Authors / CoAuthors
Wang, L. | Bastrakov, E.N. | Haese, R.
Abstract
After CO2 is injected into the saline aquifer, the formation water inside the porous media becomes more acidic. This will significantly affect the original chemical equilibrium underground, and induce or speed up various processes of dissolution and precipitation depending on the reservoir pressure and temperature. Early Cretaceous Gage Sandstone has been identified as a potential reservoir unit suitable for large-scale CO2 storage in the offshore southern Perth Basin. This study assesses the contribution of mineralisation trapping to CO2 storage capacity of Gage Sandstone through a comprehensive geochemical modelling. Analyses of mineral assemblage in reservoir rocks and properties of formation water were used to assess dissolutions of unstable components under acidic environment such as potassium-feldspar, plagioclase and carbonate, and the precipitation of calcite and kaolinite, which are considered the main water-rock interactions during the post-injection period. The chemical reaction was treated as a function of time. Three software packages have been used to run the geochemical reaction simulation to ascertain the practical capabilities of predicting the effects of CO2 injection underground and the storage potential of Gage Sandstone reservoir. Sensitivity analysis was carried out based on the uses of different equations of state, different methods for solubility modelling, different models of activity coefficient estimation, different time scale, and different assemblages of minerals in the Gage sandstone. The study allowed to constrain the effects of CO2 injection on reservoir porosity and permeability.
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nonGeographicDataset
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73303
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- External PublicationAbstract
- ( Theme )
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- marine
- Australian and New Zealand Standard Research Classification (ANZSRC)
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- Earth Sciences
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- Published_Internal
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2012-01-30T00:00:00
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