Abstract
This study conducted core sampling of an offshore borehole for geological reservoir characterization of a potential CO2 storage site in southeast Korea. From this, two promising geological formations at ~739 and ~779 m were identified as prospective CO2 storage reservoirs. Injection efficiency and CO2 migration were evaluated based on directional measurements of permeabilities from core plugs. The directional transport properties were determined using both a portable probe permeameter and a pressure cell capable of applying different in situ confining pressures. Both steady state and unsteady state measurements were used to determine permeability—the method selected according to the expected permeability range of the specific sample. This expected range was based on rapid screening measurements acquired using a portable probe permeameter (PPP). Anticipated performance of the prototypical CO2 injection site was evaluated based on flow modeling of the CO2 plume migration pathway including CO2 transport through the overlying formations based on the measured directional hydraulic properties. These analyses revealed that the injection efficiency at a depth of 739 m was double that at 779 m. These correlations among and distributions of the directional permeabilities of the potential CO2 geological storage site can be utilized for the assessment of CO2 storage capacity, injectivity, and leakage risk.
Highlights
Carbon capture and storage (CCS) in underground geological formations can reduce atmospheric carbon dioxide (CO2) levels, thereby combatting climate change and minimizing the effect of industrial CO2 emissions [1]
Rock samples were cored through the full depth of the reservoir from a single offshore borehole to determine the directional hydraulic properties based on measurements using a portable probe permeameter (PPP) and a broadband rock permeability measurement system developed in this study
The CO2 injectivity of a potential reservoir is defined as the ability of the geological formation to accept injected CO2 [21], where permeability represents the capacity of the medium to transmit CO2
Summary
Carbon capture and storage (CCS) in underground geological formations can reduce atmospheric carbon dioxide (CO2) levels, thereby combatting climate change and minimizing the effect of industrial CO2 emissions [1]. Deeper reservoirs with overlying cap rocks and sufficient porosity for large storage volumes are considered suitable geological formations for CO2 storage These sites should offer significant storage capacity with adequate injectivity, where injection at high flow rates and without excessive pressure build-up results, where sufficient permeability exists [4]. Rock samples were cored through the full depth of the reservoir from a single offshore borehole to determine the directional hydraulic properties based on measurements using a portable probe permeameter (PPP) and a broadband rock permeability measurement system developed in this study. These experimental findings were used to develop a numerical model for injected CO2 plume migration
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