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Title: A numerical study of capillary pressure - saturation relationship for supercritical carbon dioxide (CO2) injection in deep saline aquifer
Authors: Khudaida, Kamal
Das, Diganta Bhusan
Keywords: Geological sequestration
Two-phase flow
Capillary pressure
Porous media
CO2
Sequestration
Deep saline aquifer
CO2 sequestration
Issue Date: 2014
Publisher: © The Institution of Chemical Engineers. Published by Elsevier B.V.
Citation: KHUDAIDA, K. and DAS, D.B., 2014. A numerical study of capillary pressure - saturation relationship for supercritical carbon dioxide (CO2) injection in deep saline aquifer. Chemical Engineering Research and Design, 92(12), pp.3017-3030
Abstract: Carbon capture and sequestration (CCS) is expected to play a major role in reducing greenhouse gas in the atmosphere. It is applied using different methods including geological, oceanic and mineral sequestration. Geological sequestration refers to storing of CO2 in underground geological formations including deep saline aquifers (DSAs). This process induces multiphase fluid flow and solute transport behaviour besides some geochemical reactions between the fluids and minerals in the geological formation. In this work, a series of numerical simulations are carried out to investigate the injection and transport behaviour of supercritical CO2 in DSAs as a two-phase flow in porous media in addition to studying the influence of different parameters such as time scale, temperature, pressure, permeability and geochemical condition on the supercritical CO2 injection in underground domains. In contrast to most works which are focussed on determining mass fraction of CO2, this paper focuses on determining CO2 gas saturation (i.e., volume fraction) at various time scales, temperatures and pressure conditions taking into consideration the effects of porosity/permeability, heterogeneity and capillarity for CO2-water system. A series of numerical simulations is carried out to illustrate how the saturation, capillary pressure and the amount of dissolved CO2 change with the change of injection process, hydrostatic pressure and geothermal gradient. For example, the obtained results are used to correlate how increase in the mean permeability of the geological formation allows greater injectivity and mobility of CO2 which should lead to increase in CO2 dissolution into the resident brine in the subsurface.
Description: This article was accepted for publication in the journal, Chemical Engineering Research and Design [© The Institution of Chemical Engineers. Published by Elsevier B.V.] and the definitive version will be available at: http://www.journals.elsevier.com/chemical-engineering-research-and-design/
Version: Accepted for publication
DOI: 10.1016/j.cherd.2014.04.020
URI: https://dspace.lboro.ac.uk/2134/14532
Publisher Link: http://dx.doi.org/10.1016/j.cherd.2014.04.020
ISSN: 0263-8762
Appears in Collections:Published Articles (Chemical Engineering)

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