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Home My WebLink About2023 Kuparuk Undefined Pool Greater Kuparuk Area 2023 Undefined Pool Report Ugnu and Coyote Formation Reporting Period January 1 to December 31, 2023 GKA Annual Surveillance Report Undefined Oil Pool 1 Page left blank intentionally. GKA Annual Surveillance Report Undefined Oil Pool 2 Donald Allan Manager, GKA Asset Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO-1076 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4692 GKA Annual Surveillance Report Undefined Oil Pool 3 March 26, 2024 Ms. Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501 Re: 2023 Undefined Oil Pool Reservoir Report Dear Commissioner Chmielowski, In compliance with Title 20 AAC 25.517, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Unit, is hereby submitting the Plans of reservoir development and operation for Undefined Oil Pools. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2023. The following is an outline of the information provided: Ugnu Formation – 2023 Report Operations Review (Attachment 1) If you have any questions concerning this data, please contact Adam Schnellbaecher at (907) 263-3701. Sincerely, Donald Allan Manager, GKA Asset Development Greater Kuparuk Area GKA Annual Surveillance Report Undefined Oil Pool 4 Attachment 1 Ugnu Formation 2023 Report Operations Review UGNU PILOTS/ STUDIES The Kuparuk River Unit working interest owners re-started the Ugnu Heavy Oil pilot and established stabilized oil flow from well 1H-401 during December 2013. A down hole heater was used to lower the oil viscosity sufficiently to allow viscous oil to flow via a progressive cavity pump installed in the well. The well was online for approximately 10 cumulative months until it was shut in March 2016 due to a failed pump. In 2017 and 2018, elastomer studies were completed to redesign a downhole pump more appropriate for the fluid chemistry and downhole conditions. A new pump design was installed in April 2019. The well was online for two weeks before the motor failed. Evaluating rig workover alternatives to bring the well back on production. One well, 1C-501, was drilled in 2023 to serve as a clean-water source well for planned West Sak injectors on drillsite 1C. Page left blank intentionally. GKA Annual Surveillance Report Undefined Oil Pool 5 Manager, GKA Asset Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO-1376 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4692 Donald Allan Manager, GKA Asset Development Greater Kuparuk Area GKA Annual Surveillance Report Undefined Oil Pool 6 Donald Allan March 26, 2024 Ms. Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501 Re: Kuparuk River-Undefined Oil Pool – Coyote Dear Commissioner Chmielowski, In compliance with Rule 11, ERIO No.8, ConocoPhillips Alaska, Inc., operator of the Kuparuk River – Undefined Oil Pool (Coyote), is hereby submitting a progress report on the pilot injection project. Attachment 2 provides the required reporting. If you have any questions concerning this data, please contact Adam Schnellbaecher at (907)-263-4188. Sincerely, Attachment 2 Undefined Oil Pool - Coyote 2023 Pilot Injection Project Progress Report Adverse events There were no adverse events related to the pilot injection project. Injection Rates and Pressures There is a single injection well in this project, 3S-701A, which was placed in injection service 9/3/2023. The table below provides the average and maximum injection rates and pressures when the well was in service in 2023. MaximumAverage3S -701A 12,1309526Injection rate, BWPD 642443Injection pressure, psi Surveillance and Tracer Testing The following surveillance work was conducted: Appraisal well 3S-24B: o Pressure monitoring during injector flowback and when producer was brought on line established connectivity in the reservoir. Producer 3S-704: o Chemical tracer data monitored frac stage contribution and initiated FCOs to ensure full lateral contribution. o PBU o Monitoring of downhole gauge for injection response Injector 3S-701A: o Chemical tracer data monitored frac stage contribution during flowback and initiated FCO. o PBU during flowback period before starting water injection service. Enhanced Recovery Response Producer 3S-704 saw injection response from 3S-701A evidenced by a pressure increase from its downhole gauge in late Q4. This was under constant choke and lift gas operating conditions. Plans for 2024 Drilling and completion of two well pairs are scheduled for 2024 to further assess the Coyote reservoir. Production logging of the current well pair is scheduled for Q1. GKA Annual Surveillance Report Undefined Oil Pool 7