER: AVDPEFF% 98 GardnerDenver 96 1200 GPSGPMLINER 301 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 96 1200 6.000 9.000 PUMPS ECD 235 BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/14/2022 RPTNUM.:11 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER 9.4 109.0 7.0 CAKEPH Pf 22 MWTIME FV WL GELS(10s/10m/30m) MUD OILMf # 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲXRͲCPS StabilizerͲNMWPORTEDFLOAT DrillCollarͲDC StabilizerͲPORTEDFLOAT DrillCollarͲSTEEL COMPONENT OD ID LENGTH LENGTH: 12 ID# STK N N 4x15 400 SPM 0.30 0milltooth milltooth RK4045 rk4080 0.690 MODELPUMP 2 12.25 smith Smith RPM OUTER: 2 JETS TFASERNO. REͲRUN 12.251 JerryOtto/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:9 RIGSUPERV: NaborsAlaskaDrilling Alkaid Conductor 20.00 108 $9,663,038 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $9,663,038 SurfaceCasing 0.818.32 296.1 SurfaceCasing SurfaceCasing SurfaceCasing 516.1423.4 01:30 05:00 5.0 TIMEBREAKDOWN Riguptorun95/8"casing,pickupGBRVolanttoolandcasingtools. Pickupandmakeup95/8"shoetrackBakerlockconnections. 18.75 232.97 2,798 SURVEYDATA MD N/S 3,236 323.0 1,894 BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms SurfaceCasing 05:30 Laydowntagcasingjointandpickupandmakeuplandingjointandsetpipeinhanger.Shoe@3,374'. RunCsg&Cement RunCsg&Cement RunCsg&Cement RunCsg&Cement RunCsg&Cement RunCsg&Cement RunCsg&Cement RunCsg&Cement Runinholewith95/8"#40,L80,LTCcasingt/1,777'. Continuerunninginholewith95/8"#40,L80,LTCcasingto2,744' Circulate,washandworktightpipefrom2.744to2,827' Continuerunninginholewith95/8"#40,L80,LTCcasingfrom2,827'tobottomtag@3,384'washdown lasttwojoints.nofillonbottom. Circconditionmud,cleanhole.Pipebegantakingweightandoverpulling.110Kdn,130Kup,400gpm@ 300psi 233.8 0.52,377 19.22 233.82 2,349 129.4 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) Other POHfrom722'standingback5"HWDP,laydownBHA#3.changesaversubtoNC50. 392.8 0.6 96.7 1.6 FROM TO SurfaceDrilling 222.1 295.79 3,159 2,854 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT SurfaceCasing 9.6 DRILLBITS 600 LENGTHOD 37192 0.65 160 INTYPE 28 HRSDRLG: drillingsupervisor@greatbearpetro.com 11 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Circulateandriguptocement95/8"surfacecasing Cementsurfacecasing,nippledowndiverterandnippleup95/8"surfacestack. GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$54,084 BOP 24.0 0FT/0FT DAILYDRILLCOST: COSTDATA 7/4/22 ROPWOB TOTALHRS 9:00 7.44 DULL: LOC: PSI HRS.ONJARS: 1.5 DAILYONHAND(gal) PHASE 0.505:30 10:00 SurfaceCasing 12:00 22:00 06:00 13:00 18:00 01:30 03:30 1.0 SurfaceCasing 2.0 2.000:00 0.5 CONSUMABLES 4.0 SurfaceCasing 00:00 4.0 SurfaceCasing18:00 06:00 12:00 10:00 2.0 22:00 1.503:30 05:00 13:00 177 0 AVDC GAUGE: 98 11.1 681 OTHER: AVDPEFF% 98 GardnerDenver 96 1200 GPSGPMLINER 301 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 96 400 6.000 9.000 PUMPS ECD 235 BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/15/2022 RPTNUM.:12 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER 10.0 116.0 6.0 CAKEPH Pf 25 MWTIME FV WL GELS(10s/10m/30m) MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ChangerubbersinleakingVollanttool, Circulateconditionmud,riguptocement. EquipmentFailureRunCsg&Cement 15 ID# STK N N 4x15 250 SPM 0.30 0milltooth milltooth RK4045 rk4080 0.690 MODELPUMP 2 12.25 smith Smith RPM OUTER: 2 JETS TFASERNO. REͲRUN 12.251 JerryOtto/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:10 RIGSUPERV: NaborsAlaskaDrilling Alkaid 3,375 Conductor 20.00 108 40 l80 3,375 $9,770,918 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $9,770,918 SurfaceCasing 0.818.32 296.1 516.1423.4 4.0 TIMEBREAKDOWN PJSMW/SLBCEMENTCREWS,PUMP595BBLSCMT,@5BPM200/500PSI,PMP241BBLS9.8PPGMUD W/RIGICP=165GPM/620PSI CONT,T/PUMP9.8MUDT/PLUGBUMPFCP=188GPM/1109PSI,3196TOTALSTKS,CHECKFLOATS. CLEANINGRIGPRESSUREWASHRIGFLOOR/CELLAR 18.75 232.97 2,798 SURVEYDATA MD N/S 3,236 323.0 1,894 BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms RunCsg&Cement RunCsg&Cement NippleUpB.O.P. NippleUpB.O.P. NIPPLEDOWN20"DIVERTERSYSTEM,DIVERTERLINE,KNIFEVALVEANDANNULAR,DRAINRISERAND RINSEOUT,NIPPLEDOWNDIVERTERRISERANDLAYDOWN Cleanoutthickmudanddebrisfromcasinghanger,pickupandrun100'1"pipe95/8"X20"annulus, stoppedat100'fromtopofwellhead.AssembleBOPcomponentsfornippleup,cleaningpitsofspudmud, prepfortakingonClayShieldmudfordrillout. 233.8 0.52,377 19.22 233.82 2,349 129.4 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) CondMud&Circ 95/8"surfacepipeinhanger.circulateandconditionmudforcement250gpm@240psi. 392.8 0.6 96.7 1.6 FROM TO SurfaceCasing 222.1 295.79 3,159 2,854 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT 9.4 DRILLBITS 500 LENGTHOD 28192 0.65 160 INTYPE 24 HRSDRLG: drillingsupervisor@greatbearpetro.com 23.9 12 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: Alkaid 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: preppingfortopjobcementoperation.assembleBOPE,cleaningpitsandloadingpipeshedwith4" performtopjob,nippleupandtest135/8"BOP GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$54,181 BOP 24.0 3383FT/3383FT DAILYDRILLCOST: COSTDATA 7/4/22 ROPWOB TOTALHRS 15:00 8.48 DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 07:00 SurfaceCasing 12:00 06:00 15:00 19:00 3.0 SurfaceCasing CONSUMABLES 1.0 11.0 SurfaceCasing 19:00 06:00 12:00 07:00 5.0 15:00 177 0 AVDC GAUGE: 98 11.1 681 OTHER: AVDPEFF% 98 GardnerDenver 96 400 GPSGPMLINER 250 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 96 400 6.000 9.000 PUMPS ECD 235 BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/16/2022 RPTNUM.:13 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER 10.0 137.0 6.0 CAKEPH Pf 45 MWTIME FV WL GELS(10s/10m/30m) Surface 9.63 MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK N N 4x15 SPM 0milltooth milltooth RK4045 rk4080 0.690 MODELPUMP 2 12.25 smith Smith RPM OUTER: 2 JETS TFASERNO. REͲRUN 12.251 JerryOtto/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:11 RIGSUPERV: NaborsAlaskaDrilling Alkaid 3,375 Conductor 20.00 108 40 l80 3,375 $9,830,937 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/12/22 $9,830,937 SurfaceCasing 0.818.32 296.1 516.1423.4 6.0 TIMEBREAKDOWN PJSM,R/USLBCEMENTERS,PRESSURETESTCEMENTLINEST/,3000PSI,PUMPED5BBLSWATERTHRU CEMENTLINEPTT/3,000PSI,B/DLINES CEMENTTOPJOB.PUMP20BBLSWATERLEADCHASEW/36BBLSCEMENTICP=76GPM/1500PSIFCP= 34GPM/1545PSI,PUMPOUTCELLARBOXANDRINSEOUTCEMENT *CEMENTTOPJOBANDCEMENTTAGAT100'WITNESSEDBYLOULAUBENSTEINPETROLEUMINSPECTOR AOGCC 18.75 232.97 2,798 SURVEYDATA MD N/S 3,236 323.0 1,894 BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms RunCsg&Cement RunCsg&Cement NippleUpB.O.P. NippleUpB.O.P. NIPPLEUP/DOWNBOPS.REMOVEWELLHEADSURFACEADAPTERSPOOL,INSTALL11"WELLHEADTESTT/ 5,000PSI5MIN.GOODTEST.NIPPLEUPBOPSHOLDPJSMW/RIGCREW,NIPPLEUPADAPTERSPOOL, SINGLEGATE,MUDCROSS,CHOKEANDKILLVALVES CONTINUENIPPLEUPBOPE.SETINSINGLEGATE,MUDCROSS,INSTALLKILLVALVEANDHCR,INSTALL ANNULARLIFTRINGANDSETONDOUBLEGATEANDNIPPLEUPANNULARTODOUBLEGATE. 233.8 0.52,377 19.22 233.82 2,349 129.4 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) RunCsg&Cement WAITINGONCEMENTANDCEMENTCREWSFORTOPJOB,RIGMAINTENANCEPERFORMDOMSAND MONTHLYINSPECTION,SERVICETOPDRIVE,CONT.CLEANINGPITSF/FLUIDSWAP 392.8 0.6 96.7 1.6 FROM TO SurfaceCasing 222.1 295.79 3,159 2,854 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 23.9 13 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Nippleup135/8"BOPE FinishnippleupBOPEandtestto5,000psi.testwitnessbyAOGCCinspector GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/4/22 CUMDRILLCOST:$54,181 BOP 24.0 3383FT/3383FT DAILYDRILLCOST: COSTDATA 7/4/22 ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 12:00 IntermediateDrilling 13:30 06:00 18:00 00:00 4.5 SurfaceCasing CONSUMABLES 6.0 6.0 IntermediateDrilling 00:00 06:00 13:30 12:00 1.5 18:00 0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/17/2022 RPTNUM.:14 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) Surface 9.63 MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: ID# STK N N 4x15 SPM 0milltooth milltooth RK4045 rk4080 0.690 MODELPUMP 2 12.25 smith Smith RPM OUTER: 2 JETS TFASERNO. REͲRUN 12.251 JerryOtto/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:12 RIGSUPERV: NaborsAlaskaDrilling Alkaid 3,375 Conductor 20.00 108 40 l80 3,375 $9,917,961 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/25/22 $9,917,961 IntermediateDrilling 0.818.32 296.1 516.1423.4 5.0 TIMEBREAKDOWN ContinuenippleupBOPE.Fillstackwithwaterandshelltestto2,500psi,goodtest RiginspectionperformedbyMattHerreraAOGCCinspector 18.75 232.97 2,798 SURVEYDATA MD N/S 3,236 323.0 1,894 BHAWT.MUD: ROT.WT.: COORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms NippleUpB.O.P. TestB.O.P. TestB.O.P. TestB.O.P. TestingBOPEperNaborsprocedureandAOGCCandSundryrequirements.250psilow5,000psihigh. annulartest250low2,500psihigh, TestingwitnessedbyAOGCCInspectorMattHerrera Apparentleakingvalveonchokemanifold,investigatedandfoundleakonfittingatwellhead.repairfitting. Testgasalarms TestingwitnessedbyAOGCCInspectorMattHerrera 233.8 0.52,377 19.22 233.82 2,349 129.4 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) NippleUpB.O.P.NippleupBOPE.pickuptestjointandsettestplug, 392.8 0.6 96.7 1.6 FROM TO IntermediateDrilling 222.1 295.79 3,159 2,854 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 9.000 BHA COMPONENT DRILLBITS LENGTHOD INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 23.9 14 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: testingBOPEandgasalarms.TestingwitnessedbyAOGCCInspectorMattHerrera FinishBOPtest,pickupdumbironBHA,RIH,pickingupdrillpipefromshed. GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/18/22 CUMDRILLCOST:$53,906 BOP 24.0 3383FT/3383FT DAILYDRILLCOST: COSTDATA ROPWOB TOTALHRS DULL: LOC: PSI HRS.ONJARS: DAILYONHAND(gal) PHASE 18:00 IntermediateDrilling 23:00 06:00 00:00 05:00 1.0 IntermediateDrilling CONSUMABLES 12.0 1.0 IntermediateDrilling 05:00 06:00 23:00 18:00 5.0 00:00 0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/18/2022 RPTNUM.:15 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) Surface 9.63 MUD OILMf # OPERATIONSCODE NPT COMPONENT OD ID LENGTH LENGTH: MonelCollarͲHWDP 0.690 ID 8.5 6.78 6.63 3.25 XͲOverͲBOTTLENECK 8 # 15 STK 3,408N N 4x14 4x15 345 SPM 3,383MILLTOOTH milltooth RP3683 RK4045 0.601 MODELPUMP 38.50SMITH smith RPM OUTER: 2 JETS TFASERNO. REͲRUN 12.252 JerryOtto/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:13 RIGSUPERV: NaborsAlaskaDrilling Alkaid 3,375 Conductor 20.00 108 40 l80 3,375 $9,986,446 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/25/22 $9,986,446 IntermediateDrilling 0.818.32 296.1 IntermediateDrilling IntermediateDrilling IntermediateDrilling 516.1423.4 03:00 04:00 2.5 TIMEBREAKDOWN Rigdownandlaydowntesttoolsandsetwearring. pickup81/2"dumbironcleanoutassembly. 18.75 232.97 2,798 2.75 5.4 29.71 SURVEYDATA MD N/S 6.5 2.5 1.14 3,236 323.0 1,894 BHAWT.MUD: ROT.WT.: 747.25 COORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms IntermediateDrilling 05:00 Continuetodrillcementfrom3,350'anddrillfloatshoe@3,375', TestB.O.P. Trips Trips CondMud&Circ Trips Drilling CondMud&Circ Drilling Pickup4"dp,RIHwithBHA#4 Continuepickingup4"drillpipefrom1,900'tocementtag@3,263' Testcasingto3,500psi.goodtest. Drillcementtofloatcollar@3,288',drillfloatcollarandcementto3,350' 1,000psi@345gpm,60rpm,95Kup,80Kdn,3to5Ktorque. Circulateoutthickcementcontaminated(peanutbutter)mud. 233.8 0.52,377 19.22 233.82 2,349 129.4 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) TestB.O.P. TestingBOPEperGreatBearPantheonandAOGCCrequirements.TestingwitnessedbyAOGCCInspector MattHerrera 392.8 0.6 96.7 1.6 FROM TO IntermediateDrilling 222.1 295.79 3,159 2,854 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 0.82 9.000 BHA 29.9 2.98 2.75 53 5.12 9 10 DrillPipe COMPONENT IntermediateDrilling 6.75 DRILLBITS 27.516.88 LENGTHOD 25 INTYPE HRSDRLG: drillingsupervisor@greatbearpetro.com 23.9 15 3.525 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Performleakofftest@3,408' Completeleakofftest,POHlaydowndumbBHA#4,PickupdrillingBHA#5,RIHpickingup4"drillpipefromshed.Drillahead. GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/18/22 CUMDRILLCOST:$53,906 BOP 24.0 3408FT/3317FT DAILYDRILLCOST: COSTDATA 6.5 ROPWOB TOTALHRS 521.22 2.75 91.82.83 DULL: LOC: PSI 7 31.65 6.75 2.75 6.76 2.88 HRS.ONJARS: 2.0 DAILYONHAND(gal) PHASE 1.005:00 12:30 IntermediateDrilling 14:30 23:30 06:00 16:30 19:00 03:00 03:30 2.0 IntermediateDrilling 0.5 1.501:00 1.0 35 CONSUMABLES 6.5 6 IntermediateDrilling 01:00 4.5 IntermediateDrilling19:00 06:00 14:30 12:30 2.0 23:30 0.503:30 04:00 16:30 MonelCollar JarͲHYDRAJAR DrillPipeͲHWDP 0 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver GPSGPMLINER 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 1000 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/19/2022 RPTNUM.:16 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER CAKEPH PfMWTIME FV WL GELS(10s/10m/30m) Surface 9.63 MUD OILMf # 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲmilltooth SubͲBITSUB StabilizerͲNMSTAB MonelCollarͲNM Stabilizer 11 COMPONENT OD ID LENGTH LENGTH: Drillcementf/3,375'tobottom@3,383',drill20'newholeto3,408' 1,000psi@345gpm,60rpm,95Kup,80Kdn,3to7Ktorque. Circulateconditionmud,evenmudweight@9.8#. Drilling CondMud&Circ 11 SubͲFLOATSUB 0.601 ID 8.5 91.8 6.82 7.45 3.88 SubͲFilterSub 8 # 103.05 STK 3,511N N 5x12 4x14 500 SPM 25 3,408PDC MILLTOOTH JP4545 RP3683 0.552 MODELPUMP 48.50Smith SMITH RPM OUTER: 2 JETS TFASERNO. REͲRUN 8.503 MarkBrouillet/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:14 RIGSUPERV: NaborsAlaskaDrilling Alkaid 3,375 l80Conductor 20.00 108 40 80 l80 3,375 $10,100,270 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/25/22 $10,100,270 IntermediateDrilling 0.818.32 296.1 IntermediateDrilling IntermediateDrilling IntermediateDrilling 516.1423.4 21:00 00:00 2.0 TIMEBREAKDOWN POHwithBHA#4 Cleaningpits PerformLOTestablish13.9EMW.chartandgraphdata. Cleaningpits 18.75 232.97 2,798 3.88 25.83 34.39 98 SURVEYDATA MD N/S 6.75 5 2.5 12 DrillPipeͲHWDP 7.75 3,236 323.0 1,894 BHAWT.MUD: 81/2"PHDrillingSmartBHA ROT.WT.:100 872.26 1.0 COORDINATES TORQUE: 79.1 194.8 1,901 13.16 240.48 BHAWT.AIR: INCLINATION 5P.U.WT.:90S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms IntermediateDrilling IntermediateDrilling 03:00 Pump,fillpipeforShallowtestMWDtools.Mudtoothicktogothroughshakers,changeshakerscreensto 50mesh,circandperformshallowMWDtest,goodtest. Trips Other Trips Trips Trips Trips Trips CondMud&Circ POHstandingback4"drillpipeand5"HWDP. Cleaningpits LaydownBHA#4,clearandcleanfloor Cleaningpits Pickup"smart"drillingBHA#5 Cleaningpits ContinuePickup"smart"drillingBHA#5,RIHwith5"HWDPt/872' Cleaningpits RIHwithBHA#5,pickingupanddrifting4"drillpipefromshedt/1,540' Cleaningpits 233.8 0.52,377 19.22 233.82 2,349 129.4 54.7 DAILYRECEIVED(gal) DAILYUSED(gal) CondMud&Circ Circulate,changeovermudfrom9.8spudmudto9.2KlayͲShielddrillingmud. Cleaningpits 392.8 0.6 96.7 1.6 FROM TO IntermediateDrilling 222.1 295.79 3,159 2,854 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 0.8 9.000 BHA 16.81 25.1 2.75 6.75 2.75 25.99 9 10 MonelCollarͲNM COMPONENT IntermediateDrilling 9.6 6.75 DRILLBITS 2.666.75 LENGTHOD 1.0 28 103 14 INTYPE 18 HRSDRLG: drillingsupervisor@greatbearpetro.com 23.9 16 1103 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Drilling81/2"pilothole Drillaheadperdirectionalplan GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/18/22 CUMDRILLCOST:$57,626 BOP 24.0 3511FT/3421FT DAILYDRILLCOST: COSTDATA 6.88 ROPWOB TOTALHRS 3:00 27.51 2.75 29.9 153,408 5.16 DULL: LOC: PSI 7 29.71 6.91 3.88 6.91 3.88 48 HRS.ONJARS: 3.0 DAILYONHAND(gal) PHASE 3.0 1.006:00 03:00 05:00 10:30 IntermediateDrilling 11:00 16:00 04:00 12:00 14:00 21:00 22:00 IntermediateDrilling 1.0 IntermediateDrilling 1.0 2.018:00 1.0 1.0 2.756.88 CONSUMABLES 04:00 4.5 6 IntermediateDrilling 18:00 2.0 IntermediateDrilling 05:00 14:00 06:00 11:00 10:30 0.5 16:00 2.022:00 00:00 12:00 MWDToolͲSonicSCOPE MonelCollar MonelCollar 3,383 AVDC GAUGE: 98 OTHER: AVDPEFF% 98 GardnerDenver 2100 GPSGPMLINER 500 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 2100 6.000 9.000 PUMPS ECD BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/20/2022 RPTNUM.:17 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER 9.3 CAKEPH Pf 18 MWTIME FV WL GELS(10s/10m/30m) Surface 9.63 MUD OILMf # 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲPDC StabilizerͲXceed StabilizerͲEcoScope LWDToolͲMicroScope LWDToolͲTeleScope 11 COMPONENT OD ID LENGTH 56LENGTH: ContinueRIHwithBHA#5,pickingupanddrifting4"drillpipefromshedf/1,540't/3,342 Cleaningpits,changescreensbackto120mesh Washanddrillfrom3,342'to3,437' Cleaningpits CirculateanddownlinkMWDtools Cleaningpits Drillingnew81/2"holefrom3,437'to3,511' 500gpm@2100psi,5kwob,4to5Ktorque,100kupwt,90kdnwt,98krot. Cleaningpits Trips Reaming DeviationSurvey Drilling 11 56LENGTH: StabilizerͲXceed StabilizerͲEcoScope LWDToolͲMicroScope LWDToolͲTeleScope 11 COMPONENT OD ID# 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲPDC TIME FV WL GELS(10s/10m/30m) Surface 9.63 MANUFACTURER 9.6 61.0 6.0 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/21/2022 RPTNUM.:18 RIG:Rig105E DAILYDRILLINGREPORT ECD 226 849 226 BITHHP RP: GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 2100 6.000 9.000 PUMPS GardnerDenver 2100 GPSGPMLINER 250 98 10.19 OTHER: AVDPEFF% 00:00 MWDToolͲSonicSCOPE MonelCollar MonelCollar 849 3,383 AVDC GAUGE: 06:00 18:00 12:00 6.0 2.756.88 CONSUMABLES 6.0 6 6.0 IntermediateDrilling 18:00 00:00 06:00 PHASE 12:00 29.71 6.91 3.88 6.91 3.88 48 HRS.ONJARS: DAILYONHAND(gal) 29.9 153,408 5.16 DULL: LOC: PSI 7 HTHPPf 18 MW 19:00 27.51 OIL 2.756.88 ROPWOB TOTALHRS 24.0 4787FT/4637FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/18/22 CUMDRILLCOST:$55,626 BOP COSTDATA MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 180 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Drilling81/2"pilothole Drillt/6,500'shorttrip Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 23.9 17 241276 EMAIL: 30 3,974 131 0.60 4009.3 6.75 DRILLBITS 33,000 2.666.75 LENGTHOD 25.0 COMPONENTLENGTH BHA 16.81 25.1 2.75 6.75 2.75 25.99 9 10 DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 0.8 9.000 FROM TO IntermediateDrilling HRS CONSUMABLE DAILYRECEIVED(gal) DAILYUSED(gal) Drilling DrillingF/3,437'MD3,351'TVD.ͲT/4,008'MDͲ3,897'TVD.W.O.B.5kͲ8k.70Ͳ100rpm,Torque9k.550 gpm2,050psi. IntermediateDrilling 20 2 Drillingf/4,713'to4,787'W.O.B.10kͲ20k,.70Ͳ150rpm,Torque0t/16k.550gpm1,650psi. Drilling Drilling Drilling www.wellez.comWellEzOnDemandver_102920ms 8P.U.WT.:105S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION 1.0 COORDINATES TORQUE: BHAWT.AIR: INCLINATION 7.75 BHAWT.MUD: 81/2"PHDrillingSmartBHA ROT.WT.:115 872.26 6.75 5 2.5 12 DrillPipeͲHWDP3.88 25.83 34.39 115 SURVEYDATA MD N/S 6.0 TIMEBREAKDOWN Drillingf/4,008'to4,670',W.O.B.5kͲ8k.70Ͳ100rpm,Torque9k.550gpm2,050psi. Drillingf/4,670t/4,713'.W.O.B.10kͲ15k.,70Ͳ125rpm,Torque0t/16k.550gpm1,650psi. IntermediateDrilling $10,168,171 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/25/22 $10,168,171 l80Conductor 20.00 108 40 105 l80 3,383 3,375 WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:15 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUN 8.503 TYPE MAKE MODELPUMP 48.50Smith SMITH MonelCollarͲNM 16 10.1998250 SPM 25 0.50 3,511PDC MILLTOOTH JP4545 RP3683 159.010 STK 7,485N N 5x12 4x14 0.552 0.601 ID 8.5 91.8 6.82 7.45 3.88 SubͲFilterSub 8 # SubͲFLOATSUB 11 SubͲFLOATSUB 0.601 ID 8.5 91.8 6.82 7.45 3.88 SubͲFilterSub 8 # 23.710 STK 5,208N N 5x12 4x14 250 SPM 25 0.50 4,615PDC MILLTOOTH JP4545 RP3683 0.552 MODELPUMP 48.50Smith SMITH RPM OUTER: 2 JETS TFASERNO. REͲRUN 8.503 MarkBrouillet/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:16 RIGSUPERV: NaborsAlaskaDrilling Alkaid 3,375 l80Conductor 20.00 108 40 105 l80 3,383 $10,302,789 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/25/22 $10,302,789 IntermediateDrilling 2.219.67 1,042.5 8.0 TIMEBREAKDOWN Drillingfrom5,056'to5,208'.122Kup,120Kdn,121Krot,550gpm,2000psi,38Kwob,150rpm,10Ͳ17K torque. Circ,downlinkMWDtools. 17.77 235.95 4,728 3.88 25.83 34.39 SURVEYDATA MD N/S 6.75 5 2.5 12 DrillPipeͲHWDP 7.75 4,971 4,541 BHAWT.MUD: 81/2"PHDrillingSmartBHA ROT.WT.: 872.26 27.8 COORDINATES TORQUE: 4,689 13.88 229.63 BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms Drilling DeviationSurvey Trips DirWork POHonelevators.t/200'.Worktightpipe@4,518',3,810'and3,760'.Breakingtighttooljoint connections. RackBackHWDP&Jars,Standbackdrillcollars,Laydown2LWDloggingtools(XceedandEcoScope), PJSM,Pullsources,PulltobitexamineBHA,DownloadTooldata. 984.9 2.34,782 16.05 229.87 4,632 DAILYRECEIVED(gal) DAILYUSED(gal) Drilling Drillingfrom4,784't/5,056'Dn,110,113rotwt.115.500gpm@2000psi.35Kwob,5to12Ktorque 150rpm. 1,013.9 2.5 960.8 3.8 FROM TO IntermediateDrilling 235.12 4,812 4,882 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO. INNER: 3.25 0.8 9.000 BHA 16.81 25.1 2.75 6.75 2.75 25.99 9 10 MonelCollarͲNM COMPONENT 9.6 6.75 DRILLBITS 2.666.75 LENGTHOD 25.0 25 593 131 0.60 29,000 INTYPE 15 HRSDRLG: drillingsupervisor@greatbearpetro.com 23.9 18 12.5421 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 180 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: PickingupBHAdownloadMWD Runinholeresumedrilling. GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/18/22 CUMDRILLCOST:$55,456 BOP 24.0 5208FT/5034FT DAILYDRILLCOST: COSTDATA 6.88 ROPWOB TOTALHRS 15:00 27.51 2.75 240.00 29.9 153,408 5.16 DULL: LOC: PSI 7 29.71 6.91 3.88 6.91 3.88 HRS.ONJARS: DAILYONHAND(gal) PHASE 12:00 IntermediateDrilling 18:30 05:30 18:30 02:30 0.5 IntermediateDrilling 2.756.88 CONSUMABLES 6.0 6 3.0 IntermediateDrilling 02:30 06:00 18:00 12:00 6.5 18:30 MWDToolͲSonicSCOPE MonelCollar MonelCollar 849 3,383 AVDC GAUGE: 98 10.19 OTHER: AVDPEFF% 10.1998 GardnerDenver 2100 GPSGPMLINER 250 6.000 MAKE GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 2100 6.000 9.000 PUMPS ECD 226 849 226 BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/22/2022 RPTNUM.:19 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER 9.3 59.0 5.4 CAKEPH Pf 13 MWTIME FV WL GELS(10s/10m/30m) Surface 9.63 MUD OILMf # 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲPDC StabilizerͲXceed StabilizerͲEcoScope LWDToolͲMicroScope LWDToolͲTeleScope 11 COMPONENT OD ID LENGTH LENGTH: 11 SubͲFLOATSUB ID 8.5 91.8 6.82 7.45 3.88 SubͲFilterSub 8 # 16.210 STK 5,435N N 6x12 275 SPM 0.50 5,208PDC JP2456 0.663 MODELPUMP 68.50Smith RPM OUTER: 2 JETS TFASERNO. REͲRUN 5 RO MarkBrouillet/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:17 RIGSUPERV: NaborsAlaskaDrilling Alkaid 3,375 l80Conductor 20.00 108 40 105 l80 3,383 $10,358,245 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/25/22 $10,358,245 IntermediateDrilling 2.219.67 1,042.5 7.5 TIMEBREAKDOWN RIHwithbit#5to5,158' CheckMWDtools,washandreamf/5,158to5,208' 17.77 235.95 4,728 3.88 25.83 34.39 139 SURVEYDATA MD N/S 6.75 5 2.5 12 DrillPipeͲHWDP 7.75 4,971 4,541 BHAWT.MUD: 81/2"PHDrillingSmartBHA2 ROT.WT.:128 872.32 40.0 COORDINATES TORQUE: 4,689 13.88 229.63 BHAWT.AIR: INCLINATION 8,000P.U.WT.:122S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms Trips DirWork Drilling Drilling Drilling81/2"pilotholef/5,208t/5,302',3to15Kwob,180rpm,137upwt,105Kdnwt,113rotwt.550 gpm@2100psi. Drillingf/5,302t/5,632'.12wob,175rpm,torque8K,540gpm@2150psi,138upwt,106Kdnwt,115 rotwt. 984.9 2.34,782 16.05 229.87 4,632 DAILYRECEIVED(gal) DAILYUSED(gal) DirWork PickupdrillingBHA,makeupbit#5,swapoutMWDtools 1,013.9 2.5 960.8 3.8 FROM TO IntermediateDrilling 235.12 4,812 4,882 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO.4 INNER: 3.25 0.88 9.000 BHA 16.81 25.03 2.75 6.75 2.75 26.04 9 10 MonelCollarͲNM COMPONENT 9.6 6.75 DRILLBITS 29,000 2.666.75 LENGTHOD 14.0 27 227 131 0.60 240 INTYPE 15 HRSDRLG: drillingsupervisor@greatbearpetro.com 21.14 19 13.5424 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 180 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Drilling81/2"pilotholesection Drillahead GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/18/22 CUMDRILLCOST:$55,456 BOP 24.0 5632FT/5435FT DAILYDRILLCOST: COSTDATA 6.88 ROPWOB PR TOTALHRS 3:00 27.51 2.75 29.95.16 DULL: LOC:1 PSI 7 29.71 6.91 3.88 6.84 3.88 48 HRS.ONJARS: DAILYONHAND(gal) PHASE 11:30 IntermediateDrilling 16:00 06:00 16:30 00:00 0.5 IntermediateDrilling 2.756.88 CONSUMABLES 5.5 6 6.0 IntermediateDrilling 00:00 06:00 16:00 11:30 4.5 16:30 MWDToolͲSonicSCOPE MonelCollar MonelCollar 849 5,208 AVDC GAUGE: 98 10.19 828 OTHER: AVDPEFF% 10.1998 828 GardnerDenver 85 2000 GPSGPMLINER 275 6.000 MAKE 3 GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 85 2000 6.000 9.000 8 PUMPS ECD 226 849 226 BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/23/2022 RPTNUM.:20 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER 9.3 51.0 5.4 CAKEPH Pf 14 MWTIME FV WL GELS(10s/10m/30m) Surface 9.63 MUD OILMf # 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲPDC StabilizerͲXceed StabilizerͲEcoScope LWDToolͲMicroScope LWDToolͲTeleScope 11 COMPONENT OD ID LENGTH 56LENGTH: 11 SubͲFLOATSUB ID 8.5 91.8 6.82 7.45 3.88 SubͲFilterSub 8 # 97.020 STK 7,439N N 6x12 275 SPM 0.50 5,208PDC JP2456 0.663 MODELPUMP 68.50Smith RPM OUTER: 2 JETS TFASERNO. REͲRUN 5 RO MarkBrouillet/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:18 RIGSUPERV: NaborsAlaskaDrilling Alkaid 3,375 l80Conductor 20.00 108 40 105 l80 3,383 $10,510,945 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/25/22 $10,510,945 IntermediateDrilling 0.318.41 Ͳ750.8 1,320.9Ͳ1,086.9 6.0 TIMEBREAKDOWN Drillingfrom6,010'to6581/550gpm@2,150psi,170rpm,Bitwt.26k.Torque8kaverage.Upwt.158k, Downwt.120k.Rotwt.125k. Drillingfrom6,581'to7,039'/550gpm@2,200psi,170rpm,Bitwt.22k.Torque8kaverage.Upwt. 165k,Downwt.125k.Rotwt.135k. 18.61 227.03 5,534 3.88 25.83 34.39 125 SURVEYDATA MD N/S 6.75 5 2.5 12 DrillPipeͲHWDP 7.75 5,831 Ͳ1,064.6 5,353 BHAWT.MUD: 81/2"PHDrillingSmartBHA2 ROT.WT.:158 872.32 56.0 COORDINATES TORQUE: Ͳ1,019.4 Ͳ1,042.5 5,544 18.68 231.20 BHAWT.AIR: INCLINATION 8P.U.WT.:120S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms Drilling Drilling Drilling Drillingfrom7,039'to7,439'/550gpm@2350psi,170rpm,Bitwt.20k.Torque9kaverage.Upwt. 185k,Downwt.130k.Rotwt.150k. 1,260.9 1.65,640 18.59 226.32 5,444 Ͳ709.3 Ͳ689.0 DAILYRECEIVED(gal) DAILYUSED(gal) Drilling DrillF/5,632'MD5,436'TVD.ͲT/6,010'MD5,794'TVD.Flowrate550gpm,Pressure2,150psi,Flowout 40%.Rotaryspeed170rpm,Bitwt.26k.Torque8kaverage.Upwt.158k,Downwt.120k.Rotwt.125k. 1,291.0 0.2 1,230.4 0.5 FROM TO IntermediateDrilling Ͳ730.2 227.42 5,625 5,736 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO.4 INNER: 3.25 0.88 9.000 BHA 16.81 25.03 2.75 6.75 2.75 26.04 9 10 MonelCollarͲNM COMPONENT 9.7 6.75 DRILLBITS 31,000 2.666.75 LENGTHOD 23.0 29 2,231 131 0.60 220 INTYPE 16 HRSDRLG: drillingsupervisor@greatbearpetro.com 21.14 20 241807 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 180 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: Drilling Drillaheadpergeology GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/18/22 CUMDRILLCOST:$55,456 BOP 24.0 7439FT/7151FT DAILYDRILLCOST: COSTDATA 6.88 ROPWOB PR TOTALHRS 3:00 27.51 2.75 29.95.16 DULL: LOC:1 PSI 7 29.71 6.91 3.88 6.84 3.88 48 HRS.ONJARS: DAILYONHAND(gal) PHASE 12:00 IntermediateDrilling 18:00 00:00 06:00 6.0 IntermediateDrilling 2.756.88 CONSUMABLES 6.0 6 06:00 18:00 12:00 6.0 00:00 MWDToolͲSonicSCOPE MonelCollar MonelCollar 849 5,208 AVDC GAUGE: 98 10.19 828 OTHER: AVDPEFF% 10.1998 828 GardnerDenver 85 2000 GPSGPMLINER 275 6.000 MAKE 3 GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 85 2300 6.000 9.000 8 PUMPS ECD 226 849 226 BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/24/2022 RPTNUM.:21 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER 9.2 56.0 5.4 CAKEPH Pf 14 MWTIME FV WL GELS(10s/10m/30m) Surface 9.63 MUD OILMf # 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲPDC StabilizerͲXceed StabilizerͲEcoScope LWDToolͲMicroScope LWDToolͲTeleScope 11 COMPONENT OD ID LENGTH 56LENGTH: 10 LENGTH: StabilizerͲXceed StabilizerͲEcoScope LWDToolͲMicroScope LWDToolͲTeleScope 11 COMPONENT OD ID# 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲPDC TIME FV WL GELS(10s/10m/30m) Surface 9.63 MANUFACTURER 9.3 62.0 6.8 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/25/2022 RPTNUM.:22 RIG:Rig105E DAILYDRILLINGREPORT ECD 226 849 226 BITHHP RP:3 GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 85 2550 6.000 9.000 8 PUMPS GardnerDenver 85 2500 GPSGPMLINER 250 98 10.19 828 OTHER: AVDPEFF% 22:00 MWDToolͲSonicSCOPE MonelCollar MonelCollar 849 5,208 AVDC GAUGE: 23:00 06:00 18:00 12:00 6.0 00:00 2.756.88 CONSUMABLES 6.0 6 IntermediateDrilling 05:30 1.0 IntermediateDrilling 4.0 IntermediateDrilling 5.505:30 18:00 00:00 22:00 23:00 06:00 PHASE 12:00 29.71 6.91 3.88 6.84 3.88 HRS.ONJARS: 0.5 DAILYONHAND(gal) 29.95.16 DULL: LOC:1 PSI 7 HTHPPf 14 MW 3:00 27.51 OIL 2.756.88 ROPWOB PR TOTALHRS 24.0 8950FT/8584FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/18/22 CUMDRILLCOST:$55,456 BOP COSTDATA MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 180 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: CirculateholecleanatTD Circulateholeclean,POH,TestBOPEperSundry Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 21.14 21 22.51511 EMAIL: 26 2,231 131 0.60 2609.8 6.75 DRILLBITS 31,000 2.666.75 LENGTHOD 23.0 COMPONENTLENGTH BHA 16.81 25.03 2.75 6.75 2.75 26.04 9 10 DESCRIPTION: PUMPHHP SEAL:BITNO.4 INNER: 3.25 0.88 9.000 FROM TO IntermediateDrilling Ͳ972.9 230.43 6,982 7,165 HRS CONSUMABLE Ͳ937.9 DAILYRECEIVED(gal) DAILYUSED(gal) Drilling DrillF/7,439'MDͲT/7,855'MDͲ7,546TVD. Flowin550GPM,2,550PSI,Rotary175RPM,Torque12k. WOB21k. UpWt.215k,Downwt.133kRotwt.153k. 1,738.2 0.8 IntermediateDrilling 1,678.0 0.3 1,707.8 0.67,069 18.56 234.92 6,800 Ͳ954.9 Circulategas,flowcheck,servicetopdrive Drillingfrom8,488'to8,583' 13kwob,175rpm,13ktorque500gpm@2,600psi Drillingfrom8,583'toEdDunkinTDofPilotHole@8,950MD8,584TVD.240Kup,135Kdn.170Krot12K torque@90rpm,500gpm@2,550psi. Circulateandconditionholecleanfortripout. Drilling Drilling CondMud&Circ Drilling Drilling CondMud&Circ www.wellez.comWellEzOnDemandver_102920ms P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION 56.0 COORDINATES TORQUE: Ͳ1,391.5 Ͳ1,415.9 6,974 18.02 235.15 BHAWT.AIR: INCLINATION 7.75 7,261 Ͳ1,440.4 6,710 BHAWT.MUD: 81/2"PHDrillingSmartBHA2 ROT.WT.: 872.32 6.75 5 2.5 12 DrillPipeͲHWDP 18.44 232.49 6,891 3.88 25.83 34.39 SURVEYDATA MD N/S 1.0 TIMEBREAKDOWN Drillingfrom7,855'to8,279'.500gpm@2,000psi.225kup,135kdn,160rot,550gpm@2,250psi.21k wob,torque12k. Drillingfrom8,279'to8,488'observeddrillingbreakcircout2,900unitstotalgas. Addingdefoamtocontrolmudaircutaffectingpumppressure.Dilutingmudwith250bbl8.8#wholemud. 13kwob,175rpm,13ktorque,500gpm@2,600psi IntermediateDrilling 0.718.55 Ͳ991.8 IntermediateDrilling 1,768.5Ͳ1,464.2 $13,175,141 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:7/25/22 $13,175,141 l80Conductor 20.00 108 40 105 80 l80 3,383 3,375 WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:19 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUN 5 RO TYPE MAKE MODELPUMP 68.50Smith MonelCollarͲNM 15 10.1998 828250 SPM 0.50 5,208PDC JP2456 97.020 STK 7,439N N 6x12 0.663 ID 8.5 91.8 6.82 7.45 3.88 SubͲFilterSub 8 # SubͲFLOATSUB 10 SubͲFLOATSUB 0.552 ID 8.5 91.8 6.82 7.45 3.88 SubͲFilterSub 8 # 467.825 STK 8,950N N 6x12 5x12 250 SPM 1,800 0.50 5,208PDC PDC XS616 JP4545 0.660 MODELPUMP 58.50Smith Smith RPM OUTER: 2 JETS TFASERNO. REͲRUN 8.504 MarkBrouillet/PaulSmith FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:20 RIGSUPERV: NaborsAlaskaDrilling Alkaid 3,375 l80Conductor 20.00 108 40 105 80 l80 3,383 $13,268,208 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:8/2/22 $13,268,208 IntermediateDrilling 0.120.60 Ͳ1,276.3 IntermediateDrilling IntermediateDrilling IntermediateDrilling 2,303.0Ͳ1,917.2 18:00 23:00 1.0 TIMEBREAKDOWN MonitorwellforflowͲstatic.Pulledfrom8,950'MDto8,510'onelevators.Pumped2lbs.overdryjob. Trippedonelevatorsworkingareasofconcernuntilnooverpullnoted. EncounteredtightspotworkedthroughareaF/5,845'ͲT/5,640with550gpm2,150psi.140rpm.Backream thestandshutdownpump.runstandbackdowntorigfloorandpulltotopofstand,Rackbackwithno overpullnoted. 20.64 236.79 8,506 3.88 25.83 34.39 SURVEYDATA MD N/S 6.75 5 2.5 12 DrillPipeͲHWDP 7.75 8,950 Ͳ1,892.8 8,457 BHAWT.MUD: 81/2"PHDrillingSmartBHA2 ROT.WT.: 872.32 40.0 COORDINATES TORQUE: Ͳ1,877.7 Ͳ1,886.8 8,815 18.79 238.30 BHAWT.AIR: INCLINATION P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION www.wellez.comWellEzOnDemandver_102920ms IntermediateDrilling .Standback5"HWDPoutofwayfortripinwithdrillpipeonlytocement.Laydown81/2"smartBHA. Trips Reaming Trips Reaming Trips CondMud&Circ Trips DirWork 5,640'to5,415'pulledonelevatorsworkingareaofoverpullsuntilsatisfied. BackreamF/5,415'ͲT/5,200'140rpm,2100psi550gpm. PulloutofholeF/5,200'ͲT/3,380'Insidecasingshoe.Assemblypulledwithnodifficultythroughthese depths. Circulatebottomsup.Monitorwellforflowatcasingshoe. Pulloutofholeto747'(BHA) 2,266.8 4.58,847 20.20 239.05 8,487 Ͳ1,256.6 Ͳ1,251.0 DAILYRECEIVED(gal) DAILYUSED(gal) CondMud&Circ Continuecirculatetocleanholeandconditionmudfortripout. 2,273.9 4.4 2,256.2 1.9 FROM TO IntermediateDrilling Ͳ1,260.3 236.79 8,584 8,867 HRS CONSUMABLE DESCRIPTION: PUMPHHP SEAL:BITNO.5 INNER: 3.25 0.88 9.000 BHA 16.81 25.03 2.75 6.75 2.75 26.04 9 10 MonelCollarͲNM COMPONENT 9.6 6.75 DRILLBITS 29,500 2.666.75 LENGTHOD 8.0 24 3,742 131 0.65 160 INTYPE 15 HRSDRLG: drillingsupervisor@greatbearpetro.com 21.14 22 EMAIL: 24HRFTG: CL LGSKPV CaYP MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 180 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: testingBOPE TestBOPE,RigupSLBforEͲlinecoresamples, GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/26/22 CUMDRILLCOST:$55,456 BOP 24.0 8950FT/8584FT DAILYDRILLCOST: COSTDATA 7/25/22 6.88 25.0 ROPWOB TOTALHRS 21:00 72.0 27.51 2.75 29.9 105,208 5.16 DULL: LOC:I PSI 7 29.71 6.91 3.88 6.84 3.88 HRS.ONJARS: 0.5 DAILYONHAND(gal) PHASE 7.006:00 07:30 IntermediateDrilling 12:30 16:00 14:30 15:30 18:00 20:00 2.0 IntermediateDrilling 2.0 1.517:30 2.756.88 CONSUMABLES 1.5 6 IntermediateDrilling 17:30 0.5 IntermediateDrilling15:30 06:00 12:30 07:30 5.0 16:00 3.020:00 23:00 14:30 MWDToolͲSonicSCOPE MonelCollar MonelCollar 849 3,408 AVDC GAUGE: 98 10.19 828 OTHER: AVDPEFF% 10.1998 828 GardnerDenver 85 2500 GPSGPMLINER 250 6.000 MAKE 1 GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 85 2550 6.000 9.000 2 PUMPS BT ECD 226 849 226 BITHHP RP: 1 WELL/JOBINFORMATION RPTDATE:7/26/2022 RPTNUM.:23 RIG:Rig105E DAILYDRILLINGREPORT OD MD TVDWEIGHT NO. SIZE FEET HRSOUT HTHP MANUFACTURER 9.4 51.0 6.8 CAKEPH Pf 18 MWTIME FV WL GELS(10s/10m/30m) Surface 9.63 MUD OILMf # 1 2 3 OPERATIONSCODE NPT 4 5 DrillBitͲPDC StabilizerͲXceed StabilizerͲEcoScope LWDToolͲMicroScope LWDToolͲTeleScope 11 COMPONENT OD ID LENGTH LENGTH: Fluidpackandtestingchokemanifold,pullrearring,settestplug,TestBOPEperAOGCCsundryandGBP expectations.testannular250/2,500psi,allothertests250lowand4,800psihigh,chartandrecordtests. Upper4"fixedborepiperansfailedtotesthighpressuretest,opendoorschangeramsandretest, TestB.O.P. 10 LENGTH: COMPONENT OD ID# 1 OPERATIONSCODE NPT DrillPipeͲMuleShoe TIME FV WL GELS(10s/10m/30m) Surface 9.63 MANUFACTURER 9.4 53.0 7.0 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/27/2022 RPTNUM.:24 RIG:Rig105E DAILYDRILLINGREPORT BT ECD BITHHP RP:1 GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 6.000 9.000 2 PUMPS GardnerDenver GPSGPMLINER 96 OTHER: AVDPEFF% 00:00 3,408 AVDC GAUGE:N 05:30 06:00 12:00 08:30 3.5 CONSUMABLES 2.5 0.5 IntermediateDrilling 12.0 IntermediateDrilling 12:00 06:00 00:00 05:30 PHASE 08:30 HRS.ONJARS: DAILYONHAND(gal) 105,208 DULL: LOC:XI PSI HTHPPf 16 MW 21:00 72.0 OIL 7.00 25.0 ROPWOB TD TOTALHRS 24.0 8950FT/8584FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/26/22 CUMDRILLCOST:$53,581 BOP COSTDATA 7/25/22 MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 180 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: POOHwithwirelineRigwireliners@)6:00 Rigdownwireliners,MakeupcementmuleshoeRihinholetoTD,Rigupcementersstartplugbackoperations Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 21.14 23 EMAIL: 22 3,742 101 7.009.9 DRILLBITS LENGTHOD 8.0 COMPONENTLENGTH BHA DESCRIPTION: PUMPHHP SEAL:BITNO.5 INNER: 3.34 20.7 9.000 FROM TO IntermediateDrilling Ͳ1,260.3 236.79 8,584 8,867 HRS CONSUMABLE Ͳ1,251.0 DAILYRECEIVED(gal) DAILYUSED(gal) TestB.O.P. Rebuildtopset4"rams.250psi.low4,800'PSI.Goodtest.RigdownfromBOPtest.Pulltestplugset10Ͳ 1/8"IDwearbushing. 2,273.9 4.4 IntermediateDrilling 2,256.2 1.9 2,266.8 4.58,847 20.20 239.05 8,487 Ͳ1,256.6 Continuesidewallcoringcompleteat05:30 POOHwithwirerlinesidecoretools Other Coring Coring Other www.wellez.comWellEzOnDemandver_102920ms P.U.WT.: S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION 40.0 COORDINATES TORQUE: Ͳ1,877.7 Ͳ1,886.8 8,815 18.79 238.30 BHAWT.AIR: INCLINATION 8,950 Ͳ1,892.8 8,457 BHAWT.MUD: 81/2"PHDrillingSmartBHA2 ROT.WT.: 20.70 20.64 236.79 8,506 SURVEYDATA MD N/S 5.5 TIMEBREAKDOWN RigUpSLBWirelineforsidewallcorerun.Testtools.Goodtest. Runcoringtoolinholetobottom.Corelatedepth.startsidewallcoring IntermediateDrilling 0.120.60 Ͳ1,276.3 2,303.0Ͳ1,917.2 $13,752,431 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:8/2/22 $13,752,431 l80Conductor 20.00 108 40 105 80 LͲ80,l80 3,383 3,375 WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:21 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/PaulSmith/JerryOtto FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUN 8.504 CT TYPE MAKE MODELPUMP 58.50Smith Smith 15 96 SPM 1,800 6.00 5,208PDC PDC XS616 JP4545 467.825 STK 8,950N N 6x12 5x12 0.660 0.552 ID 4 # 11 PlugBack PlugBack PlugBack LENGTH: PulloutofCement6800t/6550slow5perstand CirculationAndconditionClearDPandwellofexcesscement POOHwithMuleshoeassembly COMPONENT OD ID# 1 OPERATIONSCODE NPT DrillPipeͲMuleShoe TIME FV WL GELS(10s/10m/30m) Surface 9.63 MANUFACTURER 2.009.5 53.0 6.9 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/28/2022 RPTNUM.:25 RIG:Rig105E DAILYDRILLINGREPORT BT ECD BITHHP RP:1 GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 1300 6.000 9.000 2 PUMPS GardnerDenver 1300 GPSGPMLINER 300 96 OTHER: AVDPEFF% 12:00 3,408 AVDC GAUGE:N 18:00 06:00 09:30 06:30 3.0 19:00 2.521:30 00:00 CONSUMABLES 03:00 0.5 IntermediateDrilling 19:30 1.0 IntermediateDrilling IntermediateDrilling 2.5 IntermediateDrilling 1.5 0.519:30 09:30 19:00 03:00 12:00 18:00 20:00 21:30 1.5 3.0 PHASE 1.501:30 06:00 06:30 HRS.ONJARS: 0.5 DAILYONHAND(gal) 105,208 DULL: LOC:XI PSI HTHPPf 20 MW 21:00 72.0 OIL 6.901.70 25.0 ROPWOB TD TOTALHRS 24.0 8850FT/8584FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/26/22 CUMDRILLCOST:$53,581 BOP COSTDATA 7/25/22 MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 180 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: POOHw/Plugbackcementassembly RIHpickinguppipefornextsection,tagcementplugcementjobnumber2ifneeded Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 21.14 24 EMAIL: 23 3,742 111 0.709.6 DRILLBITS 29,000 LENGTHOD 8.0 COMPONENT IntermediateDrilling LENGTH BHA DESCRIPTION: PUMPHHP SEAL:BITNO.5 INNER: 3.34 20.4 9.000 FROM TO IntermediateDrilling Ͳ1,260.3 536 236.79 8,584 8,867 HRS CONSUMABLE Ͳ1,251.0 DAILYRECEIVED(gal) DAILYUSED(gal) Coring POOHw/openholesidecore 2,273.9 4.4 IntermediateDrilling 2,256.2 1.9 2,266.8 4.58,847 20.20 239.05 8,487 Ͳ1,256.6 Tripinholeto8950Breakcirtoassuremulewasopen@7138200GPMpsi400p/u175s/o125 Circulateandconditionmud PrejobAndJSAwithcementers R/Ucementerstestlinesto3000PSI CementPlugBatchandpump35Bbls10PPGmudpush,145Bbls15.8Cementfollowedby5Bbls10PPG MudPush,6BblsofWaterandchasewith66Bblsof9.5PPGDrillMud 01:30 Pulloutofcementf/8932t/6800slow5minperstands Coring PlugBack PlugBack PlugBack PlugBack PlugBack PlugBack PlugBack www.wellez.comWellEzOnDemandver_102920ms IntermediateDrilling 3P.U.WT.:120S.O.WT.: AZIMUTH TVD E/W DLSV.SECTION 40.0 COORDINATES TORQUE: Ͳ1,877.7 Ͳ1,886.8 8,815 18.79 238.30 BHAWT.AIR: INCLINATION 8,950 Ͳ1,892.8 8,457 BHAWT.MUD: 5,532 cementplugbackassembly ROT.WT.:175 20.40 20.64 236.79 8,506 125 SURVEYDATA MD N/S 31 460 20:00 00:00 6.0 TIMEBREAKDOWN DrillWater 491 L/Dcoresampletool,R/Dwireliners P/UMuleshoe,RIHpicking27singlesfrompipeshedRIHto2375 Fuel 6,068 IntermediateCasing 0.120.60 Ͳ1,276.3 IntermediateDrilling IntermediateDrilling IntermediateDrilling 2,303.0Ͳ1,917.2 $13,785,894 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:8/2/22 $13,785,894 l80Conductor 20.00 108 40 105 80 LͲ80,l80 3,383 3,375 WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:22 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/JerryOtto FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUN 8.504 CT TYPE MAKE MODELPUMP 58.50Smith Smith 16 96300 SPM 1,800 0.55 5,208PDC PDC XS616 JP4545 467.825 STK 8,950N N 6x12 5x12 0.660 0.552 ID 4 # 8 31LENGTH: DrillPipeͲhwdp COMPONENT OD ID# 1 2 OPERATIONSCODE NPT DrillPipeͲMuleShoe TIME FV WL GELS(10s/10m/30m) Surface 9.63 MANUFACTURER 2.009.4 48.0 9.4 CAKEPH MUD OD MD TVDWEIGHT NO. SIZE FEET HRSOUT 1 WELL/JOBINFORMATION RPTDATE:7/29/2022 RPTNUM.:26 RIG:Rig105E DAILYDRILLINGREPORT BT ECD BITHHP RP:1 GardnerDenver PZͲ9(PZJ) PZͲ9(PZJ) 1750 6.000 9.000 2 PUMPS GardnerDenver 1750 GPSGPMLINER 250 96 OTHER: AVDPEFF% 15:00 3,408 AVDC GAUGE:N 16:30 06:00 09:00 07:30 1.5 18:30 CONSUMABLES 1.5 IntermediateDrilling 22:30 2.0 IntermediateDrilling 6.0 IntermediateDrilling 4.022:30 09:00 18:30 15:00 16:30 06:00 PHASE 07:30 HRS.ONJARS: 7.5 DAILYONHAND(gal) 105,208 DULL: LOC:XI PSI HTHPPf 15 MW 21:00 72.0 OIL 9.402.44 25.0 ROPWOB TD TOTALHRS 24.0 7030FT/6800FT DAILYDRILLCOST: GRADE 7/6/2022 9079920515 DRILLINGAFEAMT: CASING LASTBOPTEST:7/29/22 CUMDRILLCOST:$51,881 BOP COSTDATA 7/25/22 MD/TVD: AlaskaͲFranklinHills 50Ͳ223Ͳ20037Ͳ00Ͳ00 180 CASINGTYPE PRESENTOPERATIONS: ACTIVITYPLANNED: PickupLateralBHA M/UBHA#10(Lateralassembly)RIHT/7030,Polishcement,KickoffandDrillLateral Mf 24HRFTG: CL LGSKPV CaYP HRSDRLG: drillingsupervisor@greatbearpetro.com 21.14 25 EMAIL: 6 3,742 101 0.809.6 DRILLBITS LENGTHOD 8.0 COMPONENTLENGTH BHA 612 DESCRIPTION: PUMPHHP SEAL:BITNO.5 INNER: 3.34 20.4 9.000 FROM TO IntermediateDrilling Ͳ1,260.3 426 236.79 8,584 8,867 HRS CONSUMABLE Ͳ1,251.0 DAILYRECEIVED(gal) DAILYUSED(gal) PlugBack POOHf/1258t/surfBHA#7(PlugbackMuleShoe) 2,273.9 4.4 IntermediateDrilling 2,256.2 1.9 2,266.8 4.58,847 20.20 239.05 8,487 Ͳ1,256.6 TIHf/4824t/7030tagcementwithpipefromderrick Circulateat400GPM1350PSIsetdown35koncementincreasepumpsto500GPMpsi1730setdown3xs with35k(NOGO)circulateandconditioncontaminatedcementmudoutofwell,pumpdryjob POOHfrom7030t/surf M/UTestequipmentTestBOPs PlugBack PlugBack PlugBack PlugBack TestB.O.P. www.wellez.comWellEzOnDemandver_102920ms 3P.U.WT.:120S.O.WT.: AZIMUTH TVD E/W DLSV.SECTIONCOORDINATES TORQUE: Ͳ1,877.7 Ͳ1,886.8 8,815 18.79 238.30 BHAWT.AIR: INCLINATION 8,950 Ͳ1,892.8 8,457 BHAWT.MUD: 5,106 cementplugbackassembly ROT.WT.:150 632.40 20.64 236.79 8,506 130 SURVEYDATA MD N/S 63 441 1.5 TIMEBREAKDOWN DrillWater 44 M/UBHA#8*MuleShoe)M/U5"HWDPL/Djars TIHf/638t/4824pickingup4"DPfrompipeshed Fuel IntermediateDrilling 0.120.60 Ͳ1,276.3 IntermediateDrilling 2,303.0Ͳ1,917.2 $14,086,154 CUMWELLCOST: LASTBOPDRILL: NEXTBOPTEST:8/5/22 $14,086,154 l80Conductor 20.00 108 40 105 80 LͲ80,l80 3,383 3,375 WELLNAME:Alkaid2PH JOB:Alkaid2PHsurfacehole RKB: DOL:23 RIGSUPERV: NaborsAlaskaDrilling Alkaid MarkBrouillet/JerryOtto FIELD:LEASE: API#: ELEVATION: DFS: AFE#: CONTRACTOR: SPUDDATE: RIGPHONE: IN 6.000 RPM OUTER: 2 JETS TFASERNO. REͲRUN 8.504 CT TYPE MAKE MODELPUMP 58.50Smith Smith 12 96250 SPM 1,800 0.60 5,208PDC PDC XS616 JP4545 467.825 STK 8,950N N 6x12 5x12 0.660 0.552 ID 4 # Al k a i d 2 P H S u r v e y G e o d e t i c R e p o r t - N A D 2 7 Z 4 (D e f S u r v e y ) 2. 1 0 . 8 3 2 . 2 Co m m e n t s MD (ft ) In c l (°) Az i m T r u e (°) TV D S S (ft ) TV D (ft ) VSE C (ft ) AH D (ft ) Cl o s u r e (ft ) NS (ft ) EW (ft ) DL S (°/ 1 0 0 f t ) No r t h i n g (ft U S ) Ea s t i n g (ft U S ) La t i t u d e (°) Lo n g i t u d e (°) RT E 0. 0 0 0 . 0 0 0 . 0 0 - 1 9 9 . 7 3 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 N / A 5 8 4 6 0 4 7 . 6 2 6 6 2 7 7 8 . 3 1 6 9 . 9 8 5 8 6 4 6 3 - 1 4 8 . 7 0 1 4 4 3 5 0 20 . 1 5 0 . 0 0 0 . 0 0 - 1 7 9 . 5 8 2 0 . 1 5 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 0 . 0 0 5 8 4 6 0 4 7 . 6 2 6 6 2 7 7 8 . 3 1 6 9 . 9 8 5 8 6 4 6 3 - 1 4 8 . 7 0 1 4 4 3 5 0 29 8 . 7 0 0 . 1 2 3 5 2 . 2 7 9 8 . 9 7 2 9 8 . 7 0 - 0 . 1 3 0 . 2 9 0 . 2 9 0 . 2 9 - 0 . 0 4 0 . 0 4 5 8 4 6 0 4 7 . 9 1 6 6 2 7 7 8 . 2 6 6 9 . 9 8 5 8 6 5 4 2 - 1 4 8 . 7 0 1 4 4 3 8 1 38 7 . 9 0 0 . 4 1 5 9 . 1 9 1 8 8 . 1 7 3 8 7 . 9 0 - 0 . 4 9 0 . 6 7 0 . 5 9 0 . 5 5 0 . 2 2 0 . 4 3 5 8 4 6 0 4 8 . 1 7 6 6 2 7 7 8 . 5 2 6 9 . 9 8 5 8 6 6 1 2 - 1 4 8 . 7 0 1 4 4 1 7 2 48 2 . 0 7 0 . 5 4 1 3 8 . 9 3 2 8 2 . 3 4 4 8 2 . 0 7 - 0 . 8 8 1 . 3 4 0 . 8 9 0 . 3 8 0 . 8 0 0 . 6 6 5 8 4 6 0 4 8 . 0 2 6 6 2 7 7 9 . 1 0 6 9 . 9 8 5 8 6 5 6 8 - 1 4 8 . 7 0 1 4 3 7 0 9 57 5 . 2 6 0 . 7 4 1 2 1 . 0 4 3 7 5 . 5 2 5 7 5 . 2 5 - 1 . 2 0 2 . 3 7 1 . 6 3 - 0 . 2 6 1 . 6 1 0 . 3 0 5 8 4 6 0 4 7 . 4 0 6 6 2 7 7 9 . 9 2 6 9 . 9 8 5 8 6 3 9 3 - 1 4 8 . 7 0 1 4 3 0 6 7 75 4 . 7 1 0 . 7 9 1 1 9 . 4 7 5 5 4 . 9 5 7 5 4 . 6 8 - 2 . 2 7 4 . 7 6 3 . 9 6 - 1 . 4 6 3 . 6 8 0 . 0 3 5 8 4 6 0 4 6 . 2 3 6 6 2 7 8 2 . 0 1 6 9 . 9 8 5 8 6 0 6 3 - 1 4 8 . 7 0 1 4 1 4 1 6 85 1 . 3 4 0 . 6 7 1 0 7 . 1 0 6 5 1 . 5 8 8 5 1 . 3 1 - 2 . 9 3 5 . 9 9 5 . 1 8 - 1 . 9 6 4 . 8 0 0 . 2 0 5 8 4 6 0 4 5 . 7 6 6 6 2 7 8 3 . 1 4 6 9 . 9 8 5 8 5 9 2 8 - 1 4 8 . 7 0 1 4 0 5 2 3 94 5 . 5 4 0 . 6 7 1 0 1 . 8 2 7 4 5 . 7 7 9 4 5 . 5 0 - 3 . 6 7 7 . 0 9 6 . 2 7 - 2 . 2 3 5 . 8 6 0 . 0 7 5 8 4 6 0 4 5 . 5 1 6 6 2 7 8 4 . 2 2 6 9 . 9 8 5 8 5 8 5 3 - 1 4 8 . 7 0 1 3 9 6 7 3 10 4 0 . 3 0 0 . 8 3 2 2 1 . 0 0 8 4 0 . 5 3 1 0 4 0 . 2 6 - 3 . 4 0 7 . 9 6 6 . 6 1 - 2 . 8 6 5 . 9 5 1 . 3 7 5 8 4 6 0 4 4 . 8 8 6 6 2 7 8 4 . 3 2 6 9 . 9 8 5 8 5 6 8 1 - 1 4 8 . 7 0 1 3 9 6 0 0 11 3 8 . 2 1 1 . 5 1 2 2 6 . 9 4 9 3 8 . 4 2 1 1 3 8 . 1 5 - 1 . 4 5 9 . 9 5 6 . 2 4 - 4 . 2 8 4 . 5 5 0 . 7 0 5 8 4 6 0 4 3 . 4 4 6 6 2 7 8 2 . 9 4 6 9 . 9 8 5 8 5 2 9 4 - 1 4 8 . 7 0 1 4 0 7 2 3 12 3 2 . 0 2 2 . 9 2 2 3 0 . 3 3 1 0 3 2 . 1 5 1 2 3 1 . 8 8 2 . 1 5 1 3 . 5 8 6 . 8 9 - 6 . 6 5 1 . 8 0 1 . 5 1 5 8 4 6 0 4 1 . 0 1 6 6 2 7 8 0 . 2 5 6 9 . 9 8 5 8 4 6 4 7 - 1 4 8 . 7 0 1 4 2 9 1 0 13 2 8 . 9 4 5 . 3 3 2 3 8 . 1 9 1 1 2 8 . 8 2 1 3 2 8 . 5 5 9 . 1 0 2 0 . 5 4 1 1 . 3 0 - 1 0 . 6 0 - 3 . 9 2 2 . 5 5 5 8 4 6 0 3 6 . 9 4 6 6 2 7 7 4 . 6 1 6 9 . 9 8 5 8 3 5 6 8 - 1 4 8 . 7 0 1 4 7 4 7 8 14 2 3 . 0 4 5 . 6 5 2 3 8 . 8 7 1 2 2 2 . 4 8 1 4 2 2 . 2 1 1 8 . 1 0 2 9 . 5 4 1 9 . 2 0 - 1 5 . 3 0 - 1 1 . 6 0 0 . 3 5 5 8 4 6 0 3 2 . 0 8 6 6 2 7 6 7 . 0 3 6 9 . 9 8 5 8 2 2 8 4 - 1 4 8 . 7 0 1 5 3 6 0 3 15 1 7 . 4 9 6 . 4 9 2 3 5 . 2 2 1 3 1 6 . 4 0 1 5 1 6 . 1 3 2 8 . 0 8 3 9 . 5 3 2 8 . 7 9 - 2 0 . 7 5 - 1 9 . 9 7 0 . 9 8 5 8 4 6 0 2 6 . 4 5 6 6 2 7 5 8 . 7 9 6 9 . 9 8 5 8 0 7 9 5 - 1 4 8 . 7 0 1 6 0 2 7 4 16 1 3 . 2 1 9 . 1 9 2 3 8 . 1 6 1 4 1 1 . 2 2 1 6 1 0 . 9 5 4 1 . 1 3 5 2 . 5 8 4 1 . 6 1 - 2 7 . 8 7 - 3 0 . 9 0 2 . 8 5 5 8 4 6 0 1 9 . 1 0 6 6 2 7 4 8 . 0 1 6 9 . 9 8 5 7 8 8 5 0 - 1 4 8 . 7 0 1 6 8 9 9 9 17 0 8 . 5 2 1 0 . 8 4 2 3 9 . 7 4 1 5 0 5 . 0 8 1 7 0 4 . 8 1 5 7 . 6 9 6 9 . 1 5 5 7 . 9 6 - 3 6 . 4 0 - 4 5 . 1 1 1 . 7 5 5 8 4 6 0 1 0 . 2 7 6 6 2 7 3 3 . 9 8 6 9 . 9 8 5 7 6 5 1 9 - 1 4 8 . 7 0 1 8 0 3 3 1 18 0 5 . 8 8 1 1 . 6 6 2 4 0 . 2 2 1 6 0 0 . 5 6 1 8 0 0 . 2 9 7 6 . 6 5 8 8 . 1 5 7 6 . 7 9 - 4 5 . 9 0 - 6 1 . 5 6 0 . 8 5 5 8 4 6 0 0 0 . 4 2 6 6 2 7 1 7 . 7 4 6 9 . 9 8 5 7 3 9 2 4 - 1 4 8 . 7 0 1 9 3 4 5 0 19 0 1 . 3 9 1 3 . 1 6 2 4 0 . 4 8 1 6 9 3 . 8 4 1 8 9 3 . 5 7 9 7 . 1 4 1 0 8 . 6 7 9 7 . 1 9 - 5 6 . 0 5 - 7 9 . 4 0 1 . 5 7 5 8 4 5 9 8 9 . 9 0 6 6 2 7 0 0 . 1 3 6 9 . 9 8 5 7 1 1 5 0 - 1 4 8 . 7 0 2 0 7 6 7 8 19 9 5 . 6 8 1 4 . 7 1 2 3 9 . 8 0 1 7 8 5 . 3 5 1 9 8 5 . 0 8 1 1 9 . 8 0 1 3 1 . 3 8 1 1 9 . 8 1 - 6 7 . 3 6 - 9 9 . 0 9 1 . 6 5 5 8 4 5 9 7 8 . 1 7 6 6 2 6 8 0 . 6 8 6 9 . 9 8 5 6 8 0 6 0 - 1 4 8 . 7 0 2 2 3 3 8 1 20 9 1 . 4 5 1 6 . 5 1 2 3 9 . 0 7 1 8 7 7 . 5 9 2 0 7 7 . 3 2 1 4 5 . 5 4 1 5 7 . 1 5 1 4 5 . 5 4 - 8 0 . 4 7 - 1 2 1 . 2 7 1 . 8 9 5 8 4 5 9 6 4 . 5 9 6 6 2 6 5 8 . 7 9 6 9 . 9 8 5 6 4 4 7 8 - 1 4 8 . 7 0 2 4 1 0 7 5 21 8 6 . 4 7 1 7 . 5 5 2 3 5 . 7 4 1 9 6 8 . 4 4 2 1 6 8 . 1 7 1 7 3 . 3 6 1 8 4 . 9 7 1 7 3 . 3 6 - 9 5 . 4 8 - 1 4 4 . 6 9 1 . 5 0 5 8 4 5 9 4 9 . 0 9 6 6 2 6 3 5 . 6 9 6 9 . 9 8 5 6 0 3 7 8 - 1 4 8 . 7 0 2 5 9 7 5 7 22 8 2 . 3 1 1 8 . 9 2 2 3 4 . 7 7 2 0 5 9 . 4 7 2 2 5 9 . 2 0 2 0 3 . 3 3 2 1 4 . 9 6 2 0 3 . 3 4 - 1 1 2 . 5 8 - 1 6 9 . 3 3 1 . 4 6 5 8 4 5 9 3 1 . 4 7 6 6 2 6 1 1 . 4 3 6 9 . 9 8 5 5 5 7 0 7 - 1 4 8 . 7 0 2 7 9 4 0 6 23 7 7 . 3 9 1 9 . 2 2 2 3 3 . 8 2 2 1 4 9 . 3 3 2 3 4 9 . 0 6 2 3 4 . 3 7 2 4 6 . 0 2 2 3 4 . 3 8 - 1 3 0 . 7 1 - 1 9 4 . 5 5 0 . 4 5 5 8 4 5 9 1 2 . 8 1 6 6 2 5 8 6 . 6 0 6 9 . 9 8 5 5 0 7 5 3 - 1 4 8 . 7 0 2 9 9 5 2 4 24 7 2 . 8 6 1 9 . 5 6 2 3 5 . 1 7 2 2 3 9 . 3 8 2 4 3 9 . 1 1 2 6 6 . 0 4 2 7 7 . 7 1 2 6 6 . 0 6 - 1 4 9 . 1 1 - 2 2 0 . 3 5 0 . 5 9 5 8 4 5 8 9 3 . 8 6 6 6 2 5 6 1 . 1 9 6 9 . 9 8 5 4 5 7 2 5 - 1 4 8 . 7 0 3 2 0 1 0 4 25 6 6 . 2 8 1 9 . 7 5 2 3 4 . 4 2 2 3 2 7 . 3 6 2 5 2 7 . 0 9 2 9 7 . 4 5 3 0 9 . 1 4 2 9 7 . 4 8 - 1 6 7 . 2 3 - 2 4 6 . 0 3 0 . 3 4 5 8 4 5 8 7 5 . 2 0 6 6 2 5 3 5 . 9 1 6 9 . 9 8 5 4 0 7 7 6 - 1 4 8 . 7 0 3 4 0 5 8 1 26 6 2 . 0 0 1 9 . 8 1 2 3 5 . 2 0 2 4 1 7 . 4 3 2 6 1 7 . 1 6 3 2 9 . 8 2 3 4 1 . 5 3 3 2 9 . 8 7 - 1 8 5 . 8 9 - 2 7 2 . 5 0 0 . 2 8 5 8 4 5 8 5 5 . 9 8 6 6 2 5 0 9 . 8 5 6 9 . 9 8 5 3 5 6 7 5 - 1 4 8 . 7 0 3 6 1 6 9 4 27 5 7 . 5 7 1 9 . 5 2 2 3 3 . 3 0 2 5 0 7 . 4 3 2 7 0 7 . 1 6 3 6 1 . 9 5 3 7 3 . 6 9 3 6 2 . 0 2 - 2 0 4 . 6 8 - 2 9 8 . 6 0 0 . 7 3 5 8 4 5 8 3 6 . 6 4 6 6 2 4 8 4 . 1 5 6 9 . 9 8 5 3 0 5 4 3 - 1 4 8 . 7 0 3 8 2 5 1 1 28 5 3 . 3 0 1 8 . 7 2 2 3 2 . 9 7 2 5 9 7 . 8 8 2 7 9 7 . 6 1 3 9 3 . 2 5 4 0 5 . 0 4 3 9 3 . 3 5 - 2 2 3 . 4 9 - 3 2 3 . 6 9 0 . 8 4 5 8 4 5 8 1 7 . 3 1 6 6 2 4 5 9 . 4 7 6 9 . 9 8 5 2 5 4 0 4 - 1 4 8 . 7 0 4 0 2 5 2 0 29 4 7 . 9 9 1 8 . 8 0 2 3 2 . 1 0 2 6 8 7 . 5 4 2 8 8 7 . 2 7 4 2 3 . 6 2 4 3 5 . 4 9 4 2 3 . 7 6 - 2 4 2 . 0 1 - 3 4 7 . 8 6 0 . 3 1 5 8 4 5 7 9 8 . 2 7 6 6 2 4 3 5 . 7 1 6 9 . 9 8 5 2 0 3 4 3 - 1 4 8 . 7 0 4 2 1 7 9 7 30 4 3 . 8 2 1 9 . 1 8 2 3 4 . 3 2 2 7 7 8 . 1 5 2 9 7 7 . 8 8 4 5 4 . 7 4 4 6 6 . 6 7 4 5 4 . 9 2 - 2 6 0 . 6 8 - 3 7 2 . 8 3 0 . 8 5 5 8 4 5 7 7 9 . 0 8 6 6 2 4 1 1 . 1 4 6 9 . 9 8 5 1 5 2 4 3 - 1 4 8 . 7 0 4 4 1 7 1 3 31 4 0 . 1 9 1 8 . 9 0 2 3 4 . 2 1 2 8 6 9 . 2 5 3 0 6 8 . 9 8 4 8 6 . 1 5 4 9 8 . 1 1 4 8 6 . 3 6 - 2 7 9 . 0 4 - 3 9 8 . 3 5 0 . 2 9 5 8 4 5 7 6 0 . 1 8 6 6 2 3 8 6 . 0 2 6 9 . 9 8 5 1 0 2 2 6 - 1 4 8 . 7 0 4 6 2 0 6 7 To t a l G r a v i t y F i e l d S t r e n g t h : 10 0 1 . 9 7 5 6 m g n ( 9 . 8 0 6 6 5 B a s e d ) To t a l C o r r M a g N o r t h - > T r u e N o r t h : Gr a v i t y M o d e l : 57 1 7 9 . 0 3 4 n T DO X To t a l M a g n e t i c F i e l d S t r e n g t h : Ma g n e t i c D i p A n g l e : No r t h R e f e r e n c e : 80 . 5 5 1 ° Ju l y 2 0 , 2 0 2 2 BG G M 2 0 2 2 Tr u e N o r t h 0. 0 0 0 0 ° 15 . 9 3 6 1 ° Gr i d C o n v e r g e n c e U s e d : Gr i d S c a l e F a c t o r : 19 9 . 7 3 0 f t a b o v e M S L TV D R e f e r e n c e E l e v a t i o n : Gr o u n d E l e v a t i o n : 17 9 . 5 8 0 f t a b o v e M S L Fi e l d : Re p o r t D a t e : Al a s k a - F r a n k l i n H i l l s Cl i e n t : Gr e a t B e a r P a n t h e o n Au g u s t 2 2 , 2 0 2 2 - 0 8 : 4 8 A M Mi n i m u m C u r v a t u r e / L u b i n s k i 23 6 . 6 6 0 ° ( T r u e N o r t h ) 0. 0 0 0 f t , 0 . 0 0 0 f t Ro t a r y T a b l e Su r v e y / D L S C o m p u t a t i o n : TV D R e f e r e n c e D a t u m : Ve r t i c a l S e c t i o n A z i m u t h : Ve r t i c a l S e c t i o n O r i g i n : Al k a i d 2 P H St r u c t u r e / S l o t : We l l : Bo r e h o l e : 50 2 2 3 2 0 0 3 7 0 0 Al k a i d 2 Al k a i d 2 / A - 2 Lo c a t i o n G r i d N / E Y / X : NA D 2 7 A l a s k a S t a t e P l a n e , Z o n e 0 4 , U S F e e t 94 . 2 7 0 ° / 2 3 2 2 . 4 6 6 f t / 5 . 3 5 8 / 0 . 2 7 1 Co o r d i n a t e R e f e r e n c e S y s t e m : Su r v e y N a m e : Al k a i d 2 P H Su r v e y D a t e : Ve r s i o n / P a t c h : We l l H e a d Lo c a l C o o r d R e f e r e n c e d T o : 15 . 9 3 6 ° Ma g n e t i c D e c l i n a t i o n : De c l i n a t i o n D a t e : 0. 9 9 9 9 3 0 1 Ma g n e t i c D e c l i n a t i o n M o d e l : N 6 9 . 9 8 5 8 6 4 6 3 , W 1 4 8 . 7 0 1 4 4 3 5 0 To r t / A H D / D D I / E R D R a t i o : CR S G r i d C o n v e r g e n c e A n g l e : Ju l y 2 1 , 2 0 2 2 Lo c a t i o n L a t / L o n g : 1. 2 2 0 2 ° N 5 8 4 6 0 4 7 . 6 2 0 f t U S , E 6 6 2 7 7 8 . 3 0 7 f t U S AP I # : Dr i l l i n g O f f i c e 2 . 1 0 . 8 3 2 . 2 A l a s k a - F r a n k l i n H i l l s \ A l k a i d 2 \ A l k a i d 2 \ A l k a i d 2 P H \ A l k a i d 2 P H 8 / 2 2 / 2 0 2 2 9 : 3 4 A M P a g e 1 o f 3 Co m m e n t s MD (ft ) In c l (°) Az i m T r u e (°) TV D S S (ft ) TV D (ft ) VSE C (ft ) AH D (ft ) Cl o s u r e (ft ) NS (ft ) EW (ft ) DL S (°/ 1 0 0 f t ) No r t h i n g (ft U S ) Ea s t i n g (ft U S ) La t i t u d e (°) Lo n g i t u d e (°) 32 3 5 . 2 7 1 8 . 3 1 2 3 5 . 7 9 2 9 5 9 . 3 6 3 1 5 9 . 0 9 5 1 6 . 4 7 5 2 8 . 4 5 5 1 6 . 6 9 - 2 9 6 . 4 4 - 4 2 3 . 1 9 0 . 8 2 5 8 4 5 7 4 2 . 2 5 6 6 2 3 6 1 . 5 5 6 9 . 9 8 5 0 5 4 7 1 - 1 4 8 . 7 0 4 8 1 8 8 0 33 0 6 . 7 1 1 7 . 8 8 2 3 5 . 0 1 3 0 2 7 . 2 7 3 2 2 7 . 0 0 5 3 8 . 6 6 5 5 0 . 6 3 5 3 8 . 8 8 - 3 0 9 . 0 4 - 4 4 1 . 4 6 0 . 6 9 5 8 4 5 7 2 9 . 2 7 6 6 2 3 4 3 . 5 6 6 9 . 9 8 5 0 2 0 2 9 - 1 4 8 . 7 0 4 9 6 4 4 7 33 5 7 . 2 5 1 8 . 1 1 2 3 5 . 9 6 3 0 7 5 . 3 4 3 2 7 5 . 0 7 5 5 4 . 2 6 5 6 6 . 2 5 5 5 4 . 4 9 - 3 1 7 . 8 9 - 4 5 4 . 3 2 0 . 7 4 5 8 4 5 7 2 0 . 1 5 6 6 2 3 3 0 . 8 9 6 9 . 9 8 4 9 9 6 1 2 - 1 4 8 . 7 0 5 0 6 7 0 8 9- 5 / 8 " 33 7 4 . 0 0 18 . 0 7 2 3 6 . 2 7 3 0 9 1 . 2 6 3 2 9 0 . 9 9 5 5 9 . 4 7 5 7 1 . 4 5 5 5 9 . 6 9 - 3 2 0 . 7 9 - 4 5 8 . 6 4 0 . 6 3 5 8 4 5 7 1 7 . 1 6 6 6 2 3 2 6 . 6 3 6 9 . 9 8 4 9 8 8 2 0 -1 4 8 . 7 0 5 1 0 1 5 1 34 5 4 . 0 3 1 7 . 8 8 2 3 7 . 7 8 3 1 6 7 . 3 8 3 3 6 7 . 1 1 5 8 4 . 1 6 5 9 6 . 1 4 5 8 4 . 3 7 - 3 3 4 . 2 3 - 4 7 9 . 3 6 0 . 6 3 5 8 4 5 7 0 3 . 2 8 6 6 2 3 0 6 . 2 1 6 9 . 9 8 4 9 5 1 4 7 - 1 4 8 . 7 0 5 2 6 6 7 3 35 5 3 . 2 6 1 6 . 5 1 2 3 6 . 2 6 3 2 6 2 . 1 8 3 4 6 1 . 9 1 6 1 3 . 4 9 6 2 5 . 4 8 6 1 3 . 6 9 - 3 5 0 . 1 8 - 5 0 3 . 9 7 1 . 4 5 5 8 4 5 6 8 6 . 8 1 6 6 2 2 8 1 . 9 4 6 9 . 9 8 4 9 0 7 8 8 - 1 4 8 . 7 0 5 4 6 3 0 3 36 4 4 . 7 7 1 3 . 3 0 2 3 1 . 8 1 3 3 5 0 . 6 0 3 5 5 0 . 3 3 6 3 6 . 9 9 6 4 9 . 0 0 6 3 7 . 2 0 - 3 6 3 . 9 2 - 5 2 3 . 0 6 3 . 7 2 5 8 4 5 6 7 2 . 6 7 6 6 2 2 6 3 . 1 5 6 9 . 9 8 4 8 7 0 3 6 - 1 4 8 . 7 0 5 6 1 5 3 0 37 4 4 . 4 7 1 6 . 0 0 2 2 9 . 4 8 3 4 4 7 . 0 5 3 6 4 6 . 7 8 6 6 2 . 0 5 6 7 4 . 2 1 6 6 2 . 3 3 - 3 7 9 . 9 4 - 5 4 2 . 5 2 2 . 7 7 5 8 4 5 6 5 6 . 2 4 6 6 2 2 4 4 . 0 4 6 9 . 9 8 4 8 2 6 5 8 - 1 4 8 . 7 0 5 7 7 0 5 1 38 3 7 . 0 9 1 8 . 5 5 2 3 4 . 3 9 3 5 3 5 . 4 9 3 7 3 5 . 2 2 6 8 9 . 4 4 7 0 1 . 7 0 6 8 9 . 7 8 - 3 9 6 . 8 1 - 5 6 4 . 2 1 3 . 1 7 5 8 4 5 6 3 8 . 9 1 6 6 2 2 2 2 . 7 2 6 9 . 9 8 4 7 8 0 4 8 - 1 4 8 . 7 0 5 9 4 3 4 6 39 2 3 . 7 5 1 9 . 1 7 2 3 6 . 7 3 3 6 1 7 . 5 0 3 8 1 7 . 2 3 7 1 7 . 4 5 7 2 9 . 7 1 7 1 7 . 7 8 - 4 1 2 . 6 4 - 5 8 7 . 3 1 1 . 1 3 5 8 4 5 6 2 2 . 5 9 6 6 2 1 9 9 . 9 6 6 9 . 9 8 4 7 3 7 2 2 - 1 4 8 . 7 0 6 1 2 7 7 2 40 2 0 . 0 3 1 9 . 8 5 2 4 4 . 4 5 3 7 0 8 . 2 6 3 9 0 7 . 9 9 7 4 9 . 4 6 7 6 1 . 8 2 7 4 9 . 7 2 - 4 2 8 . 3 7 - 6 1 5 . 2 8 2 . 7 7 5 8 4 5 6 0 6 . 2 8 6 6 2 1 7 2 . 3 3 6 9 . 9 8 4 6 9 4 2 5 - 1 4 8 . 7 0 6 3 5 0 7 9 41 1 5 . 1 2 2 0 . 3 1 2 4 9 . 2 8 3 7 9 7 . 5 8 3 9 9 7 . 3 1 7 8 1 . 5 6 7 9 4 . 4 5 7 8 1 . 6 8 - 4 4 1 . 1 7 - 6 4 5 . 2 9 1 . 8 1 5 8 4 5 5 9 2 . 8 4 6 6 2 1 4 2 . 6 1 6 9 . 9 8 4 6 5 9 2 7 - 1 4 8 . 7 0 6 5 9 0 0 8 42 1 1 . 0 7 1 9 . 9 3 2 4 7 . 1 5 3 8 8 7 . 6 7 4 0 8 7 . 4 0 8 1 3 . 8 9 8 2 7 . 4 5 8 1 3 . 9 2 - 4 5 3 . 4 1 - 6 7 5 . 9 3 0 . 8 6 5 8 4 5 5 7 9 . 9 5 6 6 2 1 1 2 . 2 3 6 9 . 9 8 4 6 2 5 8 1 - 1 4 8 . 7 0 6 8 3 4 4 9 43 0 9 . 2 7 1 9 . 0 4 2 4 6 . 3 1 3 9 8 0 . 2 5 4 1 7 9 . 9 8 8 4 6 . 1 4 8 6 0 . 2 1 8 4 6 . 1 4 - 4 6 6 . 3 5 - 7 0 6 . 0 2 0 . 9 5 5 8 4 5 5 6 6 . 3 8 6 6 2 0 8 2 . 4 2 6 9 . 9 8 4 5 9 0 4 7 - 1 4 8 . 7 0 7 0 7 4 4 8 44 0 1 . 0 3 1 8 . 6 8 2 4 2 . 2 2 4 0 6 7 . 0 9 4 2 6 6 . 8 2 8 7 5 . 5 2 8 8 9 . 8 6 8 7 5 . 5 2 - 4 7 9 . 2 1 - 7 3 2 . 7 3 1 . 4 9 5 8 4 5 5 5 2 . 9 5 6 6 2 0 5 6 . 0 0 6 9 . 9 8 4 5 5 5 3 2 - 1 4 8 . 7 0 7 2 8 7 4 9 44 9 5 . 9 1 1 8 . 4 4 2 3 3 . 6 3 4 1 5 7 . 0 5 4 3 5 6 . 7 8 9 0 5 . 6 3 9 2 0 . 0 0 9 0 5 . 6 4 - 4 9 5 . 2 0 - 7 5 8 . 2 6 2 . 8 9 5 8 4 5 5 3 6 . 4 3 6 6 2 0 3 0 . 8 1 6 9 . 9 8 4 5 1 1 6 4 - 1 4 8 . 7 0 7 4 9 1 1 0 45 9 2 . 4 5 1 7 . 6 4 2 3 0 . 1 6 4 2 4 8 . 8 5 4 4 4 8 . 5 8 9 3 5 . 4 2 9 4 9 . 8 9 9 3 5 . 4 2 - 5 1 3 . 6 2 - 7 8 1 . 7 9 1 . 3 9 5 8 4 5 5 1 7 . 5 0 6 6 2 0 0 7 . 6 9 6 9 . 9 8 4 4 6 1 3 0 - 1 4 8 . 7 0 7 6 7 8 7 2 46 8 8 . 5 3 1 3 . 7 2 2 2 9 . 6 3 4 3 4 1 . 3 3 4 5 4 1 . 0 6 9 6 1 . 2 0 9 7 5 . 8 5 9 6 1 . 2 0 - 5 3 0 . 3 4 - 8 0 1 . 6 6 4 . 0 8 5 8 4 5 5 0 0 . 3 7 6 6 1 9 8 8 . 1 8 6 9 . 9 8 4 4 1 5 6 3 - 1 4 8 . 7 0 7 8 3 7 1 6 47 8 2 . 3 1 1 6 . 0 6 2 2 9 . 8 7 4 4 3 1 . 9 6 4 6 3 1 . 6 9 9 8 5 . 1 2 9 9 9 . 9 5 9 8 5 . 1 3 - 5 4 5 . 9 0 - 8 2 0 . 0 5 2 . 5 0 5 8 4 5 4 8 4 . 4 2 6 6 1 9 7 0 . 1 3 6 9 . 9 8 4 3 7 3 1 0 - 1 4 8 . 7 0 7 9 8 3 8 4 48 7 5 . 3 0 1 7 . 6 2 2 3 3 . 1 9 4 5 2 0 . 9 6 4 7 2 0 . 6 9 1 0 1 1 . 9 4 1 0 2 6 . 8 8 1 0 1 1 . 9 7 - 5 6 2 . 6 3 - 8 4 1 . 1 5 1 . 9 7 5 8 4 5 4 6 7 . 2 5 6 6 1 9 4 9 . 3 8 6 9 . 9 8 4 3 2 7 4 0 - 1 4 8 . 7 0 8 1 5 2 1 5 49 7 1 . 4 8 1 9 . 6 9 2 3 5 . 1 2 4 6 1 2 . 0 8 4 8 1 1 . 8 1 1 0 4 2 . 6 7 1 0 5 7 . 6 4 1 0 4 2 . 7 1 - 5 8 0 . 6 2 - 8 6 6 . 1 0 2 . 2 5 5 8 4 5 4 4 8 . 7 4 6 6 1 9 2 4 . 8 2 6 9 . 9 8 4 2 7 8 2 4 - 1 4 8 . 7 0 8 3 5 1 1 2 50 6 8 . 7 0 2 0 . 6 9 2 3 3 . 3 2 4 7 0 3 . 3 3 4 9 0 3 . 0 6 1 0 7 6 . 1 9 1 0 9 1 . 1 9 1 0 7 6 . 2 4 - 6 0 0 . 2 4 - 8 9 3 . 3 1 1 . 2 1 5 8 4 5 4 2 8 . 5 4 6 6 1 8 9 8 . 0 4 6 9 . 9 8 4 2 2 4 6 2 - 1 4 8 . 7 0 8 5 6 8 1 2 51 6 4 . 0 0 1 8 . 9 9 2 3 5 . 5 3 4 7 9 2 . 9 7 4 9 9 2 . 7 0 1 1 0 8 . 5 0 1 1 2 3 . 5 3 1 1 0 8 . 5 7 - 6 1 9 . 0 8 - 9 1 9 . 6 0 1 . 9 5 5 8 4 5 4 0 9 . 1 5 6 6 1 8 7 2 . 1 6 6 9 . 9 8 4 1 7 3 1 5 - 1 4 8 . 7 0 8 7 7 7 7 5 52 5 9 . 1 8 1 8 . 5 8 2 3 8 . 9 5 4 8 8 3 . 0 8 5 0 8 2 . 8 1 1 1 3 9 . 1 4 1 1 5 4 . 1 8 1 1 3 9 . 2 0 - 6 3 5 . 6 6 - 9 4 5 . 3 6 1 . 2 3 5 8 4 5 3 9 2 . 0 2 6 6 1 8 4 6 . 7 6 6 9 . 9 8 4 1 2 7 8 3 - 1 4 8 . 7 0 8 9 8 3 1 7 53 5 3 . 8 6 1 8 . 7 5 2 3 4 . 7 6 4 9 7 2 . 7 9 5 1 7 2 . 5 2 1 1 6 9 . 4 2 1 1 8 4 . 4 6 1 1 6 9 . 4 8 - 6 5 2 . 2 2 - 9 7 0 . 7 1 1 . 4 3 5 8 4 5 3 7 4 . 9 2 6 6 1 8 2 1 . 7 7 6 9 . 9 8 4 0 8 2 5 8 - 1 4 8 . 7 0 9 1 8 5 3 5 54 4 9 . 2 5 1 8 . 6 9 2 3 2 . 7 6 5 0 6 3 . 1 3 5 2 6 2 . 8 6 1 1 9 9 . 9 9 1 2 1 5 . 0 8 1 2 0 0 . 0 6 - 6 7 0 . 3 2 - 9 9 5 . 4 0 0 . 6 8 5 8 4 5 3 5 6 . 3 1 6 6 1 7 9 7 . 4 8 6 9 . 9 8 4 0 3 3 1 3 - 1 4 8 . 7 0 9 3 8 2 2 4 55 4 4 . 0 3 1 8 . 6 8 2 3 1 . 2 0 5 1 5 2 . 9 1 5 3 5 2 . 6 4 1 2 3 0 . 2 5 1 2 4 5 . 4 4 1 2 3 0 . 3 5 - 6 8 9 . 0 2 - 1 0 1 9 . 3 2 0 . 5 3 5 8 4 5 3 3 7 . 1 0 6 6 1 7 7 3 . 9 6 6 9 . 9 8 3 9 8 2 0 3 - 1 4 8 . 7 0 9 5 7 2 9 8 56 4 0 . 3 4 1 8 . 5 9 2 2 6 . 3 2 5 2 4 4 . 1 8 5 4 4 3 . 9 1 1 2 6 0 . 7 1 1 2 7 6 . 2 0 1 2 6 0 . 8 6 - 7 0 9 . 2 9 - 1 0 4 2 . 4 4 1 . 6 2 5 8 4 5 3 1 6 . 3 5 6 6 1 7 5 1 . 2 8 6 9 . 9 8 3 9 2 6 6 5 - 1 4 8 . 7 0 9 7 5 7 3 8 57 3 5 . 6 8 1 8 . 6 1 2 2 7 . 0 3 5 3 3 4 . 5 4 5 5 3 4 . 2 7 1 2 9 0 . 6 6 1 3 0 6 . 6 1 1 2 9 0 . 9 0 - 7 3 0 . 1 5 - 1 0 6 4 . 5 7 0 . 2 4 5 8 4 5 2 9 5 . 0 2 6 6 1 7 2 9 . 6 1 6 9 . 9 8 3 8 6 9 6 4 - 1 4 8 . 7 0 9 9 3 3 7 9 58 3 1 . 1 4 1 8 . 4 0 2 2 7 . 4 2 5 4 2 5 . 0 7 5 6 2 4 . 8 0 1 3 2 0 . 5 5 1 3 3 6 . 9 0 1 3 2 0 . 8 8 - 7 5 0 . 7 3 - 1 0 8 6 . 8 0 0 . 2 6 5 8 4 5 2 7 3 . 9 8 6 6 1 7 0 7 . 8 1 6 9 . 9 8 3 8 1 3 4 2 - 1 4 8 . 7 1 0 1 1 1 1 3 59 2 5 . 8 7 1 8 . 3 4 2 3 1 . 3 2 5 5 1 4 . 9 7 5 7 1 4 . 7 0 1 3 5 0 . 1 4 1 3 6 6 . 7 5 1 3 5 0 . 5 6 - 7 7 0 . 1 6 - 1 1 0 9 . 4 5 1 . 3 0 5 8 4 5 2 5 4 . 0 7 6 6 1 6 8 5 . 5 9 6 9 . 9 8 3 7 6 0 3 2 - 1 4 8 . 7 1 0 2 9 1 7 0 60 2 1 . 4 4 1 8 . 2 9 2 3 5 . 6 4 5 6 0 5 . 7 1 5 8 0 5 . 4 4 1 3 8 0 . 1 1 1 3 9 6 . 7 7 1 3 8 0 . 5 6 - 7 8 8 . 0 2 - 1 1 3 3 . 5 7 1 . 4 2 5 8 4 5 2 3 5 . 7 0 6 6 1 6 6 1 . 8 6 6 9 . 9 8 3 7 1 1 5 2 - 1 4 8 . 7 1 0 4 8 4 0 3 61 1 6 . 7 8 1 8 . 4 6 2 3 9 . 3 2 5 6 9 6 . 1 9 5 8 9 5 . 9 2 1 4 1 0 . 1 5 1 4 2 6 . 8 1 1 4 1 0 . 5 8 - 8 0 4 . 1 7 - 1 1 5 8 . 9 0 1 . 2 3 5 8 4 5 2 1 9 . 0 2 6 6 1 6 3 6 . 8 8 6 9 . 9 8 3 6 6 7 4 0 - 1 4 8 . 7 1 0 6 8 6 0 4 62 1 2 . 3 0 1 8 . 4 8 2 4 2 . 3 3 5 7 8 6 . 7 9 5 9 8 6 . 5 2 1 4 4 0 . 3 2 1 4 5 7 . 0 7 1 4 4 0 . 6 9 - 8 1 8 . 9 1 - 1 1 8 5 . 3 1 1 . 0 0 5 8 4 5 2 0 3 . 7 1 6 6 1 6 1 0 . 7 8 6 9 . 9 8 3 6 2 7 1 0 - 1 4 8 . 7 1 0 8 9 6 6 8 63 0 7 . 6 8 1 8 . 2 9 2 4 4 . 4 7 5 8 7 7 . 3 0 6 0 7 7 . 0 3 1 4 7 0 . 1 9 1 4 8 7 . 1 5 1 4 7 0 . 4 8 - 8 3 2 . 3 8 - 1 2 1 2 . 2 1 0 . 7 4 5 8 4 5 1 8 9 . 6 8 6 6 1 5 8 4 . 1 9 6 9 . 9 8 3 5 9 0 2 8 - 1 4 8 . 7 1 1 1 1 1 1 5 64 0 2 . 6 3 1 8 . 0 8 2 4 4 . 6 7 5 9 6 7 . 5 1 6 1 6 7 . 2 4 1 4 9 9 . 5 4 1 5 1 6 . 7 8 1 4 9 9 . 7 5 - 8 4 5 . 1 1 - 1 2 3 8 . 9 7 0 . 2 3 5 8 4 5 1 7 6 . 3 8 6 6 1 5 5 7 . 7 0 6 9 . 9 8 3 5 5 5 5 1 - 1 4 8 . 7 1 1 3 2 4 5 6 64 9 6 . 6 2 1 8 . 3 1 2 4 2 . 7 0 6 0 5 6 . 8 0 6 2 5 6 . 5 3 1 5 2 8 . 6 6 1 5 4 6 . 1 3 1 5 2 8 . 8 2 - 8 5 8 . 1 2 - 1 2 6 5 . 2 7 0 . 7 0 5 8 4 5 1 6 2 . 8 2 6 6 1 5 3 1 . 6 9 6 9 . 9 8 3 5 1 9 9 5 - 1 4 8 . 7 1 1 5 3 4 3 1 65 9 2 . 2 1 1 8 . 3 9 2 4 0 . 9 1 6 1 4 7 . 5 3 6 3 4 7 . 2 6 1 5 5 8 . 6 3 1 5 7 6 . 2 2 1 5 5 8 . 7 5 - 8 7 2 . 3 4 - 1 2 9 1 . 7 9 0 . 6 0 5 8 4 5 1 4 8 . 0 4 6 6 1 5 0 5 . 4 8 6 9 . 9 8 3 4 8 1 0 9 - 1 4 8 . 7 1 1 7 4 5 7 9 66 8 7 . 7 3 1 8 . 0 9 2 3 9 . 0 8 6 2 3 8 . 2 5 6 4 3 7 . 9 8 1 5 8 8 . 4 8 1 6 0 6 . 1 1 1 5 8 8 . 5 7 - 8 8 7 . 2 8 - 1 3 1 7 . 6 8 0 . 6 8 5 8 4 5 1 3 2 . 5 5 6 6 1 4 7 9 . 9 1 6 9 . 9 8 3 4 4 0 2 5 - 1 4 8 . 7 1 1 9 5 2 2 4 67 8 3 . 1 4 1 8 . 2 5 2 3 4 . 8 3 6 3 2 8 . 9 1 6 5 2 8 . 6 4 1 6 1 8 . 2 1 1 6 3 5 . 8 5 1 6 1 8 . 3 0 - 9 0 3 . 5 0 - 1 3 4 2 . 6 0 1 . 4 0 5 8 4 5 1 1 5 . 8 0 6 6 1 4 5 5 . 3 5 6 9 . 9 8 3 3 9 5 9 3 - 1 4 8 . 7 1 2 1 5 0 9 7 68 7 8 . 9 5 1 8 . 2 8 2 3 4 . 8 2 6 4 1 9 . 8 9 6 6 1 9 . 6 2 1 6 4 8 . 2 2 1 6 6 5 . 8 8 1 6 4 8 . 3 2 - 9 2 0 . 8 0 - 1 3 6 7 . 1 5 0 . 0 3 5 8 4 5 0 9 7 . 9 9 6 6 1 4 3 1 . 1 8 6 9 . 9 8 3 3 4 8 6 6 - 1 4 8 . 7 1 2 3 4 6 6 9 69 7 4 . 2 5 1 8 . 0 0 2 3 5 . 1 5 6 5 1 0 . 4 5 6 7 1 0 . 1 8 1 6 7 7 . 8 8 1 6 9 5 . 5 5 1 6 7 7 . 9 8 - 9 3 7 . 8 2 - 1 3 9 1 . 4 4 0 . 3 1 5 8 4 5 0 8 0 . 4 5 6 6 1 4 0 7 . 2 5 6 9 . 9 8 3 3 0 2 1 3 - 1 4 8 . 7 1 2 5 4 0 4 6 70 6 9 . 0 2 1 8 . 5 7 2 3 4 . 9 2 6 6 0 0 . 4 4 6 8 0 0 . 1 7 1 7 0 7 . 6 0 1 7 2 5 . 2 8 1 7 0 7 . 7 1 - 9 5 4 . 8 6 - 1 4 1 5 . 8 1 0 . 6 1 5 8 4 5 0 6 2 . 9 0 6 6 1 3 8 3 . 2 5 6 9 . 9 8 3 2 5 5 5 7 - 1 4 8 . 7 1 2 7 3 4 7 6 71 6 4 . 9 6 1 8 . 4 3 2 3 2 . 4 9 6 6 9 1 . 4 2 6 8 9 1 . 1 5 1 7 3 8 . 0 0 1 7 5 5 . 7 2 1 7 3 8 . 1 3 - 9 7 2 . 8 8 - 1 4 4 0 . 3 4 0 . 8 2 5 8 4 5 0 4 4 . 3 6 6 6 1 3 5 9 . 1 1 6 9 . 9 8 3 2 0 6 3 4 - 1 4 8 . 7 1 2 9 3 0 3 8 72 6 0 . 6 6 1 8 . 5 5 2 3 0 . 4 3 6 7 8 2 . 1 8 6 9 8 1 . 9 1 1 7 6 8 . 2 2 1 7 8 6 . 0 7 1 7 6 8 . 3 8 - 9 9 1 . 7 9 - 1 4 6 4 . 0 8 0 . 6 9 5 8 4 5 0 2 4 . 9 6 6 6 1 3 3 5 . 7 8 6 9 . 9 8 3 1 5 4 6 7 - 1 4 8 . 7 1 3 1 1 9 6 4 73 5 5 . 6 7 1 8 . 4 2 2 2 9 . 4 0 6 8 7 2 . 2 9 7 0 7 2 . 0 2 1 7 9 8 . 1 3 1 8 1 6 . 1 9 1 7 9 8 . 3 4 - 1 0 1 1 . 1 8 - 1 4 8 7 . 1 2 0 . 3 7 5 8 4 5 0 0 5 . 0 7 6 6 1 3 1 3 . 1 6 6 9 . 9 8 3 1 0 1 6 7 - 1 4 8 . 7 1 3 3 0 3 4 1 74 5 2 . 1 8 1 8 . 3 6 2 3 0 . 4 7 6 9 6 3 . 8 7 7 1 6 3 . 6 0 1 8 2 8 . 3 7 1 8 4 6 . 6 4 1 8 2 8 . 6 3 - 1 0 3 0 . 7 8 - 1 5 1 0 . 4 2 0 . 3 6 5 8 4 4 9 8 4 . 9 9 6 6 1 2 9 0 . 2 8 6 9 . 9 8 3 0 4 8 1 1 - 1 4 8 . 7 1 3 4 8 9 2 0 75 4 7 . 4 9 1 8 . 2 5 2 3 3 . 8 3 7 0 5 4 . 3 6 7 2 5 4 . 0 9 1 8 5 8 . 2 0 1 8 7 6 . 5 7 1 8 5 8 . 5 0 - 1 0 4 9 . 1 4 - 1 5 3 4 . 0 5 1 . 1 1 5 8 4 4 9 6 6 . 1 3 6 6 1 2 6 7 . 0 5 6 9 . 9 8 2 9 9 7 9 3 - 1 4 8 . 7 1 3 6 7 7 5 9 76 4 2 . 6 3 1 8 . 3 1 2 3 4 . 9 6 7 1 4 4 . 7 0 7 3 4 4 . 4 3 1 8 8 8 . 0 1 1 9 0 6 . 4 1 1 8 8 8 . 3 3 - 1 0 6 6 . 5 1 - 1 5 5 8 . 3 1 0 . 3 8 5 8 4 4 9 4 8 . 2 4 6 6 1 2 4 3 . 1 7 6 9 . 9 8 2 9 5 0 4 6 - 1 4 8 . 7 1 3 8 7 1 0 5 77 3 6 . 7 1 1 8 . 3 8 2 3 6 . 4 2 7 2 3 4 . 0 0 7 4 3 3 . 7 3 1 9 1 7 . 6 2 1 9 3 6 . 0 2 1 9 1 7 . 9 4 - 1 0 8 3 . 2 0 - 1 5 8 2 . 7 7 0 . 4 9 5 8 4 4 9 3 1 . 0 4 6 6 1 2 1 9 . 0 7 6 9 . 9 8 2 9 0 4 8 5 - 1 4 8 . 7 1 4 0 6 6 0 7 78 3 2 . 3 5 1 8 . 2 9 2 4 0 . 1 2 7 3 2 4 . 7 9 7 5 2 4 . 5 2 1 9 4 7 . 6 8 1 9 6 6 . 0 9 1 9 4 7 . 9 8 - 1 0 9 9 . 0 2 - 1 6 0 8 . 3 4 1 . 2 2 5 8 4 4 9 1 4 . 6 8 6 6 1 1 9 3 . 8 4 6 9 . 9 8 2 8 6 1 6 2 - 1 4 8 . 7 1 4 2 7 0 0 0 79 2 7 . 9 2 1 8 . 3 3 2 4 0 . 4 4 7 4 1 5 . 5 2 7 6 1 5 . 2 5 1 9 7 7 . 6 4 1 9 9 6 . 1 2 1 9 7 7 . 9 1 - 1 1 1 3 . 9 0 - 1 6 3 4 . 4 2 0 . 1 1 5 8 4 4 8 9 9 . 2 5 6 6 1 1 6 8 . 0 9 6 9 . 9 8 2 8 2 0 9 4 - 1 4 8 . 7 1 4 4 7 7 9 2 80 2 3 . 2 4 1 8 . 1 7 2 4 2 . 5 8 7 5 0 6 . 0 5 7 7 0 5 . 7 8 2 0 0 7 . 3 8 2 0 2 5 . 9 6 2 0 0 7 . 6 0 - 1 1 2 8 . 1 4 - 1 6 6 0 . 6 5 0 . 7 2 5 8 4 4 8 8 4 . 4 5 6 6 1 1 4 2 . 1 7 6 9 . 9 8 2 7 8 2 0 3 - 1 4 8 . 7 1 4 6 8 7 0 8 81 1 8 . 8 0 1 8 . 1 6 2 4 2 . 6 4 7 5 9 6 . 8 4 7 7 9 6 . 5 7 2 0 3 7 . 0 1 2 0 5 5 . 7 6 2 0 3 7 . 1 9 - 1 1 4 1 . 8 5 - 1 6 8 7 . 1 0 0 . 0 2 5 8 4 4 8 7 0 . 1 9 6 6 1 1 1 6 . 0 2 6 9 . 9 8 2 7 4 4 5 7 - 1 4 8 . 7 1 4 8 9 8 0 1 82 1 3 . 8 7 1 8 . 1 3 2 4 1 . 1 4 7 6 8 7 . 1 9 7 8 8 6 . 9 2 2 0 6 6 . 4 9 2 0 8 5 . 3 6 2 0 6 6 . 6 3 - 1 1 5 5 . 8 0 - 1 7 1 3 . 2 1 0 . 4 9 5 8 4 4 8 5 5 . 6 9 6 6 1 0 9 0 . 2 1 6 9 . 9 8 2 7 0 6 4 5 - 1 4 8 . 7 1 5 1 0 6 2 3 83 0 9 . 1 2 1 8 . 3 1 2 4 3 . 2 1 7 7 7 7 . 6 6 7 9 7 7 . 3 9 2 0 9 6 . 1 3 2 1 1 5 . 1 4 2 0 9 6 . 2 4 - 1 1 6 9 . 6 9 - 1 7 3 9 . 5 5 0 . 7 1 5 8 4 4 8 4 1 . 2 4 6 6 1 0 6 4 . 1 8 6 9 . 9 8 2 6 6 8 4 6 - 1 4 8 . 7 1 5 3 1 6 2 3 Dr i l l i n g O f f i c e 2 . 1 0 . 8 3 2 . 2 A l a s k a - F r a n k l i n H i l l s \ A l k a i d 2 \ A l k a i d 2 \ A l k a i d 2 P H \ A l k a i d 2 P H 8 / 2 2 / 2 0 2 2 9 : 3 4 A M P a g e 2 o f 3 Co m m e n t s MD (ft ) In c l (°) Az i m T r u e (°) TV D S S (ft ) TV D (ft ) VSE C (ft ) AH D (ft ) Cl o s u r e (ft ) NS (ft ) EW (ft ) DL S (°/ 1 0 0 f t ) No r t h i n g (ft U S ) Ea s t i n g (ft U S ) La t i t u d e (°) Lo n g i t u d e (°) 84 0 4 . 3 9 1 8 . 5 2 2 4 0 . 7 4 7 8 6 8 . 0 6 8 0 6 7 . 7 9 2 1 2 6 . 0 9 2 1 4 5 . 2 3 2 1 2 6 . 1 7 - 1 1 8 3 . 8 3 - 1 7 6 6 . 1 1 0 . 8 5 5 8 4 4 8 2 6 . 5 3 6 6 1 0 3 7 . 9 3 6 9 . 9 8 2 6 2 9 8 1 - 1 4 8 . 7 1 5 5 2 8 0 1 84 9 9 . 3 9 1 8 . 4 5 2 4 1 . 5 6 7 9 5 8 . 1 5 8 1 5 7 . 8 8 2 1 5 6 . 1 2 2 1 7 5 . 3 5 2 1 5 6 . 1 8 - 1 1 9 8 . 3 7 - 1 7 9 2 . 4 9 0 . 2 8 5 8 4 4 8 1 1 . 4 4 6 6 1 0 1 1 . 8 7 6 9 . 9 8 2 5 9 0 0 9 - 1 4 8 . 7 1 5 7 3 8 3 7 85 9 3 . 5 1 1 8 . 6 1 2 3 6 . 5 1 8 0 4 7 . 4 0 8 2 4 7 . 1 3 2 1 8 5 . 9 8 2 2 0 5 . 2 4 2 1 8 6 . 0 3 - 1 2 1 3 . 7 5 - 1 8 1 8 . 1 1 1 . 7 1 5 8 4 4 7 9 5 . 5 2 6 6 0 9 8 6 . 5 8 6 9 . 9 8 2 5 4 8 0 5 - 1 4 8 . 7 1 5 9 4 2 6 7 86 8 8 . 5 0 1 8 . 4 2 2 3 7 . 3 8 8 1 3 7 . 4 7 8 3 3 7 . 2 0 2 2 1 6 . 1 4 2 2 3 5 . 4 1 2 2 1 6 . 1 9 - 1 2 3 0 . 2 0 - 1 8 4 3 . 3 9 0 . 3 5 5 8 4 4 7 7 8 . 5 3 6 6 0 9 6 1 . 6 6 6 9 . 9 8 2 5 0 3 0 9 - 1 4 8 . 7 1 6 1 4 4 2 5 87 8 3 . 7 7 1 8 . 5 0 2 3 9 . 9 4 8 2 2 7 . 8 4 8 4 2 7 . 5 7 2 2 4 6 . 2 8 2 2 6 5 . 5 7 2 2 4 6 . 3 2 - 1 2 4 5 . 8 9 - 1 8 6 9 . 1 5 0 . 8 5 5 8 4 4 7 6 2 . 3 1 6 6 0 9 3 6 . 2 4 6 9 . 9 8 2 4 6 0 2 2 - 1 4 8 . 7 1 6 3 4 9 6 5 88 1 5 . 0 8 1 8 . 7 9 2 3 8 . 3 0 8 2 5 7 . 5 1 8 4 5 7 . 2 4 2 2 5 6 . 2 8 2 2 7 5 . 5 8 2 2 5 6 . 3 2 - 1 2 5 1 . 0 3 - 1 8 7 7 . 7 4 1 . 9 1 5 8 4 4 7 5 6 . 9 9 6 6 0 9 2 7 . 7 6 6 9 . 9 8 2 4 4 6 1 7 - 1 4 8 . 7 1 6 4 1 8 1 4 88 4 6 . 9 4 2 0 . 2 0 2 3 9 . 0 5 8 2 8 7 . 5 4 8 4 8 7 . 2 7 2 2 6 6 . 9 1 2 2 8 6 . 2 1 2 2 6 6 . 9 4 - 1 2 5 6 . 5 5 - 1 8 8 6 . 8 3 4 . 4 9 5 8 4 4 7 5 1 . 2 7 6 6 0 9 1 8 . 8 0 6 9 . 9 8 2 4 3 1 0 7 - 1 4 8 . 7 1 6 4 9 0 5 7 88 6 7 . 2 6 2 0 . 6 4 2 3 6 . 7 9 8 3 0 6 . 5 9 8 5 0 6 . 3 2 2 2 7 3 . 9 9 2 2 9 3 . 3 0 2 2 7 4 . 0 3 - 1 2 6 0 . 3 2 - 1 8 9 2 . 8 3 4 . 4 4 5 8 4 4 7 4 7 . 3 8 6 6 0 9 1 2 . 8 8 6 9 . 9 8 2 4 2 0 7 8 - 1 4 8 . 7 1 6 5 3 8 4 5 89 5 0 . 0 0 2 0 . 6 4 2 3 6 . 7 9 8 3 8 4 . 0 2 8 5 8 3 . 7 5 2 3 0 3 . 1 6 2 3 2 2 . 4 7 2 3 0 3 . 1 9 - 1 2 7 6 . 2 9 - 1 9 1 7 . 2 3 0 . 0 0 5 8 4 4 7 3 0 . 8 9 6 6 0 8 8 8 . 8 2 6 9 . 9 8 2 3 7 7 1 2 - 1 4 8 . 7 1 6 7 3 3 0 2 Pa r t MD F r o m (ft ) MD T o (ft ) EO U F r e q (ft ) Ho l e S i z e (in ) Ca s i n g D i a m e t e r (in ) 1 0 . 0 0 0 1 5 1 7 . 4 9 0 A c t S t n s 1 2 . 2 5 0 9 . 6 2 5 1 1 5 1 7 . 4 9 0 1 6 1 3 . 2 1 0 A c t S t n s 1 2 . 2 5 0 9 . 6 2 5 1 1 6 1 3 . 2 1 0 3 3 0 6 . 7 1 0 A c t S t n s 1 2 . 2 5 0 9 . 6 2 5 1 3 3 0 6 . 7 1 0 3 6 4 4 . 7 7 0 A c t S t n s 8 . 5 0 0 0 . 0 0 0 1 3 6 4 4 . 7 7 0 8 8 6 7 . 2 6 0 A c t S t n s 8 . 5 0 0 0 . 0 0 0 Fi n a l D e f i n i t i v e S u r v e y V e r i f i e d a n d S i g n e d - o f f SL B D E : Cl i e n t R e p r e s e n t a t i v e : Da t e : Su r f a c e : 10 4 0 . 7 F S L 3 4 8 6 . 4 F E L S 5 T 7 N R 1 4 E U M 58 4 6 0 4 7 . 6 2 0 6 6 2 7 7 8 . 3 0 7 BH L : 50 4 5 F S L 1 2 8 F E L 7 T 7 N R 1 4 E U M 58 4 4 7 3 0 . 8 9 0 6 6 0 8 8 8 . 8 2 0 IS C W S A R e v 0 * * * 3 - D 9 5 . 0 0 0 % C o n f i d e n c e 2 . 7 9 5 5 s i g m a Al k a i d 2 P H / A l k a i d 2 P H Al k a i d 2 P H / A l k a i d 2 P H SL B _ M W D - I N C _ O N L Y _ F I L L E R SL B _ M W D + S A G A l k a i d 2 P H / A l k a i d 2 P H SL B _ M W D - I N C _ O N L Y _ F I L L E R A l k a i d 2 P H / A l k a i d 2 P H SL B _ M W D + S A G A l k a i d 2 P H / A l k a i d 2 P H Le g a l D e s c r i p t i o n : Nor th i ng (Y ) (f t U S ) Eas ti ng (X ) (f t U S ) SL B _ M W D + S A G Su r v e y P r o g r a m : De s c r i p t i o n Su r v e y T o o l T y p e B o r e h o l e / S u r v e y Su r v e y E r r o r M o d e l : Dr i l l i n g O f f i c e 2 . 1 0 . 8 3 2 . 2 A l a s k a - F r a n k l i n H i l l s \ A l k a i d 2 \ A l k a i d 2 \ A l k a i d 2 P H \ A l k a i d 2 P H 8 / 2 2 / 2 0 2 2 9 : 3 4 A M P a g e 3 o f 3 ! 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D ) **88 ! 88 1 (1 ! /!C 4 ) 88 $$/ ' *$ ( & > =% !$ & ! 4 4 :: >& ! " #$ % From:Amanda McCaleb To:Brooks, James S (OGC) Subject:RE: Alkaid 2 PH_Well Completions or Recompletion & Log (AOGCC Form 10-407) Date:Wednesday, November 30, 2022 2:59:58 PM Excellent. Thanks James. Yours truly, Amanda From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Wednesday, November 30, 2022 2:58 PM To: Amanda McCaleb <amccaleb@pantheonresources.com> Subject: RE: Alkaid 2 PH_Well Completions or Recompletion & Log (AOGCC Form 10-407) I assumed that was the case because when I change it to a 5 it works ! No, I can add this email to the package and that should suffice. thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: Amanda McCaleb <amccaleb@pantheonresources.com> Sent: Wednesday, November 30, 2022 1:47 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: RE: Alkaid 2 PH_Well Completions or Recompletion & Log (AOGCC Form 10-407) James: You are correct. (if there was a facepalm emoji, I would use it ) That was a typo. Would you like me to resubmit the first page with the correction? My apologies. And thank you for catching that. Yours truly, Amanda From: Brooks, James S (OGC) <james.brooks@alaska.gov> You don't often get email from amccaleb@pantheonresources.com. Learn why this is important Sent: Wednesday, November 30, 2022 12:20 PM To: Amanda McCaleb <amccaleb@pantheonresources.com> Subject: RE: Alkaid 2 PH_Well Completions or Recompletion & Log (AOGCC Form 10-407) Hi, Should TD y be 5,844,730.89 instead of 8,844,730.89 ? thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: Amanda McCaleb <amccaleb@pantheonresources.com> Sent: Tuesday, November 15, 2022 1:08 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: RE: Alkaid 2 PH_Well Completions or Recompletion & Log (AOGCC Form 10-407) James: Good Afternoon. I am sorry, not everything fit on the form. In the past I was told to add additional pages instead of adjusting the form. The TD is listed on page 7 of the packet. The TD formation is Middle Schrader Bluff/Canning at 8,950’MD / 8,384’TVD. Hopefully that fixes the problem for the TD in 4b? If it does not, please let me know and I will look further into it. Thanks so much. Yours truly, Amanda McCaleb Operations Coordinator amccaleb@pantheonresources.com Cp. Ph.: (281) 435-2211 From: Brooks, James S (OGC) <james.brooks@alaska.gov> CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Sent: Monday, November 14, 2022 11:41 AM To: Amanda McCaleb <amccaleb@pantheonresources.com> Subject: FW: Alkaid 2 PH_Well Completions or Recompletion & Log (AOGCC Form 10-407) -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Wednesday, November 9, 2022 3:58 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: Alkaid 2 PH_Well Completions or Recompletion & Log (AOGCC Form 10-407) Hi, I believe that the TD y-coordinate (box 4b) may be off. Also what is the TD formation in box 29 ? thanx From: Amanda McCaleb <amccaleb@pantheonresources.com> Sent: Wednesday, November 9, 2022 3:56 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Michael Duncan <michael@greatbearpetro.com> Subject: Alkaid 2 PH_Well Completions or Recompletion & Log (AOGCC Form 10-407) RE: Well Completions or Recompletion & Log (AOGCC Form 10-407): CONFIDENTIAL Great Bear Pantheon LLC Alkaid 2 PH Please see the attached Resubmittal for the Well Completion or Recompletion & Log Application for your review. We sent a link out on October 31st, 2022 with access to our Sharefile with our initial submittal. Please let me know if we need to re-send the link. Thanks. Should you need anything further, please do not hesitate to reach out. I hope you have a nice day. Yours truly, Amanda McCaleb Operations Coordinator amccaleb@pantheonresources.com Cp. Ph.: (281) 435-2211 CiUserslatrniTDoaare MIGREAT BEAR PANTHEOM2022 SUMMER CAMPAIGN_ALKAID 2ALKAID 2_WELL FIL&Regalalay�Sample(s}'W lkad 2_Sampes - 8-17-22AW 17 Au8 22, 1403 59 &mt Omr GREAT BEAR PANTHEON Anchorrage, AK 995034 (907) 868-8070 Date Company Name Great Bear Pantheon, LLC Address 3705 Arctic Blvd., Suite 2324 City, State, ZIP Anchorage, Alaska 99503 Contact Name Josh McIntyre L 7 79S iLc-j3 j Washed & Dried Cutting Samples Well Name: Alkaid 2 PH API# 50-223-20037-00-00 1�ob Field Manifest 08/17/2022 AOGCC Attention: Meredith D. Guhl 333 W. 7th Ave. Anchorage, AK 99501 Phone: (907) 793-1235 Fax: ( Hand Delivered I 1 1 8/17/2022 1 Box 1 Washed & Dried Cutting Samples GBP 300' 1,290' Box 2 Washed & Dried Cutting Samples GBP 1.32$=' 1,950' Box 3 Washed & Dried Cutting Samples GBP 419891 'G 0 2,970' Box 4 Washed & Dried Cutting Samples GBP 34*9% 1 4,200' Box 5 Washed & Dried Cutting Samples GBP 4,2301 ' ZQO 5,400' Box 6 Washed & Dried Cutting Samples GBP C. 6,420' Box 7 Washed & Dried Cutting Samples GBP 6,4a61 C 7,560' Box 8 Washed &Dried Cuttine Samples GBP 7z98' 7-K ✓., f) 18.590, Total:8 1 1 1300' 8,590' RECEIVED AUG 18 2022 AOGcc Printed On: 8/17/2022 2:04 PM 1 of 1 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW0RQGD\$XJXVW$0 7R+ROFRPE6HDQ &F0HGLQD-RKQQ\5HJJ-DPHV%2*& 6XEMHFW5($2*&&7HVW:LWQHVV1RWLILFDWLRQ5HTXHVWVHQW:HGQHVGD\WKHWKDWDP%23(1DERUV $ONDLG)UDQNOLQKLOOVPLOH'DOWRQKLJKZD\ $WWDFKPHQWV1DERUV(5HYLVHG[OV[ dŚĂŶŬǇŽƵ͘ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚĂĚĚŝŶŐƚŚĂƚŶŽƚŝĨŝĐĂƚŝŽŶŝŶĨŽƌŵĂƚŝŽŶ͕ƚŚĞǁĞůůŶĂŵĞŚĂƐďĞĞŶĐŚĂŶŐĞĚƚŽƌĞĨůĞĐƚ ůŬĂŝĚϮW,͕ƚŚĞƚƌĂŝůŝŶŐǌĞƌŽǁĂƐĂĚĚĞĚƚŽWdηϮϮϮϬϳϲϬ͕ƚŚĞůŽǁƚĞƐƚƉƌĞƐƐƵƌĞŽĨϮϱϬǁĂƐĂĚĚĞĚ͕ĂŶĚƚŚĞ&^sDŝƐĐ͘ ĨŝĞůĚƐǁĞƌĞĐŚĂŶŐĞĚƚŽϬ͞E͘͟WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ 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). 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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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗,ŽůĐŽŵď͕^ĞĂŶф^ĞĂŶ͘,ŽůĐŽŵďΛŶĂďŽƌƐ͘ĐŽŵх ^ĞŶƚ͗&ƌŝĚĂǇ͕ƵŐƵƐƚϭϮ͕ϮϬϮϮϯ͗ϮϴWD dŽ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗DĞĚŝŶĂ͕:ŽŚŶŶǇф:ŽŚŶŶǇ͘DĞĚŝŶĂΛŶĂďŽƌƐ͘ĐŽŵх ^ƵďũĞĐƚ͗K'dĞƐƚtŝƚŶĞƐƐEŽƚŝĨŝĐĂƚŝŽŶZĞƋƵĞƐƚƐĞŶƚtĞĚŶĞƐĚĂǇƚŚĞϮϳƚŚĂƚϭϭ͗ϮϰĂŵ͗KW͕EĂďŽƌƐϭϬϱůŬĂŝĚϮ &ƌĂŶŬůŝŶŚŝůůƐŵŝůĞϮϬĂůƚŽŶŚŝŐŚǁĂǇ WŚŽĞďĞ͕ dŚĞĚĂƚĞĂŶĚƚŝŵĞǇŽƵŚĂǀĞƌĞƋƵĞƐƚĞĚĨŽƌEĂďŽƌƐϭϬϱKWƚĞƐƚŽŶϳͲϮϵͲϮϬϮϮŝƐŝŶƚŚĞĨŝƌƐƚĞŵĂŝůŽŶ ƚŚŝƐĐŚĂŝŶ͘ ^ĞĂŶ,ŽůĐŽŵď ϭϬϱZŝŐDĂŶĂŐĞƌ EKZ^Z/>>/E'/E͘ KĨĨŝĐĞϵϬϳͲϵϵϮͲϬϱϭϰDŽďŝůϵϬϳͲϯϱϱͲϭϬϰϭ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH $ONDLG3+ 37' ^ĞĂŶ͘,ŽůĐŽŵďΛŶĂďŽƌƐ͘ĐŽŵ &ƌŽŵ͗ƌŝůůŝŶŐ^ƵƉĞƌǀŝƐŽƌΛŐƌĞĂƚďĞĂƌƉĞƚƌŽ͘ĐŽŵфƌŝůůŝŶŐ^ƵƉĞƌǀŝƐŽƌΛŐƌĞĂƚďĞĂƌƉĞƚƌŽ͘ĐŽŵх ^ĞŶƚ͗&ƌŝĚĂǇ͕ƵŐƵƐƚϭϮ͕ϮϬϮϮϴ͗ϮϳWD dŽ͗,ŽůĐŽŵď͕^ĞĂŶфƐĞĂŶ͘ŚŽůĐŽŵďΛŶĂďŽƌƐ͘ĐŽŵх͖DĞĚŝŶĂ͕:ŽŚŶŶǇф:ŽŚŶŶǇ͘DĞĚŝŶĂΛEĂďŽƌƐ͘ĐŽŵх ^ƵďũĞĐƚ͗΀yd΁&t͗K'dĞƐƚtŝƚŶĞƐƐEŽƚŝĨŝĐĂƚŝŽŶZĞƋƵĞƐƚ͗KW͕EĂďŽƌƐϭϬϱůŬĂŝĚϮ&ƌĂŶŬůŝŶŚŝůůƐŵŝůĞϮϬĂůƚŽŶ ŚŝŐŚǁĂǇ &$87,21(PDLO([WHUQDOWR1DERUV_£35(&$8&,Ï1&RUUHRHOHFWUyQLFRH[WHUQRD1DERUV_ϲΟέΎΧϲϧϭέΗϛϟ·ΩϳέΑϪϳΑϧΗ ίέϭΑΎϧϰϟ· ^ĞŶƚtĞĚŶĞƐĚĂǇƚŚĞϮϳƚŚĂƚϭϭ͗ϮϰĂƐǇŽƵĐĂŶƐĞĞďĞůŽǁ WĂƵů^ŵŝƚŚ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ͕^D ƌŝůůŝŶŐƐƵƉĞƌǀŝƐŽƌΛŐƌĞĂƚďĞĂƌƉĞƚƌŽ͘ĐŽŵ DŽďŝůĞ;ϵϬϳͿϱϮϵͲϬϳϯϳ &ƌŽŵ͗ŽŽŬ͕'ƵǇ;K'ͿфŐƵǇ͘ĐŽŽŬΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕:ƵůǇϮϳ͕ϮϬϮϮϰ͗ϭϵWD dŽ͗ƌŝůůŝŶŐ^ƵƉĞƌǀŝƐŽƌΛŐƌĞĂƚďĞĂƌƉĞƚƌŽ͘ĐŽŵ Đ͗Ăƌů͕ĚĂŵ';K'ͿфĂĚĂŵ͘ĞĂƌůΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗K'dĞƐƚtŝƚŶĞƐƐEŽƚŝĨŝĐĂƚŝŽŶZĞƋƵĞƐƚ͗KW͕EĂďŽƌƐϭϬϱůŬĂŝĚϮ&ƌĂŶŬůŝŶŚŝůůƐŵŝůĞϮϬĂůƚŽŶŚŝŐŚǁĂǇ EŽƚŝĨŝĐĂƚŝŽŶƌĞĐĞŝǀĞĚ͘hŶůĞƐƐĐŽŶƚĂĐƚĞĚďǇĂŶŝŶƐƉĞĐƚŽƌǁŝƚŶĞƐƐŝƐǁĂŝǀĞĚ͘ dŚĂŶŬǇŽƵ͕ 'ƵǇŽŽŬ WĞƚƌŽůĞƵŵ/ŶƐƉĞĐƚŽƌ K' ϵϬϳͲϮϮϳͲϮϲϭϰ ŐƵǇ͘ĐŽŽŬΛĂůĂƐŬĂ͘ŐŽǀ 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 Guy Cook at 907-227-2614 or guy.cook@alaska.gov. &ƌŽŵ͗ĐĞĚͲƐǀĐͲŽŐĐĨŽƌŵƐ;ƐƉŽŶƐŽƌĞĚͿфĐĞĚͲŽŐĐͲũŽƚĨŽƌŵƐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕:ƵůǇϮϳ͕ϮϬϮϮϭϭ͗ϮϰD dŽ͗KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗K'dĞƐƚtŝƚŶĞƐƐEŽƚŝĨŝĐĂƚŝŽŶZĞƋƵĞƐƚ͗KW͕EĂďŽƌƐϭϬϱůŬĂŝĚϮ&ƌĂŶŬůŝŶŚŝůůƐŵŝůĞϮϬĂůƚŽŶŚŝŐŚǁĂǇ YƵĞƐƚŝŽŶŶƐǁĞƌ dǇƉĞŽĨdĞƐƚZĞƋƵĞƐƚĞĚ͗KW ZĞƋƵĞƐƚĞĚdŝŵĞĨŽƌ /ŶƐƉĞĐƚŝŽŶϬϳͲϮϵͲϮϬϮϮϭ͗ϬϬD >ŽĐĂƚŝŽŶEĂďŽƌƐϭϬϱůŬĂŝĚϮ&ƌĂŶŬůŝŶŚŝůůƐŵŝůĞϮϬĂůƚŽŶŚŝŐŚǁĂǇ EĂŵĞDĂƌŬƌŽƵŝůůĞƚ ͲŵĂŝůƌŝůůŝŶŐ^ƵƉĞƌǀŝƐŽƌΛŐƌĞĂƚďĞĂƌƉĞƚƌŽ͘ĐŽŵ WŚŽŶĞEƵŵďĞƌ;ϵϬϳͿ ϵϵϮͲϬϱϭϱ ŽŵƉĂŶǇ'ƌĞĂƚĞĂƌͬWĂƚŚĞŽŶ KƚŚĞƌ/ŶĨŽƌŵĂƚŝŽŶ͗ ĞŶĞĨŝĐŝĂůƚŽĚƌŝůůŝŶŐƉƌŽŐƌĂŵŝĨǁĞƚĞƐƚKWΖƐĞĂƌůǇƐŽǁĞŚĂǀĞƚŝŵĞ ƚŽĚƌŝůůůĂƚĞƌĂůĂŶĚƌƵŶĐĂƐŝŶŐďĞĨŽƌĞŶĞǆƚƚĞƐƚĚĂƚĞ ϵϬϳͲϲϯϭͲϵϴϱϬDĂƌŬƌŽƵŝůůĞƚĐĞůůŝĨŶĞĞĚĞĚ͘ ^ƵďŵŝƐƐŝŽŶ/͗ϱϯϰϳϱϵϬϱϯϬϭϱϳϰϳϲϮϱϮ hd/KEͲydZE>D/>͗dŚŝƐĞŵĂŝůŽƌŝŐŝŶĂƚĞĚĨƌŽŵŽƵƚƐŝĚĞŽĨǇŽƵƌŽƌŐĂŶŝǌĂƚŝŽŶ͘ŽŶŽƚĐůŝĐŬůŝŶŬƐŽƌŽƉĞŶ ĂƚƚĂĐŚŵĞŶƚƐƵŶůĞƐƐǇŽƵƌĞĐŽŐŶŝǌĞƚŚĞƐĞŶĚĞƌĂŶĚŬŶŽǁƚŚĞĐŽŶƚĞŶƚŝƐƐĂĨĞ͘ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:105E DATE: 7/29/22 Rig Rep.: Rig Phone: 907-992-0514 Operator: Op. Phone: Rep.: E-Mail Well Name: PTD #22220760 Sundry # Operation: Drilling: Workover: Explor.: X Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/4800 Annular:250/2500 Valves:250/4800 MASP:3240 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8 P Pit Level Indicators PP #1 Rams 1 4"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 4"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3-1/8 P Inside Reel valves 0NA HCR Valves 2 3-1/8 P Kill Line Valves 2 3-1/8 P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3050 P CHOKE MANIFOLD:Pressure After Closure (psi)2075 P Quantity Test Result 200 psi Attained (sec)15 P No. Valves 14 P Full Pressure Attained (sec)45 P Manual Chokes 0NA Blind Switch Covers: All stations Yes Hydraulic Chokes 2P Nitgn. Bottles # & psi (Avg.): 4@2460 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:6.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 07/27/22 11:24 Waived By Test Start Date/Time:7/28/2022 23:30 (date) (time)Witness Test Finish Date/Time:7/29/2022 5:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors 4" Test Joint. All PVT's and Gas Alarms tested. Closing Times Annular 28 Sec, UPR 4 Sec LPR 4 Sec, Blnd 4 Sec, HCR CH 1 Sec, HCR Kill 1 Sec Johnny Medina Great Bear Mark Brouillet/ Jerry Otto Alkaid 2 PH Test Pressure (psi): michael@greatbearpetro.com Form 10-424 (Revised 02/2022) 2022-0729_BOP_Nabors105E_Alkaid_2-PH 9 9 9 9999 9 9 9 -5HJJ Closing Times Annular 28 Sec, UPR 4 Sec LPR 4 Sec, Blnd 4 Sec, HCR CH 1 Sec, HCR Kill 1 Sec 5HJJ-DPHV%2*& )URP0HGLQD-RKQQ\-RKQQ\0HGLQD#QDERUVFRP! 6HQW7XHVGD\$XJXVW30 7R%URRNV3KRHEH/2*& &F5HJJ-DPHV%2*&+ROFRPE6HDQ 6XEMHFW5H1DERUV(ERSWHVWUHSRUW $WWDFKPHQWVERSWHVWJUHDWEHDU[OV[ )ROORZ8S)ODJ)ROORZXS )ODJ6WDWXV&RPSOHWHG ^ŽƌƌǇĨŽƌƚŚĞŵŝƐƚĂŬĞƐ :ŽŚŶŶǇDĞĚŝŶĂ ZŝŐDĂŶĂŐĞƌ EKZ^>^<Z/>>/E'/E͘ ŝƌĞĐƚϵϬϳ͘ϯϲϬ͘ϯϬϱϲůDŽďŝůϯϬϳ͘ϵϮϭ͘ϭϴϳϴ ũŽŚŶŶǇ͘ŵĞĚŝŶĂΛŶĂďŽƌƐ͘ĐŽŵůǁǁǁ͘ŶĂďŽƌƐ͘ĐŽŵ &ƌŽŵ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗dƵĞƐĚĂǇ͕ƵŐƵƐƚϮ͕ϮϬϮϮϭ͗ϮϭWD dŽ͗DĞĚŝŶĂ͕:ŽŚŶŶǇф:ŽŚŶŶǇ͘DĞĚŝŶĂΛŶĂďŽƌƐ͘ĐŽŵх Đ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗΀yd΁Z͗EĂďŽƌƐϭϬϱďŽƉƚĞƐƚƌĞƉŽƌƚ &$87,21(PDLO([WHUQDOWR1DERUV_£35(&$8&,Ï1&RUUHRHOHFWUyQLFRH[WHUQRD1DERUV_ϲΟέΎΧϲϧϭέΗϛϟ·ΩϳέΑϪϳΑϧΗ ίέϭΑΎϧϰϟ· :ŽŚŶŶǇ͕ dŚĞƐĂŵĞƌĞǀŝƐŝŽŶƐŽŶƚŚĞϳͬϭϴͬϮϮƐŚŽƵůĚďĞŵĂĚĞŽŶƚŚŝƐƌĞƉŽƌƚ;ƚŚĞƚƌĂŝůŝŶŐǌĞƌŽŶĞĞĚƐƚŽďĞĂĚĚĞĚƚŽWdηϮϮϮϬϳϲϬ͕ ƚŚĞǁĞůůŶĂŵĞƐŚŽƵůĚďĞůŬĂŝĚϮW,͕͕ƚŚĞůŽǁƚĞƐƚƉƌĞƐƐƵƌĞŝƐŵŝƐƐŝŶŐ΀ĂƐƐƵŵŝŶŐϮϱϬ΁͕ƚŚĞ&^sDŝƐĐ͘ĨŝĞůĚƐƐŚŽƵůĚƌĞĨůĞĐƚ Ϭ͞E͟ƵŶůĞƐƐĂŶĂĚĚŝƚŝŽŶĂůĐŽŵƉŽŶĞŶƚŝƐŝŶĚŝĐĂƚĞĚŝŶƚŚĞƌĞŵĂƌŬƐ͕ĂŶĚƚŚĞĂƚĞͬdŝŵĞϮϰŚƌEŽƚŝĐĞŐŝǀĞŶǁĂƐůĞĨƚ ďůĂŶŬͿ͘dŚĞŚŽŬĞ>Ŷ͘sĂůǀĞƐ͞&W͟ƐĞĞŵƐƚŽďĞĂĐĂƌƌǇŽǀĞƌĨƌŽŵƚŚĞƉƌĞǀŝŽƵƐƌĞƉŽƌƚĂƐǁĞůů͘ WůĞĂƐĞŵĂŬĞƚŚĞƐĞĐŽƌƌĞĐƚŝŽŶƐĂŶĚƌĞƐƵďŵŝƚƚŚĞƌĞƉŽƌƚ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ <RXGRQ WRIWHQJHWHPDLOIURPMRKQQ\PHGLQD#QDERUVFRP/HDUQZK\WKLVLVLPSRUWDQW $ONDLG3+ 37' 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. 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Phone: Rep.: E-Mail Well Name: PTD #22220760 Sundry # Operation: Drilling: Workover: Explor.: X Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/4800 Annular:250/2500 Valves:250/4800 MASP:3240 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8 P Pit Level Indicators PP #1 Rams 1 4"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 4"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3-1/8 P Inside Reel valves 0NA HCR Valves 2 3-1/8 P Kill Line Valves 2 3-1/8 P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3050 P CHOKE MANIFOLD:Pressure After Closure (psi)2075 P Quantity Test Result 200 psi Attained (sec)15 P No. Valves 14 P Full Pressure Attained (sec)45 P Manual Chokes 0NA Blind Switch Covers: All stations Yes Hydraulic Chokes 2P Nitgn. Bottles # & psi (Avg.): 4@2460 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:6.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 07/27/22 11:24 Waived By Test Start Date/Time:7/28/2022 23:30 (date) (time)Witness Test Finish Date/Time:7/29/2022 5:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors 4" Test Joint. All PVT's and Gas Alarms tested. Closing Times Annular 28 Sec, UPR 4 Sec LPR 4 Sec, Blnd 4 Sec, HCR CH 1 Sec, HCR Kill 1 Sec Johnny Medina Great Bear Mark Brouillet/ Jerry Otto Alkaid 2 PH Test Pressure (psi): michael@greatbearpetro.com Form 10-424 (Revised 02/2022) 2022-0729_BOP_Nabors105E_Alkaid_2-PH 99 9 9 9 9 9 9 9 9 9 9 -5HJJ Closing Times Annular 28 Sec, UPR 4 Sec LPR 4 Sec, Blnd 4 Sec, HCR CH 1 Sec, HCR Kill 1 Sec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Suprv Comm ________ALKAID 2 PH JBR 08/18/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 5K test all Gas and PVT sytems tested. HCR Kill Flange Leak BOP Misc F/P. Manual Choke on Stack F/P. Closing Times Seconds: Ann 23, UPR 4, Blnd 4, LPR 5, HCR/Chk 1, HCR/Kll 1 Test Results TEST DATA Rig Rep:Beard / MedinaOperator:Great Bear Pantheon, LLC Operator Rep:Otto / Smith Rig Owner/Rig No.:Nabors 105E PTD#:2220760 DATE:7/18/2022 Type Operation:EXPL Annular: 250/2500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopMFH220719145842 Inspector Matt Herrera Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 12.5 MASP: 3240 Sundry No: CLOSURE TIME (sec) Time/Pressure P/F Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 0 NAManual Chokes 2 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 4"P #2 Rams 1 Blinds P #3 Rams 1 4"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"FP HCR Valves 2 3 1/8"P Kill Line Valves 2 3 1/8"P Check Valve 0 NA BOP Misc 1 Flange FP System Pressure P3075 Pressure After Closure P2100 200 PSI Attained P13 Full Pressure Attained P43 Blind Switch Covers:PYES Nitgn Btls# &psi (avg)P4@2475 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 9 9 9 9 FP FP HCR Kill Flange Leak Manual Choke on Stack F/P.Closing Times Seconds: Ann 23, UPR 4, Blnd 4, LPR 5, HCR/Chk 1, HCR/Kll 1 2022-0716_Surface_Csg_TopJob_Alkaid-2_ll Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:7/20/2022 P. I. Supervisor FROM:Lou Laubenstein SUBJECT:Surface Casing Remedial Cement Petroleum Inspector Alkaid #2 Great Bear PTD 2220760 7/16/2022:I traveled to the Alkaid #2 well location to witness an annulus cement top-off of the surface casing by conductor annulus. Upon arrival I was met by the Great Bear company representative Jerry Otto. After I was brought up to speed on the situation, I witnessed a measurement of the total void being 100 ft below surface. A 1-inch stinger pipe was made up and run to the bottom of the hole. 20 bbls of fresh water was pumped prior to cement to clean and flush the bottom. Cement returns were seen after pumping 27 bbls; another barrel of cement was pumped to end the batch bringing the total to 28 bbls pumped. The stinger pipe was removed from the annulus and the cement settled just below the top of surface casing. Attachments:none 9 9 9 9 9 gp p total void being 100 ft below surface. James B. Regg Digitally signed by James B. Regg Date: 2022.08.08 18:57:44 -08'00' P.I. Supv Comm: Rig Coil Tubing Unit?NO Rig Contractor Rig Representative Operator Contractor Representative Well Permit to Drill #2220760 Sundry #NA Operation Inspection Location Working Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure P P Flow Rate Sensor P Operating Pressure P P Mud Gas Separator P Fluid Level/Condition P P Degasser P Pressure Gauges P P Separator Bypass P Sufficient Valves P P Gas Detectors P Regulator Bypass P P Alarms Separate/Distinct P Actuators (4-way valves)P P Choke/Kill Line Connections P Blind Ram Handle Cover P P Reserve Pits P Control Panel, Driller P P Trip Tank P Control Panel, Remote P P Firewall P P RIG FLOOR 2 or More Pumps P P Kelly or TD Valves P Independent Power Supply P P Floor Safety Valves P N2 Backup P P Driller's Console P Condition of Equipment P P Flow Monitor P Flow Rate Indicator P Pit Level Indicators P Valves P PPE P Gauges P Remote Hydraulic Choke P Well Control Trained P Gas Detection Monitor P FOV Upstream of Chokes P Housekeeping P Hydraulic Control Panel P Targeted Turns P Well Control Plan P Kill Sheet Current P Bypass Line P FAILURES:0 CORRECT BY: COMMENTS Matt Herrera 7/17/2022 Rig Inspection done in conjunction with initial BOP test - refer to AOGCC Inspection Report # bopMFH220719145842 INSPECT DATE AOGCC INSPECTOR Nabors 105E Nabors Great Bear Pantheon LLC Pipe Rams Blind Rams Seth Beard / Johnny Medina Jerry Otto/ Paul Smith Locking Devices, Rams BOP STACK CLOSING UNIT MISCELLANEOUS Flange/Hub Connections Drilling Spool Outlets Flow Nipple Control Lines Working Pressure, BOP Stack Stack Anchored Choke Line Kill Line Targeted Turns CHOKE MANIFOLD Alkaid #2 MUD SYSTEM Alkaid #2 Drilling Exploration ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT HCR Valve(s) Manual Valves Annular Preventer 2022-0717_Rig_Nabors105E_Alkaid-2_mh rev. 5-16-16 JBR      STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION DIVERTER Test Report for: Reviewed By: P.I. Suprv Comm ________ALKAID 2 PH JBR 07/21/2022 MISC. INSPECTIONS: GAS DETECTORS: DIVERTER SYSTEM:MUD SYSTEM: P/F P/F P/F Alarm Visual Alarm Visual Time/Pressure Size Number of Failures:0 Remarks: TEST DATA Rig Rep:Tony MoralesOperator:Great Bear Pantheon, LLC Operator Rep:Paul Smith Contractor/Rig No.:Nabors 105E PTD#:2220760 DATE:7/4/2022 Well Class:EXP Inspection No:divBDB220706154431 Inspector Brian Bixby Inspector Insp Source Related Insp No: Test Time:2 ACCUMULATOR SYSTEM: Location Gen.:P Housekeeping:P Warning Sign P 24 hr Notice:P Well Sign:P Drlg. Rig.P Misc:NA Methane:P P Hydrogen Sulfide:P P Gas Detectors Misc:0 NA Designed to Avoid Freeze-up?P Remote Operated Diverter?P No Threaded Connections?P Vent line Below Diverter?P Diverter Size:21.25 P Hole Size:12.25 P Vent Line(s) Size:16 P Vent Line(s) Length:98 P Closest Ignition Source:108 P Outlet from Rig Substructure:90 P Vent Line(s) Anchored:P Turns Targeted / Long Radius:NA Divert Valve(s) Full Opening:P Valve(s) Auto & Simultaneous: Annular Closed Time:41 P Knife Valve Open Time:23 P Diverter Misc:0 NA Systems Pressure:P3050 Pressure After Closure:P2050 200 psi Recharge Time:P21 Full Recharge Time:P47 Nitrogen Bottles (Number of):P4 Avg. Pressure:P2450 Accumulator Misc:NA0 P PTrip Tank: P PMud Pits: P PFlow Monitor: 0 NAMud System Misc:     Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Michael Duncan Chief Operating Officer Great Bear Pantheon, LLC 3705 Arctic Blvd, Suite 2324 Anchorage, AK, 99503 Re: Exploratory Field, Exploratory Pool, Alkaid 2 PH Great Bear Pantheon, LLC Permit to Drill Number: 222-076 Surface Location: 1042.6 FSL, 3493.9 FEL, Sec 5, T7N, R14E, Umiat Bottomhole Location: 4956 FSL, 219 FEL, Sec 7, T7N, R14E, Umiat Dear Mr. Duncan: Enclosed is the approved application for the permit to drill the above referenced well. 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 Great Bear Pantheon in the attached application, the following well logs are also required for this well: x Mud log and continuous gas curve recorded from base of conductor to total depth of the well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 day after completion, suspension, or abandonment of this well, or 90 days after acquisition of the data, whichever occurs first. 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, Jeremy M. Price Chair DATED this ___ day of July, 2022. Jeremy Price Digitally signed by Jeremy Price Date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y Samantha Carlisle at 10:39 am, Jun 15, 2022 2022.06.14 16:27:43 -08'00' '65 7%7%' VTL 7/2/2022 Reviewed by Steve Davies. Signed by Dave X SFD 6/23/2022 Rig inspection by AOGCC required prior to spud. Initial BOP test to 5000 psig. Annular preventer test to 2500 psig. Subsequent BOP tests to 4800 psig. Weekly BOP test frequency SC LOT to breakover. Min LOT 13.0 ppg: Depending on LOT will revisit pilot hole depth relative to HRZ top. DLB 07/01/2022 Submit daily drilling operations reports through email. Boyer on his behalf. DLB Exploratory dts 7/4/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.07.04 17:34:28 -08'00' 07/04/2022 CC 0141712109 plbrooks X S 6(&7,21 :HOO3ODW :HOO3ODQ x 6HFWLRQD:HOO3ODW x 6HFWLRQE:HOO3ODQ±$ONDLG3+ x 6HFWLRQE:HOO3ORW±$ONDLG3+ 6(&7,21D :HOO3ODW Great Bear PANTHEON Alkaid #2As-Staked Well Conductor LocationPermit to DrillISSUEDATE:REVISION:DATE:05 July 2022Rev. 105 July 2022DRAWN BY:SHEET:Shane Stragier1 of 1POINT NAMESTATE PLANECOORDINATESLATITTUDE (DD)LONGITUDE (DD)Well CenterSurfaceX = 662,778.307Y = 5,846,047.620LAT: 69.98586463LON: -148.70144349Bottom Hole(BHL)X = 660,799.780Y = 5,844,640.300LAT: 69.98213478LON: -148.71745820ALKAID #2PHNAD27 ALASKA STATE PLANE ZONE 4SECTIONS 5 & 7, T7N, R14E &UMIAT MERIDIANNAD 27Alaska State Plane Zone 4STATEOFALASKA 49THPierre M. StragierNO. LS-981207/05/2022650 W 58th Avenue Suite E Anchorage, Alaska 99518Tel: 1-907-460-1686 Great Bear PANTHEONAlkaid #2PHPermit to Drill/^^hd͗Zs/^/KE͗d͗14 June 2022C14 JUNE 2022ZtEz͗^,d͗Shane Stragier1 of 1SECTION 5, T7N, R14EUMIAT MERIDIANNAD 27Alaska State Plane Zone 4POINT NAMESTATE PLANECOORDINATESLATITTUDE (DD)LONGITUDE (DD)Well CenterSurfaceX = 662,770.711Y = 5,846,049.402LAT: 69.98586994LON: -148.70150377Bottom Hole(BHL)X = 660,799.780Y = 5,844,640.300LAT: 69.98213478LON: -148.71745820ALKAID #2PHNAD27 ALASKA STATE PLANE ZONE 4SUPERSEDED 6(&7,21E :HOO3ODQ $ONDLG3+ $ONDLG3+33URSRVDO*HRGHWLF5HSRUW 'HI3ODQ 2.10.829.1 &RPPHQWV 0' IW ,QFO $]LP7UXH 79'66 IW 79' IW 96(& IW 16 IW (: IW 7) '/6 IW 'LUHFWLRQDO 'LIILFXOW\,QGH[ ([FOXVLRQ =RQH$OHUW ([FOXVLRQ=RQH $QJOH *HR0DJ7K Q7 1RUWKLQJ IW86 (DVWLQJ IW86 /DWLWXGH 16 /RQJLWXGH (: RTE 0.00 0.00 0.00 -201.00 0.00 0.00 0.00 0.00 235.66M N/A 0.00 9.45 9383.24 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 WRP 22.00 0.00 235.66 -179.00 22.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9383.27 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 100.00 0.00 235.66 -101.00 100.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9383.37 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 200.00 0.00 235.66 -1.00 200.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9383.51 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 300.00 0.00 235.66 99.00 300.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9383.64 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 400.00 0.00 235.66 199.00 400.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9383.78 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 500.00 0.00 235.66 299.00 500.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9383.91 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 600.00 0.00 235.66 399.00 600.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9384.04 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 700.00 0.00 235.66 499.00 700.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9384.18 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 800.00 0.00 235.66 599.00 800.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9384.31 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 900.00 0.00 235.66 699.00 900.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9384.45 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 KOP Crv 1.25/100 1000.00 0.00 235.66 799.00 1000.00 0.00 0.00 0.00 235.66M 0.00 0.00 9.45 9384.58 5846049.40 662770.71 N 69 59 9.13 W 148 42 5.41 1100.00 1.50 235.66 898.99 1099.99 1.31 -0.74 -1.08 235.66M 1.50 0.29 10.64 10560.61 5846048.64 662769.65 N 69 59 9.12 W 148 42 5.44 1200.00 3.00 235.66 998.91 1199.91 5.23 -2.95 -4.32 235.66M 1.50 1.20 11.91 11798.69 5846046.36 662766.45 N 69 59 9.10 W 148 42 5.54 1300.00 4.50 235.66 1098.69 1299.69 11.77 -6.64 -9.72 235.66M 1.50 1.72 13.22 13078.32 5846042.55 662761.13 N 69 59 9.07 W 148 42 5.69 1400.00 6.00 235.66 1198.27 1399.27 20.92 -11.80 -17.28 HS 1.50 2.10 14.57 14385.40 5846037.23 662753.69 N 69 59 9.02 W 148 42 5.91 1500.00 7.50 235.66 1297.57 1498.57 32.67 -18.43 -26.98 HS 1.50 2.39 15.95 15709.97 5846030.40 662744.13 N 69 59 8.95 W 148 42 6.19 1600.00 9.00 235.66 1396.54 1597.54 47.02 -26.53 -38.83 HS 1.50 2.63 17.34 17044.76 5846022.05 662732.46 N 69 59 8.87 W 148 42 6.53 1700.00 10.50 235.66 1495.09 1696.09 63.95 -36.08 -52.81 HS 1.50 2.83 18.75 18384.28 5846012.21 662718.68 N 69 59 8.78 W 148 42 6.93 1800.00 12.00 235.66 1593.16 1794.16 83.45 -47.09 -68.92 HS 1.50 3.00 20.18 19724.29 5846000.86 662702.81 N 69 59 8.67 W 148 42 7.39 1900.00 13.50 235.66 1690.70 1891.70 105.52 -59.54 -87.14 HS 1.50 3.16 21.61 21061.38 5845988.03 662684.86 N 69 59 8.55 W 148 42 7.92 2000.00 15.00 235.66 1787.62 1988.62 130.12 -73.42 -107.47 HS 1.50 3.29 23.05 22392.74 5845973.71 662664.84 N 69 59 8.41 W 148 42 8.50 2100.00 16.50 235.66 1883.86 2084.86 157.26 -88.74 -129.88 HS 1.50 3.42 24.50 23716.00 5845957.93 662642.76 N 69 59 8.26 W 148 42 9.14 2200.00 18.00 235.66 1979.36 2180.36 186.91 -105.47 -154.36 HS 1.50 3.53 25.95 25029.11 5845940.68 662618.64 N 69 59 8.09 W 148 42 9.85 EOC #1 (3D-S)2215.92 18.24 235.66 1994.49 2195.49 191.86 -108.26 -158.45 HS 1.50 3.55 26.19 25237.06 5845937.80 662614.61 N 69 59 8.07 W 148 42 9.96 2300.00 18.24 235.66 2074.34 2275.34 218.17 -123.10 -180.18 HS 0.00 3.60 26.19 25237.41 5845922.50 662593.21 N 69 59 7.92 W 148 42 10.59 2400.00 18.24 235.66 2169.32 2370.32 249.46 -140.76 -206.02 HS 0.00 3.66 26.19 25237.84 5845904.30 662567.75 N 69 59 7.75 W 148 42 11.33 2500.00 18.24 235.66 2264.30 2465.30 280.75 -158.42 -231.86 HS 0.00 3.72 26.19 25238.27 5845886.10 662542.29 N 69 59 7.57 W 148 42 12.07 2600.00 18.24 235.66 2359.27 2560.27 312.04 -176.07 -257.70 HS 0.00 3.76 26.19 25238.70 5845867.89 662516.83 N 69 59 7.40 W 148 42 12.81 2700.00 18.24 235.66 2454.25 2655.25 343.33 -193.73 -283.55 HS 0.00 3.80 26.19 25239.12 5845849.69 662491.38 N 69 59 7.23 W 148 42 13.56 2800.00 18.24 235.66 2549.22 2750.22 374.62 -211.39 -309.39 HS 0.00 3.84 26.19 25239.55 5845831.49 662465.92 N 69 59 7.05 W 148 42 14.30 2900.00 18.24 235.66 2644.20 2845.20 405.91 -229.04 -335.23 HS 0.00 3.88 26.19 25239.98 5845813.29 662440.46 N 69 59 6.88 W 148 42 15.04 3000.00 18.24 235.66 2739.18 2940.18 437.20 -246.70 -361.07 HS 0.00 3.91 26.19 25240.41 5845795.09 662415.00 N 69 59 6.71 W 148 42 15.78 3100.00 18.24 235.66 2834.15 3035.15 468.49 -264.35 -386.91 HS 0.00 3.94 26.19 25240.84 5845776.89 662389.54 N 69 59 6.53 W 148 42 16.52 3200.00 18.24 235.66 2929.13 3130.13 499.78 -282.01 -412.75 HS 0.00 3.97 26.19 25241.27 5845758.69 662364.08 N 69 59 6.36 W 148 42 17.26 3300.00 18.24 235.66 3024.10 3225.10 531.07 -299.67 -438.60 HS 0.00 4.00 26.19 25241.70 5845740.49 662338.63 N 69 59 6.18 W 148 42 18.01 3400.00 18.24 235.66 3119.08 3320.08 562.36 -317.32 -464.44 HS 0.00 4.02 26.19 25242.13 5845722.29 662313.17 N 69 59 6.01 W 148 42 18.75 3500.00 18.24 235.66 3214.06 3415.06 593.66 -334.98 -490.28 HS 0.00 4.05 26.19 25242.57 5845704.08 662287.71 N 69 59 5.84 W 148 42 19.49 9-5/8" Csg 3522.00 18.24 235.66 3234.95 3435.95 600.54 -338.86 -495.97 HS 0.00 4.05 26.19 25242.66 5845700.08 662282.11 N 69 59 5.80 W 148 42 19.65 3600.00 18.24 235.66 3309.03 3510.03 624.95 -352.63 -516.12 HS 0.00 4.07 26.19 25243.00 5845685.88 662262.25 N 69 59 5.66 W 148 42 20.23 3700.00 18.24 235.66 3404.01 3605.01 656.24 -370.29 -541.96 HS 0.00 4.09 26.19 25243.43 5845667.68 662236.79 N 69 59 5.49 W 148 42 20.97 3800.00 18.24 235.66 3498.99 3699.99 687.53 -387.95 -567.81 HS 0.00 4.11 26.19 25243.86 5845649.48 662211.33 N 69 59 5.32 W 148 42 21.72 3900.00 18.24 235.66 3593.96 3794.96 718.82 -405.60 -593.65 HS 0.00 4.13 26.19 25244.30 5845631.28 662185.88 N 69 59 5.14 W 148 42 22.46 4000.00 18.24 235.66 3688.94 3889.94 750.11 -423.26 -619.49 HS 0.00 4.15 26.19 25244.73 5845613.08 662160.42 N 69 59 4.97 W 148 42 23.20 4100.00 18.24 235.66 3783.91 3984.91 781.40 -440.92 -645.33 HS 0.00 4.17 26.19 25245.17 5845594.88 662134.96 N 69 59 4.79 W 148 42 23.94 4200.00 18.24 235.66 3878.89 4079.89 812.69 -458.57 -671.17 HS 0.00 4.18 26.19 25245.60 5845576.68 662109.50 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ŵŽĚĞůƐ͕ŵĞĂƐƵƌĞŵĞŶƚƐ͕ĂƐƐƵŵƉƚŝŽŶƐĂŶĚŝŶĨĞƌĞŶĐĞƐƚŚĂƚĂƌĞŶŽƚŝŶĨĂůůŝďůĞ͘ ĂůĐƵůĂƚŝŽŶƐĂƌĞĞƐƚŝŵĂƚĞƐďĂƐĞĚŽŶƉƌŽǀŝĚĞĚŝŶĨŽƌŵĂƚŝŽŶ͘ůůƉƌŽƉŽƐĂůƐ͕ƌĞĐŽŵŵĞŶĚĂƚŝŽŶƐ͕ŽƌƉƌĞĚŝĐƚŝŽŶƐĂƌĞŽƉŝŶŝŽŶƐŽŶůǇ͘ EKtZZEdz/^'/sEKEZE/E'hZzKZKDW>dE^^K&d͕/E&KZDd/KEWZ^Ed͕&&d/sE^^K&DdZ/>͕WZKhd^KZ ^hWW>/^͕ZKDDEd/KE^D͕KZZ^h>d^K&d,^Zs/^ZEZ͘ ϮŽĨϭϳ ŽĐƵŵĞŶƚŽŶƚƌŽů Once approved by Schlumberger and the Operator, any deviation from this program requires document agreement (SLB QHSE Standard S010 Management of Change and Exemption Standard) Approvals Name Signature Date Author Mitch Rice Schlumberger review Schlumberger Approval Customer Approval Michael Duncan “By signing this document (or confirmation email), I confirm I have reviewed and approved it as the basis for the well cementin g program.” Cementing Program Generated From Cementics File alkaid 2_design_9_58_casing.jdcx Cementics Version 2020.1.13 Revision History Date Version Description Author 4/22/2022 Centralizing Exploring centralizer options Mitch Rice 5/14/2022 Draft Draft program for initial review Mitch Rice 5/17/2022 1 Updated mud properties Mitch Rice ϯŽĨϭϳ tĞůůĂƚĂ^ƵŵŵĂƌǇ The cementing program incorporates the following data : RigType Land Fluids Return to Rig Floor BHST 104.8 degF All depths take the rig floor as reference Mud Line Depth 0.0 ft Mud Return Depth 0.0 ft Section MD 3500.0 ft Section TVD 3423.9 ft Tubulars and Casing Hardware MD ft OD in Joint ft Weight lb/ft ID in Grade Collapse psi Burst psi Thread Prev Casing 100.0 20 40.0 106.5 19 J-55 770.0 2410.0 Casing 3500.0 9 5/8 40.0 40.0 8.835 L-80 3090.0 5750.0 Landing Collar 3420.0 Serial number : Open Hole Total Volume 713.2 bbl Minimum Diameter 12.250 in Maximum Diameter 12.250 in Mean Diameter 12.250 in Mean Annular Excess 118.6 % Mean Equivalent Diameter 14.695 in ϰŽĨϭϳ Formation – Pending Top MD ft Bottom MD ft Bottom TVD ft Frac Top ED lb/gal Frac Bottom ED lb/gal Pore Top ED lb/gal Pore Bottom ED lb/gal Lithology Res. Fluid Name 0.0 100.0 100.0 2.31 2.31 1.54 1.54 Sandstone 100.0 3500.0 3423.9 2.89 0.09 1.54 0.05 Sandstone Temperature - Pending Name Top MD ft Bottom MD ft Bottom TVD ft Temperature degF Gradient degF/100ft Relative Gradient degF/100ft Sea Current ft/min Surface 0.0 0.0 0.0 50.0 0.00 0.00 BHST 0.0 3500.0 3423.9 104.8 1.60 1.60 0.00 ϱŽĨϭϳ &ůƵŝĚƐ^ƵŵŵĂƌǇ Fluids Type Name Density lb/gal Conditions K lbf.s^n/ft2 n Ty lbf/100ft2 Spacer MUDPUSH* II 10.00 Surface 68.0 degF 1.77E-2 0.45 9.23 Drilling Fluid Drilling Fluid 9.50 Manual 2.09E-4 1.00 30.00 Slurry 10.7 ppg ARTICSET Lite III - Lead 10.70 Custom 80.0 degF 5.43E-3 0.58 13.10 Slurry G-blend Tail 15.80 Custom 80.0 degF 4.68E-3 0.86 1.75 * Compressible Rheology Parameters and Densities are displayed at P=1 atm and T=20 degC (65degF) 9.50 ϲŽĨϭϳ DƵĚŝƌĐƵůĂƚŝŽŶ Fluid MI-SWACO DF Number of Circulation 0.86 Total Volume at Ambient T 600.0 bbl Ambient Temperature 50.0 degF Correction Slope 0.00 Pumping Stages Fluid Pump Rate bbl/min Duration hr:mn Volume bbl Pause 00:03 MI-SWACO DF 5.0 02:00 600.0 Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Failure Fracturing -1693.3 3500.0 02:03 Success Production/Influx 4.8 100.0 00:36 Success Burst 5693.0 0.0 02:03 Success Collapse 2915.2 3500.0 00:09 ϳŽĨϭϳ &ůƵŝĚWůĂĐĞŵĞŶƚ Surface Densities are computed at P=1 atm and T=Surface Temperature (50.0 degF) Fluid Placement in Annulus Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal MI-SWACO DF 0.0 0.0 0.0 0.0 9.50 MUDPUSH* II 0.0 0.0 0.0 50.0 10.00 10.7 ppg ARTICSET Lite III - Lead 0.0 3000.0 3000.0 391.4 10.70 G-blend Tail 3000.0 3500.0 500.0 41.8 15.80 Fluid Placement in Pipe Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal MI-SWACO DF 0.0 3314.5 3314.5 251.3 9.50 MUDPUSH* II 3314.5 3420.0 105.5 8.0 10.00 G-blend Tail 3420.0 3500.0 80.0 6.1 15.80 ϴŽĨϭϳ WƵŵƉŝŶŐ^ĐŚĞĚƵůĞ Pumping Schedule Fluid Name Duration hr:mn Volume bbl Pump Rate bbl/min Injection Temperature degF Comment Cumulated Time hr:mn MUDPUSH* II 00:10 50.0 5.0 68.0 Spacer ahead 00:10 Plug 00:00 Drop plug 00:10 10.7 ppg ARTICSET Lite III - Lead 01:18 391.4 5.0 68.0 Pump Lead 01:28 G-blend Tail 00:10 47.9 5.0 68.0 Switch to tail 01:38 Top Plug 00:00 Drop top plug 01:38 MUDPUSH* II 00:02 8.0 5.0 68.0 Spacer behind 01:39 MI-SWACO DF : 00:52 251.3 > MI-SWACO DF 00:49 245.0 5.0 68.0 Displace 02:28 > MI-SWACO DF 00:03 6.3 2.0 68.0 Slow to bump plug 02:32 Maximum Required Hydraulic Horsepower (HHP) 50.4 hhp (at 02:28 hr:mn) ϵŽĨϭϳ ϭϬŽĨϭϳ dĞŵƉĞƌĂƚƵƌĞKƵƚƉƵƚƐ Ͳ WĞŶĚŝŶŐǁĞůůƚĞŵƉĚĂƚĂ Temperature Summary Table Static Temperature. at TOC 50.0 degF Static Temperature at BH 104.8 degF Simulated HCT at TOC 65.7 degF Simulated HCT at BH 68.1 degF Max First SK Temperature 68.0 degF Max Last SK Temperature 68.1 degF At time 00:00 hr:mn At time 02:32 hr:mn ϭϭŽĨϭϳ ĞŶƚƌĂůŝǌĂƚŝŽŶ Centralizers Alias Manufacturer Commercial Name Type Config Csg OD in Min OD in Max OD in Count 9 5/8" DMOP Integral Spiral Bowspring DMOP Full Coverage Spiral Bow bow- spring Spiral 9 5/8 12.150 12.250 25 Pattern Placement Bottom MD ft Joints Centralizer Alias Pattern Min STO Depth ft 500.0 12.50 9 5/8" DMOP Integral Spiral Bowspring 0 82.4 497.0 3020.0 63.00 9 5/8" DMOP Integral Spiral Bowspring 1/4 0.0 1075.8 3420.0 10.00 9 5/8" DMOP Integral Spiral Bowspring 1/2 10.9 3023.0 3500.0 2.00 9 5/8" DMOP Integral Spiral Bowspring 2/1 66.8 3422.7 Computation time: Cement Turns 00:59 ϭϮŽĨϭϳ ϯWZdhZ Average Fluid Concentrations Average fluid concentration in annulus ϭϯŽĨϭϳ Post-Processing Results (Annulus) ϭϰŽĨϭϳ 3D Results ϭϱŽĨϭϳ KƉĞƌĂƚŽƌ^ƵŵŵĂƌǇ Volume Summary Fluid Name Pumped Volume bbl Prepared Fluid Dead Volume bbl Prepared Fluid bbl Mix Fluid Dead Volume bbl Silo dead volume ton 10.7 ppg ARTICSET Lite III - Lead 391.4 0.0 391.4 0.0 0 G-blend Tail 47.9 0.0 47.9 0.0 0 MUDPUSH* II 58.0 0.0 58.0 0.0 0 Material Summary Additive Pumped Quantity Required Quantity Loadout Quantity Loadout Items Pack. Name Pack. Size Comment D031 5231 lb 5231 lb 5231 lb 47.55 sack 110 lb Fresh Water 13871 gal 13871 gal 13871 gal 0.00 0 gal D182 270 lb 270 lb 270 lb 5.40 sack 50 lb 10.7 ppg ARTICSET Lite III - Lead Blend 78855 lb 78855 lb 78855 lb 0.00 bulk 0 lb Mix Water 11605 gal 11605 gal 11605 gal 0.00 0 gal D044 7829 lb 7829 lb 7829 lb 142.35 sack 55 lb D079 710 lb 710 lb 710 lb 7.10 sack 100 lb D065 362 lb 362 lb 362 lb 7.25 sack 50 lb D047 90 gal 90 gal 90 gal 18.06 pail 5 gal S002 591 lb 591 lb 591 lb 5.91 sack 100 lb G-blend Tail Blend 21575 lb 21575 lb 21575 lb 0.00 bulk 0 lb D255 86 lb 86 lb 86 lb 3.92 sack 22 lb D186 34 gal 34 gal 34 gal 6.89 pail 5 gal ϭϲŽĨϭϳ Fluid Preparation 10.7 ppg ARTICSET Lite III - Lead Pumped Volume : 391.4 bbl Density : 10.70 lb/gal SVF : 33.6 % Yield : 2.79 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 88262 lb 88262 lb 10.7 ppg ARTICSET Lite III - Lead Blend: 100 lb per sack 78855 lb 78855 lb 78855 lb D044 9.0 % BWOW 7829 lb 7829 lb 7829 lb D079 0.9 % BWOB 710 lb 710 lb 710 lb D065 0.3 % BWOB 276 lb 276 lb 276 lb S002 0.8 % BWOB 591 lb 591 lb 591 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 13.362 gal/sk VBWOB 10535 gal 10535 gal Mix Water 13.262 gal/sk VBWOB 10456 gal 10456 gal 10456 gal Fresh Water 13.262 gal/sk VBWOB 10456 gal 10456 gal 10456 gal D047 0.100 gal/sk VBWOB 79 gal 79 gal 79 gal G-blend Tail Pumped Volume : 47.9 bbl Density : 15.80 lb/gal SVF : 39.9 % Yield : 1.17 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 21748 lb 21748 lb G-blend Tail Blend: 94 lb per sack 21575 lb 21575 lb 21575 lb - D907 100.0 % BWOB 21575 lb 21575 lb 21575 lb D065 0.4 % BWOC 86 lb 86 lb 86 lb D255 0.4 % BWOC 86 lb 86 lb 86 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 5.205 gal/sk VBWOB 1194 gal 1194 gal Mix Water 5.005 gal/sk VBWOB 1149 gal 1149 gal 1149 gal Fresh Water 5.005 gal/sk VBWOB 1149 gal 1149 gal 1149 gal D047 0.050 gal/sk VBWOB 11 gal 11 gal 11 gal D186 0.150 gal/sk VBWOB 34 gal 34 gal 34 gal 391.4bbl(5.615ft3/bbl)(1/2.79ft3/sx)= 788 sx VTL 47.9bbl(5.615ft3/bbl)(1/1.17ft3/sx)= 230 sx VTL ϭϳŽĨϭϳ MUDPUSH* II Pumped Volume : 58.0 bbl Density : 10.00 lb/gal Weighting Material Concentration Pumped Quantity Required Quantity Loadout Quantity MUDPUSH* II Weighting Material: 2.15 lb/gal WBVOSpacer 5231 lb 5231 lb 5231 lb - D031 2.15 lb/gal WBVOSpacer 5231 lb 5231 lb 5231 lb Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpacer 2291 gal 2291 gal Fresh Water 0.9 bbl/bbl BVOSpacer 2267 gal 2267 gal 2267 gal D182 5.00 lb/bbl WBVOBF 270 lb 270 lb 270 lb 6(&7,21E 3OXJB&HPHQW3URJUDP $ONDLG3+ WůƵŐĞŵĞŶƚŝŶŐWƌŽŐƌĂŵ ůŬĂŝĚϮʹWŝůŽƚ,ŽůĞWůƵŐϭĞŵĞŶƚŝŶŐWƌŽŐƌĂŵ sĞƌƐŝŽŶͲƌĂĨƚ ϱͬϭϳͬϮϬϮϮ Prepared for : Prepared by : Michael Duncan Mitch Rice Great Bear Pantheon 346-901-3354 mrice@slb.com 2 of 18 :KK:d/s^E^/'EKE^/Zd/KE^ Job Objectives Place a plug at 9,400 ft up to 8,000 ft. Fill pilot hole and provide a base for plug 2 which will serve as a KOP Acceptance Criteria Pump cement as designed (volume, density and rate range) and have this plug provide a base for plug 2 (KOP) Other Known Hazards Hazard Description Mitigation None known N/A Design Criteria vs. Job Objectives Place plug at bottom of hole (9400’) to 8000 ft Balanced plug placement will be utilized Planned plug volume is 118 bbls of 15.8 Class G cement This Plug 1 will serve as a base for the second plug (KOP) Operational Risk Statement Cement plugs operations are complex to design and execute and this complexity should not be underestimated. Cement plugs operat ions should never be considered as a “routine” job. To successfully set cement plugs the same methodology used to design and execute primar y cement jobs is required, which includes but is not limited to correct slurry design, mud-removal and placement design based on accurate well d ata. Cement plugs are remedial cementing treatments. The first design step is the determination of the actual problem to solve, i.e. define the purpose of setting a cement plug. The second step consists in defining the evaluation criteria: tag / no tag, positive pressure test, negative test, etc. Both steps allow for the proper specification of slurry properties and the determination of the adequate plug placement technique. This can result i n additional laboratory tests as well as additional equipment requirements. Nelson in Well Cementing (2006) discusses several factors that are key to successful plug cementing operations. 1.Displacement and under-displacement volumes play a critical role for the success of the job. The volumes specified in this prog ram should be followed. 2.Fluid contamination/mixing during plug setting can jeopardize job success. To mitigate this risk, using a stable base for the p lug, mechanical separators, and appropriate wait-on-cement-time is strongly recommended. 3.In case of a Kick-off Plug, proper knowledge of the BHA and application of correct drilling techniques are required to kick-off . In case of any deviation from the approved job procedure, a Management of Change (MoC) is required. By raising a MoC to the app ropriate level within the operator organization as well as within Schlumberger Well Services, all the operational risks can be identified and addressed prior to execution of the cement plug. s 118 bbls of 15.8 Class G cement 3 of 18 W>h'KWZd/KE^hDDZz Overview of the cementing operation (temperatures, fluid types, rates and general notes) All depths take the rig floor as reference Well & Rig Information Rig Type : Land Objective :Place a plug at 9,400 ft up to 8,000 ft Section MD : 9400.0 ft Rig Floor Elev 0.0 ft Section TVD : 9031.6 ft Mud Returns Depth : 0.0 ft Well deviation : 18.1 deg Placement & Post-Placement Conditions Top : 8006.7 ft Mechanical Separator : TBC POOH depth : 7214.1 ft Length : 1393.3 ft POOH Speed : Bottom : 9400.0 ft Pipe Rotation / Reciprocation : TBC Circ. rate : 7.7 bbl/min Support : Bottom of hole Circ. direction : Direct Design Considerations G-blend Tail MUDPUSH* II Drilling Fluid Cement Type : Slurry Spacer Type : Spacer Mud Type : Water Based / Fresh Water Slurry Dens. : 15.80 lb/gal Spacer Dens. : 10.00 lb/gal Mud Dens. : 9.40 lb/gal Volume Balance Model : Level Slurry & Spacer Underdispl. : 0.0 bbl Pumping Schedule Fluid Name Stage Volume bbl Pump Rate bbl/min Stage Time hr:mn Comment Inj. Temp. degF MUDPUSH* II 34.5 5.0 00:07 68.0 G-blend Tail 117.9 5.0 00:24 68.0 MUDPUSH* II 5.5 5.0 00:01 68.0 Drilling Fluid 80.3 5.0 00:16 68.0 Temperature Simulation – PENDING TEMP DATA BHST 193.5 degF Simulated BHCT 127.9 degF 4 of 18 t>>d^hDDZz The cementing program incorporates the following data: All depths take the rig floor as reference Section MD : 9400.0 ft Rig Floor Elev 0.0 ft Section TVD : 9031.6 ft Mud Returns Depth : 0.0 ft Tubulars and Casing Hardware MD ft OD in Weight lb/ft Grade ID in Thread Collapse psi Burst psi Joint ft Prev Casing 100.0 20 106.5 J-55 19 770.0 2410.0 40.0 3500.0 9 5/8 40.0 L-80 8.835 3090.0 5750.0 40.0 Workstring 9400.0 4 14.0 S135 3 17/50 20170.0 19490.0 40.0 Dart/Ball Launch Manifold TBC Note : previous casing (and riser) collapse and burst security not verified Open Hole Total OH Volume : 496.9 bbl Mean Diameter : 8.500 in Minimum Diameter : 8.500 in Open hole Excess : 20.0 % Maximum Diameter : 8.500 in Mean Eq. Diameter : 9.311 in 5 of 18 &>h/^^hDDZz Fluids Type Name Density lb/gal Conditions K lbf.s^n/f t2 n Ty lbf/100ft 2 Spacer MUDPUSH* II 10.00 Surface 68.0 degF 1.77E-2 0.45 9.23 Drilling Fluid Drilling Fluid 9.40 Manual 2.09E-4 1.00 15.00 Slurry 10.7 ppg ARTICSET Lite III - Lead 10.70 Surface 68.0 degF 4.75E-3 0.61 12.30 Slurry G-blend Tail 15.80 Surface 68.0 degF 4.68E-3 0.86 1.75 * Rheology and density of compressible fluids are displayed at standard conditions, ie. P = 1 atm and T = 20 degC (65 degF) 9.40 6 of 18 Dh/Zh>d/KE Fluid Drilling Fluid Number of Circulation 1.37 Total Volume at Ambient Temperature 1020.0 bbl Ambient Temperature 40.0 degF Correction Slope 0.00 Pumping Stages Fluid Pump Rate bbl/min Duration hr:mn Volume bbl Pause 00:05 Drilling Fluid 2.0 00:05 10.0 Drilling Fluid 5.0 00:10 50.0 Drilling Fluid 8.0 02:00 960.0 Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 921.4 3500.0 02:20 Success Production/Influx 281.8 3500.0 02:20 Success Burst 18476.1 0.0 02:20 Success Collapse 19442.3 9400.0 02:20 7 of 18 &>h/W>DEd Volume Balance Objectives Volume Balance Model: Level Slurry & Spacer Original Fluid: Drilling Fluid Rat Hole Fluid: Drilling Fluid Displ. Fluid: Drilling Fluid Top Spacer: MUDPUSH* II set Total Volume to: 40.0 bbl Top Slurry: G-blend Tail set Top MD to: 8000.0 ft Annulus is not filled during POOH. Volume Balance Results String Volume: 101.9 bbl Underdispl.: 0.0 bbl Displ. Volume: 80.3 bbl TOC after POOH: 8000.0 ft Cement Length after POOH: 1400.0 ft Fluid Placement in Annulus Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal Drilling Fluid 0.0 7414.1 7414.1 507.3 9.40 MUDPUSH* II 7414.1 7917.1 503.0 34.5 10.00 G-blend Tail 7917.1 9400.0 1482.9 101.8 15.80 Fluid Placement in Pipe Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal Drilling Fluid 0.0 7414.1 7414.1 80.3 9.40 MUDPUSH* II 7414.1 7917.1 503.0 5.5 10.00 G-blend Tail 7917.1 9400.0 1482.9 16.1 15.80 Note: Surface densities of compressible fluids are calculated at surface conditions, ie. P = 1 atm and T = 40.0 degF 8 of 18 ^dd/Wh>>KhdK&,K>;WKK,Ϳ POOH Summary Final DP depth : 7214.1 ft Theoretical Top of Plug: 8000.0 ft POOH Length : 2185.9 ft Theoretical Plug Length : 1400.0 ft POOH Speed : TBC Plug Bottom : 9400.0 ft Top of uncontaminated cement after POOH : 8006.7 ft Uncontaminated cement length after POOH : 1393.3 ft Contaminated cement length after POOH : 65.5 ft POOH Results Summary Note : Simulation assumes that fluids are free to balance themselves. 9 of 18 WhDW/E'^,h> Volume and rate of compressible fluids are calculated at surface conditions, ie. P = 1 atm and T = 40.0 degF Pumping Schedule Fluid Name Stage Volume bbl Pump Rate bbl/min Stage Time hr:mn Cum. Time hr:mn Comment Inj. Temp. degF MUDPUSH* II 34.5 5.0 00:07 00:07 68.0 G-blend Tail 117.9 5.0 00:24 00:30 68.0 MUDPUSH* II 5.5 5.0 00:01 00:32 68.0 Drilling Fluid 80.3 5.0 00:16 00:48 68.0 Maximum Required Hydraulic Horsepower (HHP) 79.9 hhp (at 00:48 hr:mn) Displacement Volume Considerations Volume bbl Variation bbl Theoretical displacement volume 130.1 Underdisplacement 0.0 Final Displacement 130.1 Thickening Time Requirement Based on Schlumberger Well Services Thickening Time requirement, the minimum thickening time should be either 1.5 times the cem ent placement time or cement placement time + 2 hours, whichever is greater: Consistency Pumping Time POOH Time Circulate Clean* Misc. Ops** Required TT Actual TT Additional batch mix Cement Slurry 70 Bc 00:56 00:30 1:30 0:00 05:30 TBD 0:00 * Minimum circulation volume: 1.5 string volume ** Include all stops, squeeze and eventual tool operation 10 of 18 dDWZdhZKhdWhd^;WE/E't>>dDWdͿ BHST : 193.5 degF Simulated BHCT : 127.9 degF Static Temp at TOC : 169.6 degF Simulated HCT at TOC : 128.5 degF Temperature simulation initial condition: Mud Circulation profile Initial Condition Final Condition t = 00:48 hr:mn 11 of 18 BHCT and Interface temperatures 12 of 18 t>>>E/// WELLCLEAN III Maps Ű No cement slurry Slurry concentration is less than 10 % (by unit of volume). The concentration is below minimum threshold to consider that cement is present. Ű High risk of contamination Slurry concentration is between 10 % and 50 % (by unit of volume). There is no chance of finding hard cement when tagging within a few hours. Ű Medium risk of contamination Slurry concentration is between 50 % and 90 % (by unit of volume). It is possible to find some soft cement when tagging but it will be most likely not strong enough to kick off the well or even to provide a proper wellbore isolation. Ű Low risk of contamination Slurry concentration is between 90 % and 100 % (by unit of volume). Cement plug should be designed in such a way the target of the top of cement should be within the ‘green risk’ zone. Hard cement should be found in that zone once compressive strength has developed, i.e. after the duration determined by the lab tests at downhole condition. 13 of 18 Fluid Concentrations before POOH Average fluid concentration in annulus Average fluid concentration in pipe 14 of 18 &/E>KEdD/Ed/KEZ/^<;&dZWKK,Ϳ POOH Summary Final DP depth : 7214.1 ft Theoretical Top of Plug: 8000.0 ft Theoretical Top of Plug (based on slurry volume) 8000.0 ft Estimated TOC based on uncontaminated POOH simulation 8006.7 ft Estimated TOC after POOH considering contamination during placement 8115.0 ft Final Contamination Risk Note : Simulation assumes that fluids are free to balance themselves 15 of 18 WK^dͲW>DEd/Zh>d/KE Volume of compressible fluids is displayed at ambient conditions, ie. P = 1 atm and T = 40.0 degF DP Depth for Circulation : 7125.5 ft Designed TOC : 8000.0 ft Circulating Fluid : Drilling Fluid Total Volume : 730.0 bbl Circulation direction : Direct Number of Circulations : 1.29 Circulation Stages Stage Pump Rate Duration hr:mn Volume Back-pressure psi Pause 00:03 0.0 Drilling Fluid 2.0 00:05 10.0 0.0 Drilling Fluid 8.0 01:30 720.0 0.0 Status Description Min. Pressure Margin psi at Depth ft at Time hr:mn Success Fracturing 921.4 3500.0 01:38 Success Production/Influx 281.8 3500.0 01:38 Success Burst 18720.7 0.0 01:38 Success Collapse 19616.5 7125.5 01:38 Post-Placement Well Control 16 of 18 KWZdKZ^hDDZz Fluid Volume Summary Fluid Name Pumped Volume bbl Fluid Dead Volume bbl Total Fluid Volume bbl Mix Fluid Dead Volume bbl Silo Dead Weight ton G-blend Tail 117.9 0.0 117.9 0.0 0 MUDPUSH* II 40.0 0.0 40.0 0.0 0 Material Summary Additive Pumped Quantity Required Quantity Loadout Quantity Loadout Items Pack. Name Pack. Size Comment D031 3607 lb 3607 lb 3607 lb 32.80 sack 110 lb Fresh Water 4459 gal 4459 gal 4459 gal 0.00 0 gal D182 186 lb 186 lb 186 lb 3.72 sack 50 lb G-blend Tail Blend 53433 lb 53433 lb 53433 lb 0.00 bulk 0 lb Mix Water 2896 gal 2896 gal 2896 gal 0.00 0 gal D047 28 gal 28 gal 28 gal 5.68 pail 5 gal D065 214 lb 214 lb 214 lb 4.27 sack 50 lb D255 214 lb 214 lb 214 lb 9.72 sack 22 lb S001 53 lb 53 lb 53 lb 0.53 sack 100 lb Fluid Preparations G-blend Tail Pumped Volume : 117.9 bbl Yield : 1.16 ft3/sk Slurry Density : 15.80 lb/gal SVF : 40.2 % Dry Phase Concentration Reference Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 53861 lb 53861 lb G-blend Tail Blend: 94 lb per sack 53433 lb 53433 lb 53433 lb - D907 100.0 % BWOB 53433 lb 53433 lb 53433 lb D065 0.4 % BWOC 214 lb 214 lb 214 lb D255 0.4 % BWOC 214 lb 214 lb 214 lb Liquid Phase Concentration Reference Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 5.152 gal/sk VBWOB 2928 gal 2928 gal Mix Water 5.096 gal/sk VBWOB 2896 gal 2896 gal 2896 gal Fresh Water 5.096 gal/sk VBWOB 2896 gal 2896 gal 2896 gal D047 0.050 gal/sk VBWOB 28 gal 28 gal 28 gal S001 0.1 % BWOB 53 lb 53 lb 53 lb Lab report : 17 of 18 MUDPUSH* II Pumped Volume : 40.0 bbl Slurry Density : 10.00 lb/gal Weighting Material Concentration Reference Pumped Quantity Required Quantity Loadout Quantity MUDPUSH* II Weighting Material: 2.15 lb/gal WBVOSpacer 3607 lb 3607 lb 3607 lb - D031 2.15 lb/gal WBVOSpacer 3607 lb 3607 lb 3607 lb Base Fluid Concentration Reference Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpacer 1580 gal 1580 gal Fresh Water 0.9 bbl/bbl BVOSpacer 1563 gal 1563 gal 1563 gal D182 5.00 lb/bbl WBVOBF 186 lb 186 lb 186 lb Lab report : 18 of 18 6(&7,21E 3OXJB.233URJUDP $ONDLG3+ WůƵŐĞŵĞŶƚŝŶŐWƌŽŐƌĂŵ ůŬĂŝĚϮʹWŝůŽƚ,ŽůĞWůƵŐϮʹ<KW sĞƌƐŝŽŶͲϭ ϱͬϭϳͬϮϬϮϮ Prepared for : Prepared by : Michael Duncan Mitch Rice Great Bear Pantheon 346-901-3354 mrice@slb.com 2 of 17 :KK:d/s^E^/'EKE^/Zd/KE^ Job Objectives Place a KOP on top of previous plug. KOP to be placed from 8,000 ft to 6,800 ft. Acceptance Criteria Pump program as per designed (volume, density and rate range) with no HSE incidents. Kick off at approximately 7,000 ft. Potential Flow Zones to Isolate Zone Formation / Depth Fluid / Description Comment None known TBD Other Known Hazards Hazard Description Mitigation None known TBD Design Criteria vs. Job Objectives Place a KOP on top of previous plug at 8,000 ft MD to 6,800 ft MD Balanced plug placement will be utilized Planned plug volume is 101 bbls This plug will be a KOP with intended kick off depth at ~7,000 ft Operational Risk Statement Cement plugs operations are complex to design and execute and this complexity should not be underestimated. Cement plugs operat ions should never be considered as a “routine” job. To successfully set cement plugs the same methodology used to design and execute primar y cement jobs is required, which includes but is not limited to correct slurry design, mud-removal and placement design based on accurate well d ata. Cement plugs are remedial cementing treatments. The first design step is the determination of the actual problem to solve, i.e. define the p urpose of setting a cement plug. The second step consists in defining the evaluation criteria: tag / no tag, positive pressure test, negative test, etc. Both steps allow for the proper specification of slurry properties and the determination of the adequate plug placement technique. This can result i n additional laboratory tests as well as additional equipment requirements. Nelson in Well Cementing (2006) discusses several factors that are key to successful plug cementing operations. 1.Displacement and under-displacement volumes play a critical role for the success of the job. The volumes specified in this prog ram should be followed. 2.Fluid contamination/mixing during plug setting can jeopardize job success. To mitigate this risk, using a stable base for the p lug, mechanical separators, and appropriate wait-on-cement-time is strongly recommended. 3.In case of a Kick-off Plug, proper knowledge of the BHA and application of correct drilling techniques are required to kick-off . In case of any deviation from the approved job procedure, a Management of Change (MoC) is required. By raising a MoC to the app ropriate level within the operator organization as well as within Schlumberger Well Services, all the operational risks can be identified and addressed prior to execution of the cement plug. 3 of 17 W>h'KWZd/KE^hDDZz Overview of the cementing operation (temperatures, fluid types, rates and general notes) All depths take the rig floor as reference Well & Rig Information Rig Type : Land Objective :Place a KOP on top of previous plug. KOP to be placed from 8,000 ft to 6,800 ft. Section MD : 8000.0 ft Rig Floor Elev 0.0 ft Section TVD : 7701.0 ft Mud Returns Depth : 0.0 ft Well deviation : 18.1 deg Placement & Post-Placement Conditions Top : 6808.7 ft Mechanical Separator : TBC POOH depth : 6025.9 ft Length : 1191.3 ft POOH Speed : TBC Bottom : 8000.0 ft Pipe Rotation / Reciprocation : TBC Circ. rate : 7.7 bbl/min Support : Previous Plug Circ. direction : Direct Design Considerations G-blend Tail MUDPUSH* II Drilling Fluid Cement Type : Slurry Spacer Type : Spacer Mud Type : Water Based / Fresh Water Slurry Dens. : 15.80 lb/gal Spacer Dens. : 10.00 lb/gal Mud Dens. : 9.40 lb/gal Volume Balance Model : Level Slurry & Spacer Underdispl. : 0.0 bbl Pumping Schedule Fluid Name Stage Volume bbl Pump Rate bbl/min Stage Time hr:mn Comment Inj. Temp. degF MUDPUSH* II 34.5 5.0 00:07 Pump spacer ahead 68.0 G-blend Tail 101.1 5.0 00:20 Pump slurry 68.0 MUDPUSH* II 5.5 5.0 00:01 Pump spacer behind 68.0 Drilling Fluid 67.5 5.0 00:13 Displace 68.0 Temperature Simulation BHST 170.9 degF Simulated BHCT 110.9 degF 4 of 17 t>>d^hDDZz The cementing program incorporates the following data: All depths take the rig floor as reference Section MD : 8000.0 ft Rig Floor Elev 0.0 ft Section TVD : 7701.0 ft Mud Returns Depth : 0.0 ft Tubulars and Casing Hardware MD ft OD in Weight lb/ft Grade ID in Thread Collapse psi Burst psi Joint ft Prev Casing 100.0 20 106.5 J-55 19 770.0 2410.0 40.0 3500.0 9 5/8 40.0 L-80 8.835 3090.0 5750.0 40.0 Workstring 8000.0 4 14.0 S135 3 17/50 20170.0 19490.0 40.0 Dart/Ball Launch Manifold TBA Note : previous casing (and riser) collapse and burst security not verified Open Hole Total OH Volume : 379.0 bbl Mean Diameter : 8.500 in Minimum Diameter : 8.500 in Mean Ann. Excess : 0.0 % Maximum Diameter : 8.500 in Mean Eq. Diameter : 9.311 in 5 of 17 &>h/^^hDDZz Fluids Type Name Density lb/gal Conditions K lbf.s^n/f t2 n Ty lbf/100ft 2 Spacer MUDPUSH* II 10.00 Surface 68.0 degF 1.77E-2 0.45 9.23 Drilling Fluid Drilling Fluid 9.40 Manual 2.09E-4 1.00 15.00 Slurry 10.7 ppg ARTICSET Lite III - Lead 10.70 Surface 68.0 degF 4.75E-3 0.61 12.30 Slurry G-blend Tail 15.80 Surface 68.0 degF 4.68E-3 0.86 1.75 * Rheology and density of compressible fluids are displayed at standard conditions, ie. P = 1 atm and T = 20 degC (65 degF) 6 of 17 Dh/Zh>d/KE Fluid Drilling Fluid Number of Circulation 1.23 Total Volume at Ambient Temperature 780.0 bbl Ambient Temperature 40.0 degF Correction Slope 0.00 Pumping Stages Fluid Pump Rate bbl/min Duration hr:mn Volume bbl Pause 00:05 Drilling Fluid 2.0 00:05 10.0 Drilling Fluid 5.0 00:10 50.0 Drilling Fluid 8.0 01:30 720.0 Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 1017.0 3500.0 01:50 Success Production/Influx 235.7 3500.0 01:50 Success Burst 18626.7 0.0 01:50 Success Collapse 19549.5 8000.0 01:50 7 of 17 &>h/W>DEd Volume Balance Objectives Volume Balance Model: Level Slurry & Spacer Original Fluid: Drilling Fluid Rat Hole Fluid: Drilling Fluid Displ. Fluid: Drilling Fluid Top Spacer: MUDPUSH* II set Total Volume to: 40.0 bbl Top Slurry: G-blend Tail set Top MD to: 6800.0 ft Annulus is not filled during POOH. Volume Balance Results String Volume: 86.7 bbl Underdispl.: 0.0 bbl Displ. Volume: 67.5 bbl TOC after POOH: 6800.0 ft Cement Length after POOH: 1200.0 ft Fluid Placement in Annulus Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal Drilling Fluid 0.0 6225.9 6225.9 425.7 9.40 MUDPUSH* II 6225.9 6729.0 503.0 34.5 10.00 G-blend Tail 6729.0 8000.0 1271.0 87.3 15.80 Fluid Placement in Pipe Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal Drilling Fluid 0.0 6225.9 6225.9 67.5 9.40 MUDPUSH* II 6225.9 6729.0 503.0 5.5 10.00 G-blend Tail 6729.0 8000.0 1271.0 13.8 15.80 Note: Surface densities of compressible fluids are calculated at surface conditions, ie. P = 1 atm and T = 40.0 degF 8 of 17 ^dd/Wh>>KhdK&,K>;WKK,Ϳ POOH Summary Final DP depth : 6025.9 ft Theoretical Top of Plug: 6800.0 ft POOH Length : 1974.1 ft Theoretical Plug Length : 1200.0 ft POOH Speed : TBC Plug Bottom : 8000.0 ft Top of uncontaminated cement after POOH : 6808.7 ft Uncontaminated cement length after POOH : 1191.3 ft Contaminated cement length after POOH : 59.1 ft POOH Results Summary Note : Simulation assumes that fluids are free to balance themselves. 9 of 17 WhDW/E'^,h> Volume and rate of compressible fluids are calculated at surface conditions, ie. P = 1 atm and T = 40.0 degF Pumping Schedule Fluid Name Stage Volume bbl Pump Rate bbl/min Stage Time hr:mn Cum. Time hr:mn Comment Inj. Temp. degF MUDPUSH* II 34.5 5.0 00:07 00:07 Pump spacer ahead 68.0 G-blend Tail 101.1 5.0 00:20 00:27 Pump slurry 68.0 MUDPUSH* II 5.5 5.0 00:01 00:28 Pump spacer behind 68.0 Drilling Fluid 67.5 5.0 00:13 00:42 Displace 68.0 Maximum Required Hydraulic Horsepower (HHP) 70.0 hhp (at 00:42 hr:mn) Displacement Volume Considerations Volume bbl Variation bbl Theoretical displacement volume 67.5 Underdisplacement 0.0 Final Displacement 67.5 Thickening Time Requirement Based on Schlumberger Well Services Thickening Time requirement, the minimum thickening time should be either 1.5 times the cem ent placement time or cement placement time + 2 hours, whichever is greater: Consistency Pumping Time POOH Time Circulate Clean* Misc. Ops** Required TT Actual TT Additional batch mix Cement Slurry 70 Bc 00:68 00:30 01:30 0:00 05:10 tbd 0:00 * Minimum circulation volume: 1.5 string volume ** Include all stops, squeeze and eventual tool operation 10 of 17 dDWZdhZKhdWhd^;WE/E't>>dDWdͿ BHST : 170.9 degF Simulated BHCT : 110.9 degF Static Temp at TOC : 150.4 degF Simulated HCT at TOC : 111.8 degF Temperature simulation initial condition: Mud Circulation profile Initial Condition Final Condition t = 00:42 hr:mn 11 of 17 BHCT and Interface temperatures 12 of 17 t>>>E/// WELLCLEAN III Maps Ű No cement slurry Slurry concentration is less than 10 % (by unit of volume). The concentration is below minimum threshold to consider that cement is present. Ű High risk of contamination Slurry concentration is between 10 % and 50 % (by unit of volume). There is no chance of finding hard cement when tagging within a few hours. Ű Medium risk of contamination Slurry concentration is between 50 % and 90 % (by unit of volume). It is possible to find some soft cement when tagging but it will be most likely not strong enough to kick off the well or even to provide a proper wellbore isolation. Ű Low risk of contamination Slurry concentration is between 90 % and 100 % (by unit of volume). Cement plug should be designed in such a way the target of the top of cement should be within the ‘green risk’ zone. Hard cement should be found in that zone once compressive strength has developed, i.e. after the duration determined by the lab tests at downhole condition. 13 of 17 Fluid Concentrations before POOH Average fluid concentration in annulus Average fluid concentration in pipe 14 of 17 &/E>KEdD/Ed/KEZ/^<;&dZWKK,Ϳ POOH Summary Final DP depth : 6025.9 ft Theoretical Top of Plug: 6800.0 ft Theoretical Top of Plug (based on slurry volume) 6800.0 ft Estimated TOC based on uncontaminated POOH simulation 6808.7 ft Estimated TOC after POOH considering contamination during placement 6902.2 ft Final Contamination Risk Note : Simulation assumes that fluids are free to balance themselves 15 of 17 WK^dͲW>DEd/Zh>d/KE Volume of compressible fluids is displayed at ambient conditions, ie. P = 1 atm and T = 40.0 degF DP Depth for Circulation : 7125.5 ft Designed TOC : 6800.0 ft Circulating Fluid : Drilling Fluid Total Volume : 730.0 bbl Circulation direction : Direct Number of Circulations : 1.29 Circulation Stages Stage Pump Rate Duration hr:mn Volume Back-pressure psi Pause 00:03 0.0 Drilling Fluid 2.0 00:05 10.0 0.0 Drilling Fluid 8.0 01:30 720.0 0.0 Status Description Min. Pressure Margin psi at Depth ft at Time hr:mn Success Fracturing 819.6 3500.0 00:56 Success Production/Influx 73.4 3500.0 00:36 Success Burst 18523.3 0.0 00:56 Success Collapse 19593.4 7125.5 00:03 Post-Placement Well Control 16 of 17 KWZdKZ^hDDZz Fluid Volume Summary Fluid Name Pumped Volume bbl Fluid Dead Volume bbl Total Fluid Volume bbl Mix Fluid Dead Volume bbl Silo Dead Weight ton G-blend Tail 101.1 0.0 101.1 0.0 0 MUDPUSH* II 40.0 0.0 40.0 0.0 0 Material Summary Additive Pumped Quantity Required Quantity Loadout Quantity Loadout Items Pack. Name Pack. Size Comment D031 3607 lb 3607 lb 3607 lb 32.80 sack 110 lb Fresh Water 4045.6 gal 4045.6 gal 4045.6 gal 0.00 0.0 gal D182 186 lb 186 lb 186 lb 3.72 sack 50 lb G-blend Tail Blend 45800 lb 45800 lb 45800 lb 0.00 bulk 0 lb Mix Water 2482.3 gal 2482.3 gal 2482.3 gal 0.00 0.0 gal D047 24.4 gal 24.4 gal 24.4 gal 4.87 pail 5.0 gal D065 183 lb 183 lb 183 lb 3.66 sack 50 lb D255 183 lb 183 lb 183 lb 8.33 sack 22 lb S001 46 lb 46 lb 46 lb 0.46 sack 100 lb Fluid Preparations G-blend Tail Pumped Volume : 101.1 bbl Yield : 1.16 ft3/sk Slurry Density : 15.80 lb/gal SVF : 40.2 % Dry Phase Concentration Reference Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 46166 lb 46166 lb G-blend Tail Blend: 94 lb per sack 45800 lb 45800 lb 45800 lb - D907 100.0 % BWOB 45800 lb 45800 lb 45800 lb D065 0.4 % BWOC 183 lb 183 lb 183 lb D255 0.4 % BWOC 183 lb 183 lb 183 lb Liquid Phase Concentration Reference Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 5.152 gal/sk VBWOB 2509.6 gal 2509.6 gal Mix Water 5.096 gal/sk VBWOB 2482.3 gal 2482.3 gal 2482.3 gal Fresh Water 5.096 gal/sk VBWOB 2482.3 gal 2482.3 gal 2482.3 gal D047 0.050 gal/sk VBWOB 24.4 gal 24.4 gal 24.4 gal S001 0.1 % BWOB 46 lb 46 lb 46 lb Lab report : 17 of 17 MUDPUSH* II Pumped Volume : 40.0 bbl Slurry Density : 10.00 lb/gal Weighting Material Concentration Reference Pumped Quantity Required Quantity Loadout Quantity MUDPUSH* II Weighting Material: 2.15 lb/gal WBVOSpacer 3607 lb 3607 lb 3607 lb - D031 2.15 lb/gal WBVOSpacer 3607 lb 3607 lb 3607 lb Base Fluid Concentration Reference Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpacer 1580.2 gal 1580.2 gal Fresh Water 0.9 bbl/bbl BVOSpacer 1563.3 gal 1563.3 gal 1563.3 gal D182 5.00 lb/bbl WBVOBF 186 lb 186 lb 186 lb Lab report : 6(&7,21E ò´&DVLQJ&HPHQWLQJ6WDJH 3URJUDP $ONDLG ĂƐŝŶŐĞŵĞŶƚŝŶŐWƌŽŐƌĂŵ ^ƚƌŝŶŐ͗ϱ͘ϱ͟ĂƐŝŶŐʹ^ƚĂŐĞϭ tĞůůEĂŵĞ͗ůŬĂŝĚϮ ŽŵƉĂŶǇ͗'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ &ŝĞůĚ͗ ŽŶƚĂĐƚ͗DŝĐŚĂĞůƵŶĐĂŶ WƌŽƉŽƐĂůEƵŵďĞƌ͗ϭ ĂƚĞ͗ϰͬϮϮͬϮϬϮϮ DĂĚĞǇ͗DŝƚĐŚZŝĐĞ DŽďŝůĞWŚŽŶĞ͗ϯϰϲͲϵϬϭͲϯϯϱϰ KďũĞĐƚŝǀĞ͗ƌŝŶŐĐĞŵĞŶƚĂĐƌŽƐƐůĂƚĞƌĂůƐĞĐƚŝŽŶƚŽ ϳ͕ϰϱϬĨƚƚŽƉƌĞƉĂƌĞĨŽƌƐĞĐŽŶĚƐƚĂŐĞ ĐĐĞƉƚĂŶĐĞƌŝƚĞƌŝĂ͗WƵŵƉĐĞŵĞŶƚĂƐƉůĂŶŶĞĚ;ǀŽůƵŵĞ͕ ĚĞŶƐŝƚǇĂŶĚƌĂƚĞƌĂŶŐĞͿǁŝƚŚŶŽ,^ ŝŶĐŝĚĞŶƚƐ ϮŽĨϭϱ tĞůůĂƚĂ^ƵŵŵĂƌǇ The cementing program incorporates the following data : RigType Land Fluids Return to Rig Floor BHST 186.4 degF All depths take the rig floor as reference Mud Line Depth 0.0 ft Mud Return Depth 0.0 ft Section MD 14000.0 ft Section TVD 8021.7 ft Tubulars and Casing Hardware MD ft OD in Joint ft Weight lb/ft ID in Grade Collapse psi Burst psi Thread Prev Casing 100.0 20 40.0 106.5 19 J-55 770.0 2410.0 3500.0 9 5/8 40.0 40.0 8.835 L-80 3090.0 5750.0 Casing 14000.0 5 1/2 40.0 20.0 4.778 L-80 8830.0 9190.0 Landing Collar 13960.0 Serial number : Open Hole Total Volume 822.6 bbl Minimum Diameter 8.500 in Maximum Diameter 12.500 in Mean Diameter 8.500 in Mean Annular Excess 18.0 % Mean Equivalent Diameter 8.981 in ϯŽĨϭϱ Formation – Final well formation data still pending Top MD ft Bottom MD ft Bottom TVD ft Frac Top ED lb/gal Frac Bottom ED lb/gal Pore Top ED lb/gal Pore Bottom ED lb/gal Lithology Res. Fluid Name 0.0 100.0 100.0 14.00 14.00 8.00 8.00 Sandstone 100.0 3500.0 3423.9 14.00 15.00 8.00 8.00 Sandstone 3500.0 14000.0 8021.7 15.00 16.00 8.00 8.00 Sandstone Temperature – Final Temperature data still pending Name Top MD ft Bottom MD ft Bottom TVD ft Temperature degF Gradient degF/100ft Relative Gradient degF/100ft Surface 0.0 0.0 0.0 50.0 0.00 Rock 0.0 3500.0 3423.9 108.2 1.70 1.70 BHST 3500.0 14000.0 8021.7 186.4 1.70 1.70 ϰŽĨϭϱ &ůƵŝĚƐ^ƵŵŵĂƌǇ Fluids Type Name Density lb/gal Conditions K lbf.s^n/ft2 n Ty lbf/100ft2 Spacer MUDPUSH* II 10.00 Surface 68.0 degF 1.77E-2 0.45 9.23 Drilling Fluid Drilling Fluid 9.70 Manual 2.09E-4 1.00 15.00 Slurry 10.7 ppg ARTICSET Lite III - Lead 10.70 Custom 80.0 degF 5.43E-3 0.58 13.10 Slurry G-blend Tail 15.80 Custom 80.0 degF 4.68E-3 0.86 1.75 * Compressible Rheology Parameters and Densities are displayed at P=1 atm and T=20 degC (65degF) ϱŽĨϭϱ DƵĚŝƌĐƵůĂƚŝŽŶ Fluid MI-SWACO DF Number of Circulation 1.10 Total Volume at Ambient T 1090.0 bbl Ambient Temperature 50.0 degF Correction Slope 0.00 Pumping Stages Fluid Pump Rate bbl/min Duration hr:mn Volume bbl Pause 00:03 MI-SWACO DF 2.0 00:05 10.0 MI-SWACO DF 6.0 03:00 1080.0 Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 870.8 3500.0 00:08 Success Burst 8816.4 0.0 03:08 Success Collapse 8305.8 9055.1 00:03 ϲŽĨϭϱ &ůƵŝĚWůĂĐĞŵĞŶƚ Surface Densities are computed at P=1 atm and T=Surface Temperature (50.0 degF) Fluid Placement in Annulus Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal MI-SWACO DF 0.0 6837.3 6837.3 325.9 9.70 MUDPUSH* II 6837.3 7450.0 612.7 30.0 10.00 G-blend Tail 7450.0 14000.0 6550.0 320.7 15.80 Fluid Placement in Pipe Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal MI-SWACO DF 0.0 13599.3 13599.3 301.6 9.70 MUDPUSH* II 13599.3 13960.0 360.7 8.0 10.00 G-blend Tail 13960.0 14000.0 40.0 0.9 15.80 ϳŽĨϭϱ WƵŵƉŝŶŐ^ĐŚĞĚƵůĞ Pumping Schedule Fluid Name Duration hr:mn Volume bbl Pump Rate bbl/min Injection Temperature degF Comment Cumulated Time hr:mn MUDPUSH* II 00:06 30.0 5.0 68.0 Pump spacer ahead 00:06 Plug 00:00 Drop bottom plug 00:06 G-blend Tail 01:04 321.6 5.0 68.0 Pump slurry 01:10 Top Plug 00:00 Drop top plug 01:10 MUDPUSH* II 00:02 8.0 5.0 68.0 Pump spacer behind 01:12 MI-SWACO DF : 00:52 301.6 Displace > MI-SWACO DF 00:49 295.0 6.0 68.0 02:01 > MI-SWACO DF 00:03 6.6 2.0 68.0 Slow pumps to bump plug 02:04 Maximum Required Hydraulic Horsepower (HHP) 130.6 hhp (at 02:01 hr:mn) ϴŽĨϭϱ dĞŵƉĞƌĂƚƵƌĞKƵƚƉƵƚƐ Temperature Summary Table Static Temperature. at TOC 172.0 degF Static Temperature at BH 186.4 degF Simulated HCT at TOC 139.8 degF Simulated HCT at BH 160.3 degF Max First SK Temperature 156.9 degF Max Last SK Temperature 160.3 degF At time 01:20 hr:mn At time 02:04 hr:mn ϵŽĨϭϱ ĞŶƚƌĂůŝǌĂƚŝŽŶ Centralizers Alias Manufacturer Commercial Name Type Config Csg OD in Min OD in Max OD in Count SpiraGlider HD-5 1/2- 5-Spiral850 Hannover SpiraGlider HD bow- spring Spiral 5 1/2 8.450 8.500 0 1502751-5 1/2-4- Positive Houma 1502751 rigid Positive 5 1/2 8.252 8.252 189 Pattern Placement Bottom MD ft Joints Centralizer Alias Pattern Min STO Depth ft 6500.0 162.50 - 0 0.0 1000.7 13500.0 175.00 1502751-5 1/2-4-Positive 1/1 0.0 8940.0 13920.0 10.50 1502751-5 1/2-4-Positive 1/1 0.0 13510.0 14000.0 2.00 1502751-5 1/2-4-Positive 2/1 70.6 14000.0 Computation time: Cement Turns 00:57 ϭϬŽĨϭϱ ϯWZdhZ Average Fluid Concentrations Average fluid concentration in annulus ϭϭŽĨϭϱ Final Fluid Concentrations ϭϮŽĨϭϱ Post-Processing Results (Annulus) ϭϯŽĨϭϱ 3D Results ϭϰŽĨϭϱ KƉĞƌĂƚŽƌ^ƵŵŵĂƌǇ Volume Summary Fluid Name Pumped Volume bbl Prepared Fluid Dead Volume bbl Prepared Fluid bbl Mix Fluid Dead Volume bbl Silo dead volume ton G-blend Tail 321.6 0.0 321.6 0.0 0 MUDPUSH* II 38.0 0.0 38.0 0.0 0 Material Summary Additive Pumped Quantity Required Quantity Loadout Quantity Loadout Items Pack. Name Pack. Size Comment D031 3427 lb 3427 lb 3427 lb 31.16 sack 110 lb Fresh Water 9389 gal 9389 gal 9389 gal 0.00 0 gal D182 177 lb 177 lb 177 lb 3.54 sack 50 lb G-blend Tail Blend 145823 lb 145823 lb 145823 lb 0.00 bulk 0 lb Mix Water 7904 gal 7904 gal 7904 gal 0.00 0 gal D047 78 gal 78 gal 78 gal 15.51 pail 5 gal D065 583 lb 583 lb 583 lb 11.67 sack 50 lb D255 583 lb 583 lb 583 lb 26.51 sack 22 lb D177 78 gal 78 gal 78 gal 15.51 Pail 5 gal ϭϱŽĨϭϱ Fluid Preparation G-blend Tail Pumped Volume : 321.6 bbl Density : 15.80 lb/gal SVF : 40.2 % Yield : 1.16 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 146989 lb 146989 lb G-blend Tail Blend: 94 lb per sack 145823 lb 145823 lb 145823 lb - D907 100.0 % BWOB 145823 lb 145823 lb 145823 lb D065 0.4 % BWOC 583 lb 583 lb 583 lb D255 0.4 % BWOC 583 lb 583 lb 583 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 5.146 gal/sk VBWOB 7982 gal 7982 gal Mix Water 5.096 gal/sk VBWOB 7904 gal 7904 gal 7904 gal Fresh Water 5.096 gal/sk VBWOB 7904 gal 7904 gal 7904 gal D047 0.050 gal/sk VBWOB 78 gal 78 gal 78 gal D177 0.050 gal/sk VBWOB 78 gal 78 gal 78 gal MUDPUSH* II Pumped Volume : 38.0 bbl Density : 10.00 lb/gal Weighting Material Concentration Pumped Quantity Required Quantity Loadout Quantity MUDPUSH* II Weighting Material: 2.15 lb/gal WBVOSpacer 3427 lb 3427 lb 3427 lb - D031 2.15 lb/gal WBVOSpacer 3427 lb 3427 lb 3427 lb Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpacer 1501 gal 1501 gal Fresh Water 0.9 bbl/bbl BVOSpacer 1485 gal 1485 gal 1485 gal D182 5.00 lb/bbl WBVOBF 177 lb 177 lb 177 lb 6(&7,21E ò´&DVLQJ&HPHQWLQJ6WDJH 3URJUDP $ONDLG ĂƐŝŶŐĞŵĞŶƚŝŶŐWƌŽŐƌĂŵ ^ƚƌŝŶŐ͗ϱ͘ϱΗĂƐŝŶŐͲ^ƚĂŐĞϮ tĞůůEĂŵĞ͗ůŬĂŝĚϮ ŽŵƉĂŶǇ͗'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ ŽŶƚĂĐƚ͗DĂƌŬƌŽƵŝůůĞƚ WƌŽƉŽƐĂůEƵŵďĞƌ͗ϭ ĂƚĞ͗ϰͬϮϮͬϮϬϮϮ DĂĚĞǇ͗DŝƚĐŚZŝĐĞ DŽďŝůĞWŚŽŶĞ͗ϯϰϲͲϵϬϭͲϯϯϱϰ KďũĞĐƚŝǀĞ͗ƌŝŶŐĐĞŵĞŶƚĂĐƌŽƐƐůĂƚĞƌĂůƐĞĐƚŝŽŶƚŽ ϲ͕ϬϬϬĨƚD ĐĐĞƉƚĂŶĐĞƌŝƚĞƌŝĂ͗WƵŵƉĐĞŵĞŶƚĂƐƉůĂŶŶĞĚ;ǀŽůƵŵĞ͕ ĚĞŶƐŝƚǇĂŶĚƌĂƚĞƌĂŶŐĞͿǁŝƚŚŶŽ,^ ŝŶĐŝĚĞŶƚƐ ŝƐĐůĂŝŵĞƌEŽƚŝĐĞ ^ĐŚůƵŵďĞƌŐĞƌƐƵďŵŝƚƐƚŚŝƐĚŽĐƵŵĞŶƚǁŝƚŚƚŚĞďĞŶĞĨŝƚŽĨŝƚƐũƵĚŐŵĞŶƚ͕ĞǆƉĞƌŝĞŶĐĞ͕ĂŶĚŐŽŽĚŽŝůĨŝĞůĚƉƌĂĐƚŝĐĞƐ͘ dŚŝƐŝŶĨŽƌŵĂƚŝŽŶŝƐƉƌŽǀŝĚĞĚŝŶĂĐĐŽƌĚĂŶĐĞǁŝƚŚŐĞŶĞƌĂůůǇĂĐĐĞƉƚĞĚŝŶĚƵƐƚƌǇƉƌĂĐƚŝĐĞ͕ƌĞůǇŝŶŐŽŶĨĂĐƚƐŽƌŝŶĨŽƌŵĂƚŝŽŶƉƌŽǀŝĚĞĚďǇŽƚŚĞƌƐ͕ůŝŵŝƚĂƚŝŽŶƐ͕ĐŽŵƉƵƚĞƌ ŵŽĚĞůƐ͕ŵĞĂƐƵƌĞŵĞŶƚƐ͕ĂƐƐƵŵƉƚŝŽŶƐĂŶĚŝŶĨĞƌĞŶĐĞƐƚŚĂƚĂƌĞŶŽƚŝŶĨĂůůŝďůĞ͘ ĂůĐƵůĂƚŝŽŶƐĂƌĞĞƐƚŝŵĂƚĞƐďĂƐĞĚŽŶƉƌŽǀŝĚĞĚŝŶĨŽƌŵĂƚŝŽŶ͘ůůƉƌŽƉŽƐĂůƐ͕ƌĞĐŽŵŵĞŶĚĂƚŝŽŶƐ͕ŽƌƉƌĞĚŝĐƚŝŽŶƐĂƌĞŽƉŝŶŝŽŶƐŽŶůǇ͘ EKtZZEdz/^'/sEKEZE/E'hZzKZKDW>dE^^K&d͕/E&KZDd/KEWZ^Ed͕&&d/sE^^K&DdZ/>͕WZKhd^KZ ^hWW>/^͕ZKDDEd/KE^D͕KZZ^h>d^K&d,^Zs/^ZEZ͘ ϮŽĨϭϱ tĞůůĂƚĂ^ƵŵŵĂƌǇ The cementing program incorporates the following data : RigType Land Fluids Return to Rig Floor BHST 172.0 degF All depths take the rig floor as reference Mud Line Depth 0.0 ft Mud Return Depth 0.0 ft Section MD 7450.0 ft Section TVD 7177.6 ft Tubulars and Casing Hardware MD ft OD in Joint ft Weight lb/ft ID in Grade Collapse psi Burst psi Thread Prev Casing 100.0 20 40.0 106.5 19 J-55 770.0 2410.0 3500.0 9 5/8 40.0 40.0 8.835 L-80 3090.0 5750.0 Casing 7450.0 5 1/2 40.0 20.0 4.778 L-80 8830.0 9190.0 Landing Collar 7370.0 Serial number : Open Hole Total Volume 309.5 bbl Minimum Diameter 8.500 in Maximum Diameter 12.500 in Mean Diameter 8.500 in Mean Annular Excess 16.2 % Mean Equivalent Diameter 8.981 in ϯŽĨϭϱ ϰŽĨϭϱ &ůƵŝĚƐ^ƵŵŵĂƌǇ Fluids Type Name Density lb/gal Conditions K lbf.s^n/ft2 n Ty lbf/100ft2 Spacer MUDPUSH* II 10.00 Surface 68.0 degF 1.77E-2 0.45 9.23 Drilling Fluid Drilling Fluid 9.20 Manual 2.09E-4 1.00 15.00 Slurry 10.7 ppg ARTICSET Lite III - Lead 10.70 Custom 80.0 degF 5.43E-3 0.58 13.10 Slurry G-blend Tail 15.80 Custom 80.0 degF 4.68E-3 0.86 1.75 MI-SWACO DF MI-SWACO DF 9.72 * 1.46E-2 0.48 4.64 * Compressible Rheology Parameters and Densities are displayed at P=1 atm and T=20 degC (65degF) ϱŽĨϭϱ DƵĚŝƌĐƵůĂƚŝŽŶ Fluid MI-SWACO DF Number of Circulation 2.09 Total Volume at Ambient T 1090.0 bbl Ambient Temperature 50.0 degF Correction Slope 0.00 Pumping Stages Fluid Pump Rate bbl/min Duration hr:mn Volume bbl Pause 00:03 MI-SWACO DF 2.0 00:05 10.0 MI-SWACO DF 6.0 03:00 1080.0 Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 867.1 3500.0 03:08 Success Production/Influx 171.7 3500.0 00:25 Success Burst 8933.1 0.0 03:08 Success Collapse 8355.7 7450.0 03:08 ϲŽĨϭϱ &ůƵŝĚWůĂĐĞŵĞŶƚ Surface Densities are computed at P=1 atm and T=Surface Temperature (50.0 degF) Fluid Placement in Annulus Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal MI-SWACO DF 0.0 5489.4 5489.4 259.9 9.78 MUDPUSH* II 5489.4 6000.0 510.6 25.0 10.00 G-blend Tail 6000.0 7450.0 1450.0 71.0 15.80 Fluid Placement in Pipe Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal MI-SWACO DF 0.0 7009.3 7009.3 155.4 9.78 MUDPUSH* II 7009.3 7370.0 360.7 8.0 10.00 G-blend Tail 7370.0 7450.0 80.0 1.8 15.80 ϳŽĨϭϱ WƵŵƉŝŶŐ^ĐŚĞĚƵůĞ Pumping Schedule Fluid Name Duration hr:mn Volume bbl Pump Rate bbl/min Injection Temperature degF Comment Cumulated Time hr:mn MUDPUSH* II 00:05 25.0 5.0 68.0 Pump spacer ahead 00:05 Plug 00:00 Drop bottom plug 00:05 G-blend Tail 00:15 72.8 5.0 68.0 Pump slurry 00:20 Top Plug 00:00 Drop top plug 00:20 MUDPUSH* II 00:02 8.0 5.0 68.0 Pump spacer behind 00:21 MI-SWACO DF : 00:28 155.4 > MI-SWACO DF 00:25 150.0 6.0 68.0 Displace 00:46 > MI-SWACO DF 00:03 5.4 2.0 68.0 Slow rate to bump plug 00:49 Maximum Required Hydraulic Horsepower (HHP) 100.9 hhp (at 00:46 hr:mn) ϴŽĨϭϱ dĞŵƉĞƌĂƚƵƌĞKƵƚƉƵƚƐ Temperature Summary Table Static Temperature. at TOC 148.6 degF Static Temperature at BH 172.0 degF Simulated HCT at TOC 97.5 degF Simulated HCT at BH 96.3 degF Max First SK Temperature 97.5 degF Max Last SK Temperature 96.3 degF At time 00:49 hr:mn At time 00:49 hr:mn ϵŽĨϭϱ ĞŶƚƌĂůŝǌĂƚŝŽŶ Centralizers Alias Manufacturer Commercial Name Type Config Csg OD in Min OD in Max OD in Count SpiraGlider HD-5 1/2- 5-Spiral850 Hannover SpiraGlider HD bow- spring Spiral 5 1/2 8.450 8.500 0 1502751-5 1/2-4- Positive Houma 1502751 rigid Positive 5 1/2 8.252 8.252 49 Pattern Placement Bottom MD ft Joints Centralizer Alias Pattern Min STO Depth ft 5500.0 137.50 - 0 0.0 1000.7 7410.0 47.75 1502751-5 1/2-4-Positive 1/1 8.9 7410.0 7450.0 1.00 1502751-5 1/2-4-Positive 1/1 0.0 7450.0 Computation time: Cement Turns 00:30 ϭϬŽĨϭϱ ϯWZdhZ Average Fluid Concentrations Average fluid concentration in annulus ϭϭŽĨϭϱ Final Fluid Concentrations ϭϮŽĨϭϱ Post-Processing Results (Annulus) ϭϯŽĨϭϱ 3D Results ϭϰŽĨϭϱ KƉĞƌĂƚŽƌ^ƵŵŵĂƌǇ Volume Summary Fluid Name Pumped Volume bbl Prepared Fluid Dead Volume bbl Prepared Fluid bbl Mix Fluid Dead Volume bbl Silo dead volume ton G-blend Tail 72.8 0.0 72.8 0.0 0 MUDPUSH* II 33.0 0.0 33.0 0.0 0 Material Summary Additive Pumped Quantity Required Quantity Loadout Quantity Loadout Items Pack. Name Pack. Size Comment D031 2976 lb 2976 lb 2976 lb 27.06 sack 110 lb Fresh Water 3062 gal 3062 gal 3062 gal 0.00 0 gal D182 154 lb 154 lb 154 lb 3.07 sack 50 lb G-blend Tail Blend 32975 lb 32975 lb 32975 lb 0.00 bulk 0 lb Mix Water 1772 gal 1772 gal 1772 gal 0.00 0 gal D047 18 gal 18 gal 18 gal 3.51 pail 5 gal D065 132 lb 132 lb 132 lb 2.64 sack 50 lb D255 132 lb 132 lb 132 lb 6.00 sack 22 lb D177 18 gal 18 gal 18 gal 0.32 drum 55 gal ϭϱŽĨϭϱ Fluid Preparation G-blend Tail Pumped Volume : 72.8 bbl Density : 15.80 lb/gal SVF : 40.2 % Yield : 1.16 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 33239 lb 33239 lb G-blend Tail Blend: 94 lb per sack 32975 lb 32975 lb 32975 lb - D907 100.0 % BWOB 32975 lb 32975 lb 32975 lb D065 0.4 % BWOC 132 lb 132 lb 132 lb D255 0.4 % BWOC 132 lb 132 lb 132 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 5.152 gal/sk VBWOB 1807 gal 1807 gal Mix Water 5.052 gal/sk VBWOB 1772 gal 1772 gal 1772 gal Fresh Water 5.052 gal/sk VBWOB 1772 gal 1772 gal 1772 gal D047 0.050 gal/sk VBWOB 18 gal 18 gal 18 gal D177 0.050 gal/sk VBWOB 18 gal 18 gal 18 gal MUDPUSH* II Pumped Volume : 33.0 bbl Density : 10.00 lb/gal Weighting Material Concentration Pumped Quantity Required Quantity Loadout Quantity MUDPUSH* II Weighting Material: 2.15 lb/gal WBVOSpacer 2976 lb 2976 lb 2976 lb - D031 2.15 lb/gal WBVOSpacer 2976 lb 2976 lb 2976 lb Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpacer 1304 gal 1304 gal Fresh Water 0.9 bbl/bbl BVOSpacer 1290 gal 1290 gal 1290 gal D182 5.00 lb/bbl WBVOBF 154 lb 154 lb 154 lb 6(&7,21 'LYHUWHU6\VWHP 6(&7,21 'ULOOLQJ)OXLG3URJUDP x 6HFWLRQD0XG3URJUDP x 6HFWLRQE(0XG6\VWHP6FKHPDWLF0RGHO x 6HFWLRQE(0XG*DV6HSDUDWRU x 6HFWLRQF*UDGLHQW&XUYHV1DUUDWLYH x 6HFWLRQG0XGZHLJKW&KDUW 6(&7,21D 0XG3URJUDP 9HUVLRQ NOTE: This program is provided as a guide only. Well conditions will always dictate fluid properties and product additions required for well-bore integrity. 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correlation to Merak #1 Canning, regional top seal: 7100’ MD, 6824 TVD Regional shale, high clay content, regional frac barrier Top of SMD (Schrader Bluff Equivalent): (7,405’ MD, 7111 TVD) based on PSDM seismic depth Target #1 Sand with permeability, followed Canning Formation at 7600’ MD as layered/laminated sand/shale successions. Top Alkaid seismic anomaly zone occurs in the Canning Formation 8305’ MD, 7960 TVD TD in the upper HRZ/GRZ at 9200’ MD, 8805 TVD: the HRZ/GRZ is the regional lower frac barrier 6(&7,21E 0XGZHLJKW33)*&KDUW ϬϮϬϬϬϰϬϬϬϲϬϬϬϴϬϬϬϭϬϬϬϬϭϮϬϬϬϴ ϵ ϭϬ ϭϭ ϭϮ ϭϯ ϭϰ ϭϱ ϭϲĞƉƚŚ;ĨƚͿDƵĚtĞŝŐŚƚ;ƉƉŐͿ'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ͕ůŬĂŝĚηϮWƌŽũĞĐƚĞĚWŽƌĞWƌĞƐƐƵƌĞĂŶĚ&ƌĂĐ'ƌĂĚŝĞŶƚƌĞůĂƚŝǀĞƚŽƉĂƐƚ'ƌĞĂƚĞĂƌtĞůůƐ;DƵĚǁĞŝŐŚƚǀĞƉƚŚͿŶƚŝĐŝƉĂƚĞĚWŽƌĞWƌĞƐƐƵƌĞŶƚŝĐŝƉĂƚĞĚ&ƌĂĐ'ƌĂĚŝĞŶƚůĐŽƌηϭDĞƌĂŬηϭůŬĂŝĚηϭůĐŽƌ,Z&/důĐŽƌ^ŚƵďůŝŬ&/důĐŽƌ,Z&ƌĂŐ'ƌĂĚŝĞŶƚůĐŽƌ^ŚƵďůŝĐ&ƌĂĐ'ƌĂĚŝĞŶƚ>KdůĐŽƌηϭ>KdDĞƌĂŬηϭ>KdůŬĂŝĚηϭ>Kd^ĞƋƵŽŝĂηϭ>KdDĂŐŐŝŽƌĞηϭ&/důŬĂŝĚηϭůŬĂŝĚ&ƌĂĐSFD 6/23/2022Planned this wellMud weight curves from nearby Merak 1 and Alcor 1 wells indicate an increase in geopressure coincident with the top of the HRZ. SFD 6/22/2022 6(&7,21 6KDOORZ*DV+D]DUG$QDO\VLV 1 3601 C Street Suite 1424 Anchorage, AK 99503 907-272-1232 (voice) 907-272-1344 (fax) info@petroak.com www.petroak.com To: Michael Duncan (Great Bear Petroleum) May 17, 2022 From: Petrotechnical Resources Alaska (PRA) Subject: Shallow Gas Hazards Assessment (SGHA) for proposed ALKAID#2 well Location: X=1802335, Y=5845432, Alaska State Plane Zone 4, NAD83 Surface Location: 688’ FSL, 1307’ FWL, Sec. 5, T7N, R14E This report summarizes the seismic analysis of potential shallow drilling hazards for the proposed Alkaid#2 well location estimated to spud in 2022. In completing this shallow gas hazards assessment, we reviewed several 3D seismic volumes acquired and processed for Great Bear Pantheon. The Great Bear Pantheon 3D seismic data coverage extends over an area of 800+sq. miles providing continuous seismic imaging for the wells depicted in Figure 1a. The Great Bear Pantheon (GBP) 2015 Constant Offset Vector (COV) Pre-Stack Time Migrated (PSTM) 3D seismic volume was selected from several seismic volumes covering the Alkaid#2 proposed location (Fig.1a). This volume provided the best continuous shallow data imaging over the Alkaid#2 proposed well location (Fig.4). The seismic processing datum was 900ft. so zero time on seismic displays is 900ft. above mean sea level. The approximate TVDSS depths labeled on the seismic images were estimated using checkshot and seismic synthetic time-depth information. Log curve and historical drilling data used in this assessment were taken from the Merak-1 and Alcor-1 wells (Fig.1b). We examined the GBP 2015 COV 3D PSTM seismic data and seismic interval velocity functions extracted at the locations shown on the seismic base map (Fig. 2). We examined the seismic interval velocity data cross plotted with the Alcor-1 and Merak-1 sonic logs and Alcor-1 checkshot data. We analyzed offset well mud weight versus depth data for indications of pressure. Current Location: 1043' FSL, 3494' FEL, which is ~600' to the NE of the location used for this survey. However, the current location lies near the seismic lines shown on Figures 5 and 6. SFD 6/22/2022 2 Permafrost, Gas Hydrates, Shallow Gas Seismic interval velocity data was extracted at the Alkaid#2 location and plotted with both the Alcor-1 checkshot and Merak-1 sonic curves (Fig.7). Additional seismic interval velocity functions were extracted at the Alcor-1 (Fig.8) and Merak-1 (Fig.9) well locations for comparison to sonic and checkshot data. These seismic interval velocities and the Alcor-1 checkshot data were converted to Interval Transit Time (ITT in Psec/ft) to facilitate comparison plotting with the sonic transit time data. At the Alkaid#2 proposed location, the seismic interval velocity exhibits a marked velocity inflection at -2600’tvdss suggesting a likely base of permafrost at this depth. This predicted seismic base of permafrost is over 1800ft. deeper than the geologist’s picks for Base Permafrost in the Merak-1 and in Alcor-1 wells. This seismic base of permafrost approximates the bottom of surface casing depths at both the Merak-1 and Alcor-1 well locations and agrees with the - 1600’tvdss base of permafrost geo-pick at the Alkaid-1 well as seen on seismic profile FF’ (Fig.5). The base of permafrost was recorded at 761’ TVD (-565’TVDSS) in the Merak-1 well and at 1050’ TVD (-864’TVDSS) in the Alcor-1 well. These well picks would place the Base of Permafrost between 300ms-400ms at the Alkaid#2 proposed location on the arbitrary seismic profile LL’ connecting the Merak-1 well, Alkaid#2 proposed location, and the Alcor-1 well (Fig.6). The dashed black horizon approximates the bottom of the surface casing at the Merak-1 and at the Alcor-1. The dip of the reflection events suggests the Alkaid#2 may encounter the Base of Permafrost geo-pick deeper than the Merak-1 and shallower than the Alcor-1. The seismic interval velocity function at the Alkaid#2 proposed location (Fig.7) shows a velocity inversion at -2600’tvdss similar to inversion points observed on the seismic interval velocity functions at the Alcor-1 (Fig.8) and the Merak-1 (Fig.9) well locations. This dashed black horizon would be the predicted base of permafrost based on seismic interval velocity analysis. A mismatch below -8500’tvdss is noted between the extracted seismic interval velocity ITT curves and the sonic ITT curves at both the Merak-1 and the Alcor-1 well locations (Figs.8-9). The seismic velocity functions extracted at the Alcor-1 location matches the Alcor-1 sonic to a depth of -8500’tvdss but not deeper (Fig.8). A similar behavior is noted between the seismic interval velocity function extracted at the Merak-1 location and the Merak-1 sonic (Fig.9). At both well locations the seismic interval velocity misses the velocity inversion below -8500’tvdss. The Alkaid#2 proposed well location is situated between the Alcor-1 and Merak-1 well locations as shown on two SW-NE oriented seismic profiles, FF’ and LL’ (Fig.3). No anomalous shallow amplitude events are observed on the 3D seismic data at the Alkaid#2 proposed location, at the Alcor-1, or at the Merak-1 locations as shown on seismic profiles FF’ and LL’ (Figs.5-6). No reference to shallow gas, gas hydrates, or abnormal pressure was cited in the summary drilling reports from the Alkaid-1, Merak-1 and Alcor-1 wells. Both the Merak-1 and Alcor-1 wells drilled through the same set of reflection events as will be encountered at the Alkaid#2 proposed location. The Alkaid#2 well will drill through a shallow section very similar to what was drilled at the Merak-1 and Alcor-1 well locations (Figs.5-6). No anomalous shallow amplitude events are observed between the Alcor-1 and Merak-1 we Alkaid#2 proposed well location is situated No,p (g ) reference to shallow gas, gas hydrates, or abnormal pressure was cited in the summary drilling g,g y, p reports from the Alkaid-1, Merak-1 and Alcor-1 wells. 3 Faults Inline seismic profiles, cross line seismic profiles, and coherence time slices were inspected for the shallow section from 400ms-1500ms (~ -700’to -6000’tvdss). No faults or fault discontinuities within the resolution of the seismic were observed in the shallow section covered by the 3D seismic data. No drilling losses attributed to shallow faulting were noted in the drilling summary reports for the surrounding wells which include the Alkaid-1, the Merak-1, and Alcor-1 wells. Pressure The well histories from the Alcor-1 and Merak-1 wells and the seismic interval velocity at the Alkaid#2 location indicate that the Alkaid#2 well will penetrate a normally pressurized section through the shallow interval above -8500’tvdss. The seismic interval velocity at the Alkaid#2 proposed location tracks reasonably well with the Merak-1 sonic and the Alcor-1 checkshot data down to -8500’tvdss (Fig.7). Inspection of the seismic interval velocity at the Alkaid#2 proposed location (Fig.7) indicates shallow subsurface velocities similar to the Merak-1 and Alcor-1 wells. No anomalous velocity inversions are observed in the Alkaid#2 seismic interval velocity that might indicate shallow abnormally pressured zones. The proposed Alkaid#2 well should encounter a shallow section similar in pressure to the Merak-1 and Alcor-1 wells. Mud weight and sonic log data from Merak-1 indicate that the Merak-1 well was normally pressured in the shallow section beginning with a mud weight of 8.8 ppg and ending with a mud weight of 9.6 ppg at 8750’MD (Fig.10). The jump in mud weight from 9.6ppg to 10.4ppg at 8750’MD coincides with the observed mismatch referenced earlier in the report between the Merak-1 seismic interval velocity and the Merak-1 sonic (Fig.9). Although a velocity inversion is not visible in the seismic interval velocity, an increase in geopressure should be expected at the Akaid#2 proposed location below -8500’tvdss based on the Merak-1 and Alcor-1 mud weight plots (Fig.10). Submitted by: Michael D. Helton, Consulting Geophysicist Petrotechnical Resources of Alaska 3601 C Street, Suite 1424 Anchorage, AK 99503 Email: mhelton@petroak.com Cell: (907) 242-3472 (g) No anomalous velocity inversions are observed in the Alkaid#2 y e Alkaid#2 well will penetrate a normally pressurized section No faults or fault () discontinuities within the resolution of the seismic were observed (g)gy n increase in geopressure should be expected aty, the Akaid#2 proposed location below -8500’tvdss 4 Figure1a.MapviewshowingthearealcoverageoftheGBP2015MergedCOV3DPSTMseismicdata(in violetrectangleabove).EnlargementaroundtheAlkaid#2proposedlocation.Townshipandsection outlinesareshownforscale. Figure1b.LargermapimageshowinglocationsfortheGBPAlkaidͲ1well,GBPMerakͲ1well,the proposedGBPAlkaid#2well,andtheGBPAlcorͲ1well.Sectionlinesprovidescale. 5 Figure2.BasemapshowingtheGBPAlkaidͲ1well,theGBPMerakͲ1well,theproposedGBPAlkaid#2 well,andtheGBPAlcorͲ1welllocationsandthelocationsofseismicintervalvelocityfunctionsusedin thisreport.Sectionlinesprovidescale. Figure3.Basemapshowingtheorientationoftwoarbitraryseismicprofiles(FF’&LL’)tyingorspotting theGBPAlkaidͲ1well,GBPMerakͲ1well,theproposedGBPAlkaid#2well,andtheGBPAlcorͲ1well locations.Sectionlinesprovidescale. 6 Figure4.Timesliceat1000ms(Ͳ3500’tvdss)fromtheGBP2015MergedCOV3DPSTMdatashowingthe easternextentoftheGreatBearPantheon3DseismicdatacoveragestoppingattheSagavanirktok River.Alsoshownarewelllocationsandarbitraryseismicprofileorientationsreferencedinthisreport. Sectionlinesprovidescale. 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dƌŝƉŝŶŚŽůĞWŝĐŬŝŶŐƵƉϰ͟,dͲϰϬĚƌŝůůƉŝƉĞƚŽĨůŽĂƚĐŽůůĂƌĚŽŶŽƚĚƌŝůůŽŶĨůŽĂƚĐŽůůĂƌ͘ x ^ůŝƉΘƵƚƌŝůůůŝŶĞ͕^ĞƌǀŝĐĞƌŝŐ͘ ůŬĂŝĚηϮ ƌŝůůŝŶŐWƌŽĐĞĚƵƌĞ ϰŽĨϳ x ŝƌĐƵůĂƚĞĂŶĚĐŽŶĚŝƚŝŽŶŵƵĚ͘ x dĞƐƚĐĂƐŝŶŐƚŽϯ͕ϱϬϬƉƐŝ͘ϯϬŵŝŶƵƚĞƐ͘ŚĂƌƚƚĞƐƚ͘ x ƌŝůůŽƵƚƐŚŽĞƚƌĂĐŬƉůƵƐϮϬ͛ŽĨŶĞǁŚŽůĞ͘ x ŝƌĐƵůĂƚĞĂŶĚĐŽŶĚŝƚŝŽŶĨŽƌ>͘K͘d͘ x WĞƌĨŽƌŵ>͘K͘d͘ĐŚĂƌƚƚĞƐƚ͘DŝŶŝŵƵŵ>Kdϭϭ͘ϳƉƉŐ x ŝƐƉůĂĐĞƚŽϵ͘ϮƉƉŐ͘<ůĂͲ^ŚŝĞůĚŵƵĚ͘ x ƌŝůůϴͲϭͬϮ͟ŚŽůĞƚŽϲ͕ϱϬϬ͛нͬͲ x WĂƌĂŵĞƚĞƌƐƉĞƌͬ͘͘ŽDĂŶ͘ x ŝƌĐƵůĂƚĞŚŽůĞĐůĞĂŶ͘ǆƉĞĐƚĐŽŶŶĞĐƚŝŽŶͬďĂĐŬŐƌŽƵŶĚŐĂƐ͘ x DŽŶŝƚŽƌǁĞůůĨŽƌĨůŽǁ͘ x ^ŚŽƌƚƚƌŝƉƚŽƐƵƌĨĂĐĞƐŚŽĞ͕ĂĐŬƌĞĂŵĂŶĚƉƵŵƉĂƐŚŽůĞĚŝĐƚĂƚĞƐ͘ x ŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉŽƌƵŶƚŝůƐŚĂŬĞƌƐĐůĞĂŶƵƉ͘ x d͘/͘,͘;WŝĐŬƵƉĞŶŽƵŐŚϰ͟,dͲϰϬĚƌŝůůƉŝƉĞƚŽƌĞĂĐŚWŝůŽƚŚŽůĞd͘͘Ϳ x ƌŝůůƉŝůŽƚŚŽůĞ&ͬϲ͕ϱϬϬ͛нͬͲdͬϵ͕ϰϬϬ͛DнͬͲ͘ x WĂƌĂŵĞƚĞƌƐƉĞƌͬ͘͘Ž͘DĂŶ͘ x ƌŝůůWŝůŽƚ͘ŽŶƚƌŽůZKWĂƐƌĞƋƵĞƐƚĞĚĨŽƌ>ŽŐŐŝŶŐ͘ x ŝƌĐƵůĂƚĞŚŽůĞĐůĞĂŶ͘ x DŽŶŝƚŽƌǁĞůůĨŽƌĨůŽǁ͘ x WƵůůϱͲϭϬƐƚĂŶĚƐŝĨŚŽůĞĐŽŶĚŝƚŝŽŶƐĂƌĞĨĂǀŽƌĂďůĞƉƵŵƉĚƌǇũŽď͘ x dƌŝƉŽƵƚŽŶĞůĞǀĂƚŽƌƐŝĨŚŽůĞĚŝĐƚĂƚĞƐ͘ x DŽŶŝƚŽƌǁĞůůĨŽƌĨůŽǁĂƚƐŚŽĞ͘ x d͘K͘K͘,͘ŽŶĞůĞǀĂƚŽƌƐ͘ x DŽŶŝƚŽƌǁĞůůĨŽƌĨůŽǁĂƚ,tW͘ x ZĂĐŬďĂĐŬ,tW͕ƌŝůůĐŽůůĂƌƐΘ:ĂƌƐ͘>ͬ,͘;,tWΘŽůůĂƌƐǁŝůůŶŽƚďĞƵƐĞĚĚƵƌŝŶŐ ĐĞŵĞŶƚũŽď͘ZĂĐŬĂƉƉƌŽƉƌŝĂƚĞůǇĂůůŽǁŝŶŐĂĐĐĞƐƐƚŽĚƌŝůůƉŝƉĞ͘Ϳ tŝƌĞůŝŶĞΘKWƚĞƐƚϳͬϭϰͬϮϮ x ZŝŐƵƉtŝƌĞůŝŶĞ͘^ŝĚĞǁĂůůĐŽƌĞƐ͘ZŝŐĚŽǁŶtŝƌĞůŝŶĞ x KWƚĞƐƚƉĞƌ^ƵŶĚƌǇ ĞŵĞŶƚWŝůŽƚ,ŽůĞϳͬϭϲͬϮϮ x DĂŬĞƵƉŵƵůĞƐŚŽĞƚŽĚƌŝůůƐƚƌŝŶŐ͘ x dƌŝƉƚŽďŽƚƚŽŵ͘ VTL 7/2/22 13.0 ppg ůŬĂŝĚηϮ ƌŝůůŝŶŐWƌŽĐĞĚƵƌĞ ϱŽĨϳ x ŝƌĐƵůĂƚĞΘŽŶĚŝƚŝŽŶŵƵĚǁŚŝůĞƌŝŐŐŝŶŐƵƉĐĞŵĞŶƚĞƌƐ͘ x WƵŵƉϭϱ͘ϴƉƉŐĐĞŵĞŶƚƉĞƌƉƌŽŐƌĂŵ͘ x ϭƐƚƉůƵŐd͘K͘͘ϴ͕ϬϬϬ͛;ϮϬйĞǆĐĞƐƐŵĂǆdKсϳ͕ϳϮϬ͛Ϳ x ĨƚĞƌƉƵůůŝŶŐŽƵƚŽĨĐĞŵĞŶƚ͘d͘K͘K͘,͘dͬϳ͕ϰϬϬ͛ x ŝƌĐƵůĂƚĞ͘ x WƵŵƉĚƌǇũŽď͘ x d͘K͘K͘,͘ƚŽƐƵƌĨĂĐĞƐŚŽĞ͘ x DŽŶŝƚŽƌǁĞůů͘ x d/͘,͘ƉŝĐŬŝŶŐƵƉĚƌŝůůƉŝƉĞ&ͬWŝƉĞƐŚĞĚ͘;tŚŝůĞǁĂŝƚŝŶŐŽŶĐĞŵĞŶƚͿ x dĂŐĨŝƌƐƚĐĞŵĞŶƚƉůƵŐ͘WĞƌĨŽƌŵĐĂůĐƵůĂƚŝŽŶƐĨŽƌĐĞŵĞŶƚďĂƐĞĚŽŶǁŚĞƌĞϭƐƚƉůƵŐŝƐƚĂŐŐĞĚ͘ x WĞƌĨŽƌŵϮŶĚĐĞŵĞŶƚƉůƵŐǁŝƚŚƚŽƉŽĨĐĞŵĞŶƚƉůĂŶŶĞĚĨŽƌϳ͕ϬϬϬ͛D͘͘ dĞƐƚ͘K͘W͘͘ϳͬϭϴͬϮϮ x ZŝŐƵƉƚŽƚĞƐƚ͘K͘W͘͘WƵůůt͘͘ƐĞƚƚĞƐƚƉůƵŐ͘ x dĞƐƚ͘K͘W͘͘^ƚĂƚĞK'ǁŝƚŶĞƐƐ͘ x ZŝŐĚŽǁŶĨƌŽŵ͘K͘W͘͘ƚĞƐƚ͘/ŶƐĞƌƚt͘͘ EŽƚŝĨŝĐĂƚŝŽŶƐ͗ o ĂƐŝŶŐĐƌĞǁϲͲŚŽƵƌŶŽƚŝĐĞ͘ĞŵĞŶƚĞƌƐϲͲŚŽƵƌŶŽƚŝĐĞ͘ ƌŝůůůĂƚĞƌĂůůŬĂŝĚϮϳͬϭϴͬϮϮ x WͬhZŽƚĂƌǇƐƚĞĞƌĂďůĞĂƐƐĞŵďůǇƉĞƌΘDt͘ x WŝĐŬƵƉĚƌŝůůƉŝƉĞŝĨŶĞĞĚĞĚƚŽƌĞĂĐŚd͘͘ x d͘/͘,͘ƚŽĐĂƐŝŶŐƐŚŽĞ͘&ŝůůƉŝƉĞĂƐƌĞƋƵŝƌĞĚ͘ x ^ůŝƉĂŶĚĐƵƚĚƌŝůůůŝŶĞƐĞƌǀŝĐĞƌŝŐ͘ x d͘/͘,͘ĨŝůůŝŶŐƉŝƉĞĂƐƌĞƋƵŝƌĞĚ͘ x dĂŐĐĞŵĞŶƚǁŝƚŚŵŝŶŝŵƵŵϭϬŬ͘ x ŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉƉƌŝŽƌƚŽĚƌŝůůŝŶŐĂŚĞĂĚ͘ x ŶƐƵƌĞŵƵĚƉƌŽƉĞƌƚŝĞƐĂƌĞĐŽƌƌĞĐƚ͘/ĨŶĞĞĚĞĚƉĞƌĨŽƌŵŵƵĚĚŝůƵƚŝŽŶŽƌĚŝƐƉůĂĐĞŵĞŶƚ͘ x <ŝĐŬŽĨĨĐĞŵĞŶƚͲƌŝůůůĂƚĞƌĂůŚŽůĞƐĞĐƚŝŽŶƚŽƐŚŽƌƚƚƌŝƉƉŽŝŶƚϯ͕ϬϬϬ͛ŽĨŶĞǁŚŽůĞнͬͲ͘ x ^ŚŽƌƚƚƌŝƉďĂĐŬƚŽ<ŝĐŬŽĨĨƉŽŝŶƚŝĨŶŽŚŽůĞƉƌŽďůĞŵƐĞŶĐŽƵŶƚĞƌĞĚ͘/ĨƉƌŽďůĞŵƐ ĞŶĐŽƵŶƚĞƌĞĚĂĐŬƌĞĂŵƚŽĂďŽǀĞŬŝĐŬŽĨĨƉŽŝŶƚ͘ x dƌŝƉďĂĐŬƚŽďŽƚƚŽŵ͘ ůŬĂŝĚηϮ ƌŝůůŝŶŐWƌŽĐĞĚƵƌĞ ϲŽĨϳ x ƌŝůůůĂƚĞƌĂůƐĞĐƚŝŽŶƚŽd͘ x ŝƌĐƵůĂƚĞŚŽůĞĐůĞĂŶ͘ x WůĂŶŽŶƉƵůůŝŶŐŽŶĞůĞǀĂƚŽƌƐŝĨďĂĐŬƌĞĂŵŝŶŐƌĞƋƵŝƌĞĚƵƐĞƚŚĞƐĂŵĞƉĂƌĂŵĞƚĞƌƐĂƐĚƌŝůůŝŶŐ͘ x DŽŶŝƚŽƌǁĞůůĂƚƐŚŽĞ͘WƵŵƉĚƌǇũŽď͘ x dƌŝƉŽƵƚŽŶĞůĞǀĂƚŽƌƐƚŽ,tW͘ x DŽŶŝƚŽƌǁĞůůĨŽƌĨůŽǁ͘ x >ĂǇĚŽǁŶ,͘;/ŶĐůƵĚŝŶŐ,tWͿ x ůĞĂƌĂŶĚĐůĞĂŶĨůŽŽƌ͘ KWdĞƐƚϳͬϮϯͬϮϮ x WƵůůt͘͘ x ^ĞƚƚĞƐƚƉůƵŐΘƚĞƐƚũŽŝŶƚ͘ x ŚĂŶŐĞƚŽƉƌĂŵƐƚŽϱͲϭͬϮ͟ x dĞƐƚ͘K͘W͘͘ƉĞƌ^ƵŶĚƌǇ x ZŝŐĚŽǁŶĨƌŽŵ͘K͘W͘͘ƚĞƐƚ͕/ŶƐĞƌƚt͘͘ ϱͲϭͬϮ͟ĂƐŝŶŐϳͬϮϯͬϮϮ x ZŝŐƵƉƚŽƌƵŶϱͲϭͬϮ͟ĂƐŝŶŐ>ͲϴϬ͕ϮϬƉƉĨ͘ĂƐŝŶŐ͘ x WƵůůtͬ͘͘ƵŵŵǇƌƵŶŚĂŶŐĞƌ͘ x DĂŬĞƵƉƐŚŽĞƚƌĂĐŬ͘&ŝůůĂŶĚƚĞƐƚĨůŽĂƚƐ͘ x ZƵŶϱͲϭͬϮ͟>ŝŶĞƌƉĞƌĚĞƚĂŝů͘tŝůůŚĂǀĞƉƵƉũŽŝŶƚƐŝŶůĂƚĞƌĂůĨŽƌŵĂƌŬĞƌũŽŝŶƚƐ͕dŚĞĂǀŝƐ >ǇŶĐŚƐƚĂŐĞƚŽŽůǁŝůůďĞƐĞƚĂƚϳ͕ϰϱϬ͛DĂƉƉƌŽǆŝŵĂƚĞůǇ͘ x &ŝůůŽŶƚŚĞĨůǇƚŽƉŽĨĨĞǀĞƌǇϭϬũŽŝŶƚƐ͘ x ƌĞĂŬĐŝƌĐƵůĂƚŝŽŶĂƚƐŚŽĞ͕ŝƌĐƵůĂƚĞĂƚƉƌĞͲĚĞƚĞƌŵŝŶĞĚĐŝƌĐƵůĂƚŝŽŶƉŽŝŶƚƐ͘ x ZƵŶϱͲϭͬϮ͟ĐĂƐŝŶŐƚŽďŽƚƚŽŵ͘/ĨŚŽůĞĐŽŶĚŝƚŝŽŶƐĂƌĞŐŽŽĚŵĂŬĞƵƉŚĂŶŐĞƌĂŶĚůĂŶĚŝŶŐ ũŽŝŶƚƉƌŝŽƌƚŽĐŝƌĐƵůĂƚŝŶŐ͘ WƌŽĚƵĐƚŝŽŶϮƐƚĂŐĞĐĞŵĞŶƚũŽďϳͬϮϱͬϮϮ x ŝƌĐƵůĂƚĞĂŶĚĐŽŶĚŝƚŝŽŶŵƵĚǀĞƌŝĨǇŵƵĚƉƌŽƉĞƌƚŝĞƐ͘ x ,ŽůĚWƌĞũŽďǁŝƚŚĐĞŵĞŶƚŝŶŐĐƌĞǁ͘ x WƌĞƐƐƵƌĞƚĞƐƚĐĞŵĞŶƚůŝŶĞƚŽϰ͕ϬϬϬƉƐŝ͘ ůŬĂŝĚηϮ ƌŝůůŝŶŐWƌŽĐĞĚƵƌĞ ϳŽĨϳ x dƵƌŶŽǀĞƌƚŽĐĞŵĞŶƚĞƌƐƚŽƉƵŵƉϭƐƚƐƚĂŐĞƉĞƌĐĞŵĞŶƚƉƌŽŐƌĂŵ͘ WƵŵƉĐĞŵĞŶƚ͕ƌŽƉǁŝƉĞƌƉůƵŐ͘ZŝŐǁŝůůĚŝƐƉůĂĐĞ͘^ůŽǁƌĂƚĞƚŽϭͲϮďƉŵƉƌŝŽƌƚŽǁŝƉĞƌƉůƵŐ ŐŽŝŶŐƚŚƌŽƵŐŚƐƚĂŐĞĐŽůůĂƌ͘KŶĐĞƉĂƐƚƐƚĂŐĞƚŽŽů͕ĐŽŶƚŝŶƵĞƉƵŵƉŝŶŐĂƚϰͲϲďĂƌƌĞůƉĞƌ ŵŝŶƵƚĞƌĂƚĞ͘^ůŽǁƌĂƚĞƚŽϭͲϮďƉŵĂƚϭϬďďůƐ͘&ƌŽŵďƵŵƉŝŶŐ͘ x ƵŵƉǁŝƉĞƌůĂƚĐŚƉůƵŐŝŶƚŽĐĂƚĐŚĞƌ͘ x WƌĞƐƐƵƌĞƵƉϱϬϬƉƐŝŽǀĞƌƉƌĞƐƐƵƌĞǁŚĞŶƉůƵŐďƵŵƉĞĚ͘,ŽůĚĨŽƌϱŵŝŶƵƚĞƐ͘ůĞĞĚ ƉƌĞƐƐƵƌĞŽĨĨ͕ĐŚĞĐŬĨůŽĂƚƐ͘ x WƌĞƐƐƵƌĞƵƉƚŽϯ͕ϬϬϬƉƐŝƚŽŽƉĞŶƐƚĂŐĞƚŽŽů͘ x 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Thankyou, Michael From:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Sent:Saturday,July2,202211:30AM To:MichaelDuncan<michael@greatbearpetro.com> Subject:RE:Alkaid2PHPorePressures/kicktolerance Michael, Concerningkicktolerancecalculations: 1. WillaLOToranFITbeperformed?FITto12.1orLOTtobreakover? 2. Wouldliketosee13.0minimumLOTforcasewhereporepressureexceeds9.5. Victoria From:MichaelDuncan<michael@greatbearpetro.com> Sent:Saturday,July2,202211:03AM To:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Subject:RE:Alkaid2PHPorePressures Victoria– Pleaseseemyresponsebelowinred. Thankyou, Michael From:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Sent:Saturday,July2,202210:01AM To:MichaelDuncan<michael@greatbearpetro.com> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Subject:Alkaid2PHPorePressures Michael, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 1. Themaximumreservoirpressureis4140psig.Whatdepth/EMW?ThatisamaxdepthTVDof9,000feetwitha .46psi/ftgradient.ThisgradientequatedtoaEMWof8.85 2. Whyisn’ttheTalithaAporepressure,LOTdata,fracgradientdataincluded?Thethreewellsshown,Alkaid#1, Alcor#1,andMerak#1areclosetotheAlkaid#2/#2PH.TheTalithaAisgreaterthan14milesaway. 3. BothMerak1andAlcor1wellsindicateanincreaseingeopressuredwiththetopoftheHRZ.Whydoesthe anticipatedAlkaid2PHporepressurenotreflectthis?ThewellisnotintendedtocuttheHRZ.AswithTheta WesttheplanistoTDatthebaseoftheBrookainformation. 4. Whatareweightingupplansintheeventhigherporepressuresareencountered?Theplanwouldbetoweight uptoaboveporepressure,plusenoughworking(surge/swab/trip)margin.WehavegoodoffsetsintheAlkaid, Alcor,andMerakandthusporepressureismorepredictablethaninwellssuchasTalithaandThetaWest. Nonetheless,weasalwayswillbewatchfulofmudweightandmaintaingooddrillingpractices.Therewillbe enoughweightproductonlocationtoweightup.TherewillalsobeLCMmaterialand“blackproduct”within reachtoensuregoodwellborestabilityinweightͲupscenarios. 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@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov CAUTIONͲEXTERNALEMAIL:Thisemailoriginatedfromoutsideofyourorganization.Donotclicklinksoropen attachmentsunlessyourecognizethesenderandknowthecontentissafe. CAUTIONͲEXTERNALEMAIL:Thisemailoriginatedfromoutsideofyourorganization.Donotclicklinksoropen attachmentsunlessyourecognizethesenderandknowthecontentissafe. 1 Guhl, Meredith D (OGC) From:Michael Duncan <michael@greatbearpetro.com> Sent:Saturday, July 2, 2022 11:03 AM To:Loepp, Victoria T (OGC) Subject:RE: Alkaid 2PH Pore Pressures Victoria– Pleaseseemyresponsebelowinred. Thankyou, Michael From:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Sent:Saturday,July2,202210:01AM To:MichaelDuncan<michael@greatbearpetro.com> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Subject:Alkaid2PHPorePressures Michael, 1. Themaximumreservoirpressureis4140psig.Whatdepth/EMW?ThatisamaxdepthTVDof9,000feetwitha .46psi/ftgradient.ThisgradientequatedtoaEMWof8.85 2. Whyisn’ttheTalithaAporepressure,LOTdata,fracgradientdataincluded?Thethreewellsshown,Alkaid#1, Alcor#1,andMerak#1areclosetotheAlkaid#2/#2PH.TheTalithaAisgreaterthan14milesaway. 3. BothMerak1andAlcor1wellsindicateanincreaseingeopressuredwiththetopoftheHRZ.Whydoesthe anticipatedAlkaid2PHporepressurenotreflectthis?ThewellisnotintendedtocuttheHRZ.AswithTheta WesttheplanistoTDatthebaseoftheBrookainformation. 4. Whatareweightingupplansintheeventhigherporepressuresareencountered?Theplanwouldbetoweight uptoaboveporepressure,plusenoughworking(surge/swab/trip)margin.WehavegoodoffsetsintheAlkaid, Alcor,andMerakandthusporepressureismorepredictablethaninwellssuchasTalithaandThetaWest. Nonetheless,weasalwayswillbewatchfulofmudweightandmaintaingooddrillingpractices.Therewillbe enoughweightproductonlocationtoweightup.TherewillalsobeLCMmaterialand“blackproduct”within reachtoensuregoodwellborestabilityinweightͲupscenarios. 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@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 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@alaska.gov CAUTIONͲEXTERNALEMAIL:Thisemailoriginatedfromoutsideofyourorganization.Donotclicklinksoropen attachmentsunlessyourecognizethesenderandknowthecontentissafe. 1 Guhl, Meredith D (OGC) From:Michael Duncan <michael@greatbearpetro.com> Sent:Saturday, July 2, 2022 10:47 AM To:Loepp, Victoria T (OGC) Cc:Paul Smith; Patrick Galvin Subject:RE: Alkaid 2PH Diverter line Attachments:Rig Diverter Drawing.pdf Victoria– Pleaseseetheattached.TheTiogaHeaterthatwasonthedrawingisnotandwillnotbeonlocation.Ihavecrosseditoff thedrawing.Attachedisthedrawingwiththeradiusasrequested.Theareaofthepipeshedwithintheradiusisfreeof ignitionsources.Myunderstandingisthathasbeenverifiedinthepastwithriginspectionsandwillbeverifiedagain withtheupcominginspection. Pleaseletmeknowifthisissufficient. Thankyou, MichaelDuncan GreatBearPantheon From:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov> Sent:Saturday,July2,20229:17AM To:MichaelDuncan<michael@greatbearpetro.com> Subject:Re:Alkaid2PHDiverterline Pleaseprovidethediverterschematicwitha50’radiuscirclearoundthedischargeshowingnoignitionsources. SentfrommyiPhone OnJul2,2022,at8:46AM,MichaelDuncan<michael@greatbearpetro.com>wrote: Hereistheinitialresponsefromtherig.Iwillhavemeasureddimensionsshortly. Michael SentfrommyiPhone Beginforwardedmessage: From:PaulSmith<Paul.Smith@greatbearpetro.com> Date:July2,2022at8:41:17AMAKDT To:MichaelDuncan<michael@greatbearpetro.com> Subject:RE:Alkaid2PHDiverterline CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Michael, Iwilllookatthesystemdescribeandtakepicturesafterthecall.Theinspectorsusually confirmtheregulationsaremetduringtheinitialinspectionanddivertest. Divertergoesthroughthepipeshedbuildingsteelandwalls,withnoequipmentwithin 75’ofdiverteroutlet.Noheating/Tiogainpipeshed. Theendis100+’fromwellcenter,80+’fromsubstructure.Iwillconfirmallthismorning nowthatitisactuallyinstalled.HadtorunbacktoDH,nointernetatrigstill. Thanks PaulSmith GreatBearPantheon,DSM Drillingsupervisor@greatbearpetro.com Mobile(907)529Ͳ0737 From:MichaelDuncan<michael@greatbearpetro.com> Sent:Saturday,July2,20228:24AM To:PaulSmith<Paul.Smith@greatbearpetro.com> Subject:Fwd:Alkaid2PHDiverterline SentfrommyiPhone Beginforwardedmessage: From:"Loepp,VictoriaT(OGC)"<victoria.loepp@alaska.gov> Date:July1,2022at4:38:17PMAKDT To:MichaelDuncan<michael@greatbearpetro.com> Cc:"Loepp,VictoriaT(OGC)"<victoria.loepp@alaska.gov> Subject:Alkaid2PHDiverterline Concerningthediverterline: Mustextendtoapointatleast75feetawayfromapotential sourceofignition…andatleast50feetbeyondthedrillrigsubstructure. See20AAC25.035(c) Whatarebuildingsdiverterlinegoesthrough?Ignitionsources? TiogaHeater? Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 3 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov CAUTIONͲEXTERNALEMAIL:Thisemailoriginatedfromoutsideofyour organization.Donotclicklinksoropenattachmentsunlessyou recognizethesenderandknowthecontentissafe. CAUTIONͲEXTERNALEMAIL:Thisemailoriginatedfromoutsideofyourorganization.Donotclicklinksoropen attachmentsunlessyourecognizethesenderandknowthecontentissafe. Well: Alkaid 2PH <== Data Input Name: V Loepp <== Data Input Mud Weight (ppg) 9.50 <== Data Input Weak point or LOT - Measured depth (ft) 3,522'<== Data Input Weak point or LOT True vertical depth (ft) 3,445'<== Data Input Weak point or LOT - Hole angle (deg) 18.2º<== Data Input Weak point or LOT - Hole size (in) 12.250"<== Data Input Weak point pressure or LOT - EMW (ppg) 13.00 <== Data Input Zone of interest - Measured depth (ft) 9,344'<== Data Input Zone of interest - True vertical depth (ft) 8,765'<== Data Input Zone of interest - Hole angle (deg) 18.2º<== Data Input Zone of interest - Hole size (in) 8.500"<== Data Input Zone of interest - Pore pressure EMW (ppg) 10.00 <== Data Input Gas gradient (psi/ft) 0.10 <== Data Input Bottom hole assembly OD (in) 7.0"<== Data Input Bottom hole assembly length (ft) 396'<== Data Input Drill pipe OD (in) 4.000"<== Data Input BHA annular vol. @ zone of interest (bbl/ft)0.0226 DP annular vol. @ zone of interest (bbl/ft)0.0546 DP annular vol. @ weak point (bbl/ft)0.1302 Additional safety margin (psi) 5.00 <== Data Input Weak point pressure (psi):Plo 2,329 psi Weak point pressure - Safety margin:Pmax 2,324 psi Pmax EMW 12.97 ppg Max anticipated formation pressure (psi):Pf 4,558 psi Weak Pt to Zone of Interest distance (TVD ft):OH {TVD}5,320' Weak Pt to Zone of Interest distance (MD ft):OH {MD}5,822' Maximum influx height at the bit (TVD ft):H {TVD}1,000' Maximum influx height at the bit (MD ft):H {MD}1,053' Calc. volume of {H} around BHA:V1bha 8.9 bbl Calc. volume of {H} around drill pipe:V1dp 35.9 bbl Calc. volume that H equals @ initial shut in:V1 44.9 bbl Calc. vol. that H equals @ weak point (MD ft):Vwp 137.2 bbl Calc. volume of Vwp @ initial shut in:V2 69.9 bbl Kick Tolerance: V1 44.9 bbl NOTE: KickToleranceCalculationsGreatBearAlkaid2PH 7/2/2022 VTL VLoeppinputinyellowareasonlyMW(ppg)11ppgLOT/FIT(ppg)13.0ppgTVDCasingShoe(ft)3445ftTVDIfaformationdeeperthanthecasingshoeisknowntobeweakerthanthecasingshoe(havealowerfracturegradient/LOT)thenthatweakerformationsTVDandLOTcanbeusedinplaceofthecasingshoeinformationformoreaccuratecalculationsKickIntensity(ppg)0.5ppgFormationPorePressurecannotbelessthantheMWtohaveakick!0.5ppgkicktoleranceovercurrentMWisastandardassumptionAssumethatthekickishydrocarbongas(notoilorwater)TVDofKickInflux(ft)9000ftTVDGasGradient(psi/ft) 0.1 psi/ftChangeonlyifgasgradientisknowntobedifferentHoleSize(in)8.5inchesDrillPipeOD(in)4inchesBHAOD(in)7inchesLengthofBHA(ft)396ft IftheBHAislongerthantheopenhole,thekickwillcometosurfaceveryquicklyduetothesmallerannularcapacity0.0546 bbl/ftAnnularCapacitybetweenOHandDP0.0226 bbl/ftAnnularCapacitybetweenOHandBHA358.28 psiMaximumAllowableSurfacePressure234 psiUnderbalanceduetoKickIntensity124.28 psimarginbeforecasingshoeisbrokendown/fractured(orweakestformationbelowcasingshoe)HeightofGasKick 263.3 feetVolumeofGasKick5.9bblCASE1AssumeKickisonlyaroundtheBHA(nottheDP)attheinfluxdepthVolumeofGasKick 14.4 bbl AssumeKickisonlyaroundtheDP(nottheBHA)atshoedepthVolumeatinflux6.2bblCASE2depthConversionKICKTOLERANCE:5.9 bblCompareCASE1andCASE2volumesforthegasinfluxabove.Thesmallestvolumeisselectedtorepresentthemaximumkickvolumeallowedwithoutbreakingdowntheshoe(orweakestformation)Itisdifficulttoshutinawellwithlessthana10bblkickvolume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oes not apply since the initial vertical well and subsequent horizontal will be permitted separately and will have different Permit to Drill and API Numbers. SFD 6/23/2022 WELL PERMIT CHECKLISTCompanyGreat Bear Pantheon, LLCWell Name:ALKAID 2 PHInitial Class/TypeEXP / PENDGeoArea890Unit On/Off ShoreOnProgramEXPField & PoolWell bore segAnnular DisposalPTD#:2220760Yes1 Permit fee attachedYes Entire well in ADL03917062 Lease number appropriateYes3 Unique well name and numberNo Exploratory well4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes Nearest well, Alcor 1, is plugged and abandoned.6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes DLB on 07/01/2022.10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For sNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes Set at 3522' MD19 Surface casing protects all known USDWsYes 250% excess through permafrost; 50% excess below permafrost; port collar @ 500'20 CMT vol adequate to circulate on conductor & surf csgNo21 CMT vol adequate to tie-in long string to surf csgNo pilot hole; no cementing of intermediate22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes Drilling mud and cuttings to Hilcorp Prudhoe Grind and Inject24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes Explorations well; no wells in vicinity26 Adequate wellbore separation proposedYes Diverter and route meet requirements.27 If diverter required, does it meet regulationsYes Max formation pressure is 4140 psi(8.8 ppg EMW); will drill w/ 9.2-9.6 ppg EMW28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP is 3240 psig; will test BOPs to 4800 psig; initial BOP test to 5000 psig30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No Measures required: exploratory well.35 Permit can be issued w/o hydrogen sulfide measuresYes Normal pressure expected to top of HRZ, which is the beginning of a transition to higher pressures.36 Data presented on potential overpressure zonesYes Operator's mud program appears sufficient to mitigate anticipated37 Seismic analysis of shallow gas zonesNA pressures so long as the well does not penetrate significantly into the HRZ.38 Seabed condition survey (if off-shore)Yes Michael Duncan 817-240-386539 Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate7/2/2022ApprVTLDate7/2/2022ApprSFDDate6/22/2022AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJMP07/04/22