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Home My WebLink About221-106From:Morgan, Kirk A (DNR) To:Guhl, Meredith D (OGC) Cc:Heusser, Heather A (DNR); Clifton, Sean C (DNR) Subject:Theta West Date:Thursday, May 23, 2024 1:42:08 PM The Division of Oil & Gas has not received a request for confidentiality extension for the Theta West well. Kirk A. Morgan Petroleum Geophysicist Resource Evaluation Section Manager State of Alaska Department of Natural Resources Division of Oil and Gas 550 W. 7th Ave. Suite 1100 Anchorage, AK 99501 Phone; 907-269-0135 Email; kirk.morgan@alaska.gov From:Morgan, Kirk A (DNR) To:Guhl, Meredith D (OGC); Clifton, Sean C (DNR) Cc:Heusser, Heather A (DNR) Subject:RE: Wells to be released? Date:Wednesday, May 22, 2024 9:24:48 AM Meredith DOG has not received extended confidentiality requests for Talitha A or Theta West. Extended confidentiality has be requested for Whiskey Gulch 14. That application is currently under review. Kirk Kirk A. Morgan Petroleum Geophysicist Resource Evaluation Section Manager State of Alaska Department of Natural Resources Division of Oil and Gas 550 W. 7th Ave. Suite 1100 Anchorage, AK 99501 Phone; 907-269-0135 Email; kirk.morgan@alaska.gov From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Monday, May 20, 2024 7:59 AM To: Morgan, Kirk A (DNR) <kirk.morgan@alaska.gov> Cc: Heusser, Heather A (DNR) <heather.heusser@alaska.gov> Subject: Wells to be released? Hi Kirk, I have several people repeatedly requiring about Whiskey Gulch 14, Talitha A, and Theta West data. Any updates on whether the data can be released? Thanks, 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. From:Guhl, Meredith D (OGC) To:Morgan, Kirk A (DNR) Cc:Heusser, Heather A (DNR) Subject:Theta West 1, PTD 221-106, Extended Confidentiality Requested? Date:Thursday, May 16, 2024 7:46:00 AM Good Morning Kirk, Theta West 1, drilled by Great Bear Pantheon, is due for release after May 16, 2024. Has Great Bear requested extended confidentiality for this well? Thanks, 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. DATA SUBMITTAL COMPLIANCE REPORT API No.50-223-20036-00-00Well Name/No.THETA WEST 1 Completion Status P&ACompletion Date 4/16/2022 Permit to Drill 2211060 Operator Great Bear Pantheon, LLC MD 8450 TVD 8448 Current Status P&A 5/22/2024 UIC No Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:mud, GR/RES/NEU/DEN, SonicScan/CBL-VDL-MSIP; GR/HNGS/CAL; CBL; USIT-CBL-VDL YesYes NoMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 4/28/2022350 8450 Electronic Data Set, Filename: Theta West 1_DM_Depth_350-8450ft RM.las 36493ED Digital Data DF 4/28/2022194 8450 Electronic Data Set, Filename: Theta West 1_DM_Time_RM.las 36493ED Digital Data DF 4/28/2022350 8450 Electronic Data Set, Filename: Theta West 1_VISION Service_350-8450ft RM.las 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_DM_Depth_Run01.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_DM_Depth_Run02.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_DM_Depth_Run03.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_DM_Time_Run01.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_DM_Time_Run02.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_DM_Time_Run03.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: EOWR_O.1009195.04_Great Bear Theta West #1.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West #1 EOW Letter.doc36493EDDigital Data DF 4/28/2022 Electronic File: Theta West #1 EOW Letter.pdf36493EDDigital Data DF 4/28/2022 Electronic File: PvA - Letter Plot - Theta West #1 ASP Final Survey.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West #1 ASP Final Definitive Survey Signoff SLB Signed.pdf 36493ED Digital Data Wednesday, May 22, 2024AOGCC Page 1 of 4 Theta West, 1_VISION Service_350-8450ft RM.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-223-20036-00-00Well Name/No.THETA WEST 1 Completion Status P&ACompletion Date 4/16/2022 Permit to Drill 2211060 Operator Great Bear Pantheon, LLC MD 8450 TVD 8448 Current Status P&A 5/22/2024 UIC No DF 4/28/2022 Electronic File: Theta West 1 ASP Final Survey NAD27.xlsx 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1 ASP Final Survey NAD27_Signed.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: PrintSurveyList.csv36493EDDigital Data DF 4/28/2022 Electronic File: PrintSurveyList.pdf36493EDDigital Data DF 4/28/2022 Electronic File: Theta West 1_VISION Service_350-8450ft.dlis 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_VISION_Service_2MD_8450ft_RM.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_VISION_Service_2TVD_8450ft_RM.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_VISION_Service_5MD_8450ft_RM.pdf 36493ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_VISION_Service_5TVD_8450ft_RM.pdf 36493ED Digital Data DF 4/28/2022347 8450 Electronic Data Set, Filename: Theta west 1_Depth LAS_346-8450 ft.las 36494ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_50-223-20036-00- 00_FWR.pdf 36494ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_Drilling Log 5 inch_02102022.pdf 36494ED Digital Data DF 4/28/2022 Electronic File: Theta West 1_Master Log 5 inch_02102022.pdf 36494ED Digital Data DF 4/28/2022 Electronic File: Great_Bear_Theta West_Run_1_HNGS-USIT-CBL_MainLog_22- Feb-2022.dlis 36495ED Digital Data DF 4/28/2022 Electronic File: Great_Bear_Theta West_Run_1_HNGS-USIT-CBL_RepeatPass_22- Feb-2022.dlis 36495ED Digital Data DF 4/28/2022 Electronic File: Great_Bear_Theta West_Run_2_MSIP-USIT-CBL- VDL_RepeatPass_27-Feb-2022.dlis 36495ED Digital Data DF 4/28/2022 Electronic File: Great_Bear_Theta West_Run_2__MSIP-USIT-CBL- VDL_MainLog_27-Feb-2022 (2).dlis 36495ED Digital Data Wednesday, May 22, 2024AOGCC Page 2 of 4 Theta west, 1_Depth LAS_346-8450 ft.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-223-20036-00-00Well Name/No.THETA WEST 1 Completion Status P&ACompletion Date 4/16/2022 Permit to Drill 2211060 Operator Great Bear Pantheon, LLC MD 8450 TVD 8448 Current Status P&A 5/22/2024 UIC No Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval DF 4/28/2022 Electronic File: Great_Bear_Theta_West_Run_1_Spectral_Gam ma_Ray_Field_Print_22-Feb-2022.PDF 36495ED Digital Data DF 4/28/2022 Electronic File: Great_Bear_Theta_West_Run_2_Sonic_Scanner _Field_Print_27-Feb-2022.Pdf 36495ED Digital Data DF 4/28/2022 Electronic File: Great_Bear_Theta West_Run_1_Cement_Bond_Log_Field_Print_22 -Feb-2022.PDF 36495ED Digital Data DF 4/28/2022 Electronic File: Great_Bear_Theta West_Run_2_Cement_Bond_Log_Field_Print_27 -Feb-2022.PDF 36495ED Digital Data DF 4/28/2022 Electronic File: GBP FINAL_Flowing Report THETA 1.pdf 36496ED Digital Data DF 4/28/2022 Electronic File: GBP FINAL_Flowing Report THETA 1.xlsm 36496ED Digital Data DF 4/28/2022 Electronic File: List of Form & Geological Markers_TW.xlsx 36497ED Digital Data DF 4/28/2022 Electronic File: Theta West #1 GMR.xlsm36497EDDigital Data DF 4/28/2022 Electronic File: Theta West FracCADE Report Stage 1-3 20220304.pdf 36498ED Digital Data DF 4/25/2024 Electronic File: Great Bear_Theta West Stage 1 Post Job report.pdf 38741ED Digital Data DF 4/25/2024 Electronic File: Great Bear_Theta West Stage 2 Post Job Report.pdf 38741ED Digital Data DF 4/25/2024 Electronic File: Great Bear_Theta West Stage 3 Post Job Report.pdf 38741ED Digital Data DF 5/21/2024 Electronic File: GBPan Transmittal_TW_Geochemical_2022_dated 5-21- 24.pdf 38828ED Digital Data DF 5/21/2024 Electronic File: Theta West_AS0498-0504 Geochemical Summary Sheets.pdf 38828ED Digital Data 2/14/2022360 8452 14 1800Cuttings Wednesday, May 22, 2024AOGCC Page 3 of 4 DATA SUBMITTAL COMPLIANCE REPORT API No.50-223-20036-00-00Well Name/No.THETA WEST 1 Completion Status P&ACompletion Date 4/16/2022 Permit to Drill 2211060 Operator Great Bear Pantheon, LLC MD 8450 TVD 8448 Current Status P&A 5/22/2024 UIC No INFORMATION RECEIVED Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Compliance Reviewed By:Date: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date:4/16/2022 Release Date: 5/16/2024 Wednesday, May 22, 2024AOGCC Page 4 of 4 M.Guhl 5/22/2024 Date: 05/21/2024 To: Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: CONFIDENTIAL Well: Theta West PTD: 221-106 API: 50-223-20036-00-00 Geochemical Summary – (2022) Great Bear Panth – AOGCC > Theta West > Well Completion or Recompletion, Log > Geochemical Summary (2022) Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: 221-106 T38828 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.21 14:03:08 -08'00' Date: 04/25/2024 To: Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: CONFIDENTIAL Well: Theta West PTD: 221-106 API: 50-223-20036-00-00 Post Job FracCAT Reports – Stage 1-3 (2022) Great Bear Panth – AOGCC > Theta West > Well Completion or Recompletion, Log > Frac Treatment (2022) Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: 221-106 T38741 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.25 09:03:21 -08'00' 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. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Theta West #1 (PTD 2211060) Date:Wednesday, September 21, 2022 2:39:59 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Wednesday, September 21, 2022 2:39 PM To: Patrick Galvin <pat@greatbearpetro.com> Cc: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: RE: Theta West #1 (PTD 2211060) Trip to Theta West #1 in conjunction with trio to Talitha A would work. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Patrick Galvin <pat@greatbearpetro.com> Sent: Wednesday, September 21, 2022 2:16 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Re: Theta West #1 (PTD 2211060) Yes, the site has been thoroughly cleaned since the visit. When we received a report from DNR’s visit the next day that debris remained on the site we sent a new crew to do a full new clean up. We have been assured that the site is now clean. As for the gravel mound, we intentionally left it that high anticipating subsidence over the next couple years. This site was P&A’d this April, so it hasn’t gone through even a single full season of subsidence. Our goal is to leave a small mound, and avoid any ponding at the well location. We believe that this mound will sink to become a small mound. Please let me know what we can do to attempt site clearance this season. Perhaps the inspector, when he goes out to Talitha A can take a further trip out to Theta West? Thanks. -Pat Patrick Galvin Chief Commercial Officer & General Counsel Great Bear Pantheon 3705 Arctic Blvd, Suite 2324 Anchorage, AK 99503 Main: (907) 868-8070 Mobile: (907) 575-8914 Fax: (907) 868-3887 From: Regg, James B (OGC) <jim.regg@alaska.gov> Date: Wednesday, September 21, 2022 at 12:12 PM To: Patrick Galvin <pat@greatbearpetro.com> Subject: Theta West #1 (PTD 2211060) There was debris at the location. Inspector report attached. The gravel/dirt mount over the well is ok. Has there been anyone back to clean up debris found at the Theta West #1 location? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CAUTION - EXTERNAL EMAIL: This email originated from outside of your organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2023-0920_Location_Theta-West-1_gc Page 1 of 6 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 9/20/2023 P. I. Supervisor FROM: Guy Cook SUBJECT: Site Clearance Petroleum Inspector Theta West 1 Great Bear Pantheon PTD 2211060; Sundry 322-155 9/20/23: Traveled to the Theta West 1 location via helicopter with Pollux Aviation to the coordinates povided by Patrick Galvin (Great Bear Pantheon). There was no representative from Great Bear. At the Theta West #1 drill site there was obvious debris left at location scattered around the plugged and abandoned well. The debris found at location included, an empty snack container, various small pieces of plastic, a large piece of visqueen, scrap paper, what appeared to be some kind of warning label, and some pieces of scrap wood. This is an improvement from my visit last year but still not adequate to grant site clearance. The gravel fill placed on top of the abandoned well had settled quite a bit since last year’s visit. Around the gravel fill is a large area of mud. I informed Mr. Galvin that the debris needed to be cleaned up. He informed me it would happen today. I asked for pictures of the debris gathered to be sent to me so I may give them their site clearance. The pictures were sent to me, and I am satisfied that the Theta West 1 location is cleaned up. Attachments: Photos (9)      jbr 2023-0920_Location_Theta-West-1_gc Page 2 of 6 Location Inspection – Theta West 1 (PTD 2211060) Photos by AOGCC Inspector G. Cook (except as noted) 9/20/2023 2023-0920_Location_Theta-West-1_gc Page 3 of 6 2023-0920_Location_Theta-West-1_gc Page 4 of 6 2023-0920_Location_Theta-West-1_gc Page 5 of 6 2023-0920_Location_Theta-West-1_gc Page 6 of 6 Debris collected from Theta West 1 drillsite; photo courtesy of Great Bear Pantheon 2022-0820_Location_ThetaWest -1_gc Page 1 of 6 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:8/20/2022 P. I. Supervisor FROM:Guy Cook SUBJECT:Location Inspection Petroleum Inspector Theta West #1 Great Bear Pantheon PTD 2211060; Sundry 322-155 8/19/2022:Flew out to location via helicopter with Pollux Aviation to the coordinates given to us by Patrick Galvin (Great Bear Pantheon). At the Theta West #1 drill site there was obvious debris left at location scattered around the plugged and abandoned well. Absorbent, plastic “zip-lock” bag, delineators and rags are just a few examples of the debris found. The gravel fill placed on top of the abandoned well seems excessively high. Around the gravel fill is a large area of mud. The area needs to be cleaned up before a site clearance can be given. Attachments:Photos (10) 9 James B. Regg Digitally signed by James B. Regg Date: 2022.09.21 12:04:49 -08'00' 2022-0820_Location_ThetaWest -1_gcPage 2 of 6Location Inspection – Theta West #1 (PTD 2211060)Photos by AOGCC Inspector G. Cook8/20/2022 2022-0820_Location_ThetaWest -1_gcPage 3 of 6 2022-0820_Location_ThetaWest -1_gcPage 4 of 6 2022-0820_Location_ThetaWest -1_gcPage 5 of 6 2022-0820_Location_ThetaWest -1_gcPage 6 of 6 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: 210' 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 9 5/8" L-80 3,164' 5 1/2" P-110 6,430' 3 1/2" L-80 Packer: 7,033 3 1/2" L-80 Liner: 8,277' 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 Variable Exploration 36-39 Oil-Bbl: Water-Bbl: 57 suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 00 7,770'-7,780' 7,590'-7,600' Gas Lift Stage 1 - Top: 8,065' MD; Bottom: 8,075' MD; Shot Density: 6ft; Number: 60, Diameter: 0.28"; Date: 3/8/22 Stage 2 - Top: 7,745' MD; Bottom: 7,755' MD; Shot Density: 6ft; Number: 60; Diameter: 0.28"; Date: 3/16/22 Stage 3 - Top: 7,595' MD; Bottom: 7,605' MD; Shot Density: 6ft, Number: 60; Diameter: 0.28"; Date: 3/17/22 99 Gas-Oil Ratio:Choke Size: 0150 0 3/20/2022 43 Flow Tubing 4167 0 280,935 lbs. of Sand 40/70 / 57,812 gals of WF110; 70,502 gals of YF118FlexD 71,388 lbs. of CarboLite 20/40; 143,297 lbs. of Sand 40/70 / 53,7287 gals of WF115; 64,302 gals of YF115FlexD 8,070'- 8,080'45,984 lbs. of CarboLite 20/40; 198,547 lbs. of Sand 40/70 / 62,790 gals of WF115; 76,104 gals of YF115FlexD Water-Bbl: PRODUCTION TEST 3/20/2022 Date of Test: Oil-Bbl: Per 20 AAC 25.283 (i)(2) attach electronic information 9.2 lb/ft Liner: 8,277' Packer: 7,026' Liner: 7,033' 40 lb/ft 17 lb/ft 3,164' Packer: 7,026' Packer: 7,033' CASING WT. PER FT.GRADE 9.2 lb/ft 569,801.86 569781.92 TOP SETTING DEPTH MD TOC Liner: 7,033' TOP TOC TOC 569,861.19 5,817,637.76 456.2’ FSL, 2,388.9’’ FWL, S32 T7N R11E UM 2/8/2022 CEMENTING RECORD 5,817,647.70 1385' SETTING DEPTH TVD 5817667.09 Pending 1/22/2022 8450' / 8,448.90' 8376' / 8,374.8' 240' HOLE SIZE AMOUNT PULLED MudLogs; Quad Combo: GR/RES/NEU/DEN; Sonic Scanner_CBL-VDL-MSIP; GR_HNGS-CAL; Cement Bond Log_USIT-CBL-VDL 3705 Arctic Blvd., Ste 2324, Anchorage, AK 99503 4/16/2022 50-223-20036-00-00 Theta West #1 ADL 394039 474.5’ FSL, 2,369.2’ FWL, S32 T7N R11E UM 444.4’ FSL, 2,448.1’ FWL, S32 T7N R11E UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Great Bear Pantheon, LLC WAG Gas 221-106; 322-155; 322-113; 322-088 12 1/4" BOTTOM 6,403'5-1/2" SIZE DEPTH SET (MD) 7,033' PACKER SET (MD/TVD) TUBING RECORD TOC 6,430' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 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, to production or injection? YesNo25. 26. Was hydraulic fracturing used during completion?YesNo Top: 8,065' MD; Bottom: 8,075' MD; Shot Density: 6ft; Number: 60, 0.28"; Date: 3/8/22 Top: 7,745' MD; Bottom: 7,755' MD; Shot Density: 6ft; Number: 60; 028"; Date: 3/16/22 6,403'5-1/2" SIZE DEPTH SET (MD) TUBING RECORD t each interval open (MD/TVD of Top and Bottom; Perforation Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7,033' PACKER SET (MD/TVD) Liner: 8,277'L-80 Packer: 7,033L-80 6,430'OCOCP-110 3,164'12 1/4"OCL-80 AMOUNT PULLEDBOTTOMCEMENTINGRECORDSETTING DEPTH TVD HOLE SIZETOPTOP SETTING DEPTH MD BOTTOM WT.PER FT.GRADE CASING, LINER AND CEMENTING RECORD Obtained: on, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log,spontaneous potential,gamma ray, esistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation Acronyms may be used. Attach a separate page if necessary Quad Combo: GR/RES/NEU/DEN; Sonic Scanner_CBL-VDL-MSIP; GR_HNGS-CAL; Cement Bond Log_USIT-CBL-VDL 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, onal or Inclination Survey: Yes (a(((((((ttached) No 13. Water Depth, if Offshore:21. Re-drill/Lateral Top Window MD/TVD: t electronic information per 20 AAC 25.050 (ft MSL) on 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: th: x-y- Zone- 469 81 92 y-y- 1385'81 66 09 Pending8450' / 8,448.90' on of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: oductive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 210' BF: th: 10. Plug Back Depth MD/TVD: 18. Property Designation: Exploration456.2’ FSL, 2,388.9’’ FWL, S32 T7N R11E UM 2/8/2022 8376' / 8,374.8' Theta West #1 ADL 394039 444.4’ FSL, 2,448.1’ FWL, S32 T7N R11E UM s: 7. Date Spudded: 15. API Number: 1/22/2022ic Blvd., Ste 2324, Anchorage, AK 99503 50-223-20036-00-00 or Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number / Sundry: Aband.:4/16/2022ar Pantheon, LLC 221-106; 322-155; 322-113; 322-088 Status:OilSPLUG OtherAbandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory WINJ WDSPLNo. of Completions: _____________________ Service Stratigraphic Test Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 3:35 pm, Jun 16, 2022 Abandoned 4/16/2022 MDG RBDMS 6/16/2022 MDG GCDW 04/25/2024 SFD 8/3/2022 DSR-10/25/22VTL 4/23/2024 Conventional Core(s) Yes No Sidewall Cores: 30. MD TVD 580' 340' 700' 460' 1,318' 1,078' 3,451' 3,211' 3,802' 3,562' 4,323' 4,083' 5,431' 5,191' T. SMD / K-10 5,610' 5,370' T. Hue Shale tongue 7,083' 6,843' 7,141' 6,901' 7,216' 6,976' T. Lower Fan 7,432' 7,192' Canning Formation 7,915' 7,914' 8,032' 7,792' Seabee/Torok undifferentiated:8,450' 8,448' 31. List of Attachments: Surface Abandonment 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Michael Duncan Contact Name: Michael Duncan COO Contact Email:michael@greatbearpetro.com Authorized Contact Phone:817.240.3865 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. INSTRUCTIONS Authorized Title: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. FORMATION TESTS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. MFS / Dkr D/ Middle Schrader T. Upper Schrader Bluff T. Upper Submarine Fan T. Canning Fm. T. Torok (?) Base of Permafrost: T. West Sak If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME T. Sagavanirktok T. Ugnu 29. GEOLOGIC MARKERS (List all formations and markers encountered): Theta West Basin Floor Fan On March 8th, the Basin Floor Fan formation was perforated from 8065’-8075’ with 2 ½” HSD charges at 6 SPF and 60 deg phasing. A single stage frac stimulation job pumped 78,485 gals of YF120FlexD fluid, 198,547 lbs of 40/70 White proppant, & 45,984 lbs of 20/40 CarboLite proppant into this interval. The well was then shut in & prepared at surface for Wireline operations on the 2nd interval within the Basin Floor Fan. On March 16th a composite frac plug was set at 7900’ and the 2nd interval within the Basin Floor Fan was perforated from 7745’-7755’with 2 1/2’ HSD charges at 6 SPF and 60 deg phasing. A single stage frac stimulation job pumped 67,230 gals of YF115FlexD fluid, 143,297 lbs of 40/70 White proppant, & 71,388 lbs of 20/40 CarboLite proppant into this interval. The well was then shut in & prepared at surface for Wireline operations on the 3rd interval within the Basin Floor Fan. On March 17th, a composite frac plug was set at 7700’ and 3rd interval within the Basin Floor Fan formation was perforated from 7595’-7605’ with 2 1/2’ HSD charges at 6 SPF and 60 deg phasing. A final single stage frac stimulation job pumped 70,501 gals of YF115FlexD fluid, 280,935 lbs of 40/70 White proppant into this interval. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. B. Upper Submarine Fan/ T. TPI (Top of Producing Interval). Authorized Name: No. 22. Logs Obtained; No. 30: Formation Tests; Daily Operations; Completion Reports; Frac Treatment Reports; Surveys; Wellbore Schematics; The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Signature w/Date: Well tested? Yes NoTVD 30.FORMATION TESTSs encountered) ), and summarize lithology and presence of oil, gas or wate otographs, and all subsequent laboratory analytical results No Sidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 2022.06.09 13:20:00 -08'00' Top of productive interval: 7,500' 7,549' 22 Theta West Type of Log Depth Start Stop Format LWD Logs End of Well Letter pdf End of Well Report pdf FinalDefinitiveSurvey PvA - Letter Plot - Theta West #1 ASP Final Survey pdf Theta West #1 ASP Final Definitive Survey Signoff SLB Signed pdf Theta West 1 ASP Final Survey NAD27 excel Theta West 1 ASP Final Survey NAD27_Signed pdf PrintSurvey Print Survey List pdf Print Survey List excel DrillingMechanicsDepth Theta West 1_DM_Depth_350-8450ft RM 350' - 8,450' 2/8/2022 LAS Theta West 1_DM_Depth_Run01 350' - 3,050' 1/22/2022 1/25/2022 pdf Theta West 1_DM_Depth_Run02 3,050' - 7,470' 1/28/2022 2/5/2022 pdf Theta West 1_DM_Depth_Run03 7,470' - 8,450' 2/6/2022 2/8/2022 pdf DrillingMechanicsTime Theta West 1_DM_Time_RM 194' - 8,450' 2/8/2022 LAS Theta West 1_DM_Time_Run01 1/22/2022 1/25/2022 pdf Theta West 1_DM_Time_Run02 1/28/2022 2/5/2022 pdf Theta West 1_DM_Time_Run03 2/6/2022 2/8/2022 pdf Vision_RM Theta West 1_VISION Service_350-8450ft 350'-8,450' DLIS Theta West 1_VISION Service_350-8450ft RM 350'-8,450' 2/8/2022 LAS Theta West 1_VISION_Service_2MD_8450ft_RM 350'-8,450' 1/22/2022 2/8/2022 pdf Theta West 1_VISION_Service_2TVD_8450ft_RM 350'-8,450' 1/22/2022 2/8/2022 pdf Theta West 1_VISION_Service_5MD_8450ft_RM 350'-8,450' 1/22/2022 2/8/2022 pdf Theta West 1_VISION_Service_5TVD_8450ft_RM 350'-8,450' 1/22/2022 2/8/2022 pdf Wireline-Electric Logs Cased Hole Logs Great_Bear_Theta West_Run_1_HNGS-USIT- CBL_MainLog_22-Feb-2022 DLIS Great_Bear_Theta West_Run_1_HNGS-USIT- CBL_RepeatPass_22-Feb-2022 DLIS Great_Bear_Theta West_Run_2__MSIP-USIT-CBL- VDL_MainLog_27-Feb-2022 (2)DLIS Great_Bear_Theta West_Run_2_MSIP-USIT-CBL- VDL_RepeatPass_27-Feb-2022 DLIS Great_Bear_Theta_West_Run_1_Spectral_Gamma_ Ray_Field_Print_22-Feb-2022 5,365' - 8,282' 2/23/2022 2/23/2022 pdf Logs Obtained 22 Logs Obtained Great_Bear_Theta_West_Run_2_Sonic_Scanner_Fi eld_Print_27-Feb-2022 4,442' - 7,751 2/28/2022 2/28/2022 pdf CementBondLog Great_Bear_Theta West_Run_1_Cement_Bond_Log_Field_Print_22- Feb-2022 5,365' - 8,282 2/23/2022 2/23/2022 pdf Great_Bear_Theta West_Run_2_Cement_Bond_Log_Field_Print_27- Feb-2022 4,442' - 7,751 2/28/2022 2/28/2022 pdf Mud Logs Theta West Final Well Report pdf Theta west 1_Depth LAS_346-8450 ft 346' - 8,450' 2/8/2022 LAS Theta West 1_Drilling Log 5 inch_02102022 346' - 8,450' 2/10/2022 pdf Theta West 1_Master Log 5 inch_02102022 346' - 8,450' 2/10/2022 pdf 30 FORMATION TESTS The well was then shut in & prepared at surface for Coiled Tubing operations to test the whole Basin Floor Fan interval. On March 19th, 2” Coiled tubing was rigged up and inserted into the well with a mill & motor to drill out composite frac plugs and clean out the well to a depth of 8075’. Once cleaned out, Coiled Tubing retreated to a depth of 5500’ & prepare for nitrogen lift. Halliburton N2 was rigged up to SLB Coiled Tubing & the well was opened to the well test manifold on a 26/64” choke. Nitrogen lift was started at 400 scf/min & was kept at 400 scf/min over the course of the test. On March 19th at 7:30 pm, the well was flowing at 1200 psi on a 14/64” adjustable choke with 400 scf/min N2 lift & delivering 3700 bwpd. Over the course of the test, from 3/19/22 to 3/22/22, the choke size was increased to 128/64”, FTP dropped from 1200 psi to 123 psi, and recovery rate fell from 3700 bwpd to 480 bwpd. The test for the Basin Floor formation was ended at 10:30 am on 3/22/22 with the well producing 99 bbls of 36.7 API oil at a maximum rate of 148 bopd and 366 mscf of 0.84 gravity gas. Total test time was 87 consecutive hours and total fluid recovered was 4294 bbls. 0 10 0 0 50 0 25 0 Fe e t 9 J u n e 2 0 2 2 Jo e A l s t o n - 1 o f 1 - Gr e a t B e a r P A N T H E O N Th e t a W e s t # 1 Su r f a c e a n d B H L SE C T I O N 3 2 , T 7 N , R 1 1 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 50 0 75 0 10 0 0 Sc a l e 31 33 5 29 30 28 6 4 32 Th e t a W e s t # 1 Su r f a c e 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 U D E ( D D ) LO N G I T U D E ( D D ) Su r f a c e x = 5 6 9 , 8 6 1 . 1 9 y = 5 , 8 1 7 , 6 3 7 . 7 5 69 . 9 1 2 1 0 7 2 ° 14 9 . 4 4 4 6 7 6 0 ° TH E T A W E S T # 1 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 BH L x = 5 6 9 , 7 8 1 . 9 2 y = 5 , 8 1 7 , 6 6 7 . 0 8 69 . 9 1 2 1 8 9 3 ° 14 9 . 4 4 5 3 0 3 9 ° 24 4 8 F T F. W . L . 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 SW C o r n e r x = 5 6 7 , 4 1 3 . 2 9 y = 5 , 8 1 7 , 1 7 1 . 8 1 Se c t i o n 3 2 , T 7 N R 1 1 E Co r n e r C a l l 46 6 F T F. S . L . SECTION 6. WELLBORE SCHEMATIC SECTION 6a. WELLBORE SCHEMATIC THETA WEST Complete BFF Interval ThetaWestͲWellboreSchematicͲCompleteBFFInterval ConductorHole ConductorPipe xxxxxx xxxxxxxxxxxxx Depth SurfaceHole SurfaceCasing Grade Connection 40 lb/ft PFDepth ProductionCasing Weight 5.5" lb/ft Grade:L80 HueShaleͲBottom@7420' BFF#1Perfs:7595'Ͳ7605' FracPlug@7685' BFF#2Perfs:7745'Ͳ7755' BFFPerfs(6spf;60degphase;0.36"EHD) FracPlug@8005' BFF#1Perfs:8065'Ͳ8075' HRZShaleͲTop@8410'PBTDͲ8376' TDͲ8450' 3.5"LinerWeight:9.2lb/ft PackerTopͲ7026' LinerTopͲ7033' PackerBottomͲ7033' LinerEndͲ8277' Grade TOC 17 PͲ110 6430' BTC TOC Depth Surface 3164' ~1500' LͲ80 Weight 121/4" 95/8" TOC PF PF Surface 75' Weight 28" 20" 129lb/ft SECTION 6b. WELLBORE SCHEMATIC THETA WEST Final P&A ThetaWestͲWellboreSchematicͲFinalP&A *Diagramsarenottoscale* Cementplug:200'toSurface ConductorHole ConductorPipe xxxxxx xxxxxxxxxxxxx Depth Cementplug:3064'(calc)'Ͳ3264'(6bbls) SurfaceHole SurfaceCasing Grade Connection 40 lb/ft PFDepth ProductionCasing Weight 5.5" lb/ft Grade:L80 Cementplug:6876'(calc)'Ͳ7545'(13bbls) CIBPͲ7545' HueShaleͲBottom@7420' BFF#1Perfs:7595'Ͳ7605' FracPlug@7685' BFF#2Perfs:7745'Ͳ7755' BFFPerfs(6spf;60degphase;0.36"EHD) FracPlug@8005' BFF#1Perfs:8065'Ͳ8075' HRZShaleͲTop@8410' Weight 28" 20" 129lb/ft TOC PF PF Surface 75' Weight Depth Surface 3164' PBTDͲ8376' XXXX 121/4" 95/8" LͲ80 BTC TOC 3.5"LinerWeight:9.2lb/ft PackerTopͲ7026' LinerTopͲ7033' PackerBottomͲ7033' LinerEndͲ8277' Grade TOC 17 PͲ110 ~1500' Casing&95/8"Annulus TDͲ8450' 6430' SECTION 2. Daily Drilling Reports 1 Phone 1 1.17.22 Phone 2 Tool Pusher (N): 5 API No: PTD: Field: ft ft 30.3 P.B.T.D.: From To Hrs 6:00 17:00 11:00 2 17:00 6:00 13:00 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 14 19 Rig: 14 20 Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith (907) 529-0737 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/17/22 6:00 AM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: 1/10/22 Actual Depth: 75'Last Evac Drill: NA Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Perform rig maintenande on pad, Cleaning pits, waiting on conductor and cellar to be installed.Phase: 0 Wind Speed: 5 to 10 24 hour Summary:Release F/ Talitha well @ 05:00, Move rig down ice road to Theta West drill site. Weather Gen Conditions: Fair Shoe Test: N/A HSE Events:None, IFO PM Temp: -27 Operational Details (06:00 - 06:00) Continue moving rig 1 mile F/Talitha location - T/Theta West location 24 hour Forecast:Set conductor, install cellar, move rig over well, rig up rig, rig up diverter, function test Wind Direction: W AM Temp: -24 Set down rig on pad continue to clean pits, perform rig maintenance as conductor and cellar not set. Unload 1 trailer of 7" casing. Cleaning Nordic cuttings box. *Conductor auger drill and crane unable to work due to cold -40 temps. Installing coms in camp Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available 44 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 45 Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment Total Length (ft): 0.00 2 Phone 1 1.18.22 Phone 2 Tool Pusher (N): API No: PTD: Field: ft ft P.B.T.D.: From To Hrs 6:00 18:00 12:00 2 18:00 6:00 12:00 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 14 19 Rig: 14 20 Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 AZ.Item Comment Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 45 Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 44 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Perform rig maintenance on pad, Cleaning pits, Checking pipe handling equipment slips, elevators, rig tongs, collar slips, dog collar clamp. Thourough top drive service. Load 105 joints of 4" 15.7# XT-39, rabbit, strap, tally in pipe shed. Continue to clean trough under augur.Adjust top drive torque, set to 17,500 ft/lbs. * Diverter test Witness notifications sent 1/17/2022 @ 13:20 HSE Events:None, IFO PM Temp: -17 Operational Details (06:00 - 06:00) Drill and set conductor,Rig doing Preventitive maintenance , Cleaning pits, 24 hour Forecast:Install cellar, move rig over well, Rig up diverter, function test. Wind Direction: W AM Temp: -20 Ops @ 06:00 hrs: Perform rig maintenance on pad, Cleaning pits.Phase: 0 Wind Speed: 10 t0 15 24 hour Summary:Rigging up. Weather Gen Conditions: Fair Shoe Test: N/A 1/10/22 Actual Depth: 75'Last Evac Drill: NA Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/17/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: Supervisor (N): Paul Smith / Robert Wall (907) 529-0737 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 3 Phone 1 1.19.22 Phone 2 Tool Pusher (N): API No: PTD: Field: ft ft P.B.T.D.: From To Hrs 6:00 12:00 6:00 2 12:00 18:00 6:00 2 18:00 24:00 6:00 2 24:00 6:00 6:00 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 14 19 Rig: 14 20 Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Robert Wall (907) 398-9191 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/18/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: 1/10/22 Actual Depth: 75'Last Evac Drill: NA Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Load 18jts 4" HWDP for spud. Check all pressures in tires for move.Phase: 0 Wind Speed: 10 to 15 24 hour Summary:Pick up 3 stands of 4" XT39 DP and stand back. Remove workover cuttings chute. Install drilling cuttings chute. Weather Gen Conditions: Breezy, clear Shoe Test: N/A HSE Events:No incidents, accidents, or spills. PM Temp: -17 Operational Details (06:00 - 06:00) Prepare handling equipment to pick up stands of 4" XT 39 and rack back in derrick. Clean pit #1, and trough. Stand back 5 stands, 473.77'. Electrician serviced all gaitronic phone sets. 24 hour Forecast:Install corrugated cellar box , move rig over well, Rig up diverter, function test. Wind Direction: W AM Temp: -20 Complete picking up 3313.48' of 4" XT 39 DP. 35 stands total. Loader operator staging equipment from Talitha to Theta. Ongoing operation of clearing solids from cuttings chute. Service lo torque floor valves, warm up moving system, and rolling tires. Remove workover cuttings chute, and lay down using manlift and loader. Complete cleaning augur chute. Downward pressure mechanism failed on Watson boring machine. Conductor 20" pipe installed and cemented, 80 feet in length. Cellar box excavation delayed. Machine departed to Deadhorse. Begin to install Y shape drilling cuttings chute using manlift and loader. * Diverter test Witness notifications sent 1/17/2022 @ 13:20, and updated via email 18:00 hrs 1.18.22. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available 44 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 45 Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment Total Length (ft): 0.00 4 Phone 1 1.20.22 Phone 2 Tool Pusher (N): 37 API No: PTD: Field: ft ft 30.0 P.B.T.D.: From To Hrs 6:00 12:00 6:00 2 12:00 18:00 6:00 2 18:00 24:00 6:00 2 24:00 6:00 6:00 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 14 19 Rig: 14 20 Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 96 1 2 Triplex 5.5 60 96 2 MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 AZ.Item Comment Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 45 Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 44 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Complete install of SLB transducer. MWD tools loaded in pipe shed. Rig received 62 bbls water. Circulate 45 bbls pit to pit, test all valves.Good. Keep moving system hydraulics warm, roll tires. Electrician serviced SCR #2. Lay out herculite for rig foot print. Position initial T rig mats for sub base around cellar. Follow with row of 40 foot mats for rig module. Place transition for walking rig up on mats, use 2 x 12's, and 3 x 12's. With welders measure 11" below top of rig mat for conductor cut off. Level and install load ring. Preheat to 250°, fillet weld load ring. Post heat to 900°, wrap load rig. SIMOPS: Rig prepared for move. PJSM, move rig to line up and center over 20" conductor. Installed 4" nipples in cellar for cement job. Rig in place and level. * Diverter test Witness notifications sent 1/17/2022 @ 13:20. AOGCC Inspector Adam Earl will witness test. Two hour notice to be provided. HSE Events:No incidents, accidents, or spills. PM Temp: -25 Operational Details (06:00 - 06:00) Complete installation of Magtec Y shape cuttings chute.Install Schlumberger goose neck transducer in derrick. 24 hour Forecast:Nipple up diverter spool, and install diverter line. Complete rig acceptance check list. Build spud mud. Test knife valve and bag. Flood conductor. Pick up BHA#1, spud well. Wind Direction: NE AM Temp: -33 Ops @ 06:00 hrs: Nordic Rig 3 centered over Theta West #1. Phase: 0 Wind Speed: 10 to 15 24 hour Summary: Complete install of "Y" cuttings chute for drilling. Load SLB MWD tools in pipe shed. Load 62 BBLs rig water, tranfer between pits to verify all valves are good. Load inventory of shaker screens into pits. Install cellar box, cut off at ground level. Dump 10 BBLs water in cellar. PJSM, lay out rig footprint of herculite for rig move around cellar area. Cut off conductor 11" below top of rig mat. Weld on load ring. Post heat to 900°, wrap. PJSM. Move rig, center over well. Weather Gen Conditions: Breezy, clear Shoe Test: N/A 1/10/22 Actual Depth: 75'Last Evac Drill: NA Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/19/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: Supervisor (N): Robert Wall (907) 398-9191 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 5 Phone 1 1.21.22 Phone 2 Tool Pusher (N): 37 API No: PTD: Field: ft ft 30.0 P.B.T.D.: From To Hrs 6:00 12:00 6:00 2 12:00 18:00 6:00 2 18:00 1:30 7:30 2 1:30 6:00 4:30 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 23:30 0 8.7 14 25 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 96 1 2 Triplex 5.5 60 96 2 MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 AZ.Item Comment Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 74 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Stack up diverter T spacer spool, knife valve and hydril. 21¼" 2K. Mix spud mud. Nipple up spool, hydril, knife valve to 85 feet of 16" diverter line. AOGCC Inspector Adam Earl witnessed diverter test, gas alarms, flow sensor. Annular closed 25 secs, knife valve opened in 10 secs. Koomey: 2900 system / after 1475 / 200 psi recharge 30 secs / 157 secs to full pressure. No failures. Changed out quick connects to knife valve. Adjusted diverter line to orient tattle straight down. Chain down jersey barriers to diverter line. Off load tripple silo for cement job. Install 4" ball valves on nipples in cellar. Spot MWD unit, welders shop. Load DD tools in pipe shed. Center stack. Install riser. Flood stack. PJSM for spud. * Diverter test Witness notifications sent 1/17/2022 @ 13:20. AOGCC Inspector Adam Earl witnessed test. No failures. HSE Events:No incidents, accidents, or spills. PM Temp: -35 Operational Details (06:00 - 06:00) Rig move. Rig leveled with timbers and plywood. Spill containment berms constructed. Build 250 bbls of fresh water spud mud. Place diverter T spacer in cellar, position knife valve in cellar. Prepare to nipple up hydrill. 24 hour Forecast:Flood stack. Pick up BHA. Hole diverter drill with crew. Spud well. Wind Direction: W AM Temp: -40 Ops @ 06:00 hrs: PJSM for P/U BHA.Phase: 0 Wind Speed: 5 to 10 24 hour Summary: Nipple up 21¼" hydril, diverter line, mix 370 bbls of 8.7 ppg water based gel spud mud. Spot MWD unit, tripple silos, welders shop, off load surface casing 9 5/8" 40# L-80. AOGCC witnessed diverter test, and draw down. No failures. Center stack with chain binders. Install riser. Weather Gen Conditions:Scattered clouds, light wind fr the W. Shoe Test: N/A 1/10/22 Actual Depth: 75'Last Evac Drill: NA Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/20/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.21.22 KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: Supervisor (N): Robert Wall (907) 398-9191 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 6 Phone 1 1.22.22 Phone 2 Tool Pusher (N): 37 API No: PTD: Field: 345 ft 235 ft 30.0 P.B.T.D.: From To Hrs 6:00 12:00 6:00 2 12:00 18:00 6:00 22 18:00 24:00 6:00 22 0:00 6:00 6:00 22 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1 12¼ Kymera 110 345 235 3 78 55 3x12 3x16 0.920 1RR 12¼ Kymera 345 3x12 3x16 0.920 Time Depth MW PV YP Mud Gas Readings:Used 23:30 0 9.2 30 25 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 96 1 2 Triplex 5.5 60 96 2 MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Robert Wall (907) 398-9191 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.21.22 NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/21/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: 1.21.22 Actual Depth: 75'Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Trip to bottom @ 229' MD.Phase: 0 Wind Speed: 5 mph 24 hour Summary:Pick up BHA#1, drill to 345'. POOH. Switch rig tongs. Rack back 3 stands HWDP. Pick up BHA#2. Rerun bit #1, mud motor, MWD tools, load sources. Relocate cement tripple silo. Ream last stand to bottom. Weather Gen Conditions:Scattered clouds, light wind fr the W. Shoe Test: N/A HSE Events:No incidents, accidents, or spills. PM Temp: -35 Operational Details (06:00 - 06:00) Rig up trip tank hose, secure diverter line to the second set of barriers with chain. Thaw out bleeder line, inflate boots on riser.Put away all tools in cellar from nipple up. Cellar secure and warm. Fill stack with 44.4 bbls of spud mud, no leaks. Pick up mud motor. Continue to build spud mud . 24 hour Forecast:Drill ahead with BHA#2 Wind Direction: W AM Temp: -30 Make up BHA #1. Kymera hybrid 12¼" bit w/ .92 TFA, 1.15° bend mud motor, XO to 4" 29# HWDP. Tag bottom @ 110'. Verify 80 foot conductor, and 30' RKB. Drill from 110' to 345'. 50 rpm / 5-10k wob / 7k on bottom TQ / 3k off bottom TQ / 400 gpm / 700 PP. Mostly clay seen on shakers. Flow check. POOH to mud motor. Change out rig tongs from 1200 Foleys to 1500 Foleys. Bring SLB radioactive sources to rig floor, mud filter pony collar, jars. Pick up HWDP to stand back. Adjust rig tongs, (not properly assembled), Build stands of the remaining 4" HWDP rack back. PJSM on picking up BHA#2. Make up BHA#2. RR bit #1, 12¼" hybrid, MM, Gamma Res tool, Directional module, Neutron density tool, filter pony collar, XO to 3 slick monels 6¾" OD, XO to HWDP. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 5310888 1-1-WT-A-E-I-NO- BHA Total Hours 24:00 Comments: Vis 0 Available 150 Background (Avg) % 0 5310888 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment Total Length (ft): 0.00 7 Phone 1 1.23.22 Phone 2 Tool Pusher (N): 37 API No: PTD: Field: 1,593 ft 240 AMSL 1,483 ft 1 30.0 P.B.T.D.: From To Hrs 6:00 12:00 6:00 2 12:00 14:30 2:30 2 14:30 16:30 2:00 2 16:30 21:30 5:00 2 21:30 23:00 1:30 2 23:00 6:00 7:00 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1 12¼ Kymera 110 345 235 3 78 55 3x12 3x16 0.920 1RR 12¼ Kymera 345 3x12 3x16 0.920 Time Depth MW PV YP Mud Gas Readings:Used 3:00 1490 9.4 14 21 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 74 96 210 1250 1 2 Triplex 5.5 74 96 210 1250 2 MD TVD Inc.OD ID Conn. Length 30 30.00 0.0 8.25 6 6 5-8 R 29.79 264 264.00 0.3 12.125 2.5 6 5/8 R 7.16 336 336.00 0.4 8.25 2.5 6 5/8 R 19.42 426 426.00 0.5 12.125 2.5 6 5/8 R 4.18 516 516.00 0.4 8.25 5 6 5/8 FH 27.72 607 607.00 0.4 8.25 4 6 5/8 R 29.72 700 700.00 0.3 8.25 3 6 5/8 R 9.87 728 728.00 0.4 8.25 3 6 5/8 R 8.08 818 818.00 0.3 8 3 NC 50 3.34 941 941.00 0.2 6.75 2.813 NC 50 150.50 1039 1039.00 0.5 1.14 2.813 XT 39 1.14 1134 1134.00 0.5 4 3.24 XT 39 484.11 1229 1229.00 0.6 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Total Length (ft): 926.96 283.39 Jars / Weatherford Mech 4 jts 4" XT 39 HW 5 ea- 6¾" slick monels 264.41 XO 262.2 16 jts 4" XT 39 HW 322.04 Filter sub 284.54 Bottleneck XO 247.55 322.39 SADN, Neutron Density 326.94 NM Pony collar 348.07 In line NM Stab 352.34 Telescope 219.43 NM Stab 2.01 Arc vision AZ.Item Comment 219.43 Mud motor. 7/8 1.15° Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 69 Background (Avg) % 0 5310888 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 5310888 1-1-WT-A-E-I-NO- BHA Total Hours 24:00 Comments: Drill from 746' to 928', 70 RPM, 10K WOB, 400 GPM, 1050 PP, 75K UP and DN weight. TQ on bottom 8K, TQ off bottom 5K. Out drill ability to haul cuttings to Pad 4. Dragon boxes full. Work pipe while waiting on cuttings boxes to return from Prudhoe. Drill from 928' to 1211', 70 RPM, 10K WOB, 420 GPM, 1160 PP, 75K UP and DN weight. TQ on bottom 8K, TQ off bottom 5K. Work pipe, rotate and reciprocate full stand 40 RPM, 420 GPM, 1100 PP. Weight up mud system to 9.3 PPG before drilling ahead. Resume drilling. Drill from 1211' to 1593'. 10K WOB, 100 RPM, 480 GPM, 1520 PP, 85K UP, 90K DN, 84 ROT weights, 8.5k TQ on, 7K TQ off. HSE Events:No incidents, accidents, or spills. PM Temp: -20 Operational Details (06:00 - 06:00) Break circulation @ 200 GPM, 320 PP, Warm mud, and break gel strengths to avoid losses over the shakers. Gradually stage pumps up to 400 GPM. Wash down to 320' MD. Make connection on first stand of HWDP. Drill 12¼" hole from 345' to 746'. 75 RPM, 5k WOB, 12 to15k WOB, 800 PP, 70k UP weight, 70k DN weight. 24 hour Forecast:Drill 12¼" Surface hole. Wind Direction: SW AM Temp: -15 Ops @ 06:00 hrs: Drilling @ 1593'.Phase: 0 Wind Speed: 5 mph 24 hour Summary:Drill 12¼" Surface hole from 435' to 1593'. Weather Gen Conditions:Scattered clouds, light wind fr the W. Shoe Test: N/A 1.21.22 Actual Depth: 80'Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/21/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.21.22 KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: Supervisor (N): Robert Wall (907) 398-9191 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 8 Phone 1 1.24.22 Phone 2 Tool Pusher (N): 37 API No: PTD: Field: 2,626 ft 41 240 AMSL 2,516 ft 2 30.0 P.B.T.D.: From To Hrs 6:00 11:00 5:00 2 11:00 16:30 5:30 2 16:30 17:30 1:00 2 17:30 19:00 1:30 2 19:00 22:00 3:00 2 22:00 23:30 1:30 2 23:30 6:00 6:30 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1 12¼ Kymera 110 345 235 3 78 55 3x12 3x16 0.920 1RR 12¼ Kymera 345 3x12 3x16 0.920 Time Depth MW PV YP Mud Gas Readings:Used 3:00 2343 9.5+ 14 21 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 74 96 210 1250 1 2 Triplex 5.5 74 96 210 1250 2 MD TVD Inc.OD ID Conn. Length 1325 1325.00 0.7 8.25 6 6 5-8 R 29.79 1419 14196.00 0.9 12.125 2.5 6 5/8 R 7.16 1513 1513.00 0.7 8.25 2.5 6 5/8 R 19.42 1608 1608.00 0.6 12.125 2.5 6 5/8 R 4.18 1705 1705.00 0.4 8.25 5 6 5/8 FH 27.72 1797 1797.00 0.6 8.25 4 6 5/8 R 29.72 1889 1889.00 0.5 8.25 3 6 5/8 R 9.87 1982 1982.00 0.3 8.25 3 6 5/8 R 8.08 2079 2079.00 0.3 8 3 NC 50 3.34 2176 2176.00 0.3 6.75 2.813 NC 50 150.50 2244 2244.00 0.1 1.14 2.813 XT 39 1.14 2370 2370.00 0.2 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Robert Wall (907) 398-9191 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.21.22 NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/23/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: 1.21.22 Actual Depth: 80'Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Drilling @ 2626'.Phase: 0 Wind Speed: 5 mph 24 hour Summary:Drill 12¼" Surface hole 1593' to 2626' Weather Gen Conditions: Scattered clouds, light wind fr the NE, cooling trend. Shoe Test: N/A HSE Events:No incidents, accidents, or spills. PM Temp: -10 Operational Details (06:00 - 06:00) Drill from 1593' to 1874'. 10K WOB, 100 RPM, 480 GPM, 1520 PP, 90K UP, 90K DN, 90 ROT weights, 8.5k TQ on, 7K TQ off. Stap and tally 9.625" casing. 90 joints in the shed. Drifted with 8.61" drift. 24 hour Forecast:Drill 12¼" Surface hole. TD CBU 2 x's. POOH on elevators. Wind Direction: NE AM Temp: -5 Lubricate, service top drive, Change out belts on auger. Pump 50 GPM, Rotate 30 RPM, work pipe slowly. Service draw works. Cuttings boxes all full, wait on trucks to return from G&I. Change out #2 charge pump belts. Drill from 1874' to 1940. 10K WOB, 100 RPM, 480 GPM, 1520 PP, 90K UP, 90K DN, 90 ROT weights, 8.5k TQ on, 7K TQ off. Thaw out auger chute, change out dragon box. Pump 50 GPM, Rotate 30 RPM, 200 PP, work pipe slowly. Drill from 1940' to 2125'. 10K WOB, 100 RPM, 480 GPM, 1900 PP, 90K UP, 90K DN, 90 ROT weights, 8.5k TQ on, 7K TQ off. Change out dragon boxes, found other chute now frozen, thaw out second side, circ,100 GPM, 30 RPM. Drill from 2125' to 2626' . 5 to 20K WOB, 100 RPM, 500 GPM, 1950 PP, 95K UP, 100K DN, 95 ROT weights, 9.5k TQ on, 5.5K TQ off. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 5310888 1-1-WT-A-E-I-NO- BHA Total Hours 24:00 Comments: Vis 0 Available 100 Background (Avg) % 0 5310888 Mud Properties Gas Details Fuel Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 283.2 Mud motor. 7/8 1.15° Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 276.63 In line NM Stab 286.04 Telescope 277.83 NM Stab 288.28 Arc vision 303.17 Filter sub 255.5 Bottleneck XO 286.77 SADN, Neutron Density 291.4 NM Pony collar 212.34 16 jts 4" XT 39 HW Jars / Weatherford Mech 231.7 5 ea- 6¾" slick monels 261.15 XO Total Length (ft): 926.96 4 jts 4" XT 39 HW 9 Phone 1 1.25.22 Phone 2 Tool Pusher (N): 37 API No: PTD: Field: 3,050 ft 41 212 AMSL 424 ft 3 30.0 P.B.T.D.: From To Hrs 6:00 13:30 7:30 2 13:30 15:00 1:30 5 15:00 19:00 4:00 6B.01 19:00 21:00 2:00 6B.01 21:00 21:30 0:30 22 21:30 22:30 1:00 6J 22:30 2:00 3:30 6B.01 2:00 3:00 1:00 22 3:00 6:00 3:00 22 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1 12¼ Kymera 110 345 235 3 78 55 3x12 3x16 0.920 1RR 12¼ Kymera 345 3050 2705 3x12 3x16 0.920 Time Depth MW PV YP Mud Gas Readings:Used 3:00 3050 9.7 14 21 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 74 96 210 1250 1 2 Triplex 5.5 74 96 210 1250 2 MD TVD Inc.OD ID Conn. Length 2364 2364.00 0.1 8.25 6 6 5-8 R 29.79 2463 2463.00 0.3 12.125 2.5 6 5/8 R 7.16 2551 2551.00 0.3 8.25 2.5 6 5/8 R 19.42 2647 2647.00 0.2 12.125 2.5 6 5/8 R 4.18 2742 2742.00 0.3 8.25 5 6 5/8 FH 27.72 2839 2839.00 0.4 8.25 4 6 5/8 R 29.72 2931 2931.00 0.3 8.25 3 6 5/8 R 9.87 8.25 3 6 5/8 R 8.08 8 3 NC 50 3.34 6.75 2.813 NC 50 150.50 1.14 2.813 XT 39 1.14 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Total Length (ft): 926.96 4 jts 4" XT 39 HW 16 jts 4" XT 39 HW Jars / Weatherford Mech 5 ea- 6¾" slick monels XO Filter sub Bottleneck XO 226.12 SADN, Neutron Density 267.18 NM Pony collar 227.78 In line NM Stab 273.04 Telescope 242.31 NM Stab 267.53 Arc vision AZ.Item Comment 325.39 Mud motor. 7/8 1.15° Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 120 Background (Avg) % 0 5310888 1-3-CT-S-X-1-BT-TD Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 5310888 1-1-WT-A-E-I-NO- BHA Total Hours 24:00 Comments: Clear all tools from BHA off rig floor, clean floor, remove floor mats. Rig up casing running equipment. CBU. Load landing joint, hanger, Volant casing running tool, 6' extensions and hand slips in pipe shed. Prepare to trip out of hole. Monitor well static. PJSM, Trip out of the hole on elevators from 3050' to 368'. Good hole fill, one tight spot @ 1260'. Pick up a joint of 4" for handling tool, stand back with 2 - 6¾" Monel DC's. Lay down pony collar. Bring false bowl to floor to lay down BHA. PJSM. Pull radioactive sources from MWD tools. Lay down remaining BHA components, drain motor, lay down motor with bit. HSE Events:No incidents, accidents, or spills. PM Temp: 4 Operational Details (06:00 - 06:00) Drill from 2626' to 3050'.TD. 15K WOB, 100 RPM, 485 GPM, 2050 PP, 100K UP, 100K DN, 100 ROT weights, 10k TQ on, 7K TQ off. Stap and tally 3 joint shoe track. Load 24 hour Forecast:Run casing to bottom. Rig up cementers pump cement. Wind Direction: NE AM Temp: 10 Ops @ 06:00 hrs: Rigging up to run casing. Phase: 0 Wind Speed: 15 24 hour Summary:Drill 12¼" Surface hole to 3050". Reach total depth. Weather Gen Conditions: Scattered clouds, light wind fr the NE, cooling trend. Shoe Test: N/A 1.21.22 Actual Depth: 80' 3,050 Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/24/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.21.22 KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Supervisor (N): Robert Wall (907) 398-9191 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 10 Phone 1 1.26.22 Phone 2 Tool Pusher (N): 68 API No: PTD: Field: 3,050 ft 41 212 AMSL 0ft 430.0 P.B.T.D.:30.5 From To Hrs 6:00 7:30 1:30 22 7:30 11:30 4:00 6.A.01 11:30 15:30 4:00 12 15:30 18:30 3:00 12 18:30 22:00 3:30 12 22:00 24:00 2:00 12 24:00 4:00 4:00 12 4:00 6:00 2:00 12 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1 12¼ Kymera 110 345 235 3 78 55 3x12 3x16 0.920 1RR 12¼ Kymera 345 3050 2705 3x12 3x16 0.920 Time Depth MW PV YP Mud Gas Readings:Used 3:00 3050 9.7 14 21 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 74 96 210 1250 1 2 Triplex 5.5 74 96 210 1250 2 MD TVD Inc.OD ID Conn. Length 2364 2364.00 0.1 8.25 6 6 5-8 R 29.79 2463 2463.00 0.3 12.125 2.5 6 5/8 R 7.16 2551 2551.00 0.3 8.25 2.5 6 5/8 R 19.42 2647 2647.00 0.2 12.125 2.5 6 5/8 R 4.18 2742 2742.00 0.3 8.25 5 6 5/8 FH 27.72 2839 2839.00 0.4 8.25 4 6 5/8 R 29.72 2931 2931.00 0.3 8.25 3 6 5/8 R 9.87 8.25 3 6 5/8 R 8.08 8 3 NC 50 3.34 6.75 2.813 NC 50 150.50 1.14 2.813 XT 39 1.14 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Total Length (ft): 926.96 4 jts 4" XT 39 HW 16 jts 4" XT 39 HW Jars / Weatherford Mech 5 ea- 6¾" slick monels XO Filter sub Bottleneck XO 226.12 SADN, Neutron Density 267.18 NM Pony collar 227.78 In line NM Stab 273.04 Telescope 242.31 NM Stab 267.53 Arc vision AZ.Item Comment 325.39 Mud motor. 7/8 1.15° Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 120 Background (Avg) % 0 5310888 1-3-CT-S-X-1-BT-TD Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 5310888 1-1-WT-A-E-I-NO- BHA Total Hours 24:00 Comments: Pump 40 BBLs 10# mud push, Drop bottom plug, SLB mixed and pumped 378 BBLS 10.7# Lead, 50 BBLS 15.7# Tail. Drop top plug, kick out with 10 BBLS water. Rig displaced @ 6 BPM. Run 9.625" L-80 LTC #40 casing, baker loc to pin end of #4. Perform float check, fil pipe on the fly. Torque to 7270 ft/lbs. Tag ledge @ 1477'. Work pipe and circulate. Work pipe, circulate tight spot F/1477' MD. -T/ 1,555' MD. Pump 1-3 BPM, 180-260 PP. Work joints # 34 and #35. Run casing, pumping 200 GPM, work past a large coal bed. 1955' MD. Run casing from 1955 to 3030. Washed down every other joint using the CRT. Pick up landing joint and hanger from shed. Remove running tool. Install seals on running tool. Thjread running tool back to LJ. Land hanger on load shoulder. Circulate through Volant CRT, stage up to 6 BPM. 350 PP, 11 % flow.Rig up cement hose to 1502 circulating port on CRT. Resume pumping. Pump air through outside cement line for cement truck. Attempt to clear, with steam, appears blocked. Rig up hose to cement truck. Hold PJSM in Doghouse with Cementers, Truck pusher, rig crew , mud man , Co Man. Pressure test lines to 1500 PSI low, 3700 HSE Events:No incidents, accidents, or spills. PM Temp: 4 Operational Details (06:00 - 06:00) Make up hanger to landing joint, make drift run with Cameron hand. Complete maitenance on casing elevators in welding shop, Lay dwon LJ and hanger. Rig up GBR tongs. PJSM. Run casing. 24 hour Forecast:Run casing to bottom. Circulate and condition the well. Rig up cementers pump cement. Wind Direction: NE AM Temp: 10 Ops @ 06:00 hrs: Phase: 0 Wind Speed: 15 24 hour Summary:Bring all casing running equipment to rig floor. Conduct 'dummy run' with landing joint to confirm distance from rig floor to load shoulder. Rig up GBR Volant CRT, tongs, run casing from surface to Weather Gen Conditions: Scattered clouds, light wind fr the NE, cooling trend. Shoe Test: N/A 1.21.22 Actual Depth: 80' 3,050 Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/26/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.21.22 KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Supervisor (N): Robert Wall (907) 398-9191 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 11 Phone 1 1.27.22 Phone 2 Tool Pusher (N): 68 API No: PTD: Field: 3,050 ft 41 212 AMSL 0ft 530.0 P.B.T.D.:30.5 From To Hrs 6:00 7:30 1:30 12 7:30 12:00 4:30 13 12:00 18:00 6:00 15 18:00 20:30 2:30 22 20:30 23:00 2:30 22 23:00 24:00 1:00 14 24:00 6:00 6:00 14 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 3:00 3030 9.7 15 20 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 96 1 2 Triplex 5.5 96 2 MD TVD Inc.OD ID Conn. Length 2931 2931.00 0.3 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Robert Wall (907) 398-9191 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.21.22 NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/26/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: 1.21.22 Actual Depth: 80' 3,050 Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Nippling up 13 5/8" 5K BOP stack.Phase: 0 Wind Speed: 10 to 15 24 hour Summary: Cement in place @ 07:15 hrs. 120 BBLS lead cement to surface. Took all returns to the cellar VIA the two installed 4" welded conductor outlets. Cement removal done by two 300 BBL vac trucks, followed by 2 Super sucker trucks. Of load all MWD tools used in surface, clean out cellar, nipple down diverter line, knife valve, 21¼" Hydril. Pull starter head, install Cameron well head spool. Nipple up Nordic 11" 5K BOP stack. Weather Gen Conditions:Clearing, scattered clouds. Shoe Test: N/A HSE Events:No incidents, accidents, or spills. PM Temp: -16 Operational Details (06:00 - 06:00) Drop top plug, SLB kicked out with 10 BBLs water, rig pumped 213.3 BBLs 9.7 ppg spud mud to bump plug on strokes. Pressure up to 1200 from FCP of 500. Held pressure for 5 minutes. Floats did not hold. Shut in well. CIP @ 07:15 24 hour Forecast:Nipple upflow line, riser. Test BOP's with AOGCC Inspector using 4" test joint. Pick up BHA#3. for 8½" hole section. Single in with drill pipe. Wind Direction: W AM Temp: -20 While holding pressure on floats: Clean up rig floor. Rig down cement hoses. Clean in cellar. Off load 300 BBLs spud mud to trucks for disposal. Lay down Volant CRT with GBR crew. Lay down landing joint. Complete rigging down diverter line. Open well @ 1300. No flow, cement set up. Rig down all GBR tools, keep power tongs on floor. Nipple down riser and bell nipple. Remove knife valve. Nipple down 21¼" Hydril. With loader and stinger lift annular and spool out of cellar. Nipple down starting head in cellar with Cameron hand, remove from cellar. Fix bogey tires on moving system. Clean shakers, and possum belly in pits. Remove 20 joints of 9.625" casing from ODS. Lay down remaining GBR casing equipment. Nipple up well head. Cameron 11" 5k. Test wellhead connection to 5000 psi for 10 mins. Good test. Witnessed by CoMan. Nipple up Nordic 13 5/8" 5k BOP stack. Hydril annular. Shaffer double gate. (VBR 2 7/8" x 5"), and a blind ram, Mud cross, Single gate Shaffer, (VBR 2 7/8 x 5"). Resume nipple up of BOP. Clean out suction and discharge screens in pumps. Change out one bogey tire on moving system. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available 58 Background (Avg) % 0 Mud Properties Gas Details Fuel Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 267.18 Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Total Length (ft): 0.00 12 Phone 1 1.28.22 Phone 2 Tool Pusher (N): 68 API No: PTD: Field: 3,050 ft 41 212 AMSL 0ft 630.0 P.B.T.D.:30.5 From To Hrs 6:00 12:00 6:00 14 12:00 14:00 2:00 15 14:00 21:00 7:00 15 21:00 24:00 3:00 22 24:00 4:00 4:00 22 4:00 6:00 2:00 22 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 2 8½ D505S 3050 7x11 0.650 Time Depth MW PV YP Mud Gas Readings:Used 3:00 3030 9.7 15 20 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 96 1 2 Triplex 5.5 96 2 MD TVD Inc.OD ID Conn. Length 2931 2931.00 0.3 8.5 3.25 4 1/2 R 0.85 6.375 3 NC 50 3.04 6.25 2.813 5 1/2 FH 2.99 6.75 2 5 1/2 FH 27.48 6.75 2.25 5 1/2 FH 6.10 6.75 5 NC 50 27.34 6.75 2.25 NC 50 5.10 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Total Length (ft): 870.69 Jars / Weatherford Mech 4 jts 4" XT 39 HW Bottle neckXO 16 jts 4" XT 39 HW 5 ea- 6¾" slick monels Filter sub Telescope 8 3/8" stab w/ float With ported float. Ecoscope w/ 8¼" stab. 8 3/8" ILS Bit sub XOS AZ.Item Comment 267.18 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 58 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments: Make up floor valves, pick up 4" test joint. Function all BOPE. Lower top drive and warm up. Fluid pack choke and kill lines, stack, choke manifold. Shell test BOP upper pipe rams, choke valves 11,12,4,Dart valve. 250 low, 5000 psi high. State Inspector Austin McLeod on location for witness. Test H2S sensors and methane sonsors, cellar, rig floor, shakers. Good tests. Test BOPE as per procedure with the 4" test joint. 250 psi low, 5000 psi high on all tests except annular was tested to 250 psi low, and 2500 psi high. State Inspector Austin McLeod witnessed all tests, and conducted a rig inspection.All tests passed. SIMOPS: strap pipe, clean pit #4. Transfer mud from pit 3 to pits 1 & 2. Verify valves are holding. Rig down test equipment. Set long wear bushing.(9.75" ID). Install new 4" XT39 saver sub. Re-align the target 90° in kill line for proper flow path. Rabbit, strap remaining 96 joints of DP to be picked up, and program the MWD tools in pipe shed. Bring pallet of subs into pipe shed. PJSM. Pick up BHA#3 8½" DD505S PDC bit W/ 7 x 11 jets. Packed hole rotary assembly. Load sources, trip in hole to top of HWDP Single in with 4" XT 39 on top of the BHA. HSE Events:No incidents, accidents, or spills. PM Temp: -28 Operational Details (06:00 - 06:00) Jack up rig. Move back (East) 4". Level and shim sub base and complex. Cur riser down 3'. Install riser. Secure BOPE 24 hour Forecast:Single in hole to 1000'. Wind Direction: SW AM Temp: -30 Ops @ 06:00 hrs: Single in the hole with 4" XT39 Phase: 0 Wind Speed: 15 24 hour Summary: Jack up rig , move rig, level and center over well. Conduct initial BOPE test with State Inspector as witness. All pass. Install new saver sub on top drive. Strap and tally 96 joints of 4" XT39 DP. Program MWD logging tools. Set wear bushing, 9.75" ID. Pick up BHA#3. Weather Gen Conditions:Clearing, scattered clouds. Shoe Test: N/A 1.28.2022 Actual Depth: 80' 3,050 Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/27/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.28.2022 KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Supervisor (N): Robert Wall (907) 398-9191 Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Scott Heim/Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 13 Phone 1 1.29.22 Phone 2 Tool Pusher (N): 68 API No: PTD: Field: 3,050 ft 41 212 AMSL 0ft 730.0 P.B.T.D.:30.5 From : Hrs 6:00 9:30 3:30 14 9:30 12:30 3:00 8A 12:30 16:30 4:00 21 16:30 20:00 3:30 22 20:00 21:00 1:00 6A.01 21:00 22:00 1:00 6A.01 22:00 24:00 2:00 7 0:00 2:00 2:00 22 2:00 6:00 4:00 22 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 2 8½ D505S 3050 7x11 0.650 Time Depth MW PV YP Mud Gas Readings:Used 3:00 3030 9.7 15 20 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 96 1 2 Triplex 5.5 96 2 MD TVD Inc.OD ID Conn. Length 2931 2931.00 0.3 8.5 3.25 4 1/2 R 0.85 6.375 3 NC 50 3.04 6.75 2 5 1/2 FH 27.48 6.75 2.25 5 1/2 FH 6.10 6.75 5 NC 50 27.34 6.75 2.25 NC 50 5.10 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Report #: Supervisor (D): Scott Heim (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Robert Wall (907) 398-9191 Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.28.2022 NA OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/28/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: 1.28.2022 Actual Depth: 80' 3,050 Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Cleaning pits 1, and 2. Prepare for mud swap.Phase: 0 Wind Speed: 13 24 hour Summary: Pick up 63 joints. Stand back. Circulate the casing clean @ 1500. Work on top drive relay switch. Single in to 2916. Test casing to 3500 psi. good test. POOH 14 stands, single back in to 2916'. Total new joints picked up 105. Install new saver sub in top drive. Clean pits 1 and 2 for mud displacement. Off load all old mud into two 290 BBL trucks. Flush pumps with fresh water into pit #1. Weather Gen Conditions: Cloudy Shoe Test: N/A HSE Events:No incidents, accidents, or spills. PM Temp: -13 Operational Details (06:00 - 06:00) Single in the hole picking up 4" XT 39 drill pipe. From 868' to 1511'. CBU surface to surface. 24 hour Forecast:Displace 9.6+ppg spud mud out of the hole with 9+ppg 4% KCL clayshield. Drill shoe track and 20 feet of new hole CBU, pull back into casing blow down top drive rig up and perform LOT. Drill ahead. Wind Direction: SW AM Temp: -16 Break circulation. Mud very clabbered, unable to get the pumps to up drilling rates. Shut down. Blow down top drive. Off load 220 BBLs spud mud into trucks. Clean pits 1 and 2. Pump 25 BBLs water through mud pumps into pit 1. Prepare for mud swap. Top drive repair. Change out rotate relay as per Tesco Rep. Single in the hole picking up 4" XT 39 DP.Wash down joints 62 to 65. Up weight 95k, down weight 95 Blow down top drive. Rig up head pin to test casing. Hook up hoses to test casing. Pump 3.5 BBLs to 3250 with rig pump. Bring up to 3500 with test pump. Hold and chart for 30 mins. Bleed off 25 psi. Good test. Pump in 3.5 BBLs , get back 3.3 BBLs.Rig down test equipment, blow down choke. Attempt to blow down kill line. Frozen. Begin thawing with steam. POOH 14 stands. From 2916' to 1590'. Trip back in the hole singling in the last 40 joints. 97k Up. 100k down weight. Cchange out saver sub and grabber dies. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments: Vis 0 Available 58 Background (Avg) % 0 Mud Properties Gas Details Fuel Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 267.18 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 8 3/8" ILS Telescope Bit sub Ecoscope w/ 8¼" stab. Filter sub Bottle neckXO 8 3/8" stab w/ float 5 ea- 6¾" slick monels With ported float. 4 jts 4" XT 39 HW 16 jts 4" XT 39 HW Jars / Weatherford Mech Total Length (ft): 867.70 14 Phone 1 1.30.22 Phone 2 Tool Pusher (N): 68 API No: PTD: Field: 3,343 ft 41 212 AMSL 293 ft 830.0 P.B.T.D.:30.5 From : Hrs 6:00 9:00 3:00 21 9:00 10:30 1:30 5 10:30 16:30 6:00 21 16:30 20:30 4:00 5 20:30 21:00 0:30 5 21:00 21:30 0:30 5 21:30 22:30 1:00 22 22:30 23:00 0:30 22 23:00 6:00 7:00 5 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 2 8½ D505S 3050 7x11 0.650 Time Depth MW PV YP Mud Gas Readings:Used 3:00 3070 9.05 8 18 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 85 96 250 1100 1 3070 40 160 2 Triplex 5.5 85 96 250 1100 2 3070 40 150 MD TVD Inc.OD ID Conn. Length 2931 2931.00 0.3 8.5 3.25 4 1/2 R 0.85 6.375 3 NC 50 3.04 6.75 2 5 1/2 FH 27.48 6.75 2.25 5 1/2 FH 6.10 6.75 5 NC 50 27.34 6.75 2.25 NC 50 5.10 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Total Length (ft): 867.70 4 jts 4" XT 39 HW 16 jts 4" XT 39 HW Jars / Weatherford Mech Filter sub Bottle neckXO 8 3/8" stab w/ float 5 ea- 6¾" slick monels With ported float. 8 3/8" ILS Telescope Bit sub Ecoscope w/ 8¼" stab. AZ.Item Comment 267.18 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 55 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments: Rig down test equipment. Trip to bottom. Rotary drill from 3070' to 3343' MD. 500 GPM, 1100 PP, 19% Flow, 100 RPM, 7k TQ. Displace wellbore from 9.7# spud mud to 9.05# 2% Klashield. Pump 10 BBL water spacer ahead, then 290 BBLs new mud. 3 to 4 BPM. Reciprocate pipe through out job. All returns were taken into pit 1. Clean out and empty pits 1 and 2. Thaw and clean out sump line in pit #1 via super sucker. Drill out cement from 2940 to top of the float collar @ 2945' Drill float collar, shoe track, shoe @ 3030' MD. Clean out 12¼" rate hole from 3030 to 3050'. Drill new formation from 3050' to 3070'. 450 GPM, 820 PP, 15.6% Flow, 60 RPM, 7k TQ. Drilling out of all 4 pits as active with new mud on board. Circulate bottoms up. SPR's, Monitor well for 10 mins. Static. POOH slow from 3070' to 2940'. Wellbore tried to swab. Rig up to pump down both sides for LOT. Pump 1 BBL, pressure up to 790 psi, observe break over at 14.1 ppg EMW. Using 9.05 ppg mud, 3030 TVD. Notify C.O.O. Good test. HSE Events:No incidents, accidents, or spills. PM Temp: -13 Operational Details (06:00 - 06:00) Clean pit #1. 24 hour Forecast:Drill down to core point. Wind Direction: SW AM Temp: -10 Ops @ 06:00 hrs: Drilling 8½" hole with rotary assembly @ 3343 Phase: 0 Wind Speed: 14 24 hour Summary: Clean pits 1 and 2 of residual spud mud. Displace wellbore to 9# 2% KCL Klashield. Drill shoetrack, and clean out to old TD @ 3050'. Drill 20 feet of new hole. CBU. Pull into casing, racking back two stands. Blow down top drive. Rig up head pin and cement line, fluid pack kill and choke lines to choke manifold. Perform LOT to 14.1 ppg EMW. Rig down. Drill 8½" hole with rotary assembly from 3070' to 3343'. Weather Gen Conditions: Foggy Shoe Test: N/A 14.1 ppg EMW 1.28.2022 Actual Depth: 80' 3,050 Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' Last Rig Insp.: 1.29.22 OD/Weight 20"/129# 9-5/8" / 40# 7" / 29# Last Safety Mtg: 1/29/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.28.2022 KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Supervisor (N): Robert Wall (907) 398-9191 Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Scott Heim (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 15 Phone 1 1.31.22 Phone 2 Tool Pusher (N): 68 API No: PTD: Field: 4,667 ft 41 212 AMSL 1,324 ft 9 30.0 P.B.T.D.:30.5 From : Hrs 6:00 12:00 6:00 2 12:00 19:00 7:00 2 19:00 19:30 0:30 7 19:30 24:00 4:30 2 0:00 6:00 6:00 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 2 8½ D505S 3050 7x11 0.650 Time Depth MW PV YP Mud Gas Readings:Used 3:00 3070 9.05 8 18 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 85 96 250 1535 1 3993 40 180 2 Triplex 5.5 85 96 250 1535 2 3993 40 170 MD TVD Inc.OD ID Conn. Length 3181 3181.00 0.5 8.5 3.25 4 1/2 R 0.85 3277 3277.00 0.3 6.375 3 NC 50 3.04 3371 3371.00 0.6 6.75 2 5 1/2 FH 27.48 3464 3464.00 0.5 6.75 2.25 5 1/2 FH 6.10 3559 3559.00 0.4 6.75 5 NC 50 27.34 3655 3655.00 0.2 6.75 2.25 NC 50 5.10 3749 3749.00 0.2 6.75 2.813 NC 50 150.50 3845 3845.00 0.2 6.75 2.813 NC 50 7.80 3939 3939.00 0.3 4.75 2.75 XT39 3.45 4034 4034.00 0.3 4 3.24 XT 39 484.11 4119 4119.00 0.2 4.75 2.25 XT 39 30.46 4224 4224.00 0.2 4 3.24 XT 39 121.47 Report #: Supervisor (D): Scott Heim (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Robert Wall (907) 398-9191 Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Top Schrader Bluff Last BOP Test: 1.28.2022 1.30.22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Top of West Sak Last Safety Mtg: 1/30/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' 3451 Last BOP Drill: 1.28.2022 Actual Depth: 80' 3,050 Top of Canning Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' 3802 Last Rig Insp.: Ops @ 06:00 hrs: Drilling ahead @ 4467'. Phase: 0 Wind Speed: 10 24 hour Summary:Drill 8½" hole with rotary assembly from 3343' to 4467'. Collecting 30 foot samples. Strapping, drifting, 5½" P110 17# BTC liner in pipe shed. Process 66 joints. Weather Gen Conditions: Light snow Shoe Test: N/A 14.1 ppg EMW 4323 HSE Events:No incidents, accidents, or spills. PM Temp: -9 Operational Details (06:00 - 06:00) Drill from 3343' to 3648' MD. Drilling with rotary assembly. 500 GPM, 1050 PP, 80 to 90 RPM, 9 to 10K on bottom TQ, 4 to 5K off bottom torque, 20K WOB, collecting 30 foot samples. 24 hour Forecast:Drill to core point. Pump sweep surface to surface, POOH for core barrels. Wind Direction: SW AM Temp: -5 Drill from 3648' to 3993' MD. Drilling with rotary assembly. 500 GPM, 1050 PP, 80 to 90 RPM, 9 to 10K on bottom TQ, 4 to 5K off bottom torque, 20K WOB, remain with 30 foot samples. Up weight 110k. Dn weight 110k, Rot weight 110k. Turnbuckle pin fell from derrick. Originating from torque tube bracing. Stop drilling, continue circulating @ 330 GPM, 500 PP. Derrick man inspect derrick, replacing the missing pin and securing turnbuckle. Clean suction screen on pump #2. Drill from 3993' to 4190' MD. 500 GPM, 1490 PP, 80 to 90 RPM, 9 to 10K on bottom TQ, 4 to 5K off bottom torque, 20K WOB, remain with 30 foot samples. Up weight 110k. Dn weight 110k, Rot weight 110k. Drill from 4190' - 4467' MD. 500 GPM, 1490 PP, 80 to 90 RPM, 9 to 10K on bottom TQ, 4 to 5K off bottom torque, 20K WOB, remain with 30 foot samples. Up weight 115k. Dn weight 120k, Rot weight 115k. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments: Vis 0 Available 55 Background (Avg) units 60 Mud Properties Gas Details Fuel Connection units 100 Trip Gas % NA Volume Delivered: 0 AZ.Item Comment 216.08 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 203.3 8 3/8" ILS 223.02 Telescope 209.97 Bit sub 213.18 Ecoscope w/ 8¼" stab. 232.4 Filter sub 173.23 Bottle neckXO 233.97 8 3/8" stab w/ float 207.64 5 ea- 6¾" slick monels With ported float. 146.37 4 jts 4" XT 39 HW 195.62 16 jts 4" XT 39 HW 176.89 Jars / Weatherford Mech Total Length (ft): 867.70 16 Phone 1 2.1.22 Phone 2 Tool Pusher (N): 68 API No: PTD: Field: 5,697 ft 41 212 AMSL 1,030 ft 10 30.0 P.B.T.D.:30.5 From : Hrs 6:00 12:00 6:00 2 12:00 18:00 6:00 2 18:00 24:00 6:00 2 0:00 3:30 3:30 2 3:30 6:00 2:30 7 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 2 8½ D505S 3050 7x11 0.650 Time Depth MW PV YP Mud Gas Readings:Used 3:00 5500 9.3+ 8 18 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 85 96 250 1800 1 5035 40 240 2 Triplex 5.5 85 96 250 1800 2 5035 40 250 MD TVD Inc.OD ID Conn. Length 4319 4319.00 0.3 8.5 3.25 4 1/2 R 0.85 4414 4414.00 0.2 6.375 3 NC 50 3.04 4509 4509.00 0.2 6.75 2 5 1/2 FH 27.48 4604 4604.00 0.2 6.75 2.25 5 1/2 FH 6.10 4698 4698.00 0.2 6.75 5 NC 50 27.34 4792 4792.00 0.0 6.75 2.25 NC 50 5.10 4887 4887.00 0.1 6.75 2.813 NC 50 150.50 4982 4982.00 0.0 6.75 2.813 NC 50 7.80 5076 5076.00 0.2 4.75 2.75 XT39 3.45 5171 5171.00 0.1 4 3.24 XT 39 484.11 5265 5265.00 0.4 4.75 2.25 XT 39 30.46 5359 5359.00 0.3 4 3.24 XT 39 121.47 5454 5454.00 0.5 5550 5550.00 0.6 Report #: Supervisor (D): Scott Heim (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Robert Wall (907) 398-9191 Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Top Schrader Bluff Last BOP Test: 1.28.2022 1.31.22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Top of West Sak Last Safety Mtg: 1/30/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' 3451 Last BOP Drill: 1.28.2022 Actual Depth: 80' 3,050 Top of Canning Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' 3802 Last Rig Insp.: Ops @ 06:00 hrs: Service top drive. Replace wash pipe. Circulating through the headpin at 4 BPM - 700 PSI. Phase: 0 Wind Speed: 10 24 hour Summary:Drill 8½" hole from 4467' to 5697'. Wash pipe in top drive began leaking. Rig up to circulae with 2" cement hose. CBU. Pull one stand. Set down low. Circulate through wash pipe 3 BPM. Remove old wash pipe install new. Weather Gen Conditions: Light snow Shoe Test: N/A 14.1 ppg EMW 4323 HSE Events:No incidents, accidents, or spills. PM Temp: -9 Operational Details (06:00 - 06:00) Drill from 4467' MD to 4801'. Drilling with rotary assembly. 500 GPM, 1550 PP, 80 to 90 RPM, 9 to 10K on bottom TQ, 4 to 5K off bottom torque, 25K WOB, collecting 30 foot samples. 24 hour Forecast:Drill to core point. Pump sweep surface to surface, POOH for core barrels. Wind Direction: SW AM Temp: -5 Drill from 4801' to 5131'. Drilling with rotary assembly. 500 GPM, 25k WOB, 1850 PP, 80 to 100 RPM, 9 to 10K on bottom TQ, 4 to 5K off bottom torque, 25K WOB, collecting 30 foot samples. Drill from 4801' to 5131'. Drilling with rotary assembly. 500 GPM, 25k WOB, 1850 PP, 80 to 100 RPM, 9 to 10K on bottom TQ, 4 to 5K off bottom torque, 25K WOB, collecting 30 foot samples. Drill from 5131' to 5697'. Drilling with rotary assembly. 500 GPM, 25k WOB, 1850 PP, 80 to 100 RPM, 9 to 10K on bottom TQ, 4 to 5K off bottom torque, 25K WOB, collecting 30 foot samples. Offload 290 BBLs new 2% KCL. Send out 70 BBLs old mud. Service top drive. Change out wash pipe, while circulating through head pin and cement hose, one stand off bottom. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments: Vis 0 Available 55 Background (Avg) units 80 Mud Properties Gas Details Fuel Connection units 120 Trip Gas % NA Volume Delivered: 0 AZ.Item Comment 139.64 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 176.4 8 3/8" ILS 184.35 Telescope 150.54 Bit sub 195.63 Ecoscope w/ 8¼" stab. 344.98 Filter sub 242.71 Bottle neckXO 344.08 8 3/8" stab w/ float 203.43 5 ea- 6¾" slick monels With ported float. 250.65 4 jts 4" XT 39 HW 239.61 204.07 16 jts 4" XT 39 HW 222.86 Jars / Weatherford Mech Total Length (ft): 867.70 234.14 17 Phone 1 2.2.22 Phone 2 Tool Pusher (N): 66 API No: PTD: Field: 5,697 ft 41 212 AMSL 1,030 ft 11 30.0 P.B.T.D.:30.5 From : Hrs 6:00 6:30 0:30 21 6:30 12:00 5:30 2 12:00 24:00 12:00 2 Midnight 6:00 6:00 2 0:00 0:00 24:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 2 8½ D505S 3050 7x11 0.650 Time Depth MW PV YP Mud Gas Readings:Used 15:00 6,220' 9.35 8 27 Rig: 21:00 6,513' 9.4 9 28 Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 85 96 250 2,250 1 5,530 40 280 2 Triplex 5.5 85 96 250 2,250 2 5,530 40 270 MD TVD Inc.OD ID Conn. Length 5,645' 5,645' 0.59 8.5 3.25 4 1/2 R 0.85 6,023' 6,023' 0.96 6.375 3 NC 50 3.04 6,213' 6,213' 1.33 6.75 2 5 1/2 FH 27.48 6,401' 6,401' 1.54 6.75 2.25 5 1/2 FH 6.10 6.75 5 NC 50 27.34 6.75 2.25 NC 50 5.10 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Total Length (ft): 867.70 4 jts 4" XT 39 HW 16 jts 4" XT 39 HW Jars / Weatherford Mech Filter sub Bottle neck XO 8 3/8" stab w/ float 5 ea- 6¾" slick monels With ported float. 286.51 8 3/8" ILS Telescope 281.11 Bit sub 276.99 Ecoscope w/ 8¼" stab. AZ.Item Comment 247.02 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 44 Connection units NA Trip Gas % NA Volume Delivered: 0 Vis 0 Available 43 Background (Avg) units 100 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments: Drill 8 1/2" hole from 5,697' 6,044'. 25K wob, 90 rpm, 500 gpm @ 1,900 psi. 140K up, 138K rot, 145K dn Continue drill ahead from 6,044' to 6,648'. Continue drilling from 6,648' to 6,928' 20K wob, 95 rpm, 10/12K torque. 500 gpm @ 2,250 psi. HSE Events:IFO, No incidents, accidents, or spills reported. PM Temp: -27 Operational Details (06:00 - 06:00) Repair TD wash pipe packing 24 hour Forecast:Drill to geo call core point, circ hole clean, POH, stand back BHA, pick up core assembly #1, RIH, cut core.Wind Direction: W AM Temp: -32 Ops @ 06:00 hrs: Drilling ahead @ 6,928'Phase: 0 Wind Speed: 7 24 hour Summary:Finish packing top drive swivel packing, drilling ahead from 5,697' to 6,928'Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW 4323 1.28.2022 Actual Depth: 80' 3,050 Top of Canning Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' 3802 Last Rig Insp.: 1.31.22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Top of West Sak Last Safety Mtg: 2/2/22 6:00 AM Casing: Conductor Surface Inter/TOC 6,430' 3451 Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Top Schrader Bluff Last BOP Test: 1.28.2022 KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Supervisor (N): Paul Smith (907) 398-9191 Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Scott Heim (907) 992 0516 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 18 Phone 1 2.3.22 Phone 2 Tool Pusher (N): 66 API No: PTD: Field: 7,180' ft 41 212 AMSL 1,483' ft 12 30.0 P.B.T.D.:30.5 From : Hrs. 6:00 10:00 4:00 5 10:00 15:30 5:30 2 15:30 16:30 1:00 5 16:30 17:00 0:30 5 17:00 19:30 2:30 5 19:30 22:00 2:30 5 22:00 23:00 1:00 5 23:00 23:30 0:30 6 23:30 24:00 0:30 6 Midnight 5:00 5:00 6 5:00 5:30 0:30 5 5:30 6:00 0:30 6 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 2 8½ D505S 3050 7x11 0.650 Time Depth MW PV YP Mud Gas Readings:Used 9:00 6,870' 9.3 10 29 Rig: 15:00 7,178' 9.3 10 28 Total: 21:00 7,190' 9.4 10 28 Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 85 96 200 1,450 1 7,023' 30 300 2 Triplex 5.5 85 96 200 1,450 2 7,023' 30 310 MD TVD Inc.OD ID Conn. Length 8.5 3.25 4 1/2 R 0.85 6.375 3 NC 50 3.04 6.75 2 5 1/2 FH 27.48 6.75 2.25 5 1/2 FH 6.10 6.75 5 NC 50 27.34 6.75 2.25 NC 50 5.10 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Drill ahead from 6,928' to 7,180'. "core point". 15K wob, 100 rpm, 425 gpm @ 1,500 psi. Total Length (ft): 867.70 4 jts 4" XT 39 HW 16 jts 4" XT 39 HW Jars / Weatherford Mech Filter sub Bottle neck XO 8 3/8" stab w/ float 5 ea.- 6¾" slick monels With ported float. 8 3/8" ILS Telescope Bit sub Ecoscope w/ 8¼" stab. AZ.Item Comment 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 44 Connection units 120 45 Trip Gas % NA Volume Delivered: 0 Vis 0 Available 43 Background (Avg) units 80 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments: POH f/ 7,118' to 7,055'. Observed 35K overpull @ 7,055' work tight pipe, knock loose hammering down, Back reaming tight hole from 7,058' to 7,052' 155K up, 150K dn, 400 gpm @ 1,400 psi. 6 bhp losses Observed reaming. Continue back reaming 7,118' to 6,928', wash to 6,834, pull on elevators to 6,549'. Hole not taking proper fill. Monitor well. Work stand, well swabbing, giving mud picking up, pushing mud away going down. Circulate condition mud raise mud wt. to 9.3# Flow check well, flow, pit gain 5 bbl. Circulate condition mud, pump 10 bbl. LCM pill, raise mud weight to 9.4# Stand back 1 stand, Blow down mud lines and top drive. Observed well flowing. CBU, 400 gpm 1,450 psi. 49 units max gas observed. HSE Events:IFO, No incidents, accidents, or spills reported. PM Temp: -28 Operational Details (06:00 - 06:00) At 6,928' Observed circulating 60 bph losses. Circulate and cut mud weight back to 9.2 @ 3bpm @ 647 psi. sweep well with 20 bbl. nut plug lcm. 24 hour Forecast:Finish POH, stand back and lay down BHA, test BOPE, test witness waived by Bob Noble 2/2/22 @ 07:00 Wind Direction: W AM Temp: -39 Ops @ 06:00 hrs: Pumping out of hole @ 6,359'Phase: 0 Wind Speed: 10 24 hour Summary:Control losses, drill ahead to core point, work tight pipe free, circ hole, POH pumping out due to swabbing.Weather Gen Conditions: fair Shoe Test: N/A 14.1 ppg EMW 4323 1.28.2022 Actual Depth: 80' 3,050 Top of Canning Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' 3802 Last Rig Insp.: 1.31.22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Top of West Sak Last Safety Mtg: 2/2/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' 3451 Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Top Schrader Bluff Last BOP Test: 1.28.2022 KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Supervisor (N): Paul Smith (907) 398-9191 Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Scott Heim (907) 992 0516 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 19 Phone 1 2.4.22 Phone 2 Tool Pusher (N): 66 API No: PTD: Field: 7,470 ft 41 212 AMSL 1,483' ft 12 30.0 P.B.T.D.:30.5 From : Hrs. 6:00 8:30 2:30 6 8:30 9:00 0:30 21 9:00 12:00 3:00 6 12:00 17:30 5:30 2 17:30 24:00 6:30 5 0:01 0:30 0:29 6 0:30 1:30 1:00 21 1:30 2:00 0:30 21 2:00 4:00 2:00 3 4:00 5:30 1:30 6 5:30 6:00 0:30 7 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 2 8½ D505S 3050 7x11 0.650 Time Depth MW PV YP Mud Gas Readings:Used 9:00 6,870' 9.3 10 29 Rig: 15:00 7,178' 9.3 10 28 Total: 21:00 7,190' 9.4 10 28 Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 85 96 200 1,450 1 7,023' 30 300 2 Triplex 5.5 85 96 200 1,450 2 7,023' 30 310 MD TVD Inc.OD ID Conn. Length 8.5 3.25 4 1/2 R 0.85 6.375 3 NC 50 3.04 6.75 2 5 1/2 FH 27.48 6.75 2.25 5 1/2 FH 6.10 6.75 5 NC 50 27.34 6.75 2.25 NC 50 5.10 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Report #: Supervisor (D): Scott Heim (907) 992 0516 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith/ M.Brouillet (907) 398-9191 Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: 280.0 Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.22 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Top Schrader Bluff Last BOP Test: 1.28.2022 1.31.22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Top of West Sak Last Safety Mtg: 2/2/22 6:00 PM Casing: Conductor Surface Inter/TOC 6,430' 3451 Last BOP Drill: 1.28.2022 Actual Depth: 80' 3,050 Top of Canning Last Diverter Drill: 1.21.22 Plan Depth: 75' 3,500' 9,500' 3802 Last Rig Insp.: Ops @ 06:00 hrs: POOH Phase: 0 Wind Speed: 10 24 hour Summary:Weight up[ F/9.4 ppg - T/9.6 ppg. Backream with excessive torque when pulling up. Work area until no problems visable &,402' MD - T/7,213' MD. TOOH no pump or rotation F/ 7,213' MD. - 7,023' MD. Weather Gen Conditions: fair Shoe Test: N/A 14.1 ppg EMW 4323 HSE Events:No accidents, Incidents or spills.PM Temp: -28 Operational Details (06:00 - 06:00) Pumping out of hole f/ 6,549'' to 5,646'.Pump out @ 2 BPM. 75 RPM, up wt. 150k, 150k dn. 24 hour Forecast:TOOH. Lay down BHA. Test BOPE Wind Direction: W AM Temp: -39 Attempt to POOH, 40k overpull. Make up string to top drive establish parameters. Backream F/7,402' MD.-T/7,118' MD. String torquing up. Up wt. 155k. Dn wt. 164k. Rot wt. 162k. 90 rpm. 200 gpm. 1,400 psi. TOOH F/ 7,213' MD- T/ 7,023' MD no pump or rotation. Pulled W/ no difficultiers. Repair leaking hydraulic hose on top drive. Blow down Top Drive & Mud line. Monitor well. Install pressure gauge on drillpipe. Pressure increase of 25 psi. detected. RIH T/ 7,180' MD. Took weight at 7,163' MD & 7,173' MD. Stalled rotary worked area until no weight taken on string. Drill F/ 7,180' MD - T/7,470' MD. 100 rpm, 425 gpm, 15K bit wt. Well ballooning on connections. Pressure increase of 65psi. Circulate and condition mud. Wt. up F/9.4 ppg. -T/9.6 ppg. Up wt. 155k. Dn wt. 162. 500 gpm 2,280 psi. Hole taking 10 bph loss rate . Reduce pump rate T/400 gpm, 1,580 psi. w/9.6 ppg mud wt. POOH F/7,470 MD - T/7,402' MD. Monitor Well. Confirm wellbore breathing. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 23:59 Comments: Vis 0 Available 43 Background (Avg) units 80 Mud Properties Gas Details Fuel 44 Connection units 120 45 Trip Gas % NA Volume Delivered: 0 AZ.Item Comment 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 8 3/8" ILS Telescope Bit sub Ecoscope w/ 8¼" stab. Filter sub Bottle neck XO 8 3/8" stab w/ float 5 ea.- 6¾" slick monels With ported float. 4 jts 4" XT 39 HW 16 jts 4" XT 39 HW Jars / Weatherford Mech Total Length (ft): 867.70 20 Phone 1 2.5.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 7,470 ft 41 ft 14 30.3 P.B.T.D.: From To Hrs 6:00 12:00 6:00 6 12:00 18:00 6:00 6 18:00 24:00 6:00 6 0:01 1:30 1:29 6 1:30 2:30 1:00 5 2:30 5:00 2:30 9 5:00 6:01 1:01 7 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 2 8½ D505S 3050 7,470 4,420 73.6 70 7x11 0.650 Time Depth MW PV YP Mud Gas Readings:Used 0:01 7470 9.6 14 19 Rig: 18:00 7470 9.6 14 20 Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 5,645' 5,645' 0.59 8.5 3.25 4 1/2 R 0.85 6,023' 6,023' 0.96 6.375 3 NC 50 3.04 6,213' 6,213' 1.33 6.75 2 5 1/2 FH 27.48 6,401' 6,401' 1.54 6.75 2.25 5 1/2 FH 6.10 6970 6969.50 1.7 6.75 5 NC 50 27.34 7159 7159.00 1.7 6.75 2.25 NC 50 5.10 7348 7347.76 1.7 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.11 4.75 2.25 XT 39 30.46 4 3.24 XT 39 121.47 Report #: Supervisor (D): Scott Heim (907) 992-0516 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Mark Brouillet (907) 631-9850 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: 0.0 Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 1.28.2022 2.5.22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/5/22 12:00 AM Casing: Conductor Surface Inter/TOC 6430' Last BOP Drill: 1/10/22 Actual Depth: 75'Last Evac Drill: NA Plan Depth: 75' 5,500' 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Work BHA Phase: N/A Wind Speed: -33 24 hour Summary:Backream out of hole to casing shoe @ 3,030' MD. Circulate @ 475 gpm, large amount of cuttings load on shakers.Slip & Cut drill line. Weather Gen Conditions: Fair Shoe Test: N/A HSE Events:No Accidents, Incidents, Spills PM Temp: -33 Operational Details (06:00 - 06:00) Backream Out of hole F/7,152' MD - 5,347' MD. Flow rate 140-150 gpm pressure 300- 400 psi.Rt. Wt 125k. Flow in 2-6. Torque 10k - 14k. Erratic torque spikes stalled drill string. 24 hour Forecast:Lay down BHA, Rig up & Test BOPE, P/U Coring assembly Wind Direction: N/A AM Temp: -36 Backream F/5,347' MD - T/4,183' MD. 80 rpm, 170 gpm, 480 psi. Tq. - 6k-15k. Rt. Wt. 126k. Erratic torque throughout reaming stalling drillstring intermittently. PVT @ 12:00 = 405 bbl. PVT @ 18:00 = 392 bbl. (Preventative Maintenance saver sub changed out due to high torque values.) Backream F/4,183' MD - T/3,803' MD. 90 rpm, 120 gpm, 310 psi. Tq. - 6k-15k. Rt. Wt. 115k. Add 100 bbl. Mud to pits F/Vac Truck. Backream F/3,803' MD - T/3,030' MD. 90 rpm, 120 gpm, 310 psi. Tq. - 6k-15k. Rt. Wt. 115k. Rotate and Reciprocate bottoms up X 2 @ 475 gpm, 1,575 psi 90 rpm, up wt. 95k. Dn 100k. Rot wt. 93k. Shakers showed a good cuttings load indications of hole unloading. Slip & Cut 66' of drilling line. Spool on new line notice line wear cut an additional 108' of drill line. Service top drive, blocks and traveling equipment. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 1-1-BT-S-X-I-NO-BHA Total Hours 24:00 Comments: Vis 0 Available 44 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 45 Connection % 0 Trip Gas % 0 Volume Delivered: 0 281.11 Bit sub 276.99 Ecoscope w/ 8¼" stab. AZ.Item Comment 247.02 8½" PDC bit 311.98 8 3/8" stab w/ float 309.86 5 ea.- 6¾" slick monels 286.51 8 3/8" ILS 312.35 Telescope 16 jts 4" XT 39 HW Jars / Weatherford Mech 4 jts 4" XT 39 HW Filter sub With ported float. Bottle neck XO Total Length (ft): 867.70 21 Phone 1 2.6.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 7,470 ft 41 ft 15 30.3 P.B.T.D.: From To Hrs 6:00 8:00 2:00 7 8:00 8:15 0:15 5 8:15 9:15 1:00 6 9:15 10:00 0:45 6 10:00 14:30 4:30 6 14:30 15:30 1:00 15 15:30 24:00 8:30 15 0:01 1:30 1:29 15 1:30 2:30 1:00 15 2:30 3:00 0:30 6 3:00 6:00 3:00 6 6:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1RR1 8 1/2 PDC 7470 7 X 11 Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 96 1 2 Triplex 5.5 60 96 2 MD TVD Inc.OD ID Conn. Length 6970 6969.50 1.7 8.5 3.25 4 1/2 R 0.85 7159 7159.00 1.7 6.75 NC 50 26.95 7348 7347.76 1.7 6.75 2 5 1/2 FH 5.07 6.75 2 5 1/2 FH 27.48 6.75 2.25 5 1/2 FH 6.10 6.75 5 NC 50 27.34 6.75 2.25 NC 50 5.10 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.50 4.75 2.25 XT 39 30.39 4 3.24 XT 39 121.08 Report #: Supervisor (D): Scott Heim (907) 992-0516 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Mark Brouillet (907) 631-9850 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: 0.0 Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1.22.2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/6/22 2.5.22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/5/22 12:00 AM Casing: Conductor Surface Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030 Last Evac Drill: NA Plan Depth: 75' 3,500 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Picking UP BHA Phase: N/A Wind Speed: 12 24 hour Summary:Rig service, Derrick inspection, TOOH T/BHA, Lay Down BHA, Test BOPE Weather Gen Conditions: Fair Shoe Test: N/A HSE Events:No accidents, Incidents or spills.PM Temp: -19 Operational Details (06:00 - 06:00) Rig Service, Lubricate blocks, Top Drive, Perform Derrick Inspection (Post Jarring) 24 hour Forecast:Pick Up BHA, RIH, Drill F/7,470' MD Wind Direction: West AM Temp: -19 Continue Test BOPE, W/4" & 5-1/2" Test joint. (Witness waived by AOGCC Rep Bob Noble) Rig Down F/ BOPE Test. Pull Test plug, Install Wear Bushing. Clear & Clean Floor, Prep to pick up BHA Pick up BHA, Bit, Motor, MWD, Load Sources. Pump Dry Job, Blow down Mud Lines. TOOH T/510' (Jars) Swap out to new jars. Rack HWDP & Drill collars in Derrick, 14:30Lay down 8-1/2" Drilling BHA. Drain Stack / Pull Wear Bushing/ Set Test Plug. Test BOPE, W/4" & 5-1/2" Test joint. (Witness waived by AOGCC Rep Bob Noble) Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 23:59 Comments: Vis 0 Available Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 311.98 Mud Motor Power Pak 309.86 8-3/8" Gauge Stabilizer Plunger float non ported in stabilizer AZ.Item Comment 312.35 8½" PDC bit Telescope 8 3/8" stab w/ float Ecoscope w/ 8¼" stab. 8 3/8" ILS Bottle neck XO 16 jts 4" XT 39 HW Jars / Weatherford Mech 5 ea.- 6¾" slick monels Filter sub Total Length (ft): 896.61 4 jts 4" XT 39 HW 22 Phone 1 2/7/2022 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450 ft 41 950 ft 16 30.3 P.B.T.D.: From To Hrs 6:00 7:30 1:30 6 7:30 9:30 2:00 6 9:30 11:00 1:30 5 11:00 12:00 1:00 6 12:00 14:00 2:00 6 14:00 18:00 4:00 3 18:00 20:30 2:30 2 20:30 21:00 0:30 5 21:00 24:00 3:00 2 0:00 5:00 5:00 2 5:00 6:00 1:00 3 6:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1RR1 8 1/2 PDC 7470 8450 980 7 X 11 Time Depth MW PV YP Mud Gas Readings:Used 21:00 7712 9.4 10 27 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 96 1 2 Triplex 5.5 60 96 2 MD TVD Inc.OD ID Conn. Length 6970 6969.50 1.7 312.35 8.5 3.25 4 1/2 R 0.85 7159 7159.00 1.7 311.98 6.75 NC 50 26.95 7348 7347.76 1.7 309.86 6.75 2 5 1/2 FH 5.07 7632 7631.05 1.7 6.75 2 5 1/2 FH 27.48 8199 8198.60 1.3 6.75 2.25 5 1/2 FH 6.10 6.75 5 NC 50 27.34 6.75 2.25 NC 50 5.10 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.50 4.75 2.25 XT 39 30.39 4 3.24 XT 39 121.08 Report #: Supervisor (D): Scott Heim (907) 992-0516 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Mark Brouillet (907) 631-9850 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Well at Total Depth Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/6/22 2/6/22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 1/17/22 6:00 AM Casing: Conductor Surface Inter/TOC 6430' Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030 Last Evac Drill: NA Plan Depth: 75' 3,500 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Phase: N/A Wind Speed: 6 24 hour Summary:TIH, Complete Mud Dilution F/9.6 ppg - T/9.4ppg. Drill F/7,470' MD Weather Gen Conditions: Fair Shoe Test: N/A HSE Events:No Accidents, Incidents or Spills.Windchill Temp: -53 Operational Details (06:00 - 06:00) RIH picking up remaining BHA, Drill collars & HWDp, Jars F/Derrick. 24 hour Forecast:Circulate hole clean, TOOH, Lay Down BHA, Rig up wireline, Perform logging run via wireline. Wind Direction: NW AM Temp: -44 Circulate and condition mud while troubleshooting data transmission rates. 400 gpm 1,960 psi. (Sim-OP load 20 joints 5-1/2" Casing into pipeshed Drill F/7,714' MD - T/7,995' MD 90 rpm, torque 9-12k ft/lbs. flow in 400 gpm, pressure 2,260 psi. Bit wt.15-25k. Flow out 18% up 160k, dn170k rot 165k. Drill at 175 fph controlled ROP. Drill F/7,995' MD - T/8,450' MD 90 rpm, torque 9-12k ft/lbs. flow in 400 gpm, pressure 2,260 psi. Bit wt.15-25k. Flow out 18% up 160k, dn170k rot 165k. Well at Total Depth. Circulate at 475 gpm, 2,360 psi. 90 rpm, up wt 165k, 172k Dn wt. Rot 167k. RIH picking up 4" Drillpipe F/Pipeshed, 39 joints total. (Serviced crown) Fill Pipe, Test MWD 350 gpm, 898 psi. (Sim-OP remove coring tools F/Pipeshed) RIH F/Derrick T/3,030' MD. Casing shoe, Fill pipe. Up wt. 95k Dn. Wt. 100k rt. Wt. 100k RIH F/3,030' MD - T/6,042' MD Wash & Ream F/6,042' MD - T/7,470' MD Drill F/7,470' MD - T/7,714' MD 90 rpm, torque 8-11k ft/lbs. flow in 400 gpm, pressure 2,200 psi. Bit wt. 15-25k. Flow out 18% up 158k, dn165k rot 160k. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments: Vis 439 Available 47 Background (Avg) % 400 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Mud Motor Power Pak 8-3/8" Gauge Stabilizer Plunger float non ported in stabilizer AZ.Item Comment 8½" PDC bit Telescope 8 3/8" stab w/ float 307.73 Ecoscope w/ 8¼" stab. 307.61 8 3/8" ILS Bottle neck XO 16 jts 4" XT 39 HW Jars / Weatherford Mech 5 ea.- 6¾" slick monels Filter sub Total Length (ft): 896.61 4 jts 4" XT 39 HW 23 Phone 1 2/8/2022 Phone 2 Tool Pusher (N): API No: PTD: Field: ft 41 ft 17 30.3 P.B.T.D.: From To Hrs 6:00 7:00 1:00 5 7:00 7:15 0:15 21 7:15 8:15 1:00 6 8:15 8:45 0:30 21 8:45 16:00 7:15 6 16:00 16:30 0:30 21 16:30 17:00 0:30 6 17:00 18:30 1:30 6 18:30 24:00 5:30 6 0:00 6:00 6:00 21 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1RR1 8 1/2 PDC 7470 8450 980 7 X 11 Time Depth MW PV YP Mud Gas Readings:Used 12:00 8450 9.5 11 30 Rig: 16:00 8450 9.5 12 30 Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 70 96 208 2384 1 8450 30-40 470 537 2 Triplex 5.5 72 96 212 2384 2 8450 30-40 465 500 MD TVD Inc.OD ID Conn. Length 6970 6969.50 1.7 312.35 8.5 3.25 4 1/2 R 0.85 7159 7159.00 1.7 311.98 6.75 NC 50 26.95 7348 7347.76 1.7 309.86 6.75 2 5 1/2 FH 5.07 7632 7631.05 1.7 6.75 2 5 1/2 FH 27.48 8199 8198.60 1.3 6.75 2.25 5 1/2 FH 6.10 8294 8293.57 1.2 6.75 5 NC 50 27.34 8370 8369.03 0.8 6.75 2.25 NC 50 5.10 6.75 2.813 NC 50 150.50 6.75 2.813 NC 50 7.80 4.75 2.75 XT39 3.45 4 3.24 XT 39 484.50 4.75 2.25 XT 39 30.39 4 3.24 XT 39 121.08 Total Length (ft): 896.61 4 jts 4" XT 39 HW BHA Out of hole @ 24:00 Bottle neck XO 16 jts 4" XT 39 HW Jars / Weatherford Mech 5 ea.- 6¾" slick monels Filter sub 321.38 Telescope 324.99 8 3/8" stab w/ float 307.73 Ecoscope w/ 8¼" stab. 307.61 8 3/8" ILS Mud Motor Power Pak 8-3/8" Gauge Stabilizer Plunger float non ported in stabilizer AZ.Item Comment 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 50 Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 44 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 1-4-BT-S-X-I-RO-TD Total Hours 24:00 Comments: Trip Out on elevators, F/3,030' MD - T/896' BHA (Hole took correct fill) Rack back HWDP & Jars in derrick, L/D BHA. Clear & Clean Rig Floor, Prep to P/U Wireline. Wireline truck had mechanical failure 3 miles from location. Rig performing preventative maintenance, Cleaning work areas, performing rig safety audit, cold Weather shut down in effect -55° OWFF (Observe well for flow- Static) POOH F/8,450' MD - T/7,490' MD. No problems encountered pulled slick. Drain Trip Tank, Blow down 2" fill up line. Pump out of hole @ 1 BPM, F/7,490' MD - T/ 3,030' MD (Casing shoe) Monitor well for flow Circulate bottoms up @ 475 GPM - 1,540 psi. 90 rpm. Up 95k Dn. 100k. HSE Events:No Accidents, Incidents or Spills.Windchill: -71 Operational Details (06:00 - 06:00) Circulate sweep at 475 gpm, 2,360 psi. 90 rpm, up wt 180k, 175k Dn wt. Rot 175k. 24 hour Forecast:Wireline logging. Wind Direction: WSW Temp: -49 Ops @ 06:00 hrs: Waiting on Wireline truck, Truck had equipment malfunction with brake lines freezing up Phase: N/A Wind Speed: 9 24 hour Summary:8,450' MD. Circulated hole clean, Pumped out of hole to casing shoe @3,030'. Monitored well, Pumped dry job, Tripped out of hole T/ BHA. Laid down BHA including drill collars. PJSM, Rig up wireline. Weather Gen Conditions: Fair Shoe Test: N/A 1/10/22 Actual Depth: 75' 3,030 Last Evac Drill: NA Plan Depth: 75' 3,500 9,500' Last Rig Insp.: 2/6/22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 1/17/22 6:00 AM Casing: Conductor Surface Inter/TOC 6430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/6/22 KB-GL, ft Prog FTD md: 8,450' MD - Total Depth Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Mark Brouillet (907) 631-9850 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Scott Heim (907) 992-0516 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 24 Phone 1 2/9/2022 Phone 2 Tool Pusher (N): API No: PTD: Field: ft 41 ft 18 30.3 P.B.T.D.: From To Hrs 6:00 7:00 1:00 21 7:00 12:00 5:00 21 12:00 16:30 4:30 11 16:30 18:00 1:30 11 18:00 24:00 6:00 21 2:00 2:00 11 2:00 3:30 1:30 6 3:30 4:00 0:30 6 4:00 6:00 2:00 5 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1RR2 8 1/2 PDC 7 X 11 Time Depth MW PV YP Mud Gas Readings:Used 15:00 0 9.5 12 30 Rig: 3:00 0 9.5 11 30 Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 96 2 Triplex 5.5 96 MD TVD Inc.OD ID Conn. Length 6970 6969.50 1.7 312.35 8.5 3.25 4 1/2 R 0.85 7159 7159.00 1.7 311.98 6.75 2.75 NC 50 3.00 7348 7347.76 1.7 309.86 4.75 2.75 XT39 3.43 7632 7631.05 1.7 4 3.24 XT 39 484.50 8199 8198.60 1.3 4.75 2.25 XT 39 30.39 8294 8293.57 1.2 4 3.24 XT 39 121.08 8370 8369.03 0.8 Total Length (ft): 643.25 321.38 4 jts 4" XT 39 HW 324.99 Bottle neck XO 307.73 16 jts 4" XT 39 HW 307.61 Jars / Weatherford Mech AZ.Item Comment 8½" PDC bit Bit Sub w/ float valve Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 49 Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 47 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments: TIH T/1,400' MD. Circulate @ 250 gpm, 315 PSI PJSM, Bring in logging tools to pipeshed, Sheaves and miscellaneous wireline equipment to rig floor. Spot wireline truck. Rig up wireline sheaves, bring wireline to rig floor, Stage wireline logging tools for pick up. Swap out wireline generator equipment failure due to extreme cold weather. Sim-Ops- Blow through cement line verify clear. Grease choke manifold, preventative maintenance on lo- torque valves on floor. Make up Wireline tools for Logging run # 1 Triple Combo- Gamma, NMR, Resistivity T/150' length of tool string. Wireline logging unit spooler brake failure. Sim-Ops. Rig down DD/MWD monitors, draw works encoder & external wiring. Work on rotary clutch. Assemble subs for cleanout BHA. Monitor well via trip tank hole taking .6 bph. F/20:00 - T/24:00 hole took 2 bbls. Pull logging tools from hole & lay down. Wireline unit can not be repaired on location. Unit taken to Deadhorse shop for repair or replacement. Monitoring hole via trip tank. Hole taking .6 bbl. Per hr. M/U Clean out BHA, Bit, Bit sub, X-O, HWDP & jars HSE Events:No Accidents, Incidents or Spills.Windchill: N/A Operational Details (06:00 - 06:00) Wireline truck brakes froze up 3 miles from location. Service top drive & blocks, Prep to pick up Wireline. Wireline truck on location @ 07:00. Monitor well via trip tank hole taking .6 bph. 24 hour Forecast:Wireline log. Wind Direction: N/A Temp: -51 Ops @ 06:00 hrs: Phase: N/A Wind Speed: 0 24 hour Summary:Rig up wireline, Wireline logging unit spooler brake not disengaging. Apply heaters, Mechanic working on solution Extreme cold weather causing malfunction. Weather Gen Conditions: Fair Shoe Test: N/A 1/10/22 Actual Depth: 75' 3,030 Last Evac Drill: NA Plan Depth: 75' 3,500 9,500' Last Rig Insp.: 2/6/22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 1/17/22 6:00 AM Casing: Conductor Surface Inter/TOC 6430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/6/22 KB-GL, ft Prog FTD md: 8,450' MD - Total Depth Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Mark Brouillet (907) 631-9850 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Scott Heim (907) 992-0516 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 25 Phone 1 2/10/2022 Phone 2 Tool Pusher (N): API No: PTD: Field: ft 41 ft 19 30.3 P.B.T.D.: From To Hrs 6:00 13:30 7:30 5 13:30 14:30 1:00 6 14:30 14:45 0:15 21 14:45 16:00 1:15 11 16:00 19:00 3:00 11 19:00 20:00 1:00 11 20:00 21:00 1:00 6 21:00 22:00 1:00 6 22:00 22:30 0:30 5 22:30 22:45 0:15 6 22:45 24:00 1:15 6 24:00 2:00 2:00 3 2:00 6:00 4:00 3 6:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1RR3 8 1/2 PDC 7 X 11 Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 96 2 Triplex 5.5 96 MD TVD Inc.OD ID Conn. Length 6970 6969.50 1.7 312.35 8.5 3.25 4 1/2 R 0.85 7159 7159.00 1.7 311.98 6.75 2.75 NC 50 3.00 7348 7347.76 1.7 309.86 4.75 2.75 XT39 3.43 7632 7631.05 1.7 4 3.24 XT 39 484.50 8199 8198.60 1.3 4.75 2.25 XT 39 30.39 8294 8293.57 1.2 4 3.24 XT 39 121.08 8370 8369.03 0.8 Total Length (ft): 643.25 321.38 4 jts 4" XT 39 HW 324.99 Bottle neck XO 307.73 16 jts 4" XT 39 HW 307.61 Jars / Weatherford Mech AZ.Item Comment 8½" PDC bit Bit Sub w/ float valve Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 *5-20k weight taken @ Torque 8-12k. 5,954', 5,985', 6,210', 6,319', 6,730', 6,925', 6,980' & 7,010'* Comments: TIH F/643' MD - T/ 3,030' MD. Circulate bottoms up 2,600 strokes, 500 gpm-10010 psi. flo-22% Blow down top drive / Mud line. TIH F/3,030' MD - T/5,663' MD with no problems. Wash & Ream F/ 5,663' MD - T/6,050' MD. Work tight area at 5,985', 6,000' MD. Areas worked vigorously with 450 gpm 1,420 psi, 90 rpm, torque 7-12k. Run through area with no pump no rotation took no weight. Wash & Ream F/6,050' MD- T/ 7,000' MD. 450 gpm, 1,450 psi. 90 rpm, Torque 8-12k. Worked area at 6,925' & 6,980' encountered high toque swings string took 20k. POOH with dumb iron assembly, L/D bit, bit sub, X-O. Clear & Clean Rig Floor. R/U Wireline logging tools Perform Loggging run # 1 Triple combo, CMR, Gamma. T/6,028' MD. Monitor well via trip tank Logging tools encountered obstruction at 6,028' MD. Could not work through. POOH with Wireline logging tools & L/D same M/U Cleanout Assembly, Bit, Bit sub w/ Non ported plunger style float valve, X-O, HWDP,Jars T/643' MD HSE Events:No Accidents, Incidents or Spills.Windchill: -66 Operational Details (06:00 - 06:00) Circulate @1,400' MD. Perform rig maintennace while waiting on Wireline unit repair 24 hour Forecast:TOOH, R/U Wireeline, Perform Wireline logging Wind Direction: WSW Temp: -29 Ops @ 06:00 hrs: Reaming to bottom Phase: N/A Wind Speed: 18 24 hour Summary: RIH with dumb iron T/1,400' MD. Wait on Wireline Unit, POOH lay down Dumb iron assembly, Rig up and RIH with Wireline logging tools, Took weight at 6,028' MD could not pass through. TOOH lay down Wireline logging tools, P/U cleanout assembly, TIH, Circulate at shoe 3,030' MD. RIH T/5,663' MD. Wash and ream Weather Gen Conditions: Fair Shoe Test: N/A 1/10/22 Actual Depth: 75' 3,030 Last Evac Drill: NA Plan Depth: 75' 3,500 9,500' Last Rig Insp.: 2/6/22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 1/17/22 6:00 AM Casing: Conductor Surface Inter/TOC 6430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/6/22 KB-GL, ft Prog FTD md: 8,450' MD - Total Depth Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Mark Brouillet (907) 631-9850 Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Scott Heim (907) 992-0516 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 26 Phone 1 2/11/2022 Phone 2 Tool Pusher (N): API No: PTD: Field: ft 41 ft 20 30.3 P.B.T.D.: From To Hrs 6:00 12:00 6:00 3 12:00 15:30 3:30 5 15:30 16:00 0:30 21 16:00 16:30 0:30 6 16:30 18:30 2:00 3 18:30 19:30 1:00 6 19:30 20:00 0:30 3 20:00 22:30 2:30 5 22:30 23:00 0:30 21 23:00 24:00 1:00 5 midnight 0:30 0:30 5 0:30 1:30 1:00 21 1:30 5:30 4:00 6 5:30 6:00 0:30 6 0:00 Bit # Size Depth Depth Feet Bit hrs K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1RR3 8 1/2 PDC 7 X 11 Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 96 2 Triplex 5.5 96 MD TVD Inc.OD ID Conn. Length 6970 6969.50 1.7 312.35 8.5 3.25 4 1/2 R 0.85 7159 7159.00 1.7 311.98 6.75 2.75 NC 50 3.00 7348 7347.76 1.7 309.86 4.75 2.75 XT39 3.43 7632 7631.05 1.7 4 3.24 XT 39 484.50 8199 8198.60 1.3 4.75 2.25 XT 39 30.39 8294 8293.57 1.2 4 3.24 XT 39 121.08 8370 8369.03 0.8 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hansen Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: 8,450' MD - Total Depth Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/6/22 2/6/22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 1/17/22 6:00 AM Casing: Conductor Surface Inter/TOC 6430' Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030 Last Evac Drill: NA Plan Depth: 75' 3,500 9,500' Last Rig Insp.: Ops @ 06:00 hrs: Pulling out of hole on elevators Phase: N/A Wind Speed: 14 24 hour Summary: Ream to bottom F/7,000' - T/8,450', CBU X 3, Monitor well, TOH on elevators 30-40k overpull. Backream out of hole. Large amounbts of shale at shakers. TIH, Weight up mud system to 9.6 ppg in & out. Pump sweep around. TOOH Weather Gen Conditions: Fair Shoe Test: N/A HSE Events:No Accidents, Incidents or Spills Windchill: -47 Operational Details (06:00 - 06:00) Wash & Ream F/7,000' MD- T/ 8,450' MD. 450 gpm, 1,450 psi. 90 rpm, Torque 8-12k. 24 hour Forecast:TOOH, P/U Wireline logging tools, Log run # 1&2 Wind Direction: WSW Temp: -20 8,450' MD - Circulate and weight up mud F/9.4 ppg - T/9.6 ppg. Up wt 150k dn wt. 160k. 90 rpm, 400 gpm, 1,590 psi. flo-18% PVT 470. Observe well for flow monitor via trip tank 36 bbl. Loss during circulation well exhaled 19.6 bbl. Back. 8,450' MD - Circulate 40 bbl. Hi-vis sweep 420 gpm- 1,660 psi.100 rpm 8,450' MD - Circulate 40 bbl. Hi-vis sweep 420 gpm- 1,660 psi.100 rpm, slight increase in cutting when sweep to surface. 8,450' MD Pull T/8,407' MD. Observe well for flow. Decreasing returns in 30 minute monitor. Confirming wellbore breathing. POOH F/8,407' MD - T/6,546'' MD Pumping out 1 BPM, No Rotation. Circulate Bottoms up X 3 standing back 1 stand each bottoms up, Large amounts of shale visible at shakers. 450 gpm 1,550 psi, 90 rpm. 8,219' MD. 8,219' MD. Blow down topdrive, Mud line. Observe well for flow - Wellbore breathing. Pull on elvators F/8,219' MD- T/8,189' MD. 35-40k overpull, String took weight going down. Backream Out of hole F/8,219' MD - T/ 7,745' MD. Tight areas 8,124',7,997', 7,890', 7,808' & 7,735' Decision made TIH to increase mud weight to hold back shales. Blow Down Topdrive,mudline. TIH F/7,745' MD - T/8,408' MD. Ream F/8,408' MD - T/ 8,450' MD 8,439' MD to 8,450' MD. 11' fill Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 POH on elevators from 6,546' to 6,072'. Total Hours 24:00 Comments: Vis 0 Available Background (Avg) % 0 Mud Properties Gas Details Fuel Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 8½" PDC bit Bit Sub w/ float valve Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA 321.38 4 jts 4" XT 39 HW 324.99 Bottle neck XO 307.73 16 jts 4" XT 39 HW 307.61 Jars / Weatherford Mech Total Length (ft): 643.25 27 Phone 1 2/12/2022 Phone 2 Tool Pusher (N): API No: PTD: Field: ft 41 ft 21 30.3 P.B.T.D.: From To Hrs. 6:00 6:30 0:30 21 6:30 10:30 4:00 6 10:30 10:45 0:15 21 10:45 11:30 0:45 6 11:30 13:30 2:00 11 13:30 20:30 7:00 11 20:30 23:00 2:30 21 23:00 24:00 1:00 21 Midnight 0:30 0:30 21 0:30 6:00 5:30 6 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1RR4 8 1/2 PDC 7 X 11 Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 96 2 Triplex 5.5 96 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 8.5 3.25 4 1/2 R 0.85 6.75 5.5 NC 50 26.95 6.75 2.75 NC 50 5.07 6.75 3.24 5.5 FH 3.45 6.75 2.25 NC50 27.34 6.75 2.25 NC50 5.10 3 X 6-3/4" Drill Collars 6.75 3.24 NC 50 89.67 Crossover 6.25 XT-39 3.45 16 jts 4" XT 39 HW 4 3.24 XT 39 484.50 Jars / Weatherford Mech 4.75 2.25 XT 39 30.39 4 jts 4" XT 39 HW 4 3.24 XT 39 121.08 Total Length (ft): 797.85 8-3/8" Stabilizer 324.99 8-3/8" Stabilizer Plunger float valve non ported Crossover Telescope AZ.Item Comment 8½" PDC bit PowerPack mud motor 2.38° adj. Bend. Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments:Notice sent to AOGCC for BOPE test 2/11/2022 @ 08:30 for test time of 2/13/2022 @ 08:00 Load clean out tools into pipe shed, Load clean out tools into pipe shed, M/U Cleanout assembly, change motor bend to 2.38° deg. upload, pick up and orient MWD, pick up NM DC's, TOOH on elevators w/ no difficulties F/6,072' MD - T/3,030' MD Monitor well @ BHA (Static) POH, Rack HWDP & Jars in Derrick, L/D bit, bit sub, X-O Reconfigure wireline logging tools, M/U logging string. (Hole taking .5 bph.) Rig up SLB logging tools. RIH with SMI DORK Sonic Neutron SPECRA Gama Ray. RIH Tool string stopped @ 6,050' wlm, Log up from 6,050' wlm to surface. Lay down logging tools, Rig down e-line. Monitor well. Rig service. Clear & Clean rig while waiting on BHA components for cleanout run. HSE Events:No accidents, Spills. Incident with frost bite on foot. Person evaluated by medic. Windchill: -39 Operational Details (06:00 - 06:00) Pump Dry Job / Blow down top drive & Mud line. 24 hour Forecast:Finish picking up making up clean out assembly, RIH, Ream obstruction area @ 6,028' MD. Circulate, TOOH, M/U Logging tools, Log per program Wind Direction: SSW Temp: -39 Ops @ 06:00 hrs.: Picking up clean out motor and MWD assembly Phase: 0 Wind Speed: 5 24 hour Summary:TOOH, L/D BHA/ Reconfigure logging tools/ RIH with logging tools via Wireline, make up cleanout BHA Weather Gen Conditions: Fair Shoe Test: N/A N/A 1/10/22 Actual Depth: 75' 3,030 8,450' Last Evac Drill: NA Plan Depth: 75' 3,500 9,500' Last Rig Insp.: 2/6/22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 1/17/22 6:00 AM Casing: Conductor Surface Inter/TOC 6430' Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/6/22 KB-GL, ft Prog FTD md: 8,450' MD - Total Depth Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 28 Phone 1 2/13/2022 Phone 2 Tool Pusher (N): 67 API No: PTD: Field: ft 41 ft 22 30.3 P.B.T.D.: From To Hrs. 6:00 9:30 3:30 6 9:30 12:00 2:30 3 12:00 13:30 1:30 3 13:30 14:30 1:00 6 14:30 16:00 1:30 3 16:00 16:30 0:30 21 16:30 20:30 4:00 3 20:30 21:00 0:30 5 21:00 24:00 3:00 6 Midnight 1:00 1:00 6 1:00 3:00 2:00 9 3:00 5:00 2:00 6 5:00 6:00 1:00 6 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 1RR4 8 1/2 PDC RR Time Depth MW PV YP Mud Gas Readings:Used 3:00 8,450' 9.6 12 29 Rig: 15:00 8,450' 9.6 13 30 Total: 21;00 8,450' 9.6 13 30 Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 96 2 Triplex 5.5 96 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 8.5 3.25 4 1/2 R 0.85 6.75 5.5 NC 50 26.95 6.75 2.75 NC 50 5.07 6.75 3.24 5.5 FH 3.45 6.75 2.25 NC50 27.34 6.75 2.25 NC50 5.10 3 X 6-3/4" Drill Collars 6.75 3.24 NC 50 89.67 Crossover 6.25 XT-39 3.45 16 jts 4" XT 39 HW 4 3.24 XT 39 484.50 Jars / Weatherford Mech 4.75 2.25 XT 39 30.39 4 jts 4" XT 39 HW 4 3.24 XT 39 121.08 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: 8,450' MD - Total Depth Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/6/22 2/6/22 OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 1/17/22 6:00 AM Casing: Conductor Surface Inter/TOC 6430' Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030 8,450' Last Evac Drill: NA Plan Depth: 75' 3,500 9,500' Last Rig Insp.: Ops @ 06:00 hrs.: laying down clean out BHA Phase: 0 Wind Speed: 5 24 hour Summary:RIH with 3.8° bent motor clean out assembly, clean out to 8,450', ream out to 8,372', pump out t/ 7,056', pull on elevators to 797' stand back HWDP, lay down BHA. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW N/A HSE Events:IFO, none reported.Windchill: -54 Operational Details (06:00 - 06:00) RIH with 2.38 deg bent motor clean out assembly t/ 5,910' 24 hour Forecast:Finish laying down BHA, rig up logging unit RIH for sidewall core samples. Wind Direction: SW Temp: -41 Pump dry job, blow down TD. POH on elevators from 7,046 t/ 4,290' Continue POH on elevators to 2,974" during trip out hole fluid returns diminishing, hole breathing, no indication of swabbing, hole taking proper fill at shoe 2,974'. Cut and slip drilling line. POH on elevators f/ 2,974 t/ 797'. Stand back HWDP, lay down motor cleanout assembly. Wash and ream from 5,910' to 6,099', 450 gpm, reduce pump rate to 300 gpm due to increased losses.4 rpm 7K torque Continue wash and ream f/ 6,099' t/ 6,383,washing and rotating tight spots until clean.300 gpm @ 1,300 psi. Blow down and RIH on elevators t/ 8,372', Wash and ream f/ 8,372' to 8,450', 160K rot, 175K up, 150K dn, 4 rpm, 7K torque, 350 gpm @ 1,670 psi Blow down TD, monitor well. Attempt POH on elevators @ 8,372' observed overpulls, pump out, t/ 8,182' overpulling and packing off, rotate pipe as necessary to mitigate packing off. Pump out w/o rotation t/ 7,046' 70 gpm @ 498 psi, 175K up, 150k dn, Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 529663 Total Hours 24:00 Comments:Notice sent to AOGCC for BOPE test 2/11/2022 @ 08:30 for test time of 2/13/2022 @ 08:00 Vis 0 Available 47 Background (Avg) % 0 Mud Properties Gas Details Fuel 48 Connection % 0 48 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 324.99 8½" PDC bit Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Telescope 8-3/8" Stabilizer PowerPack mud motor 2.38° bent housing 8-3/8" Stabilizer Non ported float Crossover Total Length (ft): 797.85 29 Phone 1 2.14.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 23 30.3 P.B.T.D.: From To Hrs. 6:00 7:00 1:00 6 7:00 9:00 2:00 11 9:00 13:30 4:30 11 13:30 14:30 1:00 21 14:30 15:30 1:00 15 15:30 0:00 8:30 15 Midnight 3:00 3:00 15 3:00 4:00 1:00 21 4:00 5:00 1:00 12 5:00 6:00 1:00 12 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 8450 9.6 13 28 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 AZ.Item Comment Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 47 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Pick up "johnny Wacker" flush and clean cuttings from BOP stack. Pick up set tool set "Dummy Pack off', RILDS, test to 5K for 10 min good test. Pick up landing joint and hanger, dummy run hanger, mark landing joint, lay down landing joint. Simops, rigging up casing tools to run 5 1/2" #17 P10 BTC liner. Clear floor, rig up SBL E-line for sidewall samples. RIH with sidewall sample tools, could not get past 4,025', rig down SBL E-line set tools down for load out. Lay down jars, warm TD, prep to test BOPE. Test BOPE, pull wear ring, drain stack, set test plug. Test BOPE. Tests 250 psi low 4,500 psi high, Annular 250 psi / 2,500 psi high, rams and annular tested with 4" and 5 1/2" test joints. Pe Sundry PTD #221-106, perform Koomey draw down test. Test witness waived by AOGCC inspector Guy Cook. Tests performed per AOGCC and Great Bear Pantheon expectations. Continue testing BOPE, , rig down test tools. Difficult to pull test plug,Test plug seals embedded with cuttings neck packed with cuttings. HSE Events:None reported. IFO.Wind chill -52 Operational Details (06:00 - 06:00) Lay down BHA #6, stand back HWDP 24 hour Forecast:RIH with 5 1/2" liner to TD, perform 2 stage cement job, Wind Direction: WSW AM Temp: -35 Ops @ 06:00 hrs.: Dummy run landing joint and hanger, Rigging up to run 5 1/2" liner.Phase: 0 Wind Speed: 10 to 15 mph 24 hour Summary:Finish lay down clean out BHA # 6, rig up and run in SBL E-line with sidewall coring tools, run to 4,025, could not proceed past, rig down SBL. Test BOPE., clean stack, set "dummy pack off" into well head and test, Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na 1/10/22 Actual Depth: 75' 3,030' na Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/14/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/14/22 3:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 30 Phone 1 2.15.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 24 30.3 P.B.T.D.: From To Hrs. 6:00 9:30 3:30 12 9:30 10:00 0:30 12 10:00 14:30 4:30 12 14:30 15:30 1:00 5 15:30 23:30 8:00 12 23:30 24:00 0:30 5 Midnight 1:00 1:00 5 1:00 3:00 2:00 12 3:00 5:00 2:00 5 5:00 6:00 1:00 12 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 8450 9.6 13 28 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/14/22 3:00 AM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/14/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' na Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: Ops @ 06:00 hrs.: Circulating at 128 gpm, 572 psi, landed on hanger.Phase: 0 Wind Speed: 12 MPH 24 hour Summary:Run 5-1/2" Casing. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -69 Operational Details (06:00 - 06:00) R/U to run 5-1/2" Casing. Volant running tool, Slips, Bales, Elevators. 24 hour Forecast:Mud dilution to cut weight from 9.6 ppg to 9.2 ppg, Perform 2 stage cement job.Wind Direction: SW AM Temp: -42 Work casing string F/8,369' MD - T/ 8,377' MD. Extreme difficulty working F/8,369' MD- T/8,377' MD. 80% losses while circulating and attempting to work pipe down. Could not circulate at 8,377' MD. Pick up a few feet completre circulation of bottoms up loss rate down to 8 bph. Space out and land casing on hanger set depth 8,376' MD Make up shoe track, Fill pipe, check floats. Run 5-1/2" P110 17# PPF casing T/2,983' MD. Circulate bottoms up @ 2,983' MD 130 gpm, 518 psi, RIH W/5-1/2" Casing F/ 2,983' MD - T/ 8,302' MD. Up wt 163K, Down wt. 155K Fill pipe, Establish Circulation. 1/2 bpm to1 bpm-210 psi Wash down F/8,302' MD -T/8,369' MD 60 gpm, 315 psi, string taking weight at 8,369' MD Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition **Tight spots @ 4,608', 7,335'-7,400', 6,900' - 8,377' ** Total Hours 24:00 Comments: Vis 0 Available 47 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment Total Length (ft): 0.00 31 Phone 1 2.16.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 25 30.3 P.B.T.D.: From To Hrs. 6:00 12:00 6:00 5 12:00 15:30 3:30 5 15:30 18:00 2:30 5 18:00 22:00 4:00 12 22:00 24:00 2:00 12 Midnight 3:00 3:00 6 3:00 6:00 3:00 6 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 8,376' 9.2 8 21 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 AZ.Item Comment Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 39 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Continue condition mud, reduce mud weight from 9.3# to 9.2# 4 bpm @ 570 psi. Rig up for 1st stage cement job, tie cement line into Volant tool, blow down rig surface lines, resume circulating 3 bpm @ 554 psi. Hold PJSM with all personnel involved with cement job. PT cement lines to 3,500 psi, mix and pump 40 bbl mud push followed by 68 bbl 15.8# cement tail slurry followed by 10 bbl water, release Volant tool, drop plug, displace with rig pumps, displace cement with 156.6 bbl. 9.2 mud @ 4 bpm @ 420 psi String pressured up. (Calculated displacement 182.25 bbl) Stop and evaluate, decided to set packer and open diverter, pressure up on string to 3,100 psi, no indication of packer set or diverter open, pressure up to 4,500 psi, diverted did not open, no indication of packer set. Rig down GBR casing tools, remove landing joint, Clear tools from pipe shed. Lay down 4" HWDP, lay down 4" drill pipe out of mouse hole. Load 2 7/8' pipe and test joint into pipe shed, load out GBR casing tools, rig up to lay down 4" drill pipe from mouse hole HSE Events:None reported. IFO.Wind chill -50 Operational Details (06:00 - 06:00) Circulate condition mud for cement, Reduce mud weight from 9.6# to 9.3# 4 bpm @ 570 psi. 24 hour Forecast:Finish laying down DP, pick up clean out BHA, RIH picking up 2 7/8" tubing work string. Drill out cement plug, clean out 5 1/2" casing. Wind Direction: SW AM Temp: -32 Ops @ 06:00 hrs.: Laying down drill pipe from mouse hole.Phase: 0 Wind Speed: 10 24 hour Summary: Circulate condition mud for cement job, cut mud wt from 9.6 to 9.2. rig up and pump 1st stage cement job, displace with rig pumps, casing pressured up early, diverter did not open, no indication of packer set. Rig down casing tool, lay down 4" drill pipe from mouse hole. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/16/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/14/22 3:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 32 Phone 1 2.17.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 26 30.3 P.B.T.D.: From To Hrs. 6:00 7:00 1:00 21 7:00 9:30 2:30 6 9:30 12:00 2:30 21 12:00 17:30 5:30 21 17:30 19:30 2:00 15 19:30 24:00 4:30 15 Midnight 1:30 1:30 15 1:30 2:30 1:00 14 2:30 5:30 3:00 15 5:30 6:00 0:30 6 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 AZ.Item Comment Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Could not get stack to drain through annulus valve. Pick up 4" Joint run into bottom of BOP stack blow air through 4" Drillpipe to get fluid out of BOP's Make several more attempts to release from pack-off with running tool. Pull Pack-off, Make up 4-3/4" BHA assembly. Lay down drillpipe F/ derrick via mousehole, Move 10 stands of pipe from D.S. to O.D.S. in derrick. R/U to run 2-7/8" Tubing work string, Strap & Tally pipe, Load 4-3/4" BHA components into pipeshed, Motor, Jars, 3-1/8" Drill collars, Change out handling equipment. R/U Test joint to packoff running tool, Set Pack-off. Pack off would not se t initially due to cuttings in stack. Flushed and cleaned stack repeatedly until able to set pack-off. Fill lines & Stack with H-2/O, Function annular and purge air from system. Test Annular 250 psi low, 2,500 psi high. Test Upper variable rams 250 psi low, 4,500 psi high. With 2-7/8" Test joint. Tests charted. Unable to release pack off running tool from pack-off, Back off LDS pull pack off. Trobleshoot several attempts made to rerun packoff and release from tool with no success. Sim-Ops Load pipeshed with 2-7/8" tubing and strap for tally. Flush stack with washing tool 500 gpm, 570 psi. Blow down topdrive & mud line. HSE Events:None reported. IFO.Wind chill -60 Operational Details (06:00 - 06:00) Service rig, Change out hoist cable 24 hour Forecast:TIH, Picking up 2-7/8" Tubing from pipe shed, Drill out wiper plug and landing collar.Wind Direction: WSW AM Temp: -21 Ops @ 06:00 hrs.: Picking up 4-3/4" BHA assembly.Phase: 0 Wind Speed: 22 24 hour Summary:Lay down 4" Drillpipe from derrick, Load pipeshed with 2-7/8" tubing and strap, Set pack-off, Test top pipe rams and annular with 2-7/8" test joint. Attempt to release from packoff with no success. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/17/22 6:30 AM Casing: Conductor Surface Intermediate Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/14/22 3:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 33 Phone 1 2.18.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 27 30.3 P.B.T.D.: From To Hrs. 6:00 8:30 2:30 6 8:30 9:00 0:30 5 9:00 12:00 3:00 6 12:00 12:30 0:30 5 12:30 23:00 10:30 6 23:00 23:30 0:30 6 23:30 24:00 0:30 6 Midnight 3:00 3:00 6 3:00 4:30 1:30 6 4:30 5:00 0:30 21 5:00 6:00 1:00 21 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Mill 4 3/4 Time Depth MW PV YP Mud Gas Readings:Used 21:00 8,376' 9.2 8 21 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 3.625 1.25 8RD EUE 1.25 3.06 1.25 174.80 3.125 1.25 12.19 3.7 1.25 11.24 4.75 1.25 0.96 4.75 1.25 1.80 Total Length (ft): 202.24 3 Bladed Mill Mud Motor Crossover sub 6 X Spiral drill collars HE Jar AZ.Item Comment Crossover sub Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 39 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 50244 Total Hours 24:00 Comments: TOOH F/6,440' - T/BHA 202' Lay down BHA mill, Motor, Jar, Drill collars Clear & Clean rig floor Inspect BHA components from run, Examine mill, Load 3-1/8" Mud motors into pipeshed (2) Organize floor for TIH Motor functional, bit showed no damage or wear. 667' - Circulate through BHA tools 3 BPM-540 Psi. Blow down Top drive and mud line. RIH F/667' - T/ 3,010' picking up 2 7/8" tubing from pipe shed. Circulate bottoms up @ 3,010' 120 gpm, 672 psi. up wt. 49k down wt. 55k. RIH F/3,010' - T/ 7,107' picking up 2 7/8" tubing from pipe shed. Tag cement stringer at 7,107'. M/U string to top drive establish circulation, 120 gpm, 670 psi, Tag stringer with 4k bit weight 300 psi differential. Begin to wash down F/7,107' (Joint #221 + 23.5' in). drill to 7,120", unable to progress beyond progress @ 7,201', saw 200 psi differential pressure but no drill off. Break EUE 8rd. X XT-39 Crossover out of tubing joint, Lay down tubing joint (# 223) TOOH F/7,199' - T/6,440' HSE Events:None reported. IFO.Wind chill -40 Operational Details (06:00 - 06:00) Pick up 4 3/4" mill, motor cleanout assembly. RIH picking up 2 7/8", 6.5# EUE tubing from pipe shed T/667'. 24 hour Forecast:TIH drill cement to DV clean out assembly. Drill pilot through DV Wind Direction: N.E. AM Temp: -20 Ops @ 06:00 hrs.: Rig prepping for TIH Phase: N/A Wind Speed: 10 24 hour Summary:Make up 4-3/4" BHA, RIH picking up 2-7/8' EUE 8rd tubing from pipeshed, Tag up on wiper plug and landing collar. Clean out to 7,201' , POOH, Lay down BHA inspect same, Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/18/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/14/22 3:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian & Al Hanson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 34 Phone 1 2.19.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 28 30.3 P.B.T.D.: From To Hrs. 6:00 9:30 3:30 6 9:30 14:00 4:30 6 14:00 15:00 1:00 2 15:00 17:00 2:00 5 17:00 17:30 0:30 5 17:30 18:00 0:30 6 18:00 19:30 1:30 2 19:30 20:00 0:30 2 20:00 20:30 0:30 5 20:30 21:00 0:30 5 21:00 23:30 2:30 6 23:30 24:00 0:30 6 Midnight 6:00 6:00 14 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 9 4 3/4 Milltooth 7199 Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 3.625 1.25 8RD EUE 1.25 3.06 1.25 174.80 3.125 1.25 12.19 3.7 1.25 11.80 4.75 1.25 0.96 4.75 1.25 0.47 Total Length (ft): 201.47 Milltooth bit Baker Hughes, roller cone, s# 7202 Mud Motor Crossover sub 6 X Spiral drill collars HE Jar AZ.Item Comment 324.99 Crossover sub Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Drill cement F/7,209' - T/7,224' with no difficulties no motor stalling, 20' to 30' ROP, 143 gpm,1,530 psi, 5-6k bit wt. Circulate, Pump dry job L/D Joint # 223, Break outXT-39 x 8rd EUE crossover, POOH F/7,206' racking back in derrick, to BHA 201' Lay down BHA # 9 Drain and clean stack with water, observed debris in hanger, pick up johnny wacker and flush stack with rig pumps, drain stack, still debris in hanger profile, Attempt to set packoff, No Go, packoff would not seat, pull out, found cement on bottom of pack-off, not allowing it to seat., Fill stack w/H-2/0 pull hanger to jet hanger area as it pulls out, hanger still packed with debris, Power washer rigged up & Run in stack, Power wash hanger area, Make up 4 3/4" bit, motor clean out BHA, RIH with 2 7/8" tubing from derrick. Drill out / clean out rubber, plug and cement F/ 7,201' to 7,206' work pipe observed overpulls and motor stalls on bottom @ 7,206' blow down top drive, pull 3 stands attempt to wipe BHA Run back to 7,206' Drill cement T/7,209' several motor stalls with little bit weight applied HSE Events:None reported. IFO.Wind chill -49 Operational Details (06:00 - 06:00) Service rig clean rig floor. 24 hour Forecast:Drill out cement from 7,224' to float collar @ 8,287'Wind Direction: South West AM Temp: -30 Ops @ 06:00 hrs.: Setting Pack-off into well head Phase: N/A Wind Speed: 9 24 hour Summary: Service rig gather tools, RIH with 4.75" bit and motor, clesn out to 7,224', POH, set well head pack off and test, Pick up Baker motor assembly with 4.75" bit, RIH T/7,199', drill cement F/7,199' - T/7,224', POH, lay down DC's motor and bit.attempt to set well head pack off. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/18/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/14/22 3:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hanson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 35 Phone 1 2.20.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 29 30.3 P.B.T.D.: From To Hrs. 6:00 12:00 6:00 21 12:00 14:00 2:00 21 14:00 16:30 2:30 21 16:30 18:00 1:30 6 18:00 20:30 2:30 6 20:30 1:00 4:30 2 1:00 6:00 5:00 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 9 4 3/4 Mill tooth 7199 Time Depth MW PV YP Mud Gas Readings:Used 6:00 7238 9.2 5 17 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 3.625 1.25 8RD EUE 1.25 3.06 1.25 174.80 3.125 1.25 12.19 3.7 1.25 11.80 4.75 1.25 0.96 4.75 1.25 0.47 Total Length (ft): 201.47 Mill tooth bit Baker Hughes, roller cone, s# 7202 Mud Motor Crossover sub 6 X Spiral drill collars HE Jar AZ.Item Comment 324.99 Crossover sub Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 66 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Continue cleaning and washing wellhead to set pack-off, Set pack-off into hanger, would not land, pull pack-off. Test pack-off to 250 psi / 4,500 psi, chart, good test. Rig down tools blow down lines and top drive. Pick up and make up 4 3/4" bit and motor assembly, RIH with 2 7/8" tubing from derrick t/ 850' Continue RIH f/ 850' to 7,223', After several motor stalls begin drilling f/ 7,223' to clean out depth of 7,224.Drill cement from 7,224' to 7,228'. From 7,228 to 7,231 test casing to 500 psi every foot drilled, from 7,231' to 7,238' test casing to 500 psi every 2' drilled. No communication observed @ 9 5/8" x 5 1/2" annulus during tests. Drilling off bottom psi =672 psi @ 120 gpm. 74k up 76K dn wt. Drilling @ 7,238' motor stalling, drilling difficult, work drilling parameters to make progress, observed aluminum and cement returns @ shakers. Cleaning out hanger profile, Make up pressure washer, run into stack and pressure wash hanger would not land, pick up mill pipe, wash hanger cleared debris, set pack off, RILDS HSE Events:None reported. IFO.Wind chill -63 Operational Details (06:00 - 06:00) 24 hour Forecast:Drill DV collar, test casing, drill and clean out to casing float collar @8,286'Wind Direction: ENE AM Temp: -43 Ops @ 06:00 hrs.: Drilling junk and cement @ 7,238'Phase: 0 Wind Speed: 5 24 hour Summary:Clean hanger, set and test well head pack off, pick up 4 3/4" bit and motor assembly, RIH on 2 7/8" tubing to 7,224', drill cement testing casing every 1 to 2 foot, to 7,238'. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/202022 6:00:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/14/22 3:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hanson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 36 Phone 1 2.21.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 30 30.3 P.B.T.D.: From To Hrs. 6:00 9:30 3:30 2 9:30 11:45 2:15 2 11:45 12:00 0:15 2 12:00 14:30 2:30 2 14:30 14:45 0:15 2 14:45 18:00 3:15 2 18:00 24:00 6:00 2 Midnight 6:00 6:00 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 9 4 3/4 Mill tooth 7199 Time Depth MW PV YP Mud Gas Readings:Used 21:00 8,376' 9.2 7 24 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 3.625 1.25 8RD EUE 1.25 3.06 1.25 174.80 3.125 1.25 6.56 3.7 1.25 2.27 3.125 1.25 1.15 3.7 1.25 10.73 4.75 1.25 0.96 4.75 1.25 0.50 Total Length (ft): 198.22 Mill tooth bit Baker X-Treme mud motor Baker Hughes, roller cone, s# 7202 Crossover sub TJ Disconnect Circulating sub 6 X Spiral drill collars G Force jar AZ.Item Comment 324.99 Crossover sub Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 46 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments:AOGCC notified for BOPE test 2/20/2022 @ 10:00 AM, **Witness waived by AOGCC Inspector Matt Herrera @15:07, 2/20.22 Drill cement f/ 7,518' t/7,777' circulating/clean well head and stack each connection. 120 gpm = 1,260 psi, 5k wob 200 psi differential Drill cement F/7,238' - T/ 7,250' 2-5k WOB 120 gpm, 735 psi Test 500 psi on outer annulus. No leak detected in O.A. Drill cement F/7,250' - T/ 7,251' 2-5k WOB 120 gpm, 200-300 differential pressure on motor. 735 psi Test 500 psi on outer annulus. No leak indetected in O.A. Drill cement F/7,251' - T/ 7,291' 2-5k WOB 120 gpm, 735 psi, (200-300 differential pressure on motor.) Circulate through kill line to increase annular velocity in BOP stack, Large cuttings load increase visible at shakers. 6 bbl's minute rate. Drill cement f/ 7,291' t/ 7,355' Drill cement f/ 7,355' t/7,518', circulating/clean well head and stack each connection. 120 gpm with 765 / 800 psi. 2/5K wob. 75k dn 74k up wt. 2 7,552' pump pressere increased to 1,230 psi (plugged jet). HSE Events:None reported. IFO.Wind chill -25 Operational Details (06:00 - 06:00) Drill cement F/7,237' - T/ 7,238' 2-5k WOB 120 gpm, 735 psi Test 500 psi on outer annulus. No leak detected in O.A. 24 hour Forecast:Drill and clean out casing to float collar @ 8,287', POH, perform CBL.Wind Direction: ESE AM Temp: -21 Ops @ 06:00 hrs.: Drilling cement @ 7,777'Phase: 0 Wind Speed: 5 24 hour Summary:Drilling cement with 4 3/4" bit in 5 1/2" casing f/ 7,237' to 7,777' Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/21/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/14/22 3:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hanson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 37 Phone 1 2.22.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 31 30.3 P.B.T.D.: From To Hrs. 6:00 12:00 6:00 2 12:00 17:00 5:00 2 17:00 19:30 2:30 5 19:30 23:30 4:00 6 23:30 24:00 0:30 15 Midnight 1:00 1:00 15 1:00 2:00 1:00 21 2:00 6:00 4:00 15 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in 9 4 3/4 Mill tooth 7199 8,285' 1,068 Time Depth MW PV YP Mud Gas Readings:Used 21:00 8,285' 9.4 6 22 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 3.625 1.25 8RD EUE 1.25 3.06 1.25 174.80 3.125 1.25 6.56 3.7 1.25 2.27 3.125 1.25 1.15 3.7 1.25 10.73 4.75 1.25 0.96 4.75 1.25 0.50 Total Length (ft): 198.22 BHA Laid down at 23:30 2/21/22 Mill tooth bit Baker X-Treme mud motor Baker Hughes, roller cone, s# 7202 Crossover sub TJ Disconnect Circulating sub 6 X Spiral drill collars G Force Jar AZ.Item Comment 324.99 Crossover sub Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 Vis 0 Available 40 Background (Avg) % 0 Mud Properties Gas Details Fuel Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition 7202 2-2-0-NO-A-E-TD Total Hours 24:00 Comments:AOGCC notified for BOPE test 2/20/2022 @ 10:00 AM, **Witness waived by AOGCC Inspector Matt Herrera @15:07, 2/20.22 Test BOPE 250 low / 4,500 psi high, Annular 250 low 2,500 high, on 2 7/8" test joint. All tests charted. Drill cement f/ 8,038' t/8,285'. 2.5' above float collar. 120 gpm = 1,260 psi, 5k wob 200 psi differential * circulating/clean well head and stack every 3rd. Connection* Circulate cement cuttings out of wellbore, circ hole clean, pump dry job. POH, Stand back 2 7/8" tubing, lay down drill collars and clean out BHA. Test choke manifold 250 / 4,500 psi. Set T.W.C. Continue testing choke manifold 250 low/ 4,500 high Flush stack with wash tool, drain stack, fill with water. HSE Events:None reported. IFO.Wind chill -5 Operational Details (06:00 - 06:00) Drill cement f/ 7,777' t/8,038' . 120 gpm = 1,260 psi, 5k wob 200 psi differential * circulating/clean well head and stack every 3rd. Connection* 24 hour Forecast:Complete BOP test, lay down 4" Dp, Rig up E-Line for CBL logs.Wind Direction: SSE AM Temp: 5 Ops @ 06:00 hrs.: Testing BOPE per AOGCC and Great Bear Pantheon expectations.Phase: N/A Wind Speed: 13 24 hour Summary:Drill cement f/7,777' t/8,285' - 3' from top of float collar. Circulate clean, TOOH, Rig up & test BOPE. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/22/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/22/22 7:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hanson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration 38 Phone 1 2.23.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 33 30.3 P.B.T.D.: From To Hrs. 6:00 12:00 6:00 15 12:00 18:00 6:00 11 18:00 22:00 4:00 11 22:00 24:00 2:00 11 Midnight 6:00 6:00 11 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 8450 9.4 6 22 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hanson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/22/22 7:00 AM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/22/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: Ops @ 06:00 hrs.: Rigging down SBL E-Line Phase: 0 Wind Speed: 22 24 hour Summary:Testing BOPE, rig up Schlumberger E-Line & perform CBL log, Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -19 Operational Details (06:00 - 06:00) Continue testing BOPE, 250/4,500 psi. upper VBR pipe rams would not test, Change out top rams with bottom rams. 24 hour Forecast:Lay down 4" DP from derrick out of mouse hole.Wind Direction: West AM Temp: 8 Continue testing BOPE, Installed 2-7/8" X 5-1/2" rams in bottom. Top rams good test, Bottom rams did not test. New rams are being sourced. Continue logging operation, perform USIT, CBL, Spectrial Gamma, CCL from 8,224' to 5,400' , Continue logging operation, perform USIT, CBL, Spectrial Gamma, CCL from 8,224' to 5,400' , repeat pass, POH, rig down SBL wire E- line. Schlumberger on location, rig up for running logs to perform USIT, CBL, Spectrial Gamma, CCL. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available 41 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 324.99 Total Length (ft): 0.00 39 Phone 1 2.24.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 34 30.3 P.B.T.D.: From To Hrs. 6:00 6:30 0:30 21 6:30 7:00 0:30 21 7:00 8:00 1:00 22 8:00 9:30 1:30 16 9:30 10:00 0:30 21 10:00 14:30 4:30 22 14:30 16:30 2:00 15 16:30 17:00 0:30 15 17:00 22:00 5:00 22 22:00 24:00 2:00 5 Midnight 6:00 6:00 5 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hanson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig / Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Jake Henry Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/22/22 7:00 AM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/22/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: Ops @ 06:00 hrs.: Bleed well from circulating annulus, monitor returns,Phase: N/A Wind Speed: 9 24 hour Summary: Rig down SBL CBL logging tools, lay down 4" out of derrick from mousehole, attempt to set casing packer, confirmed DV open, install rams in lower body and test, continue laying down 4' drill pipe, circulate 5 1/2" X 9 5/8" annulus for cement job. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -26 Operational Details (06:00 - 06:00) R/D wireline Sheaves, Send down Logging tools. 24 hour Forecast:Monitor returns, Pick up and make up 5 1/2" CIBP, RIH on 2 7/8" tubing to 7,127' set and cement per plan.Wind Direction: NE AM Temp: -13 Pull TWC, blow down surface lines, rig down test equipment. Lay down 4" drill pipe out of derrick from mouse hole. Rig up to circulate 9 5/8' X 5 1/2' annulus Pump down 5 1/2' casing with 9 5/8" annulus to pits, 1/2 bpm = 1,120 psi, pump 10 bbl, no returns. Swap lines to pump down annulus, pump 38 bbl @ 2 bpm, no returns. Swap back to pumping down 5 1/2" casing, stage pumps up to 2 bpm observed returns, 2 bpm @ 1,335 psi 70% losses temp 41° returns. Return losses reduces to 25% @ 43° returns. Increase rate to 3 bpm @ 1,370 psi, began with 36% losses reducing to 13% with 65° returns. increase rate to 4 bpm @ 1,390 psi, with 13% losses. 9.2# in 9.2# out, losses reduced t/ 7.5% @ 4 bpm @1,255 psi. @ 70°. Increased pump rate to 5 BPM @ 1,329 psi. initial losses 37%, losses reduced to FCP of 1,295 with 7% losses @ 77° . Total losses to hole circulating 245 bbl. 108 bbls mud volume at end of circulating. Blow down choke & Kill line, Clear & Clean floor, Prep to lay down 4" from Derrick Lay down 4" Drillpipe from derrick. Rig up to inflate downhole inflatable packer, Close blind rams pump down kill line attempt to obtain 1,500 psi to inflate packer. Pressure bleed off at 1,300 psi. Open 9-5/8" X 5-1/2" Annulus valve confirm flow. Confirming D.V. collar is open. Blow down Kill and surface lines. Lay down 4" drill pipe from derrick. Drain stack, install 2 7/8" rams in lower sng. gate, fill stack with water, test lower rams to 250/4,500 psi. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments:Load pipe shed with 43 joints 3 1/2" 9.2 # L-80 Vam Top liner. Vis 0 Available Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 324.99 Total Length (ft): 0.00 40 Phone 1 2.25.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 35 30.3 P.B.T.D.: From To Hrs. 6:00 7:30 1:30 5 7:30 8:30 1:00 5 8:30 12:00 3:30 6 12:00 14:00 2:00 6 14:00 17:00 3:00 5 17:00 19:00 2:00 5 19:00 21:00 2:00 5 21:00 21:30 0:30 5 21:30 24:00 2:30 6 Midnight 2:30 2:30 6 2:30 6:00 3:30 6 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 8450 9.2 6 20 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 4.73 na 2 3/8" reg 1.47 3.13 na 2 3/8" reg 10.73 3.13 0.69 2 3/8" reg 1.15 3.13 0.81 3 3/8" reg 2.27 3.13 1.25 2 3/8" reg 6.56 3.38 1 2 3/8" reg X 2 3/8" IF pin 0.62 3.4 1.65 2 3/8" IF 172.07 3.38 1.62 2 3/8 reg X 2 3/8" IF pin 0.66 3.625 1 2 7/8 eue box X 2 3/8" pin 0.71 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Al Hanson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/22/22 7:00 AM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/22/2022 18:00:00 PM Casing: Conductor Surface Intermediate Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: Ops @ 06:00 hrs.: T.I.H. @ 7,067'Phase: 1.5 Wind Speed: 40 24 hour Summary:Monitor well returns, RIH with 5 1/2" CIBP, set and cement, POH, lay dn set tool, Pick up 4.73" junk milling assembly, RIH on 2 3/8" tubing. t/ 6,308 Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -34 Operational Details (06:00 - 06:00) Shut down pumping monitor returns. Returned 126 bbls in 1 hour, continue monitoring returns, Total mud returned 128 bbl 24 hour Forecast:Drill CIBP @ 7,127', clean out 5 1/2" casing to 8,285'. change over well to 3% KCL brine. POH, E-Line CBL .Wind Direction: ENE AM Temp: -12 Pump dry job POH lay down CIBP setting tool. Pick up and make up Baker motor 4.73" 5 blade junk, milling assembly and 6 each 3.4" OD DCs. RIH with 4 3/4" milling assembly t/ 6,308' Rig down and blow down surface lines Pick up CIBP and setting tool, RIH to 3,384' Continue RIH with 5 1/2" CIBP to 7,127' Pump down tubing 1 bpm @ 438 psi, stop pumping, drop ball, rig up surface lines to circ. Set CIBP with 2,127 psi. stage pumps up to 2,491 psi, set 25K down on CIBP. Rig up SLB cementers, pump 5 bbl. water, test lines to 4,500 psi. pump 36.1 bbl 9.8# mud push, 70.6 bbl 13# lead cement, 41.8 bbl 15.8# tail, displace with 40.7 bbl water. CIP 19:00 hrs. Unsting from CIBP with 670 psi on tubing, 75K up wt. Pull up to 7,098' circ. hole surface to surface @ 6 bpm @ 2,300 psi. No cement returns, (max PH = 11.5 @ 10.2#) Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available 41 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 X-Treme mud motor Dual Circ Sub AZ.Item Comment 324.99 5 Blade Junk Mill X O 6 each, DC TJ Disconnect G-Force jar X O X O Total Length (ft): 196.24 41 Phone 1 2.26.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 36 30.3 P.B.T.D.: From To Hrs. 6:00 8:00 2:00 6 8:00 9:00 1:00 21 9:00 10:45 1:45 22 10:45 12:00 1:15 21 12:00 14:30 2:30 21 14:30 24:00 9:30 23 Midnight 2:00 2:00 23 2:00 3:00 1:00 21 3:00 5:00 2:00 21 5:00 6:00 1:00 6 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 845 9.4 8 20 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 4.73 na 2 3/8" reg 1.47 3.13 na 2 3/8" reg 10.73 3.13 0.69 2 3/8" reg 1.15 3.13 0.81 3 3/8" reg 2.27 3.13 1.25 2 3/8" reg 6.56 3.38 1 2 3/8" reg X 2 3/8" IF pin 0.62 3.4 1.65 2 3/8" IF 172.07 3.38 1.62 2 3/8 reg X 2 3/8" IF pin 0.66 3.625 1 2 7/8 eue box X 2 3/8" pin 0.71 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/22/22 7:00 AM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/22/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: Ops @ 06:00 hrs.: RIH with motor/ mill clean out assembly @ 7,832'Phase: N/A Wind Speed: 25 t/ 30 24 hour Summary:P/U Milling assembly, TIH, Mill cement & Retainer, Wait on weather, resume drilling cement. t/ 7,218' RIH Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -23 Operational Details (06:00 - 06:00) TIH F/6,308' tag cement at 7,113' 14' of cement on top of retainer. 1/4 bbl. Was dropped out of pipe when stinging out of retainer 24 hour Forecast:Clean out cement to float collar, circ hole clean, change over well to 3% KCL brine. POH, rig up SBL to run CBL.Wind Direction: ENE AM Temp: -10 Winds subsiding, visibility >1/2 mile, coms up, resume rig operations. Lay down singles from string, run stands out of derrick to drill. Drill cement f/ 7,161' t/ 7,218' 3 - 5 K wob.120 gpm @ 1,100 psi, off bottom 1,400 /1,300 psi on bottom psi. Wash to 7,250' Blow down top drive, RIH on elevators t/ 7,832' Drill cement F/ 7,113' - T/ 7,126' 107 gpm, 992 psi, 2-4k bit wt. up wt. 72k, down wt. 75k. Drill retainer 2-6k bit weight, 125 gpm, 1,565 psi. Retainer 7,126'- 7,128' Drill cement F/ 7,128' - T/ 7,129' 120 gpm, 1,280 psi, 3-5 k bit wt. Drill cement F/ 7,129' - T/ 7,161' 120 gpm, 1,450 psi, 3-5 k bit wt. 330 psi differential pressure on mud motor. Stop operations due to weather, Extreme high wind, Low visibility, Snow drifting, No ice road travel due to road conditions. Continue with no rig operations, limited visibility, no coms or road access due to high winds and blowing snow. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available 41 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 X-Treme mud motor Dual Circ Sub AZ.Item Comment 324.99 5 Blade Junk Mill X O 6 each, DC TJ Disconnect G-Force jar X O X O Total Length (ft): 196.24 42 Phone 1 2.27.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 37 30.3 P.B.T.D.: From To Hrs. 6:00 7:30 1:30 6 7:30 9:00 1:30 5 9:00 13:00 4:00 21 13:00 18:00 5:00 5 18:00 21:00 3:00 5 21:00 23:30 2:30 5 23:30 2:30 3:00 6 2:30 4:00 1:30 6 4:00 6:00 2:00 11 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 8450 9.4 8 20 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 4.73 na 2 3/8" reg 1.47 3.13 na 2 3/8" reg 10.73 3.13 0.69 2 3/8" reg 1.15 3.13 0.81 3 3/8" reg 2.27 3.13 1.25 2 3/8" reg 6.56 3.38 1 2 3/8" reg X 2 3/8" IF pin 0.62 3.4 1.65 2 3/8" IF 172.07 3.38 1.62 2 3/8 reg X 2 3/8" IF pin 0.66 3.625 1 2 7/8 eue box X 2 3/8" pin 0.71 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Al Hanson Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/22/22 7:00 AM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/27/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: Ops @ 06:00 hrs.: Rigging SBL for logs Phase: 0 Wind Speed: 22 24 hour Summary:Clean put 5 1/2" casing to 8,284', circulate, change well over to 3% KCL, POH, Rig up SBL E-Line. Weather Gen Conditions: Partly cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported, IFO Wind chill -20 Operational Details (06:00 - 06:00) Continue RIH on elevators F/ 7,832' with 4 3/4" mill and motor clean out assembly T/ 8,256' Wash down F/ 8,256' - T/ 8,284' 120 gpm, 1,246 psi. 24 hour Forecast:Complete CBL log, test BOP with 3 1/2", pick up 3 1/2" liner and setting tools, RIH, set and cement liner per program. Wind Direction: E AM Temp: -9 Lay down clean out BHA #12. Rig up SBL E-Line for CBL, USIT, MSIP. Circulate any excess cement cuttings out of hole @ 120 gpm 1,240 psi. 3,038 strokes pumped. Blow down top drive & mud lines. Install TIW valve. Wait on roads to be cleared of snow drifts caused by high winds for Vac truck with Brine. Drop ball to open circulating sub in string. Circulate while cleaning pit and making spacer pill. Continue cleaning pits, mix high vis spacer. Change over well bore to 3% KCL, pump 35 bbl high vis spacer, pump KCL to surface. 5 bpm @ 2,140 psi. POH, standing back 2 7/8" tubing. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available 40 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 X-Treme mud motor Dual Circ Sub AZ.Item Comment 324.99 5 Blade Junk Mill X O 6 each, DC TJ Disconnect G-Force jar X O X O Total Length (ft): 196.24 43 Phone 1 2.28.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 38 30.3 P.B.T.D.: From To Hrs. 6:00 14:00 8:00 21 14:00 22:00 8:00 15 22:00 6:00 8:00 11 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 8,285' 8.45 2 1 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/22/22 7:00 AM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/22/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: Ops @ 06:00 hrs.: Rigging down SLB logging Phase: 0 Wind Speed: 10 24 hour Summary:Trouble Logging, Trouble testing BOPE, SBL log, Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -22 Operational Details (06:00 - 06:00) Computer malfunction in wireline unit. Replace computer. 24 hour Forecast:Pick up Baker 3 1/2" liner tools, pick up 3 1/2" liner, RIH, set and cement liner.Wind Direction: SW AM Temp: -5 Set Two way check , Test upper rams with 3-1/2" test joint. Would not test, Pull Test joint, Attempt to test blind rams would not test, Attempt to pull two way check for inspection, Debris on top of two way check, Suck out stack run power washer in on T-Bar to dislodge debris from top of two way check, attempt to pull two way check, Would not pull. Repeat process until two way check pulled. Logging with SBL E-Line for CBL, USIT, MSIP. Running in hole encountered obstruction @ 7,770' wlm, pulled free with 8K over pull, log up from 7,740' wlm. Run repeat pass. POH with E-Line tools. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available 27 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 324.99 Total Length (ft): 0.00 44 Phone 1 3.1.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 14 8,450' ft 0ft 39 30.3 P.B.T.D.: From To Hrs. 6:00 8:30 2:30 11 8:30 11:30 3:00 15 11:30 14:00 2:30 12 14:00 15:30 1:30 12 15:30 21:00 5:30 5 21:00 23:00 2:00 6B 23:00 1:00 2:00 12 1:00 2:00 1:00 12 2:00 2:30 0:30 5 2:30 3:30 1:00 12 3:30 6:00 2:30 6B 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 8,285' 8.45 2 1 Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/23/2022 17:00:00 PM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# 3 1/2" Last Safety Mtg: 3/1/22 6:00 AM Casing: Conductor Surface Intermediate Tie Back liner Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' 8,376' 8,277 Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,284 Last Rig Insp.: Ops @ 06:00 hrs.: Laying down liner running tool.Phase: 0 Wind Speed: 3 24 hour Summary:Finish SBL CBL E-Line logs, test BOP upper rams and annular with 3 1/2" test joint. Pick up and run 3 1/2" liner, cement liner in place, clean hole, POH. Lay down liner running tool. Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na na HSE Events:None reported. IFO.Wind chill -1 Operational Details (06:00 - 06:00) Wireline logging, Repeat pass, T.O.O.H. with logging tools on wireline. Rig down, lay down tools from run. 24 hour Forecast:Pick up liner packer with seal assembly, RIH, stab into liner top, set packer and test packer and liner to 3,500 psi, POH laying down 2 7/8" tubing. Freeze protect 5 1/2" casing Wind Direction: E AM Temp: -1 Rig up cementers, pump 10 bbl h2o, PT lines to 4,500 psi, batch and pump 16 bbl #15.8 cement followed with 55 bbl 3% KCL, pick up 15 to expose dog assembly from the 3" seal bore, slack off set 10K wt. 10' higher in tool, set pump trips for 1,500 psi, launch "Pee Wee" dart, hold pressure, pick up to open Side Exhaust Ports (indicated by loss of pressure), pump 5 bbl, (2.5 bbl cmt. through exhaust ports), slack off close exhaust port, pick up liner wiper plug, bump plug with10.5 bbl , with 2,700 psi, open bleeder check floats, holding, pressure up to 1,500 psi, pull out of tool, (indicated by loss of pressure). pump 5 bb. with cement unit to clear liner tools of cmt., switch to rig pumps. CIP @ 02:13. Circulate bottoms up with rig pumps @ 5 bpm @ 1,720 psi. Indications of cement contamination @ bottoms up. Rig down and blow down cement and surface lines. POH with 2' liner running tool, standing back 2 7/8" tubing work string lay down liner running tool. Test upper 2-7/8" X 5-1/2 Variable pipe rams 250 psi low , 4,500 psi high with 3-1/2" test joint, 10 min. per test test charted, Test Annular 250 psi low, 2,500 psi high, 10 min per test charted. (All tests good.) R/U and run 38 joints 3-1/2" 9.2# Vam top liner. Shoe track assembly with liner deployment sleeve. (1,243.51') RIH with completion liner on 2-7/8" tubing from derrick f/ 1,243' t/ 8,000' Prep for cement and blow air through surface lines. Rig up manifold for cement job. (Cement unit delayed due to mechanical issues, arrived on location @ 20:00) RIH with liner f/ 8,000' , tag at 8,275', wash to hard bottom @ 8,277'. 2.5 bpm @ 758 psi. Drop 5/8" ball to set BSE Liner Running Tool, let fall 30 min, pump @ 1 bpm 3 bpm @167 psi, raise rate to 2 bpm @ 463 psi, 3 bpm @ 780 psi, circ 1.5 tubing volume with no indication of ball on seat. Drop 3/4" ball, seat and set BSE-LRT with 2,600 psi. TOL = 7,033' Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments:3 1/2" Liner top set @ 7,033' 3 1/2" shoe set @ 8,277' Vis 0 Available 27 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 324.99 Total Length (ft): 0.00 45 Phone 1 3.2.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 40 30.3 P.B.T.D.: From To Hrs. 6:00 11:00 5:00 6 11:00 12:30 1:30 21 12:30 12:45 0:15 21 12:45 15:30 2:45 6 15:30 16:30 1:00 21 16:30 17:00 0:30 6 17:00 18:30 1:30 5 18:30 24:00 5:30 6B Midnight 6:00 6:00 14 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used 21:00 8,285' 8.45 2 1 Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/22/22 7:00 AM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 2/22/22 6:00 AM Casing: Conductor Surface Intermediate Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: Ops @ 06:00 hrs.: Nipple down BOPE Phase: 0 Wind Speed: 5 24 hour Summary: RIH with 5 1/2" liner tie back packer and seal assembly, set and test pkr and casing, POH laying down 2 7/8" tubing, freeze protect well with diesel, continue POH laying down 2 7/8" tubing work string. Set TWC, nipple down BOPE. Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -9 Operational Details (06:00 - 06:00) R.I.H. with production packer T/7,026' 70k up 75k down wt. 24 hour Forecast:Nipple down BOPE, nipple up frac tree, rig down and prep rig to move to Deadhorse.Wind Direction: SSW AM Temp: 5 POH laying down 2 7/8" tubing. Set Two Way Check, nipple down BOPE. Set packer hydraulically with 2,200 psi. Pull test 40k over (115k) Stack wt. (30k) Verifying packer set. Space out in stack, Close top pipe rams, Attempt to test casing and packer pumping down kill line, Fluid returning up tubing string once pressure reached 1,120 psi. Release from Production packer with 20 revolutions to the right. Pick up with no overpull verifying string off packer. Blow down top drive, choke & kill lines. Lay down 2-7/8' T.O.O.H. to pipeshed, F/6,996' - 4,955' Test 5-1/2" Casing and production packer T/3,500 psi - 30 minutes, Charted test. Run 10 stands F/Derrick in the hole F/4,955' - T/5,915' R/U Little Red pump 32 bbls. Diesel for freeze protect, Chase with 17.5 bbls. Brine. Blow down all circulating lines. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available 27 Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 324.99 Total Length (ft): 0.00 46 Phone 1 3.3.22 Phone 2 Tool Pusher (N): 69 API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 14 18:00 6:00 12:00 2 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP 1 Triplex 5.5 60 97 1 2 Triplex 5.5 60 97 2 MD TVD Inc.OD ID Conn. Length 8370 8369.03 0.8 Report #: Supervisor (D): Mark Brouillet (907) 631-9850 Tool Pusher (D): Brian Pederson Report Date: Daily Drilling Report Well Name:THETA WEST #1 Rig/Contractor: Nordic #3 Well Type: Exploration Supervisor (N): Paul Smith Al Hansen Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Spud: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Spud to TD): GL, ft Progress: Cum. Cost: Spud Date: 1/22/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" Last BOP Test: 2/22/22 7:00 AM OD/Weight 20"/129# 9-5/8" / 40# 5½" / 17# Last Safety Mtg: 3/3/22 5:30 AM Casing: Conductor Surface Intermediate Last BOP Drill: 1/10/22 Actual Depth: 75' 3,030' 8,376' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' Last Rig Insp.: Ops @ 06:00 hrs.: Prep rig for move rig off well.Phase: 0 Wind Speed: 5 24 hour Summary:Nipple down BOPE, nipple up Frac tree, pull TWC, top off tree with diesel for freeze protect, Rig down prep to move rig off well. Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -3 Operational Details (06:00 - 06:00) Continue nipple down BOPE. Set BOPs back on rig stump. Nipple up 5" Frac tree, freeze protect with diesel, test tree to 5,000 psi, 10 min test Good, Pull BPV. Install 1002 cap. Secure well. 24 hour Forecast:Move rig off well, pick up matting boards, continue to prep rig for demobe to Deadhorse. Move rig down ice road.Wind Direction: S AM Temp: -3 Clear cellar and pipe shed of GBP tools and equipment. Warm up moving system. Clean cellar and rig of fluids. Remove rig containment, blow down cellar and substructure. Prep to move rig off well. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available Background (Avg) % 0 Mud Properties Gas Details Fuel Pump Data Slow Pump Rates Model Continental Emsco Continental Emsco Surveys BHA Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment 324.99 Total Length (ft): 0.00 SECTION 3. Daily Completion Reports 1 Phone 1 3.7.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: OD/Weight 20"/129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Continue moving operations to Theta West pad. Spotting frac tanks, CT, & finalize Expro equipment (75% rigged up). Cruz moving heaters to Theta & grooming snow as equipment is removed. Phase: 0 Wind Speed: 5 24 hour Summary:Begin moving operations to Theta West location from Talitha location. Theta location cleaned & graded. Walked pad & spotted for new rigup. Validated rigup for Yellowjacket wireline & equipment/function for slim hole tools. Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO. Wind chill -16 Operational Details (06:00 - 06:00) Load remaining drilling equipment on Theta West onto trailers & load out. Clean/groom pad. Begin moving Expro compound/tanks & SLB coiled tubing. Go to Deadhorse & confirm parts & function with Yellowjacket regarding slimhole plugs/setting tools. 24 hour Forecast:Finalize moving Ops to Theta West pad. Rig up SLB Frac as much as possible. Begin moving teardown of Camp Kickass & move all comms/supplies to Galena Camp. Wind Direction: N AM Temp: -5 Continue Expro rigup on Theta pad. Move heaters & light plants to Theta. Groom Talitha & prep for camp move. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Comments: Vis 0 Available Background (Avg) % 0 Mud Properties Gas Details Fuel Connection % 0 Trip Gas % 0 Volume Delivered: 0 AZ.Item Comment Pump Data Slow Pump Rates Model Surveys BHA Total Length (ft): 0.00 2 Phone 1 3.8.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Flowback rigging up on Theta, fueling & location grooming Ops Phase: 0 Wind Speed: 11 24 hour Summary:Continue relocation operations to Theta West. Only Lil Red, one Expro tank & some dunnage remain at Talitha location. Expro 80% in place & rigged up. Theta location clean, graded & wellhead clear Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO. Wind chill -23 Operational Details (06:00 - 06:00) Theta location cleared & groomed. Expro 80% in place. Continue moving Talitha to Theta location. Only co man camp, lil read & single Expro tank remain at Talitha. 24 hour Forecast:SLB frac to set tanks, sand bins & spot available units. Expro to get 100% rigged up. YJ Wireline set to AOL to perforate BFF Stage 1(8065-75'). Will run temp survey & gauge ring then perforate. Pump small DFIT after Wind Direction: SW AM Temp: -5 Total Hours 24:00 Spot CT unit @ wellhead. Continue moving locations. Fueling available units. Cruz maintaining road & moving light plants/heaters to next location. Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 3 Phone 1 3.9.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 11:00 5:00 11:00 21:00 10:00 21:00 1:00 4:00 1:00 6:00 5:00 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 RIH w/2.75" GR to 8170' (no stick); RIH w/2.5" temp tool (Temp @ perfs - 186 deg). POOH & test casing/tree w/CT. Good test Receive sundry approval. RIH to perf BFF Stg 1 (8065-8075). Good run. POOH & JWL RDMO. Prep for DFIT in am. Groom location. Fuel units. Expro continue rigging up. HSE Events:None reported. IFO. Wind chill -19 Operational Details (06:00 - 06:00) Finalize move to Theta. MIRU Yellowjacket wireline. AM calls. 24 hour Forecast:Pump DFIT on BFF Stg 1. Shut-in well w/crystal gauge. Frac to spot liner/tanks & begin loading sand. Finalize rig up as much as possible Wind Direction: SW AM Temp: -3 Ops @ 06:00 hrs.: SLB frac & Lil Red en route. RU to pump small DFIT on Stage 1 & monitor w/crystal gauge. Groom roads & pads from small blow last evening Phase: 0 Wind Speed: 10 24 hour Summary: Finalized movd to Theta pad. Expro 90% rigged up. CT spotted & 80% rigged up. YellowJacket WL AOL. RIH to 8170 with 2.75" GR, then 2.5" temp tool. POOH. Test casing & WH to 7500 with CT. Good test. RIH & perforate 8065'-8075'. Good shot-no change in WH PSI. YJ WL RDMO Weather Gen Conditions: Cloudy Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration 4 Phone 1 3.10.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 16:00 10:00 16:00 20:00 4:00 20:00 6:00 24:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Grooming roads. Fueling units. Expro moving heaters in place. Moving from Company Man camp to Galena Camp Phase: 0 Wind Speed: 10 24 hour Summary: Rigged up SLB pump float for pump-in/DFIT. Added crystal gauge near wellhead for standalone recording. Spotted frac tanks on liner. Pumped 40 bbls 3% KCl for DFIT. Open well @ 47 psi. ISIP @ 1538 psi (0.63 FG). RD CT float pump & shut in well with leg to gauge open. Weather Gen Conditions: Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO. Wind chill -19 Operational Details (06:00 - 06:00) Rig up float pump next to CT for DFIT pump-in. SLB AOL to set tanks & liner. 24 hour Forecast:Finish frac rigup without iron (40%). Fill sand bins for BFF Stg 1. Discuss KCl water for frac with Swaco Wind Direction: SW AM Temp: -3 Total Hours 38:00 Pumped DFIT. Added crystal gauge & shut-in well with leg open to gauge. No activity Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 5 Phone 1 3.11.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: No activity Phase: 0 Wind Speed: 10 24 hour Summary:Moved from Talitha camp to Theta camp. Rigging down portion of Talitha camp. Multiple conference calls. SLB finished available rigup & set tanks/liner/berms. Set KCl plan for tank loading Weather Gen Conditions: Mostly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO. Wind chill -36 Operational Details (06:00 - 06:00) Move down from Talitha. SLB on location finalizing available rigup & setting tanks/berms. SLB off location. 24 hour Forecast:No activity planned. Frac rigged up to extent of iron. Expro rigged up. Tanks set - will fill with 4% KCl on 3/13/22.Wind Direction: NE AM Temp: -16 Total Hours 24:00 No activity Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 6 Phone 1 3.12.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 No activity HSE Events:None reported. IFO. Wind chill -36 Operational Details (06:00 - 06:00) No activity 24 hour Forecast:SLB to move more units onto location Wind Direction: NE AM Temp: -16 Ops @ 06:00 hrs.: No activity planned. Waiting on update from SLB regarding iron testing Phase: 0 Wind Speed: 10 24 hour Summary:Continue grooming location & rigging up for Frac Stage 1. Begin partial teardown of Talitha camp Weather Gen Conditions: Mostly Cloudy Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration 7 Phone 1 3.13.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 No activity HSE Events:None reported. IFO. Wind chill -47 Operational Details (06:00 - 06:00) SLB brought units to location. 24 hour Forecast:SLB to spot remaining equipment. Begin loading KCl water into tanks in afternoon. Prep for frac on 3/14 Wind Direction: NE AM Temp: -26 Ops @ 06:00 hrs.: No activity. Ops pending SLB update on iron certification Phase: 0 Wind Speed: 10 24 hour Summary:SLB brought 5 pumps to location & spot. Continue partial teardown @ Talitha. Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration 8 Phone 1 3.14.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: SLB began rigup @ 5:30 am. Fueling trucks & grooming roads Phase: 0 Wind Speed: 16 24 hour Summary:Talitha teardown complete. Only comms shack remains. SLB arrived with chemical units & diesel transport. Spotted trucks & pumps. Begin hauling 4% KCl for frac stage 1. Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO. Wind chill -30 Operational Details (06:00 - 06:00) SLB brought chemical units to location & spotted trucks. Started hauling 4% KCl water. 24 hour Forecast:Finish frac rigup & top off frac water tanks. Remove gauge & rigup tree. Frac BFF Stage 1 Wind Direction: NE AM Temp: -8 Total Hours 24:00 Minimal activity. SLB frac on site at camp. Continue hauling frac water overnight. Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 9 Phone 1 3.15.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 11:00 5:00 11:00 20:00 9:00 20:00 6:00 10:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 SLB finishd with main rigup. Only need to prime-up, PT & run chemical lines. Waiting on sundry approval. Location shut down for remainder of evening HSE Events:None reported. IFO. Wind chill -48 Operational Details (06:00 - 06:00) SLB AOL with remaining equipment. Last loads of 4% KCl put into frac tanks. 24 hour Forecast:Frac BFF Stage 1. Upon successful completion of frac stage, will RIH with WL to perforate BFF Stage 2 (7745'- 7755'). Prep for Stage 2 Frac. Wind Direction: NE AM Temp: -22 Ops @ 06:00 hrs.: SLB off camp @ 6 am & starting trucks. Waiting on sundry approval. Once approved, will commence with prime-up & PT. YJ Wireline on way to location. Lil Red in place. Phase: 0 Wind Speed: 14 24 hour Summary:Took DFIT gauge out of line - no data. Backed up with CT data. SLB aol with remaining units & rigged up. Finished loading frac water. Weather Gen Conditions: Mostly sunny Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration 10 Phone 1 3.16.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 11:00 5:00 11:00 14:00 3:00 14:00 17:30 3:30 17:30 20:30 3:00 20:30 2:00 5:30 2:00 6:00 4:00 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Sundry notification provided. Prime up & PT SLB. Crews in place for Frac Stage 1. PU/PT good. Have safety meeting. Begin mixing gel for BFF stage 1 frac Start BFF frac stage 1, Open Well: 1156 psi, FET ISIP: 1311 psi, EOJ ISIP: 1603 psi; Severe NWB frictions; Job pumped well & to completion RIH w/YJ wireline; Encountered hard stop @ top of packer (7002'; 28' tool) w/plug & guns (2.5"); POOH & RBI w/ 1 11/16" tool/weight bar; Run to bottom & back out; Tight spot near top of packer-Dragged on way in; Opt to run plug & guns on separate runs Set plug @ 7900'; Ran free with just plug; Dropped ball to seal plug; Will test plug & perforate after positive plug test; Filling 4% KCl water & unloading sand for stage 2 HSE Events:None reported. IFO. Wind chill -38 Operational Details (06:00 - 06:00) SLB finished warming trucks & setting up FracCat; Only need PU/PT. Water loaded 100%. Prop loaded 100%. Waiting on sundry notification @ 11 am 24 hour Forecast:PT Stage 2 plug & perforate; Frac BFF Stage 2, Set plug & perforate for stage 3 frac, Haul water, prop & chemicals for Stage 3 Wind Direction: NE AM Temp: -15 Ops @ 06:00 hrs.: Plug set & dropped plug ball; Final water & proppant for stage 2 on location Phase: 0 Wind Speed: 15 24 hour Summary:SLB frac fully rigged up; Lacking PU/PT, Yellowjacket WL spotted; Lil Red & Aux Frac Support in place, Received sundry approval @ 2 pm; Proceeded with frac stage 1; Went well & to completion; RIH w/YJ WL to P&P BFF Stg 2 Weather Gen Conditions: Cloudy Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration 11 Phone 1 3.17.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 11:00 11:00 19:30 8:30 19:30 23:00 3:30 23:00 2:00 2:30 2:00 6:00 4:00 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: WL AOL. Finishing loading proppant & KCl water. Phase: 0 Wind Speed: 9 24 hour Summary:RIH w/Stage 2 perfs; Shot 7745-7755' successfully; POOH & begin frac rigup; Unloading proppant & filling frac tanks; Frac stage 2 - no issues; RD frac & shut-in well Weather Gen Conditions: Mostly Sunny Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO. Wind chill -48 Operational Details (06:00 - 06:00) Set plug @ 7900'; POOH. RIH w/perf guns to 7745-7755. Successful shoot for stage 2. POOH. Prep for frac stage 2. 24 hour Forecast:RIH w/Stage 3 perfs to shoot 7595-7605'; Finish loading frac water & proppant for stage 3. Rig up frac, test & Frac BFF Stage 3. Wind Direction: NE AM Temp: -27 Total Hours 18:30 Finish loading frac water & proppant for stage 3. Begin prime-up & pressure test. Good test. Have pre-frac safety meeting. Start BFF frac stage 2, Open Well: 1208 psi, FET ISIP: 1510 psi, EOJ ISIP: 1820 psi. Job pumped well & to completion RD frac, clear area for WL & shut-in well Fueling units, loading proppant & water for stage 3 Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 12 Phone 1 3.18.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 41 30.3 P.B.T.D.: From To Hrs. 6:00 9:00 3:00 9:00 11:30 2:30 11:30 18:00 6:30 18:00 22:30 4:30 22:30 1:00 2:30 1:00 6:00 5:00 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 YJ WL RIH with stage 3 plug & guns. Successfully shoot 7595-7605'. POOH. RDMO SLB turning on units, prepping for BFF stage 3 frac. SLB to do chemical change - testing & approval internally needed. Change known since 3/16/22 @ 16:00. Final approval received @ 18:00 on 3/17/22. SLB finish rigging up for stage 3. PU/PT Pump frac BFF Stage 3 treatment. Pumped well & to completion. 280k proppant pumped. Open Well: 1360 psi LD Hole ISIP: 1774 psi FET ISIP: 1742 psi EOJ ISIP: 2024 psi Rig frac off well & begin CT rig up HSE Events:None reported. IFO. Wind chill -46 Operational Details (06:00 - 06:00) Fueling units, receiving sand & filling up frac tanks w/4% KCl. 24 hour Forecast:Finish BOP test. Get on well with CT. RIH for 2 plug drillout. Drillout plugs & GTB. POOH w/CT, change to cement nozzle, drop to 6500' & begin flowing well with N2. Wind Direction: NE AM Temp: -21 Ops @ 06:00 hrs.: SLB CT rigging up & readying for BOP test Phase: 0 Wind Speed: 15 24 hour Summary: RIH for stage 3 perforating; Shoot successfully. POOH & RDMO YJ WL. Continue filling frac tanks & offloading sand. Frac filling chemicals & readying to PU/PT. Delay due to SLB chemical change/approval. Received final approval. Pumped BFF stage 3. Pumped well & to completion. Shut in well & rig up SLB CT. Prep for BOP test. Weather Gen Conditions: Cloudy Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/17/22 9:00 PM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration 13 Phone 1 3.19.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 14 30.3 P.B.T.D.: From To Hrs. 6:00 11:00 5:00 11:00 17:30 6:30 17:30 20:00 2:30 20:00 3:30 7:30 3:30 6:00 2:30 6:00 6:00 0:00 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/17/22 9:00 PM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Coil OOH & changing BHA. Halliburton N2 on way to location.Phase: 0 Wind Speed: 15 24 hour Summary:CT finish BOP test, rig up & get on well. RIH to TOL with 2.75" mill & motor. Mill out both frac plugs & push to bottom; Issues milling 2nd plug & getting to bottom, Could not get past bottom perf @ 8074', POOH & pull BHA; Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO. Wind chill -51 Operational Details (06:00 - 06:00) CT finishing rigging up & begin BOP test; Frac begin breaking iron loose; Empty trash fluid tank & haul off 24 hour Forecast:Set coil to depth of 6500' & open choke to Expro. Begin flow testing well with N2 @ 400 scf/min. Wind Direction: NE AM Temp: -25 Total Hours 24:00 Frac rigging down & moving trucks; CT finish BOP test & get on well Frac moving units off location; CT RIH to begin drillout CT run down, tag plug 1, drillout, pull up, tag plug 2, drillout, pull up & mill down to 8074' (tagged everything at 17' high); Issues noted entering liner & milling 2nd plug; Multiple tries to get through perfs; Motor stalling (hard) at bottom of perfs (8074') CT POOH w/mill & motor; CT getting off well to change BHA; Shift change Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 14 Phone 1 3.20.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 10 30.3 P.B.T.D.: From To Hrs. 6:00 9:00 3:00 9:00 12:30 3:30 12:30 17:15 4:45 17:15 18:15 1:00 18:15 23:30 5:15 23:30 6:00 6:30 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Worley trucks moving flowback water; Continue flow test w/N2; SLB CT shift change Phase: 0 Wind Speed: 12 24 hour Summary: CT coming out of hole to change BHA; Halliburton N2 on location; Repaired seal/leak on CT injector; RIH w/CT to 1000 ft & begin flow test; Start N2 lift & open choke; Well flowing @ 1220 psi; Continue CT depth changes, choke changes & N2 rates to encourage flow Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO. Wind chill -47 Operational Details (06:00 - 06:00) CT POOH; Off well to change drillout BHA to cement nozzle; HES N2 AOL; CT Lubricator froze up; Heavy leak from injector head gearbox; Requested shutdown for mechanic review & repair 24 hour Forecast:Continue flowing well with N2; Hauling flowback; SLB frac to remove remaining frac units Wind Direction: NE AM Temp: -24 Total Hours 24:00 SLB lube truck arrived to drain gearbox; Mechanic arrived to repair seal & repair injector head leak; Add dribble hose to minimize spill impact CT leak repaired; Injector head hoisted above well; CT on well; N2 cooling down & PT; CT pressure test RIH w/CT; WH @ 1160 psi; Stop at 1000 ft; Begin N2 @ 400 scf/min Flow testing well; Avg return 2200 bwpd; WH @ 1198 psi; Move CT end of tubing to 2000 ft Continue flow testing well; CT @ 2000 ft; WH @ 1070 psi; Circ @ 1892 psi; N2 @ 400 scf/min Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 15 Phone 1 3.21.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 10 30.3 P.B.T.D.: From To Hrs. 6:00 12:00 6:00 12:00 18:00 6:00 18:00 0:00 6:00 0:00 6:00 6:00 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Continue flow test; started cutting oil @ 16:30; CT @ 4500'; N2 @ 400 scf/min Continue flow test; CT @ 5000'; N2 @ 500 scf/min Continue flow test; CT @ 5500'; N2 @ 500 sc/min; Total fluid recovered: 3281 bbls HSE Events:None reported. IFO. Wind chill -45 Operational Details (06:00 - 06:00) Continue flow test; CT @ 2500'; N2 @ 400 scf/min 24 hour Forecast:Continue flow test; SLB frac to remove all equipment from location Wind Direction: NW AM Temp: -28 Ops @ 06:00 hrs.: Flow testing Phase: 0 Wind Speed: 6 24 hour Summary:Continue flow test; SLB Frac removed frac tanks & auxiliary equipment Weather Gen Conditions: Mostly Clear Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Ray Miller 210-275-8895 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration 17 Phone 1 3.23.22 Phone 2 Tool Pusher (N): API No: PTD: Field: 8,450' ft 0ft 10 30.3 P.B.T.D.: From To Hrs. 6:00 10:30 4:30 10:30 12:00 1:30 12:00 0:00 12:00 0:00 6:00 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Discontinue pumping N2, POH with coil, secure injector on deck, blow down Expro surface lines, Release Halliburton N2 unit. Well shut in. blowing down securing equipment and personnel for high wind event predicted. Release LRS operator. Well shut in. HSE Events:None reported. IFO. Wind chill -37 Operational Details (06:00 - 06:00) Continue flow test; CT @ 6,500' ; N2 @ 700 scf/min 24 hour Forecast:Continue shut in secure people and equipment for high wind weather event.Wind Direction: E AM Temp: -15 Ops @ 06:00 hrs.: Well shut in.Phase: 0 Wind Speed: 15 t/ 20 24 hour Summary: Continue flow test; Stop pumping N2, pull coil out of hole, set injector on SBL unit deck, release N2 unit, blow down Expro, pull free produces water from uprights send out for disposal. Release LRS operator. Secure equipment and personnel for coming weather event. Weather Gen Conditions: Mostly Clear Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Ray Miller/ Paul Smith 210-275-8895 / 907-5290737 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Carl Bowers 817-964-7371 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Schlumberger Well Type: Exploration 18 Phone 1 3.24.22 Phone 2 Tool Pusher (N): 24 API No: PTD: Field: 8,450' ft 0ft 19 30.3 P.B.T.D.: From To Hrs. 6:00 6:00 24:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 HSE Events:None reported. IFO.Wind chill -41 Operational Details (06:00 - 06:00) Well shut in. Secure equipment and personnel during high wind blowing snow event. 24 hour Forecast:Continue suspended operations, when weather allows, dig out location and clear roads to resume normal operations. Wind Direction: E AM Temp: -14 Ops @ 06:00 hrs.: Well shut in, no outside operations due to high winds and blowing snow.Phase: 2 to 3 Wind Speed: 25 t/ 40 24 hour Summary:Well shut in. Secure equipment and personnel for high wind event.Weather Gen Conditions: Mostly Clear Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Paul Smith 907-529 0737 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration 19 Phone 1 3.25.22 Phone 2 Tool Pusher (N): 24 API No: PTD: Field: 8,450' ft 0ft 20 30.3 P.B.T.D.: From To Hrs. 6:00 6:00 24:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Well shut in,Phase: 0 Wind Speed: 20 24 hour Summary:Well shut in. Weather Gen Conditions: Mostly Clear Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -21 Operational Details (06:00 - 06:00) Well shut in. resupply equipment and camp wih fuel and water. 24 hour Forecast:Continue well shut in. Dig out location and clear roads to resume normal operations.Wind Direction: E AM Temp: -8 Total Hours 24:00 Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 20 Phone 1 3.26.22 Phone 2 Tool Pusher (N): 24 API No: PTD: Field: 8,450' ft 0ft 21 30.3 P.B.T.D.: From To Hrs. 6:00 6:00 24:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments:*LRS unit on location, operator on stand by Deadhorse. *SLB coil unit on location, 1 operator on location. *Expro on location operational. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 HSE Events:None reported. IFO.Wind chill -32 Operational Details (06:00 - 06:00) Well shut in, monitor pressure build up. 24 hour Forecast:Continue well shut in for pressure build.Wind Direction: E AM Temp: -8 Ops @ 06:00 hrs.: Well shut in. Monitor well head pressure.Phase: 1 Wind Speed: 15 24 hour Summary:Well shut in. Monitor pressure build up Clean pad of snow keep roads cleat of blowing snow.Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Paul Smith 907-529 0737 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration 21 Phone 1 3.27.22 Phone 2 Tool Pusher (N): 27 API No: PTD: Field: 8,450' ft 0ft 22 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last Lube Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Well shut in. Monitor well head pressure. Continue clear pad of blowing snow.Phase: 1 Wind Speed: 22 24 hour Summary:Well shut in. Monitor well head pressure build up. Keep pad and roads clear of blowing snow. Travel limites due to blowing snow. Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -25 Operational Details (06:00 - 06:00) Well shut in, monitor pressure build up. Rigging down Wolverine camp prepare for transport. Send Theta West #1 0il and gas samples to Anchorage. 24 hour Forecast:Continue well shut in for pressure build.Wind Direction: ENE AM Temp: -2 Total Hours 24:00 Well shut in, monitor pressure build up. Continue clear pad of blowing snow. Comments:*LRS unit on location, operator on stand by Deadhorse. *SLB coil unit on location, 1 operator on location. *Expro on location operational. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 22 Phone 1 3.28.22 Phone 2 Tool Pusher (N): 26 API No: PTD: Field: 8,450' ft 0ft 23 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments:*LRS unit on location, operator on stand by Deadhorse. *SLB coil unit on location, 1 operator on location. *Expro on location operational. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Well shut in, monitor pressure build up. Continue clear pad of drifting snow. Travel limited due to drifting snow. HSE Events:None reported. IFO.Wind chill -35 Operational Details (06:00 - 06:00) Well shut in, monitor pressure build up. Continue clear pad of blowing snow. Lower Expro flare boom. LRS heat produced oil for transport to Hilcorp sales. 24 hour Forecast:Continue well shut in for pressure build. Clear drifting snow due to high winds.Wind Direction: E AM Temp: -21 Ops @ 06:00 hrs.: Well shut in. Monitor well head pressure. Continue clear pad of drifting snow.Phase: 2 Wind Speed: 21 24 hour Summary:Well shut in. Monitor well head pressure build up. Keep pad and roads clear of blowing snow. Travel limited due to blowing snow. Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration 23 Phone 1 3.29.22 Phone 2 Tool Pusher (N): 26 API No: PTD: Field: 8,450' ft 0ft 24 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Well shut in. Monitor well head pressure. Continue clear pad of drifting snow.Phase: 2 Wind Speed: 23 24 hour Summary:Well shut in. Monitor well head pressure build up. Keep pad and roads clear of blowing snow. Travel limited due to blowing snow. Weather Gen Conditions: Partly Cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -33 Operational Details (06:00 - 06:00) Well shut in, monitor pressure build up. Continue clear pad of blowing snow. 24 hour Forecast:Continue well shut in for pressure build. Clear drifting snow due to high winds.Wind Direction: ENE AM Temp: -8 Total Hours 24:00 Well shut in, monitor pressure build up. Continue clear pad of drifting snow. Travel limited due to drifting snow. Comments:*LRS unit on location, operator on stand by Deadhorse. *SLB coil unit on location, 1 operator on location. *Expro on location operational. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 24 Phone 1 3.30.22 Phone 2 Tool Pusher (N): 26 API No: PTD: Field: 8,450' ft 0ft 25 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments:*LRS unit on location, operator on location. *SLB coil unit on location, 1 operator on location. *Expro on location, operational. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Well shut in, monitor pressure build up. Continue clear pad of drifting snow. Travel limited due to drifted snow. HSE Events:None reported. IFO.Wind chill -37 Operational Details (06:00 - 06:00) Well shut in, monitor pressure build up. Continue clear pad of blowing snow. LRS heat produced oil to keep mobile for transport to Hilcorp sales. 24 hour Forecast:Continue well shut in for pressure build. Clear drifting snow due to high winds.Wind Direction: ENE AM Temp: -18 Ops @ 06:00 hrs.: Well shut in. Monitor well head pressure. Continue clear pad of drifting snow.Phase: 0 Wind Speed: 17 24 hour Summary:Well shut in. Monitor well head pressure build up. Keep pad and roads clear of blowing snow. Travel limited due to blown snow. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration 25 Phone 3.31.22 Phone Tool Pusher (N): 27 API No: PTD: Field: 8,450' ft 0ft 26 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Well shut in. Rigging down Expro spread 50%.Phase: 0 Wind Speed: 21 24 hour Summary: Well shut in. Load and transport produced oil to Hilcorp sales. Begin rigging down tank farm, set out Wolverine camp and prep for demobe/transport, digging out and warming up coil unit for operations, rigging down Expro test spread. Continue clearing snow from roads and pad. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -46 Operational Details (06:00 - 06:00) Well shut in. Take down tank farm stairs and landings. Load produced oil and transport to Hilcorp sales, Set out Wolverine camp units for transport off location. Clear snow from pad. 24 hour Forecast:Set CIBP in 3 1/2" liner with Yellow Jacket E-line, RIH with coil, Fluid pack well, Pressure test plug / casing, tag plug with AOGCC witness. Proceed with pumping cmt plug #1. Wind Direction: ENE AM Temp: -26 ** AOGCC 48 hour witness requested for 4/1/22 22:00 for 3 1/2" liner CIBP tag and PT. Total Hours 24:00 Well shut in. Schlumberger coil digging out and warm up to be operational for BOP test and well work. 100 bbl hot water on location to thaw slop tank and assist Expro rig down, vacuum lines as they are taken loose. Continue clear pad of drifted snow. Comments:*LRS unit on location, operator in Deadhorse. *SLB coil unit on location, crews arrive to clear snow warm up and make unit operational, *last day of 24 hr. coil operations. *Expro on location, rigging down test spread. Yellow Jack E-line requested to arrive 3/31/22 AM. AOGCC 48 hour notice for witness requested. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 26 Phone 4.1.22 Phone Tool Pusher (N): 30 API No: PTD: Field: 8,450' ft 0ft 27 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments:*LRS unit on location, operator in Deadhorse. *SLB coil unit on location, day and night crews on location. *Expro on location, rigging down test spread. Alaska E-line unit in Deadhorse, operators to arrive from Kenai today and mobilize when weather allows.. AOGCC 48 hour notice for witness. Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition ** AOGCC 48 hour witness requested for 4/1/22 22:00 for 3 1/2" liner CIBP tag and PT. Total Hours 24:00 Well shut in. Schlumberger coil digging out and warm up to be operational for BOP test and well work. Expro rig down. Continue clear pad of drifted snow. HSE Events:None reported. IFO.Wind chill -41 Operational Details (06:00 - 06:00) Well shut in. Demobe transport Wolverine camp units. Clear snow from pad and road. 24 hour Forecast: When weather permits, Mobilize E-line unit and tools to location. Set CIBP in 3 1/2" liner with Yellow Jacket E-line, RIH with coil, Fluid pack well, Pressure test plug / casing, tag plug with AOGCC witness. Proceed with pumping cmt plug #1. Wind Direction: ENE AM Temp: -22 Ops @ 06:00 hrs.: Well shut in. Rigging down Expro spread 90%Phase: 2 to 3 Wind Speed: 26 24 hour Summary:Well shut in. Unable to procure and mobilize needed equipment due to high winds and blowing snow. Continue clearin snow from roads and pad. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration 27 Phone 4.2.22 Phone Tool Pusher (N): 30 API No: PTD: Field: 8,450' ft 0ft 28 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 3/19/22 5:15 PM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Well shut in. Rigging down Expro spread ready to demobe today. Cruz clearing road and pad.Phase: 0 Wind Speed: 13 24 hour Summary:Well shut in. Unable to procure and mobilize needed equipment due to high winds and blowing snow. Continue clearin snow from roads and pad. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -34 Operational Details (06:00 - 06:00) Well shut in. Clear snow from pad and road. 24 hour Forecast:When weather permits, Mobilize E-line unit and tools to location. Set CIBP in 3 1/2" liner with Alaska E-line, RIH with coil, Fluid pack well, Pressure test plug / casing, tag plug with AOGCC witness. Proceed with pumping cmt plug #1. Wind Direction: ENE AM Temp: -18 Total Hours 24:00 Well shut in. Schlumberger coil digging out and warm up to be operational for BOP test and well work. Expro rig down. Continue clear pad of drifted snow. **Alaska E-line and slick line units with operators mobilizing from deadhorse as soon as roads are clear for travel to location. ** AOGCC 48 hour witness requested for 4/1/22 22:00, updated AOGCC inspector 4/1/22. *LRS unit on location, operator in Deadhorse. *SLB coil unit on location, day and night crews on location. *Expro on location, rigging down test spread, ready to begin transport. AOGCC 48 hour notice for witness. Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 29 Phone 4.4.22 Phone Tool Pusher (N): 30 API No: PTD: Field: 8,450' ft 0ft 30 30.3 P.B.T.D.: From To Hrs. 6:00 20:30 14:30 20:30 23:00 2:30 23:00 0:00 1:00 Midnight 1:00 1:00 1:00 2:00 1:00 2:00 3:30 1:30 3:30 5:00 1:30 5:00 6:00 1:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Pumping diesel to freeze protect coil and well at 1,500'Phase: 0 Wind Speed: 17 24 hour Summary: Test coil BOPE, Fluid pack coil with diesel, test coil BOPE, RIH with coil to CIBP, fluid pack well, test casing and CIBP (AOGCC witnessed), tag CIBP, (AOGCC witnessed), rig up Schlumberger cement and lay in 1st cement plug, pull up and lay in 2nd cement plug. pull to 1,500 and freeze protect. Weather Gen Conditions: Overcast Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -45 Operational Details (06:00 - 06:00) Lay over coil mast "T" bar, pick up coil BOPE, set on well, remove flange, install test flange, set back on deck for BOP test. Test coil BOPE per Schlumberger procedure.. 24 hour Forecast:Blow down and rig down coil unit, WOC, RIH with Pollard slick line with cement bailer to tag cement plug @ 3,064' (AOGCC to witness tag), pressure test cement (AOGCC to witness test), rig up Alaska Eline for 5 1/2' tubing punch. Wind Direction: W AM Temp: -20 Continue circ and pull coil nozzle to 1,500', pump 77 bbl. diesel freeze protect coil and well to 1,500'. *Expro 95% demobe, transported off location. Tank farm transported off location, 2 people to operate Expro choke for bleed off. * AOGCC 48 hour witness for tag and pressure test 2nd plug requested for 4/3/22 06:00. *LRS unit and operator on location. *SLB coil unit with day and night crews on location. Total Hours 24:00 RIH with coil cmt nozzle. Tag CIBP @ 7,537 *Coil measure. (7,545 WLM.) AOGCC tag witness by Lou Laubenstein. Pump 10 bbl hot diesel to warn interface diesel to brine. Pump 45 bbl warm fluid to warm coil. Pressure up 5 1/2" casing against CIBP with coil unit to 3,300 psi for 30 minutes, final pressure 3,123 psi. Good test per AOGCC witness Lou Laubenstein. Continue circ. To displace well to #9.4 brine with coil unit. Rig up Schlumberger cement unit. During circulations returned 32.2 bbl crude from well. Set cement plug #1: with cement nozzle @ 7,532' pump and lay in with coil, 8 bbl #15.8 cement @.5 bpm to per well plan, CIP @ 03:05 AM. Calculated TOC @ 6,883, Continue circ while pull up coil to 3,264' Set cement plug #2: With coil nozzle @ 3,264' pump and displace 5 bbl. #15.8 cement @ .5 bpm with coil to 3,064' per well plan. CIP 05:00. Calculated TOC @ 3,064' Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 30 Phone 4.5.22 Phone Tool Pusher (N): 30 API No: PTD: Field: 8,450' ft 0ft 31 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 24:00 PM 6:00 24:00 PM 2:00 2:00 2:00 6:00 4:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Resting Pollard slick line personnel.Phase: Wind Speed: 24 hour Summary:Wait on cement, Spot Pollard equipment. Weather Gen Conditions: Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill Operational Details (06:00 - 06:00) Waiting on cement. Rigging down coil unit, blow down coil with N2 for transport. 24 hour Forecast: WOC, Rest crews, RIH with Pollard slick line with cement bailer to tag cement plug @ 3,064' (AOGCC to witness tag), pressure test cement (AOGCC to witness test), rig up Alaska Eline for 5 1/2' tubing punch. Cirrculate for surface cement plug. Wind Direction: AM Temp: *Expro 95% demobe, transported off location. 2 people to operate Expro choke for bleed off. *AOGCC 48 hour witness for tag and pressure test plug notice given 3//30/22. *LRS unit and operator on location. *SLB coil unit with day and night crews on location, rigging down. Total Hours 24:00 Waiting on cement. Rigging down coil, Set back BOPs lay mast over. Vac surface lines, ready unit for transport. Waiting on cement. Pollard travel to location, timed out with travel from Kenai, spot eqiupment. Rest crews. **Gave AOGCC Lou Laubenstein update email at 02:00 for tag cement and pressure test witness at Noon 4/5/22. Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 31 Phone 4.6.22 Phone Tool Pusher (N): 30 API No: PTD: Field: 8,450' ft 0ft 32 30.3 P.B.T.D.: From To Hrs. 6:00 8:00 2:00 8:00 14:00 6:00 14:00 15:00 1:00 15:00 17:00 2:00 17:00 24:00 7:00 Midnight 6:00 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition *Expro 95% demobe, transported off location. 3 people to operate Expro choke for circulation. *LRS unit and operator on location. * SLB coil unti off location 18:00 4/5/22 Total Hours 24:00 Install wellhead adapter and flange, rig up slick line lubricator, RIH with bailer, tag TOC @ 3,004'. POH, clean and re-run bailer to 3,004' confirm hard cement Tag and cement witnessed by AOGCC inspector Lou Laubenstein. Pressure test 5 1/2" casing and plug to 3,000 psi for 30 min, good test, PT witnessed by AOGCC inspector Lou Laubenstein. Rig down Pollard slick line unit, Unit left location for another job. Wait on E-line unit to perforate 5 1/2" casing for final cement job. Wait on E-line unit to perforate 5 1/2" casing for final cement job. HSE Events:None reported. IFO.Wind chill -31 Operational Details (06:00 - 06:00) Rest Pollard wire line crews. 24 hour Forecast:Rig up E-line perforate at 200' establish circulation, remove frac tree, install 5 K valve, rig up and cement @ surface.Wind Direction: NE AM Temp: -18 Ops @ 06:00 hrs.: Waiting on E-line unit.Phase: 0 Wind Speed: 10 24 hour Summary:Rest crews, run bailer and tag cement, PT 5 1/2" and cement plug, witnesses by AOGCC, rig down slick line, wait on E-line unit. Weather Gen Conditions: Partly Couudy Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration 28 Phone 4.3.22 Phone Tool Pusher (N): 30 API No: PTD: Field: 8,450' ft 0ft 29 30.3 P.B.T.D.: From To Hrs. 6:00 12:00 6:00 12:00 5:00 5:00 5:00 7:30 2:30 7:30 8:30 1:00 8:30 9:30 1:00 9:30 2:00 4:30 2:00 4:00 2:00 4:00 6:00 2:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Rigging up to test coil BOPE.Phase: 0 Wind Speed: 13 24 hour Summary: Clear road and pad for operations, Mobilize Alaska E-line from Dead Horse, Run gauge ring with Pollard SL, swap to Alaska E-line, run pressure log for BHP. POH, run and set CIBP @ 7,545' POH rig down and off well, begin process of testing coil BOPs. Weather Gen Conditions: Mostly cloudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -34 Operational Details (06:00 - 06:00) Clear road and pad of blown snow, mobilize and transport Alaska E-line units and personnel from Dead Horse. Set coil BOPs on coil deck. 24 hour Forecast: Fluid pack coil with diesel, test coil BOPE, RIH with coil to CIBP, fluid pack well, test casing and CIBP (AOGCC witness), tag CIBP, (AOGCC witness), rig up Schlumberger cement and lay in 1st cement plug, pull up and lay in 2nd cement plug. Wind Direction: ENE AM Temp: -13 POH with set tool, rig E-line off well. *Expro 90% demobe, transported off location. Tank farm transported off location, 2 people to operate Expro choke for bleed off. Total Hours 24:00 Spot Alaska E-line and Pollard slick line units. Rig up Pollard Slick line. Test lub with LRS, RIH with 2.76" gauge ring on slick line, work gage ring 1,400' to 1,500' (ice), RIH to 8,016' WLM, hard set down. POH. Tools were iced up, lay dn slick line tools. Rig down Pollard slick line, swap units, Rig up Alaska E-line. * AOGCC 48 hour witness requested for 4/1/22 22:00, update AOGCC inspector 4/3/22. *LRS unit and operator on location. *SLB coil unit with day and night crews on location. Make up "Legacy" 2.75" OD "Big Boy" CIBP, RIH, correlate and set @ 7,545', pick up and run back to tag, good tag, on depth. Pick up and make up E-line lub, LRS pumped 21.5 bbl 1 bpm diesel into well to thaw @ 150 deg. Icp = 600 psi FCP= 870 psi. Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 RIH with down hole pressure gauge / temp gauges / CCL / Gamma. Fluid level erratic 1,100' to 1,486, below observed normal gradient, good fluid, set down @ 8,056' WLM, set 20 min to record BHP. Observed BHP of 3,895.2 psi with 780 psi well head pressure. POH. 32 Phone 4.7.22 Phone Tool Pusher (N): 30 API No: PTD: Field: 8,450' ft 0ft 33 30.3 P.B.T.D.: From To Hrs. 6:00 18:00 12:00 18:00 6:00 12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Waiting on Alaska E-line unit and crews Phase: 0 Wind Speed: 15 24 hour Summary:No activity waiting on E-line Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -25 Operational Details (06:00 - 06:00) Wait on E-line unit to perforate 5 1/2" casing for final cement job. Removed fluids from "slop tank" for disposal. 24 hour Forecast:Rig up E-line, perforate @ 200', confirm circulation, remove frac tree, install valve, rig up and cement 5 1/2" and 5 1/2" X 9 5/8" annuus. Wind Direction: ESE AM Temp: -5 *Expro 95% demobe, transported off location. 3 people to operate Expro choke for circulation. *LRS unit and operator on location. * SLB coil unit off location 18:00 4/5/22 Total Hours 24:00 Wait on E-line unit to perforate 5 1/2" casing for final cement job. Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 33 Phone 4.8.22 Phone Tool Pusher (N): 22 API No: PTD: Field: 8,450' ft 0ft 34 30.3 P.B.T.D.: From To Hrs. 6:00 8:00 2:00 8:00 13:30 5:30 13:30 19:00 5:30 19:00 22:00 3:00 22:00 22:30 0:30 22:30 24:00 1:30 Midnight 6:00 6:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: WOC Phase: 0 Wind Speed: 13 24 hour Summary:Wait on E-line unit, perforate 5 1/2" casing, establish communication to 9 5/8" casing. Perform surface plug cement job. Wait on cement to cure for test. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -21 Operational Details (06:00 - 06:00) Wait on E-line unit to perforate 5 1/2" casing for final surface cement job (plug # 3). 24 hour Forecast:Pressure test tubing and annulus to 2,000 psi, Excavate cellar, Begin removing well head for abandonment Wind Direction: ENE AM Temp: -6 * Schlumberger bulk truck off location, pump truck left on location. *Expro 100% rigged down, ready for transport off location. 3 people per shift. *LRS unit and operator on location. * SLB coil unit off location 18:00 4/5/22 Total Hours 24:00 Rig up Alaska E-line, pick up lub, Observed 29 psi annulus 26 psi on tubing. RIH with guns, Shoot holes @ 208'. Establish communication to annulus. (Pressure equalized @ 26 psi.) Pressure up to 90 psi on annulus, tubing pressure increased to 90 psi. Remove Expro flow lines, bleed well to 0 psi, Nipple down frac tree, nipple up adapters to 2" 1502 for pumping cement. Spot and rig up Schlumberger cement unit. Spot and retard vac trucks. Pump 15 bbl. #15.7 Aricticset cmt down 5 1/2" taking returns from 5 1/2" X 9 5/8" annulus, observed #15.7 cement returns, Stop pumping. Observed annulus on slight vac, shut in well. CIP 22:20. WOC. Clean flush surface lines and clean cellar. WOC. Thaw and clean in cellar, finish rigging down Expro equipment for transport. Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 34 Phone 4.9.22 Phone Tool Pusher (N): 22 API No: PTD: Field: 8,450' ft 0ft 35 30.3 P.B.T.D.: From To Hrs. 6:00 13:30 7:30 13:30 15:00 1:30 15:00 1:30 10:30 1:30 6:00 4:30 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition * transport Expro equipment off site. * Schlumberger bulk truck off location, pump truck left on location. *Expro 100% rigged down, off location. 3 people per shift. *LRS unit and operator on location. Total Hours 24:00 Pressure test well. Tie into annulus with LRS with gauge on tubing. Pressure up to 1,050 psi, tubing pressure increased to 1,050. Pressure up to 1,200 psi, pressure bled to 800 psi in 30 min. no test. Blend and test cement for surface plug. Remove scaffolding from cellar. Transport Expro equipment off location. Schlumberger cement tests complete, travel to location. HSE Events:None reported. IFO.Wind chill -19 Operational Details (06:00 - 06:00) Wait on cement to cure. 24 hour Forecast:Pressure test tubing and annulus to 2,000 psi, Excavate cellar, Begin removing well head for abandonment Wind Direction: W AM Temp: 0 Ops @ 06:00 hrs.: WOC Phase: 0 Wind Speed: 24 24 hour Summary:Wait on cement to cure for test. Weather Gen Conditions: Fair Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration 35 Phone 4.10.22 Phone Tool Pusher (N): 0 API No: PTD: Field: 8,450' ft 0ft 36 30.3 P.B.T.D.: From To Hrs. 6:00 8:00 2:00 8:00 8:30 0:30 8:30 12:00 3:30 12:00 6:00 18:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Waiting for cement to cure Phase: 0 Wind Speed: 14 24 hour Summary:Cement surface plug, clean up Weather Gen Conditions: Coudy Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill -13 Operational Details (06:00 - 06:00) Rig up Schlumberger unit to cement, retard clean up truck. 24 hour Forecast:Pressure test tubing and annulus to 2,000 psi, Excavate cellar, Begin removing well head for abandonment Wind Direction: ESE AM Temp: 0 * 100% Expro equipment transport off site. * Schlumberger equipment off location *LRS unit and operator on location for surface pressure test Total Hours 24:00 Pump 15 bbls #15.7 Aricticset cement down 5 1/2" , good cement returnes. Plug 3.2 CIP 08:30 Clean up cement unit, pump cellar. Wait for cement to cure. Excavate cellar, remove matting boards and material around cellar. Rig down and move Wolverine camp. Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 36 Phone 4.11.22 Phone Tool Pusher (N): 0 API No: PTD: Field: 8,450' ft 0ft 37 30.3 P.B.T.D.: From To Hrs. 6:00 8:00 2:00 8:00 10:00 2:00 10:00 6:00 20:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Mobilize equipment for surface plug #3 Phase: 0 Wind Speed: 8 24 hour Summary:WOC, pressure test surface plugs, No Test, mobilize equipment for surface plug cement, Weather Gen Conditions: Light Snow Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill 0 Operational Details (06:00 - 06:00) Wait for cement sample to cure. 24 hour Forecast:Displace diesel freeze protect with water. Pump cement plug #3, WOC, Test surface plugs, Begin removing well head for abandonment, Wind Direction: SW AM Temp: 11 Total Hours 24:00 Pressure test tubing and annulus to 1,000 psi with LRS unit tubing pressiure came up with annulus pressure. Bled to 600 psi in 30 min, No Test. Discuss options, mobilize equipment, lab test cement for surface plug #3.3 Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 37 Phone 4.12.22 Phone Tool Pusher (N): 0 API No: PTD: Field: 8,450' ft 0ft 38 30.3 P.B.T.D.: From To Hrs. 6:00 8:00 2:00 8:00 11:00 3:00 11:00 12:00 1:00 12:00 14:00 2:00 14:00 6:00 16:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Displace diesel freeze protect with water to prevent cement contamination of cement. Pumping down 5 1/2" returning 9 5/8" annulus, 15 bbl 80 deg water stopping for 15 min for diesel to migrate, pumped a total of 105 bbls displacing diesel. Well balanced with water Pump 15 bbl 15.7 Aricticset cement down 5 1/2" returning from 9 5/8" annulus, good cement returns during pump job. Shut down well static, in 15 min well on slight vac, after 15 well on very slight vac @ 5 1/2". *CIP 11:20 AM. Clean cellar of cement and diesel, wash up and rig down cement unit. Wait for cement to cure and set for pressure test. HSE Events:None reported. IFO.Wind chill -6 Operational Details (06:00 - 06:00) Mobilize equipment for surface cement plug #3.3 24 hour Forecast:WOC, pressure test surface plugs. Cut off wellhead.Wind Direction: WNW AM Temp: 5 Ops @ 06:00 hrs.: WOC, Phase: 0 Wind Speed: 6 24 hour Summary:Mobilize equipment for surface cement plug, displace diesel freeze protect, pump cement plug #3.3, WOC Weather Gen Conditions: Mostly cloudy Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration 38 Phone 4.13.22 Phone Tool Pusher (N): 0 API No: PTD: Field: 8,450' ft 0ft 39 30.3 P.B.T.D.: From To Hrs. 6:00 8:00 2:00 8:00 6:00 22:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Total Length (ft): 0.00 Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Total Hours 24:00 Cement samples still soft, continue waiting for cement to cure. *Load out Galena camp complete, *Cleaning location, load misc. tools and equipment, load out well head tools and equipment HSE Events:None reported. IFO.Wind chill Operational Details (06:00 - 06:00) WOC, mobilize personnel for pressure test. 24 hour Forecast:Wait for cement to cure, Test casing and annulus to 2,000 psi, cut off wellhead, continue with P & A operation Wind Direction: AM Temp: Ops @ 06:00 hrs.: WOC, Phase: Wind Speed: 24 hour Summary:WOC, Weather Gen Conditions: Shoe Test: N/A 14.1 ppg EMW na NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Supervisor (N): Paul Smith 907-529 0737 NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration 39 Phone 4.14.22 Phone Tool Pusher (N): 0 API No: PTD: Field: 8,450' ft 0ft 40 30.3 P.B.T.D.: From To Hrs. 0:00 9:00 9 9:00 10:00 1 10:00 11:00 1 11:00 22:30 11.5 22:30 24:00 1.5 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff % Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N):NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Perform DDTs, mobilize equipment for wellhead cut off Phase: Wind Speed: 24 hour Summary:Wait on cement , rig up little red hot oil, MIT cement in IA and tbg as to P&A procedures Weather Gen Conditions: Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill Operational Details (06:00 - 06:00) wait on cement 24 hour Forecast:Well head cut off, top off cement final inspection with AOGCC Wind Direction: AM Temp: Total Hours 24 clear well head and IA valves of dried cement Rig up LRS MIT TBG and IA test good, Bled down pressure, rigged down little red Days work continue to demob equipment durning test time Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 41 Phone 4.15.22 Phone Tool Pusher (N): 0 API No: PTD: Field: 8,450' ft 0ft 40 30.3 P.B.T.D.: From To Hrs. 0:00 24:00 6:00 6 24:00 6:00 14:00 8 14:00 16;00 2 16:00 17:00 1 16:00 17:00 0:00 7 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N):NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Move out co-man office Phase: 1 Wind Speed: 15/20 24 hour Summary:dig out Ice roads.dig out Theta Pad, Dig out well cellar, top fill 5-1/2, notifie state Weather Gen Conditions: Blowing snow Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill n/a Operational Details (06:00 - 06:00) wait on weather 24 hour Forecast:AOGCC inspection, weld on name plate, pull cellar box Wind Direction: NE AM Temp: -3 Total Hours 24 Digout and open roads and pads digout sniow from cellar box Top fill 5-1/2 rig up wait on cement Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 42 Phone 4.16.22 Phone Tool Pusher (N): 0 API No: PTD: Field: 8,450' ft 0ft 40 30.3 P.B.T.D.: From To Hrs. 0:00 24:00 24 24:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D): Jerry Otto 907-252 5297 Tool Pusher (D): NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor: Well Type: Exploration Supervisor (N):NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md: Budget Amount: Actual Days since Start: RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress: Cum. Cost: Stg 1 Perf Date: 3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size: 28" 12-1/4" 8-1/2" 8-1/2" Last Pressure Test: 4/4/22 12:00 AM OD/Weight 20"/ 129# 9-5/8" / 40# 5-1/2" / 17# 3-1/2"/ 9.2# Last Safety Mtg: Casing: Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth: 75' 3,030' 8,376' 8,277' Last Evac Drill: NA Plan Depth: 75' 3,500' 8,440' 8,376' Last Rig Insp.: Ops @ 06:00 hrs.: Plow open ice road Phase: 1 Wind Speed: 15/20 24 hour Summary:Weather hold Due too high winds (35/45mph) and drifting snow Weather Gen Conditions: Blowing snow Shoe Test: N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill n/a Operational Details (06:00 - 06:00) Wait on weather drifting snows winds to 45mph 24 hour Forecast:pPlow open ice road,Top fill 5-1/2 Tbg, inspection with AOGCC Wind Direction: NE AM Temp: -3 Total Hours 24 Comments: Bit Performance Bit Type: Ser # Avg ROP IADC Dull Condition Background (Avg) % 0 Connection % 0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas % 0 Volume Delivered: 0 Pump Data Slow Pump Rates Total Length (ft): 0.00 43 Phone 4.17.22 Phone Tool Pusher (N): 0 API No: PTD: Field: 8,450' ft 0ft 40 30.3 P.B.T.D.: From To Hrs. 0:00 6:00 6 6:00 15:00 9 15:00 18:00 3 18:00 24:00 6 24:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0:00 0 Bit # Size Depth Depth Feet Bit hrs. K-revs Avg. Nozzles TFA [in] In Out Drilled Run rpm sq in Time Depth MW PV YP Mud Gas Readings:Used Rig: Total: Pump Type Liner Sz SPM Eff %Flow SPP Pump Depth SPM SPP MD TVD Inc.OD ID Conn. Length Report #: Supervisor (D):Jerry Otto 907-252 5297 Tool Pusher (D):NA Report Date: Daily Completion Report Well Name:THETA WEST #1 Rig/Contractor:Well Type:Exploration Supervisor (N):NA Camp POB: on location 50-223-20036-00-00 221-106 South Prudhoe Bay Lease no: KB-GL, ft Prog FTD md:Budget Amount: Actual Days since Start:RKB, ft TD @ 06:00 Daily Cost: Planned Days (Perf to Test): GL, ft Progress:Cum. Cost: Stg 1 Perf Date:3/8/2022 Project Number:RKB-CSG Flg, ft Hole Size:28"12-1/4"8-1/2"8-1/2"Last Pressure Test:4/4/22 12:00 AM OD/Weight 20"/ 129#9-5/8" / 40#5-1/2" / 17#3-1/2"/ 9.2#Last Safety Mtg: Casing:Conductor Surface Intermediate Liner Last BOP Drill: NA Actual Depth:75'3,030'8,376'8,277'Last Evac Drill:NA Plan Depth:75'3,500'8,440'8,376'Last Rig Insp.: Ops @ 06:00 hrs.: pull cellar Phase: Wind Speed:10-May 24 hour Summary:wait on cement, final inspection of Theta west #1with AOGCC, weld on marker plate Weather Gen Conditions:Blowing snow Shoe Test:N/A 14.1 ppg EMW na HSE Events:None reported. IFO.Wind chill n/a Operational Details (06:00 - 06:00) Days work, waiting on cement 24 hour Forecast:complete dwmob Wind Direction:NE AM Temp:-7 Total Hours 24 open roads with snow blower. Demob Schumberger transport Final inspection with AOGCC, weld on marker plate Days work, Comments: Bit Performance Bit Type:Ser #Avg ROP IADC Dull Condition Background (Avg) %0 Connection %0 Mud Properties Gas Details Fuel Vis 0 Available Model Surveys BHA AZ.Item Comment Trip Gas %0 Volume Delivered:0 Pump Data Slow Pump Rates Total Length (ft):0.00 SECTION 4. Directional Survey SECTION 4a. Directional Survey SLB Final Survey NAD27 7K H W D : H V W 6 X U Y H \ * H R G H W L F 5 H S R U W 1 $ ' ' H I 6 X U Y H \ &R P P H Q W V 0' IW ,Q F O $] L P 7 U X H 79 ' 6 6 IW 79 ' IW 96( & IW $+ ' IW &O R V X U H IW 16 IW (:IW '/ 6 I W 1R U W K L Q J IW 8 6 (D V W L Q J IW 8 6 /D W L W X G H /R Q J L W X G H 57 ( 1 $ 9- 5 / 8 " C s g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i 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 Ye s N o 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 v e y T o o l C o d e s Al l t a r g e t s a n d / o r w e l l p o s i t i o n o b j e c t i v e s h a v e b e e n a c h i e v e d . I h a v e c h e c k e d t o t h e b e s t o f m y a b i l i t y t h a t t h e f o l l o w i n g d a t a i s c o r r e c t : Su r f a c e C o o r d i n a t e s De c l i n a t i o n & C o n v e r g e n c e GR S S u r v e y C o r r e c t i o n s SECTION 4b. Directional Survey Plot !" #$ %&'(% )! *+,-*. /,/& ',0--12 & ,3 43/,// &50-'62 5160(- ,,07-" 870',665 9 $ 675--/0-5 5'1('5#. : ,05'12 $ -7/6501( 1,7'75#. ,07777,5-' ;&<# <4 8/-,#4$9 ! %! !"#$%#& ' ( ') &* +,-./0 1'% 2(' ( /* &1, 2(' ( /* 3* ./0 42(4 ' ( 45 5 /* ,6 7 '( 42(4 ' ( 45 /* 282.73 2(' ( /* ') &* +, 4 5 5 5 %& 5 " 5 ') &* +,-./0 1'% 2(' ( "% &1, 2(' ( "% 3* ./0 42(4 ' ( 45 "5 %4 ,6 7 '( 42(4 ' ( 45 "% 282.73 2(' ( "% ') &* +, '." ) ' 92:'4 2!(4 ;79/ '. ;7 2! SECTION 10. Surface Abandonment 10a. Summary 10b. Photos SECTION 10a. Surface Abandonment Summary MEMORANDUM STATE OF ALASKA Alaska Oil and Gas Conservations Commission Date: 5/12/2022 RE: Surface Abandonment Great Bear Pantheon, LLC PTD 221-106; Sundry 322-155 4/16/22: The Theta West #1 well head was cutoff 4’ below tundra grade. All inner strings of pipe were verified to have cement to surface. Integrity of cement was checked with a five foot bar. The ¼” marker plate containing all required well information was welded onto the outer conductor pipe. A complete bead of weld was visually verified around the outer edge of the pipe where it meets the marker plate. The cellar was then backfilled to reestablish grade. SECTION 10b. Surface Abandonment Photos SECTION 5. FRAC TREATMENT REPORT Attachment G Sc h l u m b e r g e r P r i v a t e Schlumberger-Private FracCADE* STIMULATION PROPOSAL Operator : Great Bear Pantheon Well : Theta West County : North Slope State : Alaska Country : United States Prepared for : Michael Duncan Service Point : Prudhoe Bay, Alaska Business Phone : 1 907 659 2434 Date Prepared : 3-06-2021 FAX No. : 1 907 659 2538 Prepared by : Brett McLaughlin Phone : 432-231-9070 E-Mail Address : bmclaughlin3@slb.com * Mark of Schlumberger Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. 2 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Section 1: Wellbore Configuration Bottom Hole Temperature 200 degF Deviated Hole NO Treat Down Tubing Well Type Vertical Well Location OnShore Tubing Data OD (in) Weight (lb/ft) ID (in) Depth (ft) 5.5 17 4.892 7000 3.500 9.2 2.990 8285 Perforation Data – Stage 1 Top MD (ft) Top TVD (ft) Bottom MD (ft) Bottom TVD (ft) Shot Density (shot/ft) Number Diameter (in) 8070 8070 8080 8080 6.00 60 .28 Perforation Data – Stage 2 Top MD (ft) Top TVD (ft) Bottom MD (ft) Bottom TVD (ft) Shot Density (shot/ft) Number Diameter (in) 7770 7770 7780 7780 6.00 60 .28 Perforation Data – Stage 3 Top MD (ft) Top TVD (ft) Bottom MD (ft) Bottom TVD (ft) Shot Density (shot/ft) Number Diameter (in) 7590 7590 7600 7600 6.00 60 .28 3 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Section 2: Propped Fracture Schedule – Stage 1 4 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length (X f ) greater than 200 ft Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Clean Fluid Volume (gal) Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Load Hole/Br 10.0 WF110 7800 10.0 0.00 ISIP 5-10-15 0.0 WF110 0 10.0 0.00 FET 40.0 WF110 6800 10.0 0.00 ISIP 5-10-15 0.0 WF110 0 10.0 0.00 PAD 40.0 WF110 24000 10.0 0.00 0.5 PPA 40.0 WF110 9000 10.0 40/70 Sand 0.50 1.0 PPA 40.0 WF110 9000 10.0 40/70 Sand 1.00 1.5 PPA 40.0 WF110 9000 10.0 40/70 Sand 1.50 2.0 PPA 40.0 WF110 9000 10.0 40/70 Sand 2.00 2.5 PPA 40.0 WF110 9000 10.0 40/70 Sand 2.50 2.5 PPA 40.0 YF115FlexD 9000 15.0 40/70 Sand 2.50 3.0 PPA 40.0 YF115FlexD 9000 15.0 40/70 Sand 3.00 4.0 PPA 40.0 YF115FlexD 9500 15.0 40/70 Sand 4.00 5.0 PPA 40.0 YF115FlexD 9000 15.0 40/70 Sand 5.00 5.0 PPA 40.0 YF115FlexD 9200 15.0 20/40 Carbo 5.00 6.0 PPA 40.0 YF115FlexD 9000 15.0 20/40 Carbo 6.00 FLUSH 40.0 WF115 6320 15.0 0.00 FreezeProtec 40.0 FreezeProtect 1000 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. Fluid Totals 2142 bbl of WF110 1320 bbl of YF115FlexD Proppant Totals 200,000 lb of 40/70 Sand 100,000 lb Of 20/40 C-Lite Pad Percentages % PAD Clean 19.4 % PAD Dirty 17.5 5 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Stage 1 Initial Fracture Top TVD.......................... 8068.0 ft Initial Fracture Bottom TVD....................... 8081.0 ft Propped Fracture Half-Length...................... 858.9 ft Propped Width at Well............................. 0.015 in Average Propped Width............................. 0.0293 in Average Gel Concentration......................... 571.7 lb/mgal Average Fluid Retained Factor..................... 0.60 EOJ Hydraulic Height at Well...................... 75.3 ft EOJ Net Pressure.................................. 2497 psi Efficiency........................................ 0.404 Effective Conductivity............................ 2669 md.ft Effective Fcd..................................... 3.1 Max Surface Pressure.............................. 5704 psi Figure 1. Conductivity Plots Proppant Concentration 0.0 PPA 2.0 PPA 4.0 PPA 6.0 PPA 8.0 PPA > 10.0 PPA Length (ft) 0 200 400 600 800 1000 1200 1400 Fracture Width Frac#1 MD = 9412.55ft Width (in) -2.00 0 2.00 Lithology and Stress Stress (psi) 5000 6000 7000 Sat. and Young's Modulus We l l D e p t h ( T V D ) ( f t ) 7900 7950 8000 8050 8100 8150 8200 Young's Mod. (psi) 1.0x1062.0x1063.0x1064.0x1065.0x106 6 Attachment G Client : Great Bear Pantheon Well :Theta West Formation :BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Figure 2. Flow Capacity 7 Attachment G Client : Great Bear Pantheon Well :Theta West Formation :BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Figure 3. Surface Pressure Plot 8 Attachment G Client : Great Bear Pantheon Well :Theta West Formation :BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Figure 4. Net Pressure Plot 9 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Section 3: Propped Fracture Schedule – Stage 2 10 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length (X f ) greater than 200 ft Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Clean Fluid Volume (gal) Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Load Hole/Br 10.0 WF110 7700 10.0 0.00 ISIP 5-10-15 0.0 WF110 0 10.0 0.00 FET 40.0 WF110 6800 10.0 0.00 ISIP 5-10-15 0.0 WF110 0 10.0 0.00 PAD 40.0 WF110 17000 10.0 0.00 0.5 PPA 40.0 WF110 6600 10.0 40/70 Sand 0.50 1.0 PPA 40.0 WF110 7300 10.0 40/70 Sand 1.00 1.5 PPA 40.0 WF110 7300 10.0 40/70 Sand 1.50 2.0 PPA 40.0 WF110 7300 10.0 40/70 Sand 2.00 2.5 PPA 40.0 WF110 7300 10.0 40/70 Sand 2.50 2.5 PPA 40.0 YF115FlexD 3000 15.0 40/70 Sand 2.50 3.0 PPA 40.0 YF115FlexD 7300 15.0 40/70 Sand 3.00 4.0 PPA 40.0 YF115FlexD 7300 15.0 40/70 Sand 4.00 5.0 PPA 40.0 YF115FlexD 2400 15.0 40/70 Sand 5.00 5.0 PPA 40.0 YF115FlexD 7200 15.0 20/40 Carbo 5.00 6.0 PPA 40.0 YF115FlexD 6500 15.0 20/40 Carbo 6.00 FLUSH 40.0 WF115 6150 15.0 0.00 FreezeProtec 40.0 FreezeProtect 1000 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. Fluid Totals 1773 bbl of WF110 802 bbl of YF115FlexD Proppant Totals 125,000 lb of 40/70 Sand 75,000 lb Of 20/40 C-Lite Pad Percentages % PAD Clean 19.7 % PAD Dirty 17.8 11 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Stage 2 Initial Fracture Top TVD.......................... 7768 ft Initial Fracture Bottom TVD....................... 7781 ft Propped Fracture Half-Length...................... 710.3 ft Propped Width at Well............................. 0.041 in Average Propped Width............................. 0.201 in Average Gel Concentration......................... 455.2 lb/mgal Average Fluid Retained Factor..................... 0.60 EOJ Hydraulic Height at Well...................... 87.2 ft EOJ Net Pressure.................................. 1633 psi Efficiency........................................ 0.356 Effective Conductivity............................ 2112 md.ft Effective Fcd..................................... 3.0 Max Surface Pressure.............................. 4586 psi Figure 5. Stage 2 Conductivity Plot Proppant Concentration 0.0 PPA 2.0 PPA 4.0 PPA 6.0 PPA 8.0 PPA > 10.0 PPA Length (ft) 0 100 200 300 400 500 600 700 800 900 1000 Fracture Width Width (in) -2.00 -1.00 0 1.00 2.00 Lithology and Stress Stress (psi) 450050005500600065007000 Sat. and Young's Modulus We l l D e p t h ( T V D ) ( f t ) 7400 7500 7600 7700 7800 7900 8000 Young's Mod. (psi) 1.0x1062.0x1063.0x1064.0x1065.0x1066.0x106 12 Attachment G Client : Great Bear Pantheon Well :Theta West Formation :BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Figure 6. Stage 2 Design Pressures 13 Attachment G Client : Great Bear Pantheon Well :Theta West Formation :BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Figure 7. Stage 2 Flow Capacity 14 Attachment G Client : Great Bear Pantheon Well :Theta West Formation :BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Figure 8. Stage 2 Net Pressure Plot 15 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Section 3: Propped Fracture Schedule – Stage 3 16 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length (X f ) greater than 200 ft Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Clean Fluid Volume (gal) Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Load Hole/Br 10.0 WF110 7600 10.0 0.00 ISIP 5-10-15 0.0 WF110 0 10.0 0.00 FET 40.0 WF110 6800 10.0 0.00 ISIP 5-10-15 0.0 WF110 0 10.0 0.00 PAD 40.0 WF110 21000 10.0 0.00 0.5 PPA 40.0 WF110 8000 10.0 40/70 Sand 0.50 1.0 PPA 40.0 WF110 9000 10.0 40/70 Sand 1.00 1.5 PPA 40.0 WF110 9000 10.0 40/70 Sand 1.50 2.0 PPA 40.0 WF110 9000 10.0 40/70 Sand 2.00 2.5 PPA 40.0 WF110 9000 10.0 40/70 Sand 2.50 2.5 PPA 40.0 YF115FlexD 6000 15.0 40/70 Sand 2.50 3.0 PPA 40.0 YF115FlexD 9000 15.0 40/70 Sand 3.00 4.0 PPA 40.0 YF115FlexD 9000 15.0 40/70 Sand 4.00 5.0 PPA 40.0 YF115FlexD 6000 15.0 40/70 Sand 5.00 5.0 PPA 40.0 YF115FlexD 7200 15.0 20/40 Carbo 5.00 6.0 PPA 40.0 YF115FlexD 6500 15.0 20/40 Carbo 6.00 FLUSH 40.0 WF115 6000 15.0 0.00 FreezeProtec 40.0 FreezeProtect 1000 0.00 Please note that this pumping schedule is under-displaced by 5.0 bbl. Fluid Totals 2057 bbl of WF110 1040 bbl of YF115FlexD Proppant Totals 175,000 lb of 40/70 Sand 75,000 lb Of 20/40 C-Lite Pad Percentages % PAD Clean 19.7 % PAD Dirty 17.8 17 Attachment G Client : Great Bear Pantheon Well : Theta West Formation : BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Stage 3 Initial Fracture Top TVD.......................... 7588 ft Initial Fracture Bottom TVD....................... 7601 ft Propped Fracture Half-Length...................... 825.1 ft Propped Width at Well............................. 0.010 in Average Propped Width............................. 0.247 in Average Gel Concentration......................... 485.2 lb/mgal Average Fluid Retained Factor..................... 0.60 EOJ Hydraulic Height at Well...................... 78.0 ft EOJ Net Pressure.................................. 2022 psi Efficiency........................................ 0.377 Effective Conductivity............................ 2266 md.ft Effective Fcd..................................... 2.7 Max Surface Pressure.............................. 4875 psi Figure 9. Stage 2 Conductivity Plot Proppant Concentration 0.0 PPA 2.0 PPA 4.0 PPA 6.0 PPA 8.0 PPA > 10.0 PPA Length (ft) 0 200 400 600 800 1000 1200 Fracture Width Width (in) -2.00 0 2.00 Lithology and Stress Stress (psi) 4000 5000 6000 7000 Sat. and Young's Modulus We l l D e p t h ( T V D ) ( f t ) 7400 7450 7500 7550 7600 7650 7700 Young's Mod. (psi) 1.0x1062.0x1063.0x1064.0x1065.0x106 18 Attachment G Client : Great Bear Pantheon Well :Theta West Formation :BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Figure 10. Stage 2 Design Pressures 19 Attachment G Client : Great Bear Pantheon Well :Theta West Formation :BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Figure 11. Stage 2 Flow Capacity 20 Attachment G Client : Great Bear Pantheon Well :Theta West Formation :BFF District : Prudhoe Bay, Alaska Sc h l u m b e r g e r P r i v a t e Schlumberger-Private Figure 12. Stage 2 Net Pressure Plot April,222022 SteveDavies SeniorPetroleumGeologist AOGCC Steve.davies@alaska.gov RE:TransmittalLetter Steve: GreatBearPantheonhassubmittedthefollowingdataperrequestfromtheAOGCConApril22nd,2022: x 1.SundryReport(Form10Ͳ407) x 2.DailyDrillingReports x 3.CompletionReports x 4.DirectionalSurveys x 5.FracTreatmentReport x 6.WellboreSchematics x 7.WellTestingData_Reports x 8.Logs x 9.ListofFormations&GeologicalMarkersObserved Ifanyfurtherinformationisneeded,pleaseletusknow. Sincerely, MichaelDuncan ChiefOperatingOfficer (817)240Ͳ3865 PTD: 221-106 LWD: T36493 Mudlogs: T36494 Wireline: T36495 Well Testing: T36496 List of Formations: T36497 Frac Treatment Reports: T36498 Kayla Junke Digitally signed by Kayla Junke Date: 2022.04.28 10:24:38 -08'00' 2022-0417_Surface_Abandon_ThetaWest-1_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 4-19-2022 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector Theta West #1 Great Bear Pantheon LLC PTD 2211060; Sundry 322-155 4-17-2022: I traveled to Theta West #1 to witness the surface abandonment. The well was cut off @ 39 inches below tundra grade. Hard set-up cement was found in all strings. The marker plate has the correct information scribed on. The approval was given to weld on the plate and bury. Final site clearance inspection to follow this summer. Attachments: Photos (2)   2022-0417_Surface_Abandon_ThetaWest-1_ae Page 2 of 2 Surface Abandonment – Theta West #1 (PTD 2211060) Photos by AOGCC Inspector A. Earl 4/17/2022 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 32 Township: 7N Range: 11E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 8376 ft MD Lease No.: ADL 394039 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 75 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3030 Feet Csg Cut@ Feet Intermediate: 5 1/2" O.D. Shoe@ 8376 Feet Csg Cut@ Feet Production: 3 1/2" O.D. Shoe@ 8277 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: O.D. Tail@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 7537 ft 7537 ft 9.4 ppg C.T. Tag Fullbore Balanced 3264 ft 3002 ft 9.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 3300 3170 3114 IA OA Initial 15 min 30 min 45 min Result Tubing 3320 3145 3088 IA 25 27 28 OA 29 28 27 Remarks: Attachments: Jerry Otto P Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): 4/3/22: I arrived on location to witness the tag and pressure test on the CIBP that was to be the bottom of isolation in the P&A operation. The top of the plug was found @ 7,537', then 3000lb of down force was applied to the plug then re-tagged, showing the same depth. A 3000 psi pressure test was completed, going 10% over the required test pressure and passed. Operator was to lay in 13 bbls cement on top of the CIBP to bring cement top up into the 5.5-inch casing (not witnessed). 4/5/22: I arrived on location to witness the tag and pressure test of the second cement plug in the P&A operation. Wireline performed the tag using a bailer with a tool weight of 160 lbs. Top of cement was found @ 3,002 ft MD and a good cement sample was retrieved. A 3000 psi pressure test was completed with passing results. April 5, 2022 Lou Laubenstein Well Bore Plug & Abandonment Theta West #1 Great Bear Pantheon, LLC PTD 2211060; Sundry 322-155 none Test Data: P Casing Removal: rev. 11-28-18 2022-0405_Plug_Verification_Theta-West-1_ll 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 3000lb of down force was applied to the plug second cement plug bottom of isolation in the P&A Top of cement was found @ 3,002 ft MD g good cement sample James B. Regg Digitally signed by James B. 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33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϮϬͬϰϬĂƌďŽ 33$<))OH['ϮϬͬϰϬĂƌďŽ )/86+:) )UHH]H3URWHF)UHH]H3URWHFW WůĞĂƐĞŶŽƚĞƚŚĂƚƚŚŝƐƉƵŵƉŝŶŐƐĐŚĞĚƵůĞŝƐƵŶĚĞƌͲĚŝƐƉůĂĐĞĚďǇϱ͘Ϭďďů͘ &ůƵŝĚdŽƚĂůƐ ϮϭϰϮďďůŽĨt&ϭϭϬ ϭϯϮϬďďůŽĨz&ϭϭϱ&ůĞǆ WƌŽƉƉĂŶƚdŽƚĂůƐ ϮϬϬ͕ϬϬϬůďŽĨϰϬͬϳϬ^ĂŶĚ ϭϬϬ͕ϬϬϬůďKĨϮϬͬϰϬͲ>ŝƚĞ WĂĚWĞƌĐĞŶƚĂŐĞƐ йWůĞĂŶϭϵ͘ϰ йWŝƌƚǇϭϳ͘ϱ ϱƚƚĂĐŚŵĞŶƚ' ůŝĞŶƚ ͗ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ tĞůů ͗ dŚĞƚĂtĞƐƚ &ŽƌŵĂƚŝŽŶ͗ && ŝƐƚƌŝĐƚ ͗ WƌƵĚŚŽĞĂǇ͕ůĂƐŬĂ 6FKOXPEHUJHU3ULYDWH^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ƚĂŐĞϭ /ŶŝƚŝĂů&ƌĂĐƚƵƌĞdŽƉds͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϴϬϲϴ͘ϬĨƚ /ŶŝƚŝĂů&ƌĂĐƚƵƌĞŽƚƚŽŵds͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϴϬϴϭ͘ϬĨƚ WƌŽƉƉĞĚ&ƌĂĐƚƵƌĞ,ĂůĨͲ>ĞŶŐƚŚ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϴϱϴ͘ϵĨƚ WƌŽƉƉĞĚtŝĚƚŚĂƚtĞůů͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘Ϭ͘ϬϭϱŝŶ ǀĞƌĂŐĞWƌŽƉƉĞĚtŝĚƚŚ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘Ϭ͘ϬϮϵϯŝŶ ǀĞƌĂŐĞ'ĞůŽŶĐĞŶƚƌĂƚŝŽŶ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϱϳϭ͘ϳůďͬŵŐĂů ǀĞƌĂŐĞ&ůƵŝĚZĞƚĂŝŶĞĚ&ĂĐƚŽƌ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘Ϭ͘ϲϬ K:,ǇĚƌĂƵůŝĐ,ĞŝŐŚƚĂƚtĞůů͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϳϱ͘ϯĨƚ K:EĞƚWƌĞƐƐƵƌĞ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϮϰϵϳƉƐŝ ĨĨŝĐŝĞŶĐǇ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘Ϭ͘ϰϬϰ ĨĨĞĐƚŝǀĞŽŶĚƵĐƚŝǀŝƚǇ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϮϲϲϵŵĚ͘Ĩƚ ĨĨĞĐƚŝǀĞ&ĐĚ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϯ͘ϭ DĂǆ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϱϳϬϰƉƐŝ Figure 1. Conductivity Plots Proppant Concentration 33$ 33$ 33$ 33$ 33$ !33$ /HQJWKIW Fracture Width Frac#1 MD = 9412.55ft :LGWKLQ Lithology and Stress 6WUHVVSVL Sat. and Young's Modulus :HOO'HSWK79'IW <RXQJ V0RGSVL [[[[[ DĂǆ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϱϳϬϰƉƐŝ ϵƚƚĂĐŚŵĞŶƚ' ůŝĞŶƚ ͗ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ tĞůů ͗ dŚĞƚĂtĞƐƚ &ŽƌŵĂƚŝŽŶ͗ && ŝƐƚƌŝĐƚ ͗ WƌƵĚŚŽĞĂǇ͕ůĂƐŬĂ 6FKOXPEHUJHU3ULYDWH^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ĞĐƚŝŽŶϯ͗WƌŽƉƉĞĚ&ƌĂĐƚƵƌĞ^ĐŚĞĚƵůĞʹ^ƚĂŐĞϮ ϭϬƚƚĂĐŚŵĞŶƚ' ůŝĞŶƚ ͗ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ tĞůů ͗ dŚĞƚĂtĞƐƚ &ŽƌŵĂƚŝŽŶ͗ && ŝƐƚƌŝĐƚ ͗ WƌƵĚŚŽĞĂǇ͕ůĂƐŬĂ 6FKOXPEHUJHU3ULYDWH^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ WƵŵƉŝŶŐ^ĐŚĞĚƵůĞ dŚĞĨŽůůŽǁŝŶŐŝƐƚŚĞWƵŵƉŝŶŐ^ĐŚĞĚƵůĞƚŽĂĐŚŝĞǀĞĂƉƌŽƉƉĞĚĨƌĂĐƚƵƌĞŚĂůĨͲůĞŶŐƚŚ;y Ĩ ͿŐƌĞĂƚĞƌƚŚĂŶϮϬϬĨƚ :ŽďĞƐĐƌŝƉƚŝŽŶ ^ƚĞƉ EĂŵĞ WƵŵƉ ZĂƚĞ ;ďďůͬŵŝŶͿ &ůƵŝĚEĂŵĞ ^ƚĞƉůĞĂŶ &ůƵŝĚ sŽůƵŵĞ ;ŐĂůͿ 'Ğů ŽŶĐ͘ ;ůďͬŵŐĂůͿ WƌŽƉ͘ dǇƉĞĂŶĚDĞƐŚ WƌŽƉ͘ ŽŶĐ͘ ;WWͿ /RDG+ROH%U:) ,6,3:) )(7:) ,6,3:) 3$':) 33$:)ϰϬͬϳϬ^ĂŶĚ 33$:)ϰϬͬϳϬ^ĂŶĚ 33$:)ϰϬͬϳϬ^ĂŶĚ 33$:)ϰϬͬϳϬ^ĂŶĚ 33$:)ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϮϬͬϰϬĂƌďŽ 33$<))OH['ϮϬͬϰϬĂƌďŽ )/86+:) )UHH]H3URWHF)UHH]H3URWHFW WůĞĂƐĞŶŽƚĞƚŚĂƚƚŚŝƐƉƵŵƉŝŶŐƐĐŚĞĚƵůĞŝƐƵŶĚĞƌͲĚŝƐƉůĂĐĞĚďǇϱ͘Ϭďďů͘ &ůƵŝĚdŽƚĂůƐ ϭϳϳϯďďůŽĨt&ϭϭϬ ϴϬϮďďůŽĨz&ϭϭϱ&ůĞǆ WƌŽƉƉĂŶƚdŽƚĂůƐ ϭϮϱ͕ϬϬϬůďŽĨϰϬͬϳϬ^ĂŶĚ ϳϱ͕ϬϬϬůďKĨϮϬͬϰϬͲ>ŝƚĞ WĂĚWĞƌĐĞŶƚĂŐĞƐ йWůĞĂŶϭϵ͘ϳ йWŝƌƚǇϭϳ͘ϴ ϭϭƚƚĂĐŚŵĞŶƚ' ůŝĞŶƚ ͗ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ tĞůů ͗ dŚĞƚĂtĞƐƚ &ŽƌŵĂƚŝŽŶ͗ && ŝƐƚƌŝĐƚ ͗ WƌƵĚŚŽĞĂǇ͕ůĂƐŬĂ 6FKOXPEHUJHU3ULYDWH^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ƚĂŐĞϮ ,QLWLDO)UDFWXUH7RS79'IW ,QLWLDO)UDFWXUH%RWWRP79'IW 3URSSHG)UDFWXUH+DOI/HQJWKIW 3URSSHG:LGWKDW:HOOLQ $YHUDJH3URSSHG:LGWKLQ $YHUDJH*HO&RQFHQWUDWLRQOEPJDO $YHUDJH)OXLG5HWDLQHG)DFWRU (2-+\GUDXOLF+HLJKWDW:HOOIW (2-1HW3UHVVXUHSVL (IILFLHQF\ (IIHFWLYH&RQGXFWLYLW\PGIW (IIHFWLYH)FG 0D[6XUIDFH3UHVVXUHSVL Figure 5. Stage 2 Conductivity Plot Proppant Concentration 33$ 33$ 33$ 33$ 33$ !33$ /HQJWKIW Fracture Width :LGWKLQ Lithology and Stress 6WUHVVSVL Sat. and Young's Modulus :HOO'HSWK79'IW <RXQJ V0RGSVL [[[[[[ 0D[6XUIDFH3UHVVXUHSVL ϭϱƚƚĂĐŚŵĞŶƚ' ůŝĞŶƚ ͗ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ tĞůů ͗ dŚĞƚĂtĞƐƚ &ŽƌŵĂƚŝŽŶ͗ && ŝƐƚƌŝĐƚ ͗ WƌƵĚŚŽĞĂǇ͕ůĂƐŬĂ 6FKOXPEHUJHU3ULYDWH^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ĞĐƚŝŽŶϯ͗WƌŽƉƉĞĚ&ƌĂĐƚƵƌĞ^ĐŚĞĚƵůĞʹ^ƚĂŐĞϯ ϭϲƚƚĂĐŚŵĞŶƚ' ůŝĞŶƚ ͗ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ tĞůů ͗ dŚĞƚĂtĞƐƚ &ŽƌŵĂƚŝŽŶ͗ && ŝƐƚƌŝĐƚ ͗ WƌƵĚŚŽĞĂǇ͕ůĂƐŬĂ 6FKOXPEHUJHU3ULYDWH^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ WƵŵƉŝŶŐ^ĐŚĞĚƵůĞ dŚĞĨŽůůŽǁŝŶŐŝƐƚŚĞWƵŵƉŝŶŐ^ĐŚĞĚƵůĞƚŽĂĐŚŝĞǀĞĂƉƌŽƉƉĞĚĨƌĂĐƚƵƌĞŚĂůĨͲůĞŶŐƚŚ;y Ĩ ͿŐƌĞĂƚĞƌƚŚĂŶϮϬϬĨƚ :ŽďĞƐĐƌŝƉƚŝŽŶ ^ƚĞƉ EĂŵĞ WƵŵƉ ZĂƚĞ ;ďďůͬŵŝŶͿ &ůƵŝĚEĂŵĞ ^ƚĞƉůĞĂŶ &ůƵŝĚ sŽůƵŵĞ ;ŐĂůͿ 'Ğů ŽŶĐ͘ ;ůďͬŵŐĂůͿ WƌŽƉ͘ dǇƉĞĂŶĚDĞƐŚ WƌŽƉ͘ ŽŶĐ͘ ;WWͿ /RDG+ROH%U:) ,6,3:) )(7:) ,6,3:) 3$':) 33$:)ϰϬͬϳϬ^ĂŶĚ 33$:)ϰϬͬϳϬ^ĂŶĚ 33$:)ϰϬͬϳϬ^ĂŶĚ 33$:)ϰϬͬϳϬ^ĂŶĚ 33$:)ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϰϬͬϳϬ^ĂŶĚ 33$<))OH['ϮϬͬϰϬĂƌďŽ 33$<))OH['ϮϬͬϰϬĂƌďŽ )/86+:) )UHH]H3URWHF)UHH]H3URWHFW WůĞĂƐĞŶŽƚĞƚŚĂƚƚŚŝƐƉƵŵƉŝŶŐƐĐŚĞĚƵůĞŝƐƵŶĚĞƌͲĚŝƐƉůĂĐĞĚďǇϱ͘Ϭďďů͘ &ůƵŝĚdŽƚĂůƐ ϮϬϱϳďďůŽĨt&ϭϭϬ ϭϬϰϬďďůŽĨz&ϭϭϱ&ůĞǆ WƌŽƉƉĂŶƚdŽƚĂůƐ ϭϳϱ͕ϬϬϬůďŽĨϰϬͬϳϬ^ĂŶĚ ϳϱ͕ϬϬϬůďKĨϮϬͬϰϬͲ>ŝƚĞ WĂĚWĞƌĐĞŶƚĂŐĞƐ йWůĞĂŶϭϵ͘ϳ йWŝƌƚǇϭϳ͘ϴ ϭϳƚƚĂĐŚŵĞŶƚ' ůŝĞŶƚ ͗ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ tĞůů ͗ dŚĞƚĂtĞƐƚ &ŽƌŵĂƚŝŽŶ͗ && ŝƐƚƌŝĐƚ ͗ WƌƵĚŚŽĞĂǇ͕ůĂƐŬĂ 6FKOXPEHUJHU3ULYDWH^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ƚĂŐĞϯ ,QLWLDO)UDFWXUH7RS79'IW ,QLWLDO)UDFWXUH%RWWRP79'IW 3URSSHG)UDFWXUH+DOI/HQJWKIW 3URSSHG:LGWKDW:HOOLQ $YHUDJH3URSSHG:LGWKLQ $YHUDJH*HO&RQFHQWUDWLRQOEPJDO $YHUDJH)OXLG5HWDLQHG)DFWRU (2-+\GUDXOLF+HLJKWDW:HOOIW (2-1HW3UHVVXUHSVL (IILFLHQF\ (IIHFWLYH&RQGXFWLYLW\PGIW (IIHFWLYH)FG 0D[6XUIDFH3UHVVXUHSVL Figure 9. 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:HOO1DPH7KHWD:HVW &RPSDQ\*UHDW%HDU3DQWKHRQ//& )LHOG &RQWDFW0LFKDHO'XQFDQ 3URSRVDO1XPEHU 'DWH 0DGH%\5R[DQQH0DULQR 6HUYLFHIURP'LVWULFW3UXGKRH%D\$.$ 'LVWULFW3KRQH 2EMHFWLYH3XPSVHFRQGVWDJHWKURXJKVWDJH WRROZLWK72&DWIW $FFHSWDQFH&ULWHULD3XPSDVSHUSURJUDP5DWH 'HQVLW\3UHVVXUH RI 'RFXPHQW&RQWURO 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 Roxanne Marino Schlumberger review Stephen Lauper 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 cementing program.” Distribution List : Cementing Program Generated From Cementics File theta west_ 5.5-in prod_two stage_top final.jdcx Cementics Version 2020.2.4 Revision History Date Version Description Author 2/23/22 4 Cement retainer and tubing added RMarino 2/13/22 3 TOC changed to 5400 ft RMarino RI :HOO'DWD6XPPDU\ The cementing program incorporates the following data : RigType Land Fluids Return to Rig Floor BHST 137.1 degF All depths take the rig floor as reference Mud Line Depth 0.0 ft Mud Return Depth 0.0 ft Section MD 7227.0 ft Section TVD 7226.5 ft Tubulars and Casing Hardware MD ft OD in Joint ft Weight lb/ft ID in Grade Collapse psi Burst psi Thread Prev Casing 110.0 20 40.0 94.0 19.124 K-55 520 2110 3030.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 Tubing 7127.0 2 7/8 40.0 6.8 2.441 X95 12940 12548 Casing 7227.0 5 1/2 40.0 17.0 4.892 P-110 7480 10640 Landing Collar 7147.0 Serial number : RI Open Hole Total Volume 363.1 bbl Minimum Diameter 8.500 in Maximum Diameter 8.500 in Mean Diameter 8.500 in Mean Annular Excess 40.0 % Mean Equivalent Diameter 9.437 in Formation 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 70.0 70.0 10.50 10.50 8.40 8.40 70.0 1400.0 1400.0 10.50 10.50 8.40 8.43 Permafrost 1400.0 3000.0 3000.0 10.50 10.50 8.43 8.40 Sandstone 3000.0 4000.0 4000.0 10.50 10.50 8.40 8.40 Sandstone 4000.0 7227.0 7226.5 10.50 11.00 8.40 8.40 Sandstone RI Temperature 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 20.0 0.00 -196702.76 Rock 0.0 1200.0 1200.0 39.4 1.62 1.62 0.00 Rock 1200.0 2500.0 2500.0 60.5 1.62 1.62 0.00 Rock 2500.0 3500.0 3500.0 76.7 1.62 1.62 -196702.76 Rock 3500.0 4000.0 4000.0 84.8 1.62 1.62 0.00 Rock 4000.0 7200.0 7199.5 136.6 1.62 1.62 0.00 BHST 7200.0 7227.0 7226.5 137.1 1.62 1.62 0.00 Rock 7227.0 7600.0 7599.4 143.1 1.62 1.62 0.00 Rock 7600.0 8600.0 8599.4 159.3 1.62 1.62 0.00 Rock 8600.0 9000.0 8999.4 165.8 1.62 1.62 0.00 Rock 9000.0 9400.0 9399.4 172.3 1.62 1.62 0.00 RI )OXLGV6XPPDU\ Fluids Type Name Density lb/gal Conditions K lbf.s^n/ft2 n Ty lbf/100ft2 Wash Fresh Water 8.32 Manual 1.04E-4 1.00 1.00 Drilling Fluid WBM 1 9.20 Manual 0.00E+0 0.00 0.00 Spacer MUDPUSH II Spacer 1 9.80 Manual 0.00E+0 0.00 0.00 Wash Fresh Water 1 8.32 Manual 0.00E+0 0.00 0.00 Slurry 15.8 ppg slurry 1 15.80 Manual 1.23E-2 0.78 0.00 Slurry 13.0ppg Lead Slurry 1 13.00 Manual 1.03E-2 0.71 4.00 * Compressible Rheology Parameters and Densities are displayed at P=1 atm and T=20 degC (65degF) RI 0XG&LUFXODWLRQ Fluid WBM Number of Circulation 2.65 Total Volume at Ambient T 1125.0 bbl Ambient Temperature 60.0 degF Correction Slope 0.80 Pumping Stages Fluid Pump Rate bbl/min Duration hr:mn Volume bbl WBM 2.0 00:15 30.0 WBM 4.0 00:15 60.0 WBM 5.0 00:15 75.0 8.0 02:00 960.0 Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 92 3030.0 02:45 Success Production/Influx 215 3030.0 02:45 Success Burst 9549 0.0 02:45 Success Collapse 12564 7127.0 02:45 RI )OXLG3ODFHPHQW Surface Densities are computed at P=1 atm and T=Surface Temperature (20.0 degF) Fluid Placement in Annulus Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal WBM 0.0 4699.7 4699.7 236.1 9.20 MUDPUSH II Spacer 4699.7 5400.0 700.3 40.0 9.80 13.0ppg Lead Slurry 5400.0 6500.0 1100.0 62.8 13.00 15.8 ppg slurry 6500.0 7227.0 727.0 41.5 15.80 Fluid Placement in Pipe Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal WBM 0.0 5479.7 5479.7 31.7 9.20 Fresh Water 5479.7 7147.0 1667.3 10.0 8.32 15.8 ppg slurry 7147.0 7227.0 80.0 1.9 15.80 RI 3XPSLQJ6FKHGXOH Pumping Schedule Fluid Name Duration hr:mn Volume bbl Pump Rate bbl/min Injection Temperature degF Comment Cumulated Time hr:mn MUDPUSH II Spacer 00:20 40.0 2.0 68.0 Cement Line 00:20 13.0ppg Lead Slurry 1 00:31 62.8 2.0 68.0 Cement Line 00:51 15.8 ppg slurry 1 00:22 43.4 2.0 68.0 Cement Line 01:13 Fresh Water 00:05 10.0 2.0 68.0 Cement Line 01:18 WBM : 00:22 31.7 Rig Displaces > WBM 00:10 20.0 2.0 68.0 01:28 > WBM 00:12 11.7 1.0 68.0 slow down for plug bump 01:40 Maximum Required Hydraulic Horsepower (HHP)30.1 hhp (at 00:00 hr:mn) RI :HOO6HFXULW\ Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 32 7227.0 01:40 Success Production/Influx 208 3030.0 01:40 Success Burst 10022 7127.0 01:40 Success Collapse 12102 7127.0 01:40 Success Dead-End Collapse 6495 7127.0 01:40 Success Dynamic u-tubing in Dead-End 0 0.0 00:00 Success Balanced u-tubing in Dead-End 0 0.0 00:00 RI 7HPSHUDWXUH2XWSXWV Temperature Summary Table Static Temperature. at TOC 107.5 degF Static Temperature at BH 137.1 degF Simulated HCT at TOC 83.2 degF Simulated HCT at BH 70.5 degF Max First SK Temperature 83.2 degF Max Last SK Temperature 70.4 degF At time 01:40 hr:mn At time 01:40 hr:mn RI &HQWUDOL]DWLRQ Centralizers Alias Manufacturer Commercial Name Type Config Csg OD in Min OD in Max OD in Count CT_2A05500675000C 0 CaseTech Std Bow Spring bow- spring 5 1/2 6.000 7.625 54 Pattern Placement Bottom MD ft Joints Centralizer Alias Pattern Min STO Depth ft 4000.0 100.00 CT_2A05500675000C0 0 0.0 3540.0 9000.0 0.00 CT_2A05500675000C0 2/3 0.0 7227.0 Computation time: Cement Turns 00:39 RI :(//&/($1 ,,, Average Fluid Concentrations Average fluid concentration in annulus Average fluid concentration in pipe RI Final Fluid Concentrations RI Post-Processing Results (Annulus) RI '$3(5785( Average Fluid Concentrations Average fluid concentration in annulus Average fluid concentration in pipe RI Final Fluid Concentrations RI Post-Processing Results (Annulus) RI 2SHUDWRU6XPPDU\ Volume Summary Fluid Name Pumped Volume bbl Prepared Fluid Dead Volume bbl Prepared Fluid bbl Mix Fluid Dead Volume bbl Silo dead volume ton 15.8 ppg slurry 1 43.4 0.0 43.4 0.0 0 13.0ppg Lead Slurry 1 62.8 0.0 62.8 0.0 0 MUDPUSH II Spacer 40.0 2.0 42.0 0.0 0 Fresh Water 10.0 0.0 10.0 0.0 0 Material Summary Additive Pumped Quantity Required Quantity Loadout Quantity Loadout Items Pack. Name Pack. Size Comment D031 3607 lb 3788 lb 3788 lb 34.43 sack 110 lb Fresh Water 4965 gal 5043 gal 5043 gal 0.00 0 gal D182 186 lb 195 lb 195 lb 3.91 sack 50 lb 15.8 ppg slurry 1 Blend 19732 lb 19732 lb 19732 lb 0.00 bulk 0 lb Mix Water 2982 gal 2982 gal 2982 gal 0.00 0 gal D177 5 gal 5 gal 5 gal 0.10 drum 55 gal D255 162 lb 162 lb 162 lb 7.38 sack 22 lb D047 14 gal 14 gal 14 gal 2.81 pail 5 gal D065 93 lb 93 lb 93 lb 1.85 sack 50 lb 13.0ppg Lead Slurry 1 Blend 16693 lb 16693 lb 16693 lb 0.00 bulk 0 lb D013 75 lb 75 lb 75 lb 1.50 sack 50 lb D110 9 gal 9 gal 9 gal 1.78 pail 5 gal D020 1169 lb 1169 lb 1169 lb 10.62 sack 110 lb D153 67 lb 67 lb 67 lb 2.67 sack 25 lb D079 50 lb 50 lb 50 lb 0.50 sack 100 lb RI Fluid Preparation 15.8 ppg slurry 1 Pumped Volume : 43.4 bbl Density : 15.80 lb/gal SVF : 40.5 % Yield : 1.16 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 19870 lb 19870 lb 15.8 ppg slurry 1 Blend: 94 lb per sack 19732 lb 19732 lb 19732 lb - G 100.0 % BVOB 19732 lb 19732 lb 19732 lb D255 0.4 % BWOC 79 lb 79 lb 79 lb D065 0.3 % BWOC 59 lb 59 lb 59 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 5.106 gal/sk VBWOB 1072 gal 1072 gal Mix Water 5.031 gal/sk VBWOB 1056 gal 1056 gal 1056 gal Fresh Water 5.031 gal/sk VBWOB 1056 gal 1056 gal 1056 gal D177 0.025 gal/sk VBWOC 5 gal 5 gal 5 gal D047 0.050 gal/sk VBWOC 10 gal 10 gal 10 gal 13.0ppg Lead Slurry 1 Pumped Volume : 62.8 bbl Density : 13.00 lb/gal SVF : 25.8 % Yield : 1.99 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 18171 lb 18171 lb 13.0ppg Lead Slurry 1 Blend: 94 lb per sack 16693 lb 16693 lb 16693 lb - G 100.0 % BVOB 16693 lb 16693 lb 16693 lb D013 0.5 % BWOC 75 lb 75 lb 75 lb D020 7.0 % BWOC 1169 lb 1169 lb 1169 lb D255 0.5 % BWOC 83 lb 83 lb 83 lb D065 0.2 % BWOC 33 lb 33 lb 33 lb D153 0.4 % BWOC 67 lb 67 lb 67 lb D079 0.3 % BWOC 50 lb 50 lb 50 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 10.914 gal/sk VBWOB 1938 gal 1938 gal Mix Water 10.844 gal/sk VBWOB 1926 gal 1926 gal 1926 gal Fresh Water 10.844 gal/sk VBWOB 1926 gal 1926 gal 1926 gal D110 0.050 gal/sk VBWOC 9 gal 9 gal 9 gal D047 0.020 gal/sk VBWOC 4 gal 4 gal 4 gal RI MUDPUSH II Spacer Pumped Volume : 40.0 bbl Density : 10.00 lb/gal Weighting Material Concentration Pumped Quantity Required Quantity Loadout Quantity MUDPUSH II Spacer Weighting Material: 2.15 lb/gal WBVOSpacer 3607 lb 3788 lb 3788 lb - D031 2.15 lb/gal WBVOSpacer 3607 lb 3788 lb 3788 lb Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpacer 1580 gal 1659 gal Fresh Water 0.9 bbl/bbl BVOSpacer 1563 gal 1641 gal 1641 gal D182 5.00 lb/bbl WBVOBF 186 lb 195 lb 195 lb Fresh Water Pumped Volume : 10.0 bbl Density : 8.32 lb/gal Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 1.0 bbl/bbl BVOWash 420 gal 420 gal Fresh Water 1.0 bbl/bbl BVOWash 420 gal 420 gal 420 gal RI &DUOLVOH6DPDQWKD-2*& )URP/RHSS9LFWRULD72*& 6HQW7KXUVGD\)HEUXDU\$0 7R0LFKDHO'XQFDQ &F/RHSS9LFWRULD72*& 6XEMHFW7KHWD:HVW37'&HPHQWUHWDLQHU$33529$/ ƉƉƌŽǀĂůŝƐŐƌĂŶƚĞĚƚŽƌƵŶƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌŝŶƚŚĞǁĞůů͘ sŝĐƚŽƌŝĂ>ŽĞƉƉ &ƌŽŵ͗DŝĐŚĂĞůƵŶĐĂŶфŵŝĐŚĂĞůΛŐƌĞĂƚďĞĂƌƉĞƚƌŽ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕&ĞďƌƵĂƌǇϮϰ͕ϮϬϮϮϴ͗ϭϳD dŽ͗>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'ͿфǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗dŚĞƚĂtĞƐƚηϭ;WdϮϮϭͲϭϬϲͿĞŵĞŶƚƌĞƚĂŝŶĞƌ sŝĐƚŽƌŝĂʹ tĞĂƌĞƉƌĞƉĂƌŝŶŐƚŽƌƵŶƚŚĞĐĞŵĞŶƚƌĞƚĂŝŶĞƌŝŶƚŚĞǁĞůů͘/ƐĞĞŬǀĞƌďĂů;ĞŵĂŝůͿĂƉƉƌŽǀĂůƚŽŵŽǀĞĨŽƌǁĂƌĚǁŝƚŚƚŚŝƐƐƚĞƉ͘ WůĞĂƐĞůĞƚŵĞŬŶŽǁ͘ dŚĂŶŬǇŽƵ͕ DŝĐŚĂĞůƵŶĐĂŶ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ ϴϭϳ͘ϮϰϬ͘ϯϴϲϱ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH as l- loco Meenrices os /.�� A ScNumbergar �Y Field Shipping Manifest &&ft Nr Nordic 3 ow Dry Samples Set A (AOGCC) DATE 2/8/2022 Operator Great Bear Pa itheon WELL Theta West 1 Location North Slope Alaska FROM: Geoservices Nordic 3 Rig Contact Numbers Geoservices Contact: Warner Morales +1 713 480 8141 Great Bear Pantheon Geologist: 303-947-6354 AOGCC: 907-793-1235 SHIP TO: 333 W. 7th Anchorage, AK 9501 NOTE TO ORIGINATOR: SAVE TIME AND $$-AVOID MISINTERETATIONS-USE COMPLETE, DETAILED INSTRUCTIONS IN ORDER FOR THE TERMINAL TO QUICKLY AND ACCURATELY EXECUTE YOUR REQUESTS. QTY Container # Container # Number of Samples Via Transport Owned b P 0 Depth (ft) Total Weight Lbs 1 Brown Box # 1 25 Truck GBP 360 - 1080 25 1 Blue Box 1 Brown Box # 2 25 Truck GBP 1110 - 1830 25 1 Brown Box # 3 25 Truck GBP 1860 - 2580 25 1 Brown Box # 4 25 Truck GBP 2610 - 3300 25 1 Blue Box 2 Brown Box # 5 25 Truck GBP 3330 - 4050 25 1 Brown Box # 6 25 Truck GBP 4080 - 4800 25 1 Brown Box # 7 25 Truck GBP 4830 - 5550 25 1 Blue Box 3 Brown Box # 8 25 Truck GBP 5580 - 6300 25 1 Brown Box # 9 25 Truck GBP 6330 - 6810 25 1 Brawn Box # 10 25 Truck GBP 6820 - 7060 25 1 Blue Box 4 Brown Box # 11 25 Truck GBP 7070 - 7310 25 1 Brown Box # 12 25 Truck GBP 7320 - 7560 25 1 Brown Box # 13 25 Truck GBP 7570 - 8020 25 1 Blue Box 5 Brown Box # 14 22 Truck GBP 8040 - 8452 25 TOTALS 14 Envelopes : 347 1 360 - 8452 350 Please Handle this box and its contents with care! RECEIVED FEB 14 2022 AOGCC no_, �, 1�B12 Schlurn berger-Private STATE OF ALASKA Reviewed By: 334) OIL AND GAS CONSERVATION COMMISSION P.I. Supry L z"r-t— BOPE Test Report for: THETA WEST 1 Comm Contractor/Rig No.: Nordic 3 PTD#: 2211060 DATE: 1/27/2022 Inspector Austin McLeod Insp Source Operator: Great Bear Pantheon, LLC Operator Rep: Brouillet/Wall Rig Rep: Pederson/Hansen Inspector Type Operation: EXPL Sundry No: Test Pressures: Inspection No: bopSAM220129102423 Rams: Annular: Valves: MASP: Type Test: [NIT 250/5000 . 250/2500 - 250/5000 3800 % Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: P/F ACCUMULATOR SYSTEM: P/F P/F P/F Visual Alarm 1 Time/Pressure P/F Location Gen.: P Trip Tank P _P P-- System Pressure 2950 P - Housekeeping: P Pit Level Indicators P _ P Pressure After Closure 1500 P PTD On Location P Flow Indicator P - P 200 PSI Attained 26 P Standing Order Posted P Meth Gas Detector P P � Full Pressure Attained 138 P " Well Sign P H2S Gas Detector P_ - P - Blind Switch Covers: All stations P ' Drl. Rig P MS Misc NA NA Nitgn. Bottles (avg): 4g2000 - P Hazard Sec. P #4 Rams ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: -_NA CHOKE MANIFOLD: Number of Failures: 0 Test Results Test Time 6.5 Remarks: 4" joint. Annular 18 secs; Rams 6 secs; HCR's 2 secs. CH Misc - pre choke mainifold. Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 1 P-- Stripper 0__ _NA - No. Valves 12 - P-- -- ., L.uwe� Keu,y 1 % P' Annular Preventer 1 -_ 13-5/8" - _P - Manual Chokes 1_____ P Ball Type 1 P #1 Rams 1 2-7/8"x5-1/2"- P Hydraulic Chokes I P - Inside BOP _ 1 P #2 Rams 1 Blinds - P _ CH Misc I = _P_ FSV Misc 0 NA #3 Rams 1 , 2-7/8"x5-1/2"- P #4 Rams 0 NA #5 Rams - — _ -_NA INSIDE REEL VALVES: #6 Rams _0 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 _ 3-1/8" P - Quantity P/F HCR Valves _ 2 '3-1/8" P - Inside Reel Valves 0 NA — Kill Line Valves 2 ' 3-1/8" P - Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 Test Results Test Time 6.5 Remarks: 4" joint. Annular 18 secs; Rams 6 secs; HCR's 2 secs. CH Misc - pre choke mainifold. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: P.I. Supry DIVERTER Test Report for: THETA WEST 1 Comm Contractor/Rig No.: Nordic 3 . PTD#: 2211060 - DATE: 1/21/2022 " Inspector Adam Earl _ Insp Source Operator: Great Bear Pantheon, LLC Operator Rep: Duncan/Brouillet Rig Rep: Jake Henry Inspector Well Class: EXP Inspection No: divAGE220124125835 Related Insp No: MISC. INSPECTIONS: GAS DETECTORS: Visual Alarm Methane: P` P - Hydrogen Sulfide: P P Gas Detectors Mise: 0 NA Number of Failures: Remarks: 0 TEST DATA MUD SYSTEM: PIF Location Gen.: P Housekeeping: P " Warning Sign P 24 hr Notice: P Well Sign: P Drlg. Rig. P Misc: NA GAS DETECTORS: Visual Alarm Methane: P` P - Hydrogen Sulfide: P P Gas Detectors Mise: 0 NA Number of Failures: Remarks: 0 TEST DATA MUD SYSTEM: P/F Visual Alarm Trip Tank: P P Mud Pits: P . P " Flow Monitor: P P ' Mud System Mise: 0 NA ACCUMULATOR SYSTEM: P/F Time/Pressure PIF Systems Pressure: 2900 - P - Pressure After Closure: 1475 P 200 psi Recharge Time: 30 P Full Recharge Time: 157 P Nitrogen Bottles (Number of): 4 P Avg. Pressure: 2050 P Accumulator Misc: 0 NA DIVERTER SYSTEM: Size P/F 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: 85 P Closest Ignition Source: 75 P Outlet from Rig Substructure: 75 P ` Vent Line(s) Anchored: P " Turns Targeted / Long Radius: NA Divert Valve(s) Full Opening: P " Valve(s) Auto & Simultaneous: Annular Closed Time: 25---- P Knife Valve Open Time: 10 P Diverter Misc: 0 NA Test Time: 2.5 333 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 3705 Arctic Blvd., Suite 2324 Anchorage, AK 99503 Re: Exploratory Field, Exploratory Pool, Theta West 1 Great Bear Patheon Permit to Drill Number: 221-106 Surface Location: 3000' FEL, 4860' FNL, T07N, R11E, SEC. 32, UM Bottomhole Location: 3000' FEL, 4860' FNL, T07N, R11E, SEC. 32, UM Dear Mr. Duncan: Enclosed is the approved application for the permit to drill the above referenced well. Drilling operations must cease before penetrating the potentially over-pressured Kuparuk Formation. All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 January, 2022. 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basis for the well cementing program.” Distribution List : Cementing Program Generated From Cementics File Theta West_ 9 5_8in surface_ v1.jdcx Cementics Version 2020.2.4 Revision History Date Version Description Author 12/1/2021 V2 Updated Depth slauper ϯŽĨϮϬ tĞůůĂƚĂ^ƵŵŵĂƌǇ The cementing program incorporates the following data : RigType Land Fluids Return to Rig Floor BHST 80.3 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 3500.0 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 94.0 19.124 K-55 520 2110 Casing 3500.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 Landing Collar 3420.0 Serial number : Float Shoe ϰŽĨϮϬ 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 Formation 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 70.0 70.0 12.50 12.50 8.40 8.40 70.0 1200.0 1200.0 12.50 12.50 8.40 8.43 Permafrost 1200.0 3500.0 3500.0 12.50 12.50 8.43 7.20 Shale ϱŽĨϮϬ Temperature 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 20.0 0.00 -196702.76 Rock 0.0 1200.0 1200.0 32.0 1.00 1.00 0.00 Rock 1200.0 2500.0 2500.0 59.3 1.57 2.10 0.00 Rock 2500.0 3000.0 3000.0 69.8 1.66 2.10 0.00 BHST 3000.0 3500.0 3500.0 80.3 1.72 2.10 0.00 ϲŽĨϮϬ &ůƵŝĚƐ^ƵŵŵĂƌǇ Fluids Type Name Density lb/gal Conditions K lbf.s^n/ft2 nTy lbf/100ft2 Drilling Fluid Surface Mud 9.50 Surface 68.0 degF 2.80E-3 0.72 21.63 Spacer MUDPUSH II Spacer 10.00 Custom 65.0 degF [ T2 ] 2.93E-2 0.40 10.56 Slurry ARCTICSET Light III Surface Lead 10.70 Downhole 68.0 degF 1.14E-1 0.28 0.00 Slurry ARCTICSET I Surface Tail 15.70 Downhole 68.0 degF 2.13E-3 0.95 6.67 Wash Fresh Water 8.32 Manual 1.04E-4 1.00 1.00 * Compressible Rheology Parameters and Densities are displayed at P=1 atm and T=20 degC (65degF) ϳŽĨϮϬ DƵĚŝƌĐƵůĂƚŝŽŶ Fluid Surface Mud Number of Circulation 1.61 Total Volume at Ambient T 1125.0 bbl Ambient Temperature 70.0 degF Correction Slope 0.80 Pumping Stages Fluid Pump Rate bbl/min Duration hr:mn Volume bbl Surface Mud 2.0 00:15 30.0 Surface Mud 4.0 00:15 60.0 Surface Mud 5.0 00:15 75.0 8.0 02:00 960.0 Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 15 100.0 02:45 Success Production/Influx 7 100.0 02:45 Success Burst 5634 0.0 02:45 Success Collapse 2948 3500.0 02:45 ϴŽĨϮϬ &ůƵŝĚWůĂĐĞŵĞŶƚ Surface Densities are computed at P=1 atm and T=Surface Temperature (20.0 degF) Fluid Placement in Annulus Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal Surface Mud 0.0 0.0 0.0 0.0 9.50 MUDPUSH II Spacer 0.0 0.0 0.0 40.0 10.00 ARCTICSET Light III Surface Lead 0.0 3000.0 3000.0 391.9 10.70 ARCTICSET I Surface Tail 3000.0 3500.0 500.0 41.8 15.70 Fluid Placement in Pipe Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal Surface Mud 0.0 3354.1 3354.1 254.3 9.50 Fresh Water 3354.1 3420.0 65.9 5.0 8.32 ARCTICSET I Surface Tail 3420.0 3500.0 80.0 6.1 15.70 ϵŽĨϮϬ 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 Spacer 00:10 40.0 4.0 80.0 00:10 Pause 00:10 00:20 ARCTICSET Light III Surface Lead 01:38 391.9 4.0 80.0 01:58 ARCTICSET I Surface Tail 00:12 47.9 4.0 80.0 02:10 Pause 00:05 02:15 Fresh Water 00:01 5.0 4.0 80.0 02:16 Surface Mud : 00:49 254.3 > Surface Mud 00:39 234.3 6.0 80.0 02:55 > Surface Mud 00:10 20.0 2.0 80.0 03:05 Maximum Required Hydraulic Horsepower (HHP)60.2 hhp (at 02:55 hr:mn) ϭϬŽĨϮϬ ϭϭŽĨϮϬ tĞůů^ĞĐƵƌŝƚǇ Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 9 100.0 03:05 Success Production/Influx 6 100.0 03:05 Success Burst 5331 0.0 03:05 Success Collapse 2620 3500.0 03:05 N/A Dead-End Collapse 0 0.0 00:00 N/A Dynamic u-tubing in Dead-End 0 0.0 00:00 N/A Balanced u-tubing in Dead-End 0 0.0 00:00 ϭϮŽĨϮϬ dĞŵƉĞƌĂƚƵƌĞKƵƚƉƵƚƐ Temperature Summary Table Static Temperature. at TOC 20.0 degF Static Temperature at BH 80.3 degF Simulated HCT at TOC 64.1 degF Simulated HCT at BH 71.8 degF Max First SK Temperature 80.0 de gF Max Last SK Temperature 80.0 degF At time 00:00 hr:mn At time 00:00 hr:mn ϭϯŽĨϮϬ ĞŶƚƌĂůŝǌĂƚŝŽŶ Centralizers Alias Manufacturer Commercial Name Type Config Csg OD in Min OD in Max OD in Count CT_2A09631225000C 0 CaseTech Std Bow Spring bow- spring 9 5/8 10.500 13.431 18 Pattern Placement Bottom MD ft Joints Centralizer Alias Pattern Min STO Depth ft 2500.0 62.50 CT_2A09631225000C0 1/6 100.0 0.0 3500.0 25.00 CT_2A09631225000C0 1/3 100.0 2503.1 Computation time: 03:05 ϭϰŽĨϮϬ t>>>EΎ/// Imposed StandOff Bottom MD ft StandOff % 3500.0 60.0 Average Fluid Concentrations Average fluid concentration in annulus Average fluid concentration in pipe ϭϱŽĨϮϬ Final Fluid Concentrations ϭϲŽĨϮϬ Post-Processing Results (Annulus) ϭϳŽĨϮϬ 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 ARCTICSET Light III Surface Lead 391.9 2.0 393.9 0.0 0 ARCTICSET I Surface Tail 47.9 2.0 49.9 0.0 0 MUDPUSH II Spacer 40.0 2.0 42.0 0.0 0 Fresh Water 5.0 0.0 5.0 0.0 0 Material Summary Additive Pumped Quantity Required Quantity Loadout Quantity Loadout Items Pack. Name Pack. Size Comment D031 3607.44 lb 3787.81 lb 3787.81 lb 34.43 sack 110.00 lb Fresh Water 13229.03 gal 13404.07 gal 13404.07 gal 0.00 0.00 gal D182 186.10 lb 195.41 lb 195.41 lb 3.91 sack 50.00 lb ARCTICSET Light III Surface Lead Blend 79484.88 lb 79890.53 lb 79890.53 lb 0.00 bulk 0.00 lb Mix Water 11455.76 gal 11552.64 gal 11552.64 gal 0.00 0.00 gal D044 7793.17 lb 7832.94 lb 7832.94 lb 142.42 sack 55.00 lb S002 596.14 lb 599.18 lb 599.18 lb 5.99 sack 100.00 lb D047 85.21 gal 85.85 gal 85.85 gal 17.17 pail 5.00 gal D065 278.20 lb 279.62 lb 388.94 lb 7.78 sack 50.00 lb D079 715.36 lb 719.01 lb 719.01 lb 7.19 sack 100.00 lb ARCTICSET I Surface Tail Blend 22812.57 lb 23765.04 lb 23765.04 lb 0.00 bulk 0.00 lb ϭϴŽĨϮϬ Fluid Preparation ARCTICSET Light III Surface Lead Pumped Volume : 391.9 bbl Density : 10.70 lb/gal SVF : 33.9 % Yield : 2.77 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 88867.74 lb 89321.27 lb ARCTICSET Light III Surface Lead Blend: 100.00 lb per sack 79484.88 lb 79890.53 lb 79890.53 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 13.194 gal/sk VBWOB 10487.02 gal 10540.54 gal Mix Water 13.094 gal/sk VBWOB 10407.54 gal 10460.65 gal 10460.65 gal Fresh Water 13.094 gal/sk VBWOB 10407.54 gal 10460.65 gal 10460.65 gal D047 0.100 gal/sk VBWOB 79.48 gal 79.89 gal 79.89 gal ARCTICSET I Surface Tail Pumped Volume : 47.9 bbl Density : 15.70 lb/gal SVF : 47.6 % Yield : 0.94 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 22812.57 lb 23765.04 lb ARCTICSET I Surface Tail Blend: 79.74 lb per sack 22812.57 lb 23765.04 lb 23765.04 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 3.684 gal/sk VBWOB 1053.94 gal 1097.95 gal Mix Water 3.664 gal/sk VBWOB 1048.22 gal 1091.98 gal 1091.98 gal Fresh Water 3.664 gal/sk VBWOB 1048.22 gal 1091.98 gal 1091.98 gal D047 0.020 gal/sk VBWOB 5.72 gal 5.96 gal 5.96 gal ϭϵŽĨϮϬ MUDPUSH II Spacer Pumped Volume : 40.0 bbl Density : 10.00 lb/gal Weighting Material Concentration Pumped Quantity Required Quantity Loadout Quantity MUDPUSH II Spacer Weighting Material: 2.15 lb/gal WBVOSpacer 3607.44 lb 3787.81 lb 3787.81 lb - D031 2.15 lb/gal WBVOSpacer 3607.44 lb 3787.81 lb 3787.81 lb Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpace r 1580.17 gal 1659.18 gal Fresh Water 0.9 bbl/bbl BVOSpacer 1563.28 gal 1641.44 gal 1641.44 gal D182 5.00 lb/bbl WBVOBF 186.10 lb 195.41 lb 195.41 lb Fresh Water Pumped Volume : 5.0 bbl Density : 8.32 lb/gal Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 1.0 bbl/bbl BVOWash 210.00 gal 210.00 gal Fresh Water 1.0 bbl/bbl BVOWash 210.00 gal 210.00 gal 210.00 gal ϮϬŽĨϮϬ &ƌŝĐƚŝŽŶWƌĞƐƐƵƌĞĂůĐƵůĂƚŽƌ Fluid rates and rheologies are calculated at P = 15 psi and T = 68.0 degF Flow in Annulus at Various Rates Pipe External Diameter : 9.625 in Hole Diameter : 12.250 in Flow Rate – Minimum : 3.0 bbl/min Flow Rate – Maximum : 8.0 bbl/min ĂƐŝŶŐĞŵĞŶƚŝŶŐWƌŽŐƌĂŵ ^ƚƌŝŶŐ͗ ϳΗWƌŽĚƵĐƚŝŽŶĂƐŝŶŐ tĞůůEĂŵĞ͗ dŚĞƚĂtĞƐƚ ŽŵƉĂŶǇ͗ 'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ>> &ŝĞůĚ͗ ŽŶƚĂĐƚ͗ DŝĐŚĂĞůƵŶĐĂŶ ^ƚĂƚĞ͗ < WƌŽƉŽƐĂůEƵŵďĞƌ͗ Ϯ ĂƚĞ͗ ϭϮͬϭͬϮϬϮϭ DĂĚĞǇ͗ ^ƚĞƉŚĞŶ>ĂƵƉĞƌ 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 ϮŽĨϭϴ ŽĐƵŵĞŶƚŽŶƚƌŽů Document Name and Version : 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 Stephen Lauper 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 cementing program.” Distribution List : Cementing Program Generated From Cementics File Theta West_ 7-in Prod_ v1.jdcx Cementics Version 2020.2.4 Revision History Date Version Description Author 12/01/2021 V2 Updated depths slauper ϯŽĨϭϴ tĞůůĂƚĂ^ƵŵŵĂƌǇ The cementing program incorporates the following data : RigType Land Fluids Return to Rig Floor BHST 173.9 degF All depths take the rig floor as reference Mud Line Depth 0.0 ft Mud Return Depth 0.0 ft Section MD 9500.0 ft Section TVD 9499.1 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 94.0 19.124 K-55 520 2110 3500.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 Casing 9500.0 7 40.0 29.0 6.184 P-110 5410 7740 Landing Collar 9420.0 Serial number : Float Shoe ϰŽĨϭϴ Open Hole Total Volume 475.3 bbl Minimum Diameter 8.500 in Maximum Diameter 12.250 in Mean Diameter 8.500 in Mean Annular Excess 40.0 % Mean Equivalent Diameter 9.031 in Formation 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 70.0 70.0 8.50 8.50 8.40 8.40 70.0 1200.0 1200.0 8.50 11.25 8.40 8.43 Permafrost 1200.0 3000.0 3000.0 11.25 12.50 8.43 8.40 Shale 3000.0 4000.0 4000.0 12.50 12.50 8.40 8.75 Shale 4000.0 7500.0 7499.4 12.50 12.50 8.75 8.80 Sandstone 7500.0 9750.0 9749.1 12.50 12.50 8.80 9.00 Sandstone ϱŽĨϭϴ Temperature 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 20.0 0.00 -196702.76 Rock 0.0 1200.0 1200.0 39.4 1.62 1.62 0.00 Rock 1200.0 2500.0 2500.0 60.5 1.62 1.62 0.00 Rock 2500.0 3500.0 3500.0 76.7 1.62 1.62 -196702.76 Rock 3500.0 4000.0 4000.0 84.8 1.62 1.62 0.00 Rock 4000.0 9400.0 9399.2 172.3 1.62 1.62 0.00 BHST 9400.0 9500.0 9499.1 173.9 1.62 1.62 0.00 ϲŽĨϭϴ &ůƵŝĚƐ^ƵŵŵĂƌǇ Fluids Type Name Density lb/gal Conditions K lbf.s^n/ft2 nTy lbf/100ft2 Drilling Fluid WBM 9.20 Custom 68.0 degF 2.80E-3 0.72 21.63 Spacer MUDPUSH II Spacer 11.00 Custom 65.0 degF [ T2 ] 2.93E-2 0.40 10.56 Wash Fresh Water 8.32 Manual 1.04E-4 1.00 1.00 Slurry 15.8ppg Tail Slurry 15.80 Custom 132.0 degF 1.77E-2 0.72 0.00 Slurry 13.0ppg Lead Slurry 13.00 Custom 132.0 degF 2.87E-3 0.82 1.09 * Compressible Rheology Parameters and Densities are displayed at P=1 atm and T=20 degC (65degF) ϳŽĨϭϴ DƵĚŝƌĐƵůĂƚŝŽŶ Fluid WBM Number of Circulation 1.75 Total Volume at Ambient T 1125.0 bbl Ambient Temperature 60.0 degF Correction Slope 0.80 Pumping Stages Fluid Pump Rate bbl/min Duration hr:mn Volume bbl WBM 2.0 00:15 30.0 WBM 4.0 00:15 60.0 WBM 5.0 00:15 75.0 8.0 02:00 960.0 Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 284 3500.0 02:45 Success Production/Influx 331 3500.0 02:45 Success Burst 6807 0.0 02:45 Success Collapse 4881 9500.0 02:45 ϴŽĨϭϴ &ůƵŝĚWůĂĐĞŵĞŶƚ Surface Densities are computed at P=1 atm and T=Surface Temperature (20.0 degF) Fluid Placement in Annulus Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal WBM 0.0 5235.0 5235.0 153.7 9.20 MUDPUSH II Spacer 5235.0 6500.0 1265.0 40.0 11.00 15.8ppg Tail Slurry 6500.0 9500.0 3000.0 94.9 15.80 Fluid Placement in Pipe Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal WBM 0.0 9420.0 9420.0 349.9 9.20 15.8ppg Tail Slurry 9420.0 9500.0 80.0 3.0 15.80 ϵŽĨϭϴ 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 Spacer 00:08 40.0 5.0 68.0 00:08 Pause 00:10 00:18 15.8ppg Tail Slurry 00:20 97.8 5.0 68.0 00:38 Pause 00:10 00:48 WBM : 02:46 349.9 > WBM 00:25 200.0 8.0 68.0 01:13 > WBM 00:03 12.0 4.0 68.0 01:16 > WBM 02:18 137.9 1.0 68.0 03:34 Maximum Required Hydraulic Horsepower (HHP)115.8 hhp (at 00:18 hr:mn) ϭϬŽĨϭϴ ϭϭŽĨϭϴ tĞůů^ĞĐƵƌŝƚǇ Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 11 9500.0 03:34 Success Production/Influx 131 4000.0 03:34 Success Burst 6022 0.0 03:34 Success Collapse 3758 9500.0 03:34 N/A Dead-End Collapse 0 0.0 00:00 N/A Dynamic u-tubing in Dead-End 0 0.0 00:00 N/A Balanced u-tubing in Dead-End 0 0.0 00:00 ϭϮŽĨϭϴ dĞŵƉĞƌĂƚƵƌĞKƵƚƉƵƚƐ Temperature Summary Table Static Temperature. at TOC 125.3 degF Static Temperature at BH 173.9 degF Simulated HCT at TOC 119.0 degF Simulated HCT at BH 122.7 degF Max First SK Temperature 125.7 degF Max Last SK Temperature 121.8 degF At time 02:38 hr:mn At time 03:32 hr:mn ϭϯŽĨϭϴ ĞŶƚƌĂůŝǌĂƚŝŽŶ Centralizers Alias Manufacturer Commercial Name Type Config Csg OD in Min OD in Max OD in Count CT_2A09631225000C 0 CaseTech Std Bow Spring bow- spring 9 5/8 10.500 13.431 0 CT_2A07000850000C 0 CaseTech Std Bow Spring bow- spring 7 7.875 9.280 18 Pattern Placement Bottom MD ft Joints Centralizer Alias Pattern Min STO Depth ft 6000.0 150.00 - 0 0.0 3500.0 9500.0 87.50 CT_2A07000850000C0 1/5 0.0 9500.0 Computation time: Cement Turns 01:41 ϭϰŽĨϭϴ ϯWZdhZ Average Fluid Concentrations Average fluid concentration in annulus Average fluid concentration in pipe ϭϱŽĨϭϴ Final Fluid Concentrations ϭϲŽĨϭϴ Post-Processing Results (Annulus) ϭϳŽĨϭϴ 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 15.8ppg Tail Slurry 97.8 0.0 97.8 0.0 0 MUDPUSH II Spacer 40.0 2.0 42.0 0.0 0 Material Summary Additive Pumped Quantity Required Quantity Loadout Quantity Loadout Items Pack. Name Pack. Size Comment D031 5792.21 lb 6081.82 lb 6081.82 lb 55.29 sack 110.00 lb Fresh Water 3884.61 gal 3959.78 gal 3959.78 gal 0.00 0.00 gal D182 178.98 lb 187.93 lb 187.93 lb 3.76 sack 50.00 lb 15.8ppg Tail Slurry Blend 44493.15 lb 44493.15 lb 44493.15 lb 0.00 bulk 0.00 lb Mix Water 2381.15 gal 2381.15 gal 2381.15 gal 0.00 0.00 gal D177 11.83 gal 11.83 gal 11.83 gal 0.22 drum 55.00 gal D255 177.97 lb 177.97 lb 177.97 lb 8.09 sack 22.00 lb D047 23.67 gal 23.67 gal 23.67 gal 4.73 pail 5.00 gal D065 133.48 lb 133.48 lb 133.48 lb 2.67 sack 50.00 lb ϭϴŽĨϭϴ Fluid Preparation 15.8ppg Tail Slurry Pumped Volume : 97.8 bbl Density : 15.80 lb/gal SVF : 40.5 % Yield : 1.16 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 44804.60 lb 44804.60 lb 15.8ppg Tail Slurry Blend: 94.00 lb per sack 44493.15 lb 44493.15 lb 44493.15 lb - G 100.0 % BVOB 44493.15 lb 44493.15 lb 44493.15 lb D255 0.4 % BWOC 177.97 lb 177.97 lb 177.97 lb D065 0.3 % BWOC 133.48 lb 133.48 lb 133.48 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Mix Fluid 5.106 gal/sk VBWOB 2416.65 gal 2416.65 gal Mix Water 5.031 gal/sk VBWOB 2381.15 gal 2381.15 gal 2381.15 gal Fresh Water 5.031 gal/sk VBWOB 2381.15 gal 2381.15 gal 2381.15 gal D177 0.025 gal/sk VBWOC 11.83 gal 11.83 gal 11.83 gal D047 0.050 gal/sk VBWOC 23.67 gal 23.67 gal 23.67 gal MUDPUSH II Spacer Pumped Volume : 40.0 bbl Density : 11.00 lb/gal Weighting Material Concentration Pumped Quantity Required Quantity Loadout Quantity MUDPUSH II Spacer Weighting Material: 3.45 lb/gal WBVOSpacer 5792.21 lb 6081.82 lb 6081.82 lb - D031 3.45 lb/gal WBVOSpacer 5792.21 lb 6081.82 lb 6081.82 lb Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpace r 1519.71 gal 1595.69 gal Fresh Water 0.9 bbl/bbl BVOSpacer 1503.46 gal 1578.63 gal 1578.63 gal D182 5.00 lb/bbl WBVOBF 178.98 lb 187.93 lb 187.93 lb 6(&7,21 ',9(57(56<67(0 3OHDVHVHH6HFWLRQ±5LJ(%RRN 6(&7,21 '5,//,1*)/8,'6 352*5$0 6(&7,21D '5,//,1*)/8,'6 352*5$0 Version 1.2 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ DRILLING FLUIDS PROGRAM THETA WEST PANTHEON RESOURCES Prepared By Customer Approver Name Mark Fairbanks Approver Name Michael Duncan Position Project Engineer Position Project Manager Company M-I SWACO Alaska Company Great Bear ob Number RALA AFE Number ob Number WALA Approver ID MI Version 1.2 MI Version Date Description 1. Draft Mud Program for comment and review 1.2 Final mud program Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 2 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Executive Summary The Theta West Wellbore project is a hori ontal exploration well to be drilled approximately 25 miles south of Deadhorse and 8 m iles north west of the Dalton highway The Theta West is planned at a location approximately 11.5 miles WNW of Talitha. The well is scheduled to spud in early anuary of 2022 depending on weather. This will be drilled to a depth of 9 400 TD depending upon formation evaluations found while drilling testing. The 12 1/4 surface hole will be drilled with a gel WBM to a depth of 3 000 MD and cemented in place with 9 5/8 casing. An 8 1/2 production hole section will be drilled with KLA-SHIELD to 9 400 TD and cemented in place with 7 casing. A 2 7/8 production tubi ng will be installed. After logging the pilot hole will be plugged back and abandoned. The well may be perforated and fracd at this point if conditions warrant before cutting and pulling the 7 casing Well Specific Fluids Concerns Hole Cleaning Monitor torque drag and cuttings returns at shakers on all intervals. Hole Stability Primary concern is break-out during logging and evaluating operations conducted in the pilot hole observe cuttings for splinter ed or fractured cuttings indicative of wellbore break-out. Well Control Monitor pit volumes and gas readings for indications of influx Confirm with client that the required amount of weight material is on location. Lost Circulation Follow interval specific best practices and LCM decision trees consult with Project Engineer and wellsite supervisor prior to applying LCM treatments. Monitor Hydraulics and ECDs Daily well site hydraulics modelling is mandatory and should be used to evaluate hole-cleaning efficiency and circulating system health. Logistics Fluids and dry products will be supplied by and returned to the Prudhoe Bay Liquid Mud Plant. Exploration Well Information Security Do not distribute well information to any unapproved personnel. Key Performance Indicators HSE Target TRIR ero Vehicle Incidents ero HSE observations 1/day/employee Spill Rate ero Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 3 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Well Summary CSG LIN Tubular Size Hole Size Depth MD TD Depth TVD TD Depth Drilled Mud System Primary Mud Density Planned Days 9 5/8 CSG 12 1/4 3 000 3 000 3 000 SPUD MUD Unweighted 7 CSG 8.5 9 400 9 400 6 400 KLA- SHIELD 9.0 - 9.5 Production Tubing 2 7/8 TBD TBD TBD KLA- SHIELD 9.0 - 9.5 2% KCl/ NaCl brine 9.3 Planned Capacity and Volume Interval Name Drill Pipe Spec Open Hole Volume Total Hole Volume OH CAP OHxDP Capacity CSG Vol CSG String CAP OHxCSG Capacity Conductor 0 0 0 NA NA 0 0.2116 NA Surface 4 OD / 3.34 ID 455 455 0.1518 0.1362 270 0.09 0.0618 Intermediate 4 OD / 3.34 ID 456 726 0.0702 0.0546 364 0.0383 0.0226 Pilot Hole 4 OD / 3.34 ID 73 437 0.0364 0.0209 NA NA NA Unweighted 6)' 6HHSDJHRIWKLVSURJUDP Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 4 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Property and Specification Table Interval Name Surface Production Hole Si e in 12 1/4 8 1/2 Depth MD ft 0 3 000 Depth MD TD ft 3000 9400 Depth TVD TD ft 3000 9400 Depth Drilled ft 3000 9400 Hole Drilled bbls 437.5 450 Drilling Fluid Volume bbls 2 762 1650 Mud System Type Spud Mud KLA SHIELD Primary Mud Density ppg Unweighted then 9.4 -9.5 1 000 9.0-9.5 Plastic Viscosity cP ALAP ALAP Yield Point lbs 100ft 25 - 50 20-30 LSYP lbs 100ft NA 7-10 Gel Strengths 10sec 10min NA 10-18 25 API Fluid Loss 0 NC Initial 8.0 prior to TD 10 HTHP Fluid Loss cc 0min NA NA HTHP Disc Si e micron NA NA HTHP Temp NA NA pH 0 8.5- 10 9.0 - 10.0 Chlorides mg 2 500 20k Hardness mg 200 100 Low Grav Solids NA 7 MBT ppb 35 10 Drill Solids vol 9 7 Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 5 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Interval Discussion Surface A standard high viscosity fresh water / gel spud mud will be used for the surface interval to TD. The drill string will be back reamed out of the hole and 9 5/8 casing will be run to bottom and cemented in place via single stage cement job. Interval Hazards and Mitigations BHA and Bit Balling x Add SCREENKLEEN (0.25-0.5%) to minimi e clay to metal sticking if signs of bit balling are observed. Permafrost, Gravel, and Sloughing Sand x Maintain recommended rheology x Maintain lowest flow line temperature possible by using only cold make-up water Shallow Gas x Minimi e circulation time and flow rate to reduce hydrate thawing x Reduce flow rate until through the hydrate one Hole Cleaning x Maintain highest flow rate possible x Rotate at highest possible rate while drilling and circulating x The gel strengths should be elevated but flat ensuring a highly pumpable fluid with excellent hole cleaning capabilities Swabbing, Tight Hole Conditions x Clean and condition hole prior to tripping x Adjust all drilling parameters to optimi e hole cleaning control ROP maintain highest possible flow rate and rotation x Perform additional circulation prior to connections if needed to move cuttings out of the hole Shallow Gas x While not expected shallow gas may be encountered. Make sure mud weight is at least 9.4 ppg at 1 000 in case shallow gas is seen. Use MI Wate if necessary. Maintain 9.4 ppg minimum until casing is on bottom cemented. x x Closely monitor pit volumes and surface gas detection equipment Lost Circulation x Use hole cleaning best practices taking extra precautions to prevent surge and swab x Stage pumps slowly for smooth rate increases to achieve drilling rates x Monitor pick-up and slack-off weights to detect cuttings loading Drilling Fluid Properties Fluid Specifications Weight ppg Unweighted Spud Mud to 1 000 then 9.4-9.5 ppg to TD PV cP ALAP YP lb/100ft 25 50 Surface to TD Funnel Viscosity sec/qt 150 250 reducing to 100 150 below permafrost at 1 200 pH 8.5-10 API Fluid Loss ml/30 min N.C. Initial 10 cc/30 min prior to TD Chlorides mg/L 2 500 Hardness as Ca - mg/L 200 Sand Content 1.3% Drill Solids - % Vol 9 Unweighted Spud Mud to 1 000 then 9.4-9.5 ppg to TD Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 6 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Solids Control Equipment Approved and Recommended Products Primary Fluid Formulations Shakers x Use proper LO/TO procedures prior to servicing the shakers. x Inspect all shaker bed decking panels for wear replace as necessary for optimum screen performance. Follow preventive maintenance schedule to include replacing the decking panels before it becomes a performance related issue. x Install 80-140 mesh screens or finer if losses over shaker are not a problem. Ensure screens are properly tensioned per manufactures best recommendations. Spray down new screens with fresh water before operating the shakers. x Ensure all decking rubbers are in good condition x Maintain proper deck angle to optimi e shaker performance. Shaker discharge should be slightly wet but not whole mud. x Minimi e flowline jetting during drilling to prevent fluid from overrunning shakers. If possible only jet the flowline during connections or in short bursts while drilling. x Check screens for holes between each connection. x Follow Manufacturer recommended operating practices for optimum performance. Centrifuge x Ensure the centrifuge has been flushed to remove any residual mud from previous systems x Run centrifuge below permafrost. Operate centrifuge at 2 500 RPM to allow for a higher throughput. x Monitor effluent and cuttings discharge. Take -in and -out weights to evaluate centrifuge performance. Adjust feed rate RPM and scroll based on manufacturers guidelines. Cuttings should have a wet appearance and be discharged steadily. Dry or visible liquid in the cuttings are an indication that the centrifuge operating parameters need to be adjusted. Primary Products Weight Material M-I WATE Viscosifiers M-I GEL Fluid Loss additive POLY PAC SUP UL Alkalinity Control Caustic Soda Soda Ash Citric Acid Bit BHA Balling SCREENKLEEN Contingency Products Thinner CF DESCO II SAPP Cement Contamination Sodium Bicarbonate Citric Acid SAPP Lost Circulation Material NUT PLUG FINE MEDIUM M-I- II FINE MEDIUM FORM-A-BLOK Foaming/Aeration DEFOAM TRA / SCREENKLEEN Product Quantity Water - COLD lake water only 0.967 bbls Soda Ash 0.125 ppb M-I GEL 30 ppb Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 7 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Interval and System Specific Guidelines Maintain lowest circulating temperature possible all new mud from Prudhoe Bay Mud Plant and rig water additions should be made with cold lake water. Add 30-35 ppb M-I GEL into make-up water and allow to hydrate for 4-6 hours. Dilution Rates Previous wells have required up to 100 bbl/hr to maintain system properties and circulating volume. Fluid Loss Control Below the Permafrost After drilling below the base of the permafrost target API fluid loss equal to or less than 10 cc/30 min utili ing POLYPAC SUPREME UL 0.5 ppb has proven effective on past wells. Do not exceed 1.3 ppb without consulting Project Engineer. Solids Control Run all solids control equipment (See above). Run 80 100 API screes initially screening up as soon as to maintain a wet discharge for enhanced solids removal. Add drill water below shaker to avoid washing in unwanted solids. Drilling through Hydrates If hydrates are seen on surface continue circulating (at lower rates) and begin additions of SCREENKLEEN to help hydrates break out of the fluid. Water may need to be added to combat excessive viscosity seen by hydrate entrainment. Bit and BHA Balling Sticky clays at and below the permafrost can cause balling which can induce losses and slow ROP. Add SCREENKLEEN for bit balling. Soft Clays and Poor Cuttings Conveyance Add SCREENKLEEN if soft clays are causing poor cuttings conveyance on the shakers. If clays begin sticking to shaker screens consider screening up as well. Casing Run and Cementing Monitor fluid densities at the flow line and record changes. If fluid densities increase 0.2 ppg or more above system density circulate and condition mud to bring densities back in spec. Once casing is on bottom begin lowering rheology with CF D esco II and drill water to lower yield point to under 25 lb/100ft . Pre-treat bud used to bump plug with 0.5 ppb each of Sodium Bicarbonate and SAPP. Treat cement returns with cement retarder Citric Acid CF Desco II and SAPP. Waste Disposal All class II liquids cuttings and solid waste should be sent to WDF. Hydraulics Modelling Virtual Hydraulics Snapshot 12 1 4 Surface w .4 ppg Spud Mud Drilling Fluid Spud Mud Weight .3 lbgal Test Temp 0 F PV ( 80 F) 20 cP P 30 lb 100ft LS P 18 lb 100ft System Data Flow Rate 550 galmin Penetration Rate 200 fthr Rotary Speed 100 rpm Weight on Bit 10 1000 lbf Bit Nozzles 14-14-14-14-13 13-13-13- 0 - 0 Pressure Losses Modified Power Law Drill String 516 psi MWD 350 psi Motor 375 psi Bit 1 4 psi Bit On Off 100 psi Annulus 52 psi Surface Equip 2 psi U-Tube Effect 6 psi Total System 1685 psi ESD Cut ECD Cut Csg Shoe .30 .74 .51 . 6 TD .32 .76 .65 10.0 VRDH - Version 3.3 Fann 35 File - Theta West 1.MDB, 72 Date 10 11 20 Pressure Distribution Ann 7 Bit 25 DS 68 HCI Bed Ht % Hole CleaningIndex VG G F P 0 100Bed Vol % 0140280 Va(ftmin) Turb TurbLamTopBtm Top80 100 Annulus Drill String Temperature(F) 18 24 30 36 PV YP LSYP PV (cP)P, LS P (lb100ft ) 9.2 9.6 10.0 10.4 ESDECDESD CuttingsECD Cuttings Density(lbgal) 16.000 15.000 165 165 12.250 3000 3000 GeometryMD TVD Csg OD ID(ft) (in) 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 Depth (ft) 12 1 4 surface TD .4 ppg Mud 550 GPM - 200 RPM - 150 FPH MD 3000 ft TVD 3000 ft Bit Size 12.25 in Rot()Sliding( )100 0 Operator Pantheon Well Name Theta West Location North Slope, Alaska Countr y U.S.A. VIRTUAL HYDRAULICS* SnapShot*1995-2018 M-I S WA C O Mark of M-I SWACO Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 8 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Virtual Hydraulics Parametric Analysis Hole Cleaning vs. Flow Rate Production The 8.5 intermediate interval will be drilled to 9 400 TD / 9 400 TVD utili ing KLA-SHIELD. Interval Hazards and Mitigations BHA and Bit Balling x Previous Talitha wells experienced sever clay accretion at shakers and plugging of the flow line possum belly. This was remedie d by drilling with the KLA_SHIELD system maintaining 10.7 ppb KCl (3%) and 3% KLA-STOP to mitigate clay hydration and accretion. x Cuttings should be dry and uniform in shape/consistency. Mushy soft and amorphous cuttings indicate hydration. Test and record KLA-STOP concentration on each mud check and when cuttings appear hydrated. Treat as needed with KLA-STOP to maintain 3%. Hole Cleaning x Maintain Highest flow rate possible. x Rotate at highest possible rate while drilling and circulating. x The gel strengths should be elevated but flat ensuring a highly pumpable fluid with excellent hole cleaning capabilities. Swabbing Tight Hole Conditions x Clean and condition hole prior to tripping. x Adjust all drilling parameters to optimi e hole cleaning control ROP maintain highest possible flow rate and rotation. x Perform additional circulation prior to connections if needed to move cuttings out of the hole. Lost Circulation x Use hole cleaning best practices taking extra precautions to prevent surge and swab. x Stage pumps slowly for smooth rate increases to achieve drilling rates. x Monitor pick-up and slack-off weights to detect cuttings loading. Cement Contamination from Drill Out x Reserve and dilute non-contaminated clean mud for interval operations. x Monitor and adjust pH with Citric Acid and SAPP. x Treat cement with Sodium Bicarbonate and SAPP. x Discard mud with significant contamination or cross-linked polymers. x Ensure consistent mud density for FIT test. Hole Cleaning Pantheon Theta West Flow Rate (gal min)Hole Cleaning Index400 500 600 700 800 900 0 0.25 0.50 0.75 1.00 ROP 50 ft/hr ROP 100 ft/hr ROP 150 ft/hr ROP 200 ft/hr 3RRU+ROH&OHDQLQJ )DLU+ROH&OHDQLQJ *RRG+ROH&OHDQLQJ 9HU\*RRG+ROH&OHDQLQJ 12 1 4 surface TD .4 ppg Mud 550 GPM - 200 RPM - 150 FPH MD 3000 ft TVD 3000 ft Bit Size 12.25 in Date 10112021 Operator Pantheon Well Name Theta West Location North Slope, Alaska Country U.S.A. VIRTUAL HYDRAULICS* VRDH*1995-2018 S WA C O Mark of M-I SWACO Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 9 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Drilling Fluid Properties Fluid Specifications Weight ppg 9.0 9.5 PV cP ALAP YP lb/100ft 20 -30 LSYP lb/100ft 7 - 10 pH 9.0 - 10.0 API Fluid Loss ml/30 min 10 Chlorides 20k Excess Sulfite ppm 50 Solids Control Equipment Shakers x 180-230 mesh (100-120 API) x Run shakers in series flow x Ensure all decking rubbers are in good condition x Spray down shaker screens with base fluid prior to use x Maintain proper deck angle to optimi e shaker performance. Shaker discharge should be slightly wet but not whole mud. x Avoid jetting the flowline while drilling this should be done only at connections or in short bursts while circulating. x Check screens at every connection for holes or damage Centrifuge x Should only be run periodically while drilling in the production interval. Note that the centrifuge will strip out all larger Calcium Carbonate and increase the fine particle concentration effecting the PSD x Adjust feed rate as needed it is better to run less fluid than shut down and start up repeatedly. Approved and Recommended Products Primary Products Weight Material MI WATE Viscosifier DUO VIS Fluid Loss Additive POLYPAC SUPREME UL Shale Inhibitor KLA STOP Brine Shale Inhibition KCl (Potassium Chloride) Alkalinity Caustiv Soda Soda Ash Citric Acid Lubricants LOTOR Lube 776 Contingency Products Thinner CF Desco II SAPP Screen Accretion SCREENKLEEN Cement Contamination Sodium Bicarbonate SAPP Citric Acid Foaming / Aeration Defoam Extra SKREENKLEEN Lost Circulation Material WALNUT PLUG F/M M-I- II F/M Primary Fluid Formulations Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 10 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Product Quantity Water 0.93 DUO VIS 0.75-1.5 ppb KCl (Potassium Chloride) 10.7 ppb POLYPAC SUPREME UL 1.3 ppb KLA STOP 3.0% vol MI WATE 53.5 ppb (as needed to 9.5 ppg) CONCOR 404 WH 1.3 ppb BUSAN 1060 0.4 ppb Soda Ash 0.2 ppb System Specific Guidelines Displacement Pump 30-50 bbls of new/viscosified KLA SHIELD (1-2 ppb additional DUO VIS) followed by the new KLA SHIELD. Bit Balling Screen Blinding Due to Sticky Clay Consult with Drilling Engineer and MI SWACO Project engineer prior to adding SCREENKLEEN or DRIL ONE. Hole Cleaning Sweeps should not be needed to properly clean the hole. Utili e Virtual Hydraulics software to analy e the ECD impact of any high-vis or weighted sweep prior to pumping. Maintain drill string rotation and flow rates as high as allowable by ECD and equipment limitations. Wellbore Stability Monitor cuttings for quality and shape- cuttings should be dry and uniform in si e and shape. Soft hydrated sticky clay cuttings indicate poor inhibition. Monitor KLA-STOP concentration on each mud check and as needed when cuttings consistency changes. Maintain 3% concentration with KLA-STOP additions. Additionally splintered or long large cuttings may indicate additional mud weight is needed. Drill Solids: Perform whole mud dilutions and product additions as needed to control MBT values 10. Anticipate spikes in MBT values when ROP is high and when back-reaming. Prevention of Bacterial Degradation: When mixing new fluid treat base water with Busan 1060 before mixing any other products. Ensure the pH always remains above 9.0 adjust with Caustic Soda and Soda Ash as needed. If the pH is not responsive to Soda Ash utili e Caustic Soda and consult with MI SWACO Project Engineer. Treat the system proactively with Busan 1060 and alkalinity modifiers prior to any trips or extended static wellbore conditions. Lost Circulation Follow the attached LCM Decision Tree to treat seepage and moderate losses. Consult MI SWACO Project Engineer client Drilling Engineer and SLB Tool Representatives prior to using coarse fibrous or other large PSD product for catastrophic losses. Ditch Magnets Ensure ditch magnets are utili ed and cleaned once per day or as frequently as needed by the SLB Tool Representative. Corrosion Mitigation Run a corrosion ring appropriately si ed for the BHA per the corrosion mitigation plan. Ensure pH values are in-spec at all times. Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 11 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Hydraulics Modelling Virtual Hydraulics Snapshot 8.5 Virtual Hydraulics Parametric Analysis Hole Cleaning vs. Pump Rate Drilling Fluid water based Mud Weight .5 lb gal Test Temp 120 F PV ( 120 F) 18 cP P24lb100ft LS P 7 lb100ft System Data Flow Rate 550 galmin Penetration Rate 100 fthr Rotary Speed 120 rpm Weight on Bit 10 1000 lbf Bit Nozzles 15-15-15-14-14 0 - 0 - 0 - 0 - 0 Pressure Losses Modified Power Law Drill String 2766 psi MWD 300 psi Motor 250 psi Bit 371 psi Bit On Off 50 psi Annulus 311 psi Surface Equip 32 psi U-Tube Effect 51 psi Total System 4131 psi ESD Cut ECD Cut Csg Shoe .51 .63 . 7 10.0 TD .54 .66 10.18 10.30 VRDH - Version 3.3 Fann 35 File - Theta West 1.MDB,74 Date 10 11 20 Pressure Distribution Ann Bit 11 DS 80 HCI Bed Ht % Hole CleaningIndex VG G F P 0 100Bed Vol % 0 400 800 Va(ftmin) Turb TurbLamTopBtm Top100 120 140 Annulus Drill String Temperature(F) 0102030 PV YP LSYP PV (cP)P, LS P (lb100ft ) 9.2 9.6 10.0 10.4 ESDECDESD CuttingsECD Cuttings Density(lbgal) 9.625 8.835 3000 3000 8.500 9400 9400 GeometryMD TVD Csg OD ID(ft) (in) 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 Depth (ft) 8.5 Production .5 ppg 550 GPM - 100RPM - 100 FPH MD 400 ft TVD 400 ft Bit Size 8.5 in Rot()Sliding( )100 0 Operator Pantheon Well Name Theta West Location North Slope, Alaska Countr y U.S.A. VIRTUAL HYDRAULICS* SnapShot*1995-2018 M-I S WA C O Mark of M-I SWACO Hole Cleaning Pantheon Theta West Flow Rate (gal min)Hole Cleaning Index400 420 440 460 480 500 0 0.25 0.50 0.75 1.00 ROP 100 ft/hr ROP 150 ft/hr ROP 200 ft/hr ROP 250 ft/hr 3RRU+ROH&OHDQLQJ )DLU+ROH&OHDQLQJ *RRG+ROH&OHDQLQJ 9HU\*RRG+ROH&OHDQLQJ 8.5 Production .5 ppg 550 GPM - 100RPM - 100 FPH MD 400 ft TVD 400 ft Bit Size 8.5 in Date 10112021 Operator Pantheon Well Name Theta West Location North Slope, Alaska Country U.S.A. VIRTUAL HYDRAULICS* VRDH*1995-2018 S WA C O Mark of M-I SWACO Pantheon Resources Theta West 1 Fluids Technical Program Version 1.4 Page 12 of 12 ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ Completion The Talitha production string will consist of 5.5 casing string which will be cemented in place in a single stage. Plan to bump the plug with 8.9- 9.0 ppg 2% KCL/NaCl brine system to perform off-rig VSP work prior to abandonment. Ensure system is treated with BUSAN 1060 and pH is in specified parameter prior to RDMO. If corrosion inhibition is needed ie the well is not to be plug and abandoned then use corro sion inhibition formula provide below. If the well will be plug and abandoned then use KCL Salt for the base brine leaving out the other products. Completion Interval Sodium Chloride Brine Specifications Weight 60 F_ ppg 9.3 ppg Chlorides _ mg/l As needed pH 10.0 Primary Products Weighting agent KCL 2% Sodium Chloride to weight Corrosion Inhibitor CON OR 303A not needed Biocide BUSAN 1060 Oxygen Scavenger Sodium Metabisulfite Alkalinity Control Soda Ash Caustic Soda Product .5 NaCl Corrosion Inhibited Brine Water 0.905 bbl/bbl Sodium Chloride (Salt) 74.1 PPB CON OR 303A 1.3% v/v Busan 1060 0.4 ppb Sodium Metabisulfite 0.25 ppb Soda Ash 0.25 ppb Caustic Soda As needed for final pH of 10 perform off-rig VSP work prior to abandonment. 6(&7,21E ',$*5$02)08'6<67(0 3OHDVHVHH6HFWLRQ±5LJ(%RRN 6(&7,21F *5$',(17&859(6 7+(7$:(67 ϭ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¶7' )UDFWXUH*UDGLHQW 7KHIRUPDWLRQIUDFWXUHJUDGLHQWFXUYHZDVGHULYHGXVLQJOHDNRIIWHVWV/27VDQGGLDJQRVWLF IUDFWXUHLQMHFWLRQWHVWV'),7VLQWKHIROORZLQJRIIVHWZHOOV :ROIEXWWRQ/27 6HTXRLD/27 +HPL6SULQJV6DJ5LYHU/27),7 +HPL6SULQJV8QLW/27 )UDQNOLQ%OXIIV),7 3LSHOLQH6WDWH),7 -DFREV/DGGHU),7 $OFRU'),7 $ONDLG'),7/27 7DOLWKD$'),7/27 Ϯ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ϬϭϬϬϬϮϬϬϬϯϬϬϬϰϬϬϬϱϬϬϬϲϬϬϬϳϬϬϬϴϬϬϬϵϬϬϬϭϬϬϬϬϴ ϵ ϭϬ ϭϭ ϭϮ ϭϯ ϭϰ ϭϱ ϭϲĞƉƚŚ;ĨƚͿDƵĚtĞŝŐŚƚ;ƉƉŐͿ'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ͕dŚĞƚĂtĞƐƚŶƚŝĐŝƉĂƚĞĚWŽƌĞWƌĞƐƐƵƌĞĂŶĚ&ƌĂĐ'ƌĂĚŝĞŶƚŶƚŝĐŝƉĂƚĞĚWŽƌĞWƌĞƐƐƵƌĞŶƚŝĐŝƉĂƚĞĚ&ƌĂĐ'ƌĂĚŝĞŶƚ^ƉƵĚ DƵĚtĞŝŐŚƚŝŶĐƌĞĂƐŝŶŐƚŽďĂƐĞƉĞƌŵĂĨƌŽƐƚtĂƚĞƌĂƐĞĚDƵĚtĞŝŐŚƚŵĂŝŶƚĂŝŶĞĚĂďŽǀĞƉŽƌĞƉƌĞƐƐƵƌĞ 6(&7,21 $%1250$//< *(235(6685('675$7$ 6(&7,21D *(2/2*,&352*126,6 )RUPDWLRQ 'HSWK :HVW6DN6DQG 'NU'0)6 .5HJLRQDO7RS6HDO 8SSHU8SSHU)DQ 8SSHU)DQ +XH /RZHU)DQ %DVH/RZHU)DQ *5= 7RWDO'HSWK 7KHWD:HVW*HRORJLF3URJQRVLV 6(&7,21E 08':(,*+7&+$576 )5202))6(7:(//6 ϬϮϬϬϬϰϬϬϬϲϬϬϬϴϬϬϬϭϬϬϬϬϭϮϬϬϬϴ ϵ ϭϬ ϭϭ ϭϮ ϭϯ ϭϰ ϭϱ ϭϲĞƉƚŚ;ĨƚͿDƵĚtĞŝŐŚƚ;ƉƉŐͿ'ƌĞĂƚĞĂƌWĂŶƚŚĞŽŶ͕dŚĞƚĂtĞƐƚWƌŽũĞĐƚĞĚWŽƌĞWƌĞƐƐƵƌĞĂŶĚ&ƌĂĐ'ƌĂĚŝĞŶƚƌĞůĂƚŝǀĞƚŽƉĂƐƚ'ƌĞĂƚĞĂƌtĞůůƐ;DƵĚǁĞŝŐŚƚǀĞƉƚŚͿŶƚŝĐŝƉĂƚĞĚWŽƌĞWƌĞƐƐƵƌĞŶƚŝĐŝƉĂƚĞĚ&ƌĂĐ'ƌĂĚŝĞŶƚůĐŽƌηϭDĞƌĂŬηϭdĂůŝƚŚĂůŬĂŝĚηϭůĐŽƌ,Z&/důĐŽƌ^ŚƵďůŝŬ&/důĐŽƌ,Z&ƌĂŐ'ƌĂĚŝĞŶƚůĐŽƌ^ŚƵďůŝĐ&ƌĂĐ'ƌĂĚŝĞŶƚ>KdůĐŽƌηϭ>KdDĞƌĂŬηϭ>KdůŬĂŝĚηϭ>Kd^ĞƋƵŽŝĂηϭ>KdDĂŐŐŝŽƌĞηϭ&/důŬĂŝĚηϭdĂůŝƚŚĂ>KddĂůŝƚŚĂ&/d 6(&7,21 6(,60,&5()5$&7,2125 5()/(&7,21 6(&7,21D 6+$//2:*$6+$=$5' $1$/<6,6 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 Pantheon, Anchorage, Alaska From: Petrotechnical Resources Alaska (PRA) Date: November 3, 2021 Subject: Shallow Gas Hazards Assessment (SGHA) for proposed Theta West #1 (Alt B) well; Surface Location: X=1709895, Y=5817385, ASP Zone 4, NAD83, US Survey Feet; 445' FSL, 2453' FWL, Sec. 32, T7N R11E, Umiat Meridian This report summarizes the seismic analysis of potential shallow gas hazards for the proposed Theta West (Alt B) well location estimated to spud in late 2021 or early 2022. In completing this shallow gas hazards assessment, we reviewed several subset analytical seismic 3D volumes created by eSeis, Inc. 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. We examined seismic interval velocity data extracted from the eSeis subset interval velocity volume cross plotted with the Wolfbutton 25-6-9, Panthera 28-6-9, and Talitha-A sonic logs. We analyzed offset well mud weight vs. depth data for indications of pressure. We examined the eSeis interval velocity data for an estimation of the base of permafrost and for indications of abnormal pressure. We inspected the eSeis Lithology, eSeis HC Lithology, and eSeis AVO Types volumes to help determine the likelihood of shallow gas associated with any high amplitude reflection events observed on the final 3D structural stack volume. Various Great Bear Pantheon 3D seismic data volumes were examined for shallow amplitude anomalies including the CGG 2015 Constant Offset Vector (COV) Pre-Stack Time Migrated (PSTM) 3D seismic stack, the CGG 2016 PSTM 3D subset seismic stack, and the 2021 eSeis PSTM subset stacks (Fig.1a). The eSeis Lithology, eSeis HC Lithology, and eSeis AVO Types analytical volumes facilitated the calibrated AVO analysis of observed shallow, high amplitude stack reflection events. Log curve data and historic drilling data used in this report were taken from the Wolfbutton 25- 6-9, the Panthera 28-6-9, and the Talitha-A historical well files (Fig.1b). We examined the eSeis seismic interval velocity volume and an interval velocity function extracted at the Theta West (Alt-B) location shown on an outline of the eSeis interval velocity volume (Fig.2). 2 Except for the eSeis seismic interval velocity volume, the seismic processing datum is 900ft., so zero time on non-velocity-related seismic displays is 900ft. above mean sea level. The eSeis interval velocity seismic volume uses a datum of 1000ft., so zero time on the seismic interval velocity profiles is 1000ft. above mean sea level. The approximate TVDSS depths labeled on the seismic images were estimated using checkshot and seismic synthetic time-depth information. Permafrost, Gas Hydrates, Shallow Gas The Base Permafrost was picked at the following depths for surrounding wells: 1280.5’TVD (- 946.5’TVDSS) in the Wolfbutton 25-6-9, 1440’TVD (-1050.5’TVDSS) in the Panthera 28-6-9, and 1344’TVD (-1025’TVDSS) in the Talitha-A. The dashed blue horizon (Fig.3a) indicates the Base Permafrost on an arbitrary seismic profile O-O’ tying the Wolfbutton 25-6-9 and the Panthera 28-6-9 well locations to the Theta West (Alt B) well location. Similarly, the Base Permafrost is shown by the dashed blue horizon on an arbitrary seismic profile T-T’ tying the Theta West (Alt B) well location to the Talitha-A well location (Fig.3b). Inspection of the NW-to-SE arbitrary seismic profile (22-22’) extracted from the eSeis seismic interval velocity volume (Fig.4) depicts the shallow interval velocities at the Theta West (Alt B), the Talitha-A, and the Pipeline State#1 well locations. Hotter colors indicate faster interval velocities while cooler colors indicate slower interval velocities. The interval velocity scale runs from 6000ft/sec to 13,000ft/sec. Due to low fold in the shallow section, the seismic interval velocity estimate has an increasing uncertainty with decreasing depth. The greatest error occurs in the upper 300-400ms where there is little to no seismic coverage. This lack of data causes the linear boundary just above the 200ms time line resulting from applying a seismic processing datum of 1000ft. above sea level and a subsurface velocity of 10,000ft/sec. Well control at the Talitha-A and Pipeline State#1 locations establish Base Permafrost picks as depicted at roughly -1,000’tvdss. No shallow sonic data was collected at the Talitha-A location and uncertainty may exist with using the Pipeline State#1 sonic as evidenced by the three separate Base Permafrost picks made by the same geologist (K. Bird image in Fig.5). We observe an interval velocity interval within the permafrost section that appears slower at the Pipeline State#1 location matching the behavior of the Pipeline State sonic curve (Fig.5). Seismic interval velocity functions were extracted at the Theta West (Alt B) proposed well location and at the Talitha-A well location (Fig.2). These interval velocities were converted to Interval Transit Time (ITT) for comparison cross plotting with the Wolfbutton 25-6-9, Talitha-A, and Panthera 28-6-9 sonic interval transit time data. The interval velocity function extracted at the Theta West (Alt B) location is shown plotted on the Wolfbutton 25-6-9 and the Panthera 28- 6-9 sonic ITT curves (Fig.6). The Theta West (Alt B) interval velocity function is shown plotted with the Talitha-A seismic interval velocity function, along with the Wolfbutton 25-6-9, Panthera 28-6-9, and Talitha-A sonic curves (Fig.7). Note the Talitha-A sonic log does not cover the shallow section. The seismic interval velocity at the Theta West (Alt B) location appears to track with the slower zones of travel time in the Wolfbutton sonic within the permafrost interval. This uncertainty 3 likely results from low seismic fold and the low frequency of seismic data which may be combining to mask detection of the interbedded, higher velocity permafrost layers. Below - 1000’tvdss the curves start to track similarly, demonstrating increasing velocity with depth. The seismic interval velocity function extracted at the Talitha-A location exhibits a similar behavior to the Theta West Alt-B interval velocity curve. The inflection point at -1000’tvdss appears to record the slowest ITT (~140Psec/ft) below which the velocities tend to increase with depth. We believe this observation supports encountering a Base Permafrost at the Theta West (Alt B) location at -1000’TVDSS, on trend with the Base Permafrost picks recorded at the Wolfbutton 25-6-9 (-947’tvdss), Panthera 28-6-9 (-1051’tvdss), and Talitha-A (-1025’tvdss) well locations. No reference to shallow gas anomalies or gas hydrates was noted in a review of the well history reports for the Wolfbutton 25-6-9 well and for the Talitha-A well. An arbitrary seismic profile from the eSeis AVO Types volumes ties the Wolfbutton 25-6-9 to the Theta West (Alt-B) location (Fig.3c). This arbitrary seismic profile shows a mixture of non-gas-sand AVO behavior at the Wolfbutton 25-6-9 well location somewhat similar to the Theta West (Alt-B) location. More discontinuous seismic reflection character is evident at the Wolfbutton 25-6-9 well location as compared to more continuous seismic reflection character at the Theta West (Alt-B) location as seen on the arbitrary seismic profile extracted from the 2016 Great Bear 3D PSTM data (Fig.3a). The Wolfbutton 25-6-9 and Panthera 28-6-9 wells drilled the shallow section with no reported anomalous indications of gas hydrates or abnormal geopressure. The Panthera 28-6-9 well plan cited a mud weight program starting with 8.5ppg varying to a final mud weight of 9.0-9.4ppg. The Talitha-A mud log indicates a similar mud weight program over the shallow section starting with a mud weight of 8.8ppg at 100’MD increasing to 9.4-9.5ppg at the 3175’MD casing point. At the proposed Theta West (Alt B) well location, the West-to-East seismic profile R-R’ extracted from the eSeis PSTM stack volume (Fig. 8) does not show high amplitude reflection events. Examination of the eSeis HC Lithology volume confirms the absence of high amplitude seismic reflection events. The top seismic profile image (Fig.9) is line R-R’ from the eSeis PSTM stack subset volume and the bottom seismic profile image is from the eSeis HC Lithology volume. The yellow colors indicate possible sands. If the sands are high amplitude and exhibit an AVO type consistent with gas, the color will be red as opposed to yellow. The lack of red colored events on the HC Lithology profile and horizon extractions indicates the likelihood of wet sands as opposed to gas sands. Figure 10 shows the same West-to-East seismic profile R-R’ tying the proposed Theta West (Alt B) well location. The top seismic profile image is from the eSeis PSTM stack subset volume and the bottom seismic profile image is from the eSeis AVO Types volume. Through the use of colors, the eSeis AVO Types volume shows the AVO classification for reflection events visible on the PSTM stack structural volume. AVO classifications are depicted by the following color scheme: PinkÆAVO ClassI (Type1), RedÆAVO ClassII (Type2), p a Base Permafrost at the Theta West (Alt B) location at -1000’TVDSS, () f non-gas-sand AVO behavior (g ) y p g at the Wolfbutton 25-6-9 well location somewhat similar to the Theta West (Alt-B) location. At the proposed Theta West (Alt B) well locationa,p PSTM stack volume (Fig. 8) does not show high amplitude reflection () events. No reference to shallow gas anomalies or gas hydrates was noted in a review of the well history ggy reports for the Wolfbutton 25-6-9 well and for the Talitha-A well. A pyp The lack of red colored events on the HCg, pp y Lithology profile and horizon extractions indicates the likelihood of wet sands as opposed to gas sands. 4 GreenÆAVO ClassIII (Type3), VioletÆAVO ClassIV (Type4), and Light BlueÆAVO ClassV (Type5). Pink/red, violet, and light blue colors are present at the Theta West (Alt-B) location indicating interbedded sands, shales, and coals (AVO Types 1, 2, 4, and 5). The lack of a high impedance response indicated by the absence of red colors on the HC Lithology volume (see Fig.9) indicates the likelihood of encountering wet sands as opposed to gas sands. Faults Inline and cross line seismic profiles were inspected for the shallow section from 400ms-1500ms (~ -700’to -6000’tvdss). No faults within the resolution of the seismic were observed in the shallow section of the available 3D seismic data. No drilling losses attributed to shallow faulting were noted in the drilling summary reports for the surrounding wells which include the Wolfbutton 25-6-9, the Panthera 28-6-9, the Talitha-A, and the Pipeline State #1 wells. Pressure Sonic velocity data from the Wolfbutton 25-6-9 cross plotted with a seismic interval velocity extracted at the Theta West (Alt B) location indicates that below the Base Permafrost the Theta West (Alt B) well should penetrate a normally pressured section similar to that encountered by the Wolfbutton well. Below the Base Permafrost, the Interval Transit Time (ITT) curve calculated from the seismic interval velocity function extracted at the Theta West (Alt B) location matches the Wolfbutton 25-6-9 velocity trend fairly well (Fig.6). As previously mentioned, within the permafrost section, the Theta West (Alt-A) seismic ITT curve estimates a slower velocity trend than the Wolfbutton 25-6-9 sonic. The Wolfbutton 25-6-9 and Panthera 28-6-9 mud weight vs. depth reports indicate that these wells were normally pressured in the shallow section. The Panthera 28-6-9 pre-drill mud weight program started at 8.5ppg and ending with a mud weight range of 9.0-9.4ppg . The Wolfbutton 25-6-9 pre-drill mud weight program stated a mud weight range of 8.8-9.2ppg from 114’-2500’. No anomalous velocity inversions are observed on the Theta West (Alt A) seismic interval velocity (Fig.6) that might indicate abnormally pressured zones. Given the uncertainty within the permafrost section, inspection of the northwest to southeast seismic interval velocity profile (Fig.4) indicates a subsurface velocity profile similar to the Talitha-A and Pipeline State#1 wells below the Base Permafrost. The Theta West (Alt B) drilling program will integrate best drilling practices utilized in the successful drilling of previous Great Bear Pantheon operated wells: Alcor#1, Merak#1, Alkaid#1, and Talitha-A. The Theta West (Alt B) drilling plan acknowledges the possibility of encountering shallow drilling hazards and incorporates processes to mitigate those risks while drilling. p,, drilling plan acknowledges the possibility of ,() gp g p encountering shallow drilling hazards and incorporates processes to mitigate those risks w pgpg ggppg No anomalous velocity inversions are observed on the Theta West (Alt A) seismic interval velocity ( p p No faults within the resolution of the seismic were observed No drilling losses attributed to shallow faultingg were noted in the drilling summary reports for the surrounding wells w y t below the Base Permafrost the Theta() West (Alt B) well should penetrate a normally pressured section were normally pressured in the shallow section. (Fig.6) that might indicate abnormally pressured zones. y y ( () g The lack of a high impedance, , ( yp ,,, ) g p response indicated by the absence of red colors on the HC Lithology volume (see Fig.9) indicatespy the likelihood of encountering wet sands as opposed to gas sands. Wolfbutton 25-6-9 and Panthera 28-6-9 m 5 Submitted by: 0LFKDHO'+HOWRQ &RQVXOWDQW*HRSK\VLFLVW 3HWURWHFKQLFDO5HVRXUFHVRI$ODVND &6WUHHW6XLWH $QFKRUDJH$. (PDLOPKHOWRQ#SHWURDNFRP &HOO 6 Figure 1a. Map view showing the areal coverage of the Great Bear Pantheon 3D seismic data used in this report. Township and section outlines are shown for scale. Figure 1b. Map showing the Panthera 28-6-9, the Wolfbutton 25-6-9, the Talitha-A, the Pipeline State#1, and the proposed Great Bear Theta West (Alt B) well locations. Other well locations are shown for reference. Township and section outlines are displayed for scale. Redacted 5/22/2024 M. Guhl 10 Figure 6. Seismic velocity function extracted from the eSeis interval velocity volume at the proposed Theta West (Alt B) location, converted to Interval Transit Time (ITT --Psec/ft), and plotted with the Panthera 28-6-9 and Wolfbutton 25-6-9 sonic curves. 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