2015
DOI: 10.1016/j.ijggc.2015.05.023
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Evaluation of relative permeability functions as inputs to multiphase flow models simulating supercritical CO2 behavior in deep geologic formations

Abstract: a b s t r a c tMultiphase flow models that simulate flow and entrapment behavior of supercritical CO 2 (scCO 2 ) can be used to design and evaluate CO 2 sequestration strategies in deep geologic formations. The accuracy of model predictions depends on the constitutive models that relate capillary pressure (P c ) and relative permeability (k r ) to phase saturations (S w ). Any studies to evaluate various constitutive models remain a major challenge, as necessary data are not easy to obtain in field settings. A… Show more

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Cited by 11 publications
(5 citation statements)
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“…Furthermore, continuum‐based numerical simulations will be carried out to test the significance of capillary heterogeneity, following the work of Mori et al . [].…”
Section: Discussionmentioning
confidence: 99%
“…Furthermore, continuum‐based numerical simulations will be carried out to test the significance of capillary heterogeneity, following the work of Mori et al . [].…”
Section: Discussionmentioning
confidence: 99%
“…Consequently, the exclusion of relative permeability heterogeneities during such modelling exercise could easily give the notion that reverse gradation in the transition zone has negligible effects on caprock pressurisation in comparison to the absence of a basal transition zone. This further accentuates the relevance of relative permeability functions in reservoir simulations as portrayed by Onoja and Shariatipour (2018) and Mori et al (2015). Over the 20-year scCO2 injection period, the modelling exercise indicates that the average pressure along the reference depth (i.e.…”
Section: Pressure Evolution In the Caprockmentioning
confidence: 80%
“…The analysis of caprock integrity usually relies on predictions from reservoir and geomechanical models, where the former provides pressure data for the latter. The accuracy of predictions from CO2 storage simulations is highly dependent on the description of the capillary pressure (Pc), wetting saturation (Sw), and relative permeability (kr) relationship (Pc-Sw-kr relationship) in the flow model (Mori et al, 2015). Due to the lack of experimentally descriptive Pc-Sw-kr relationships for saline formations, most numerical models employ constitutive models by Brooks andCorey (1964) or van Genuchten (Van Genuchten, 1980) to describe flow characteristics when simulating geologic CO2 sequestration (e.g.…”
Section: 1mentioning
confidence: 99%
“…Utilising a fixed value to represent the pore size distribution index of an entire storage formation fails to account for the differences in the average pore size of rock lithologies within strata in the reservoir. Additionally, predictions from such reservoir models may fall short of precision because the accuracy of flow processes in a porous medium is highly dependent on the description of the Pc-S-kr relationship (Mori et al, 2015).…”
Section: Describing Flow Characteristics In Reservoir Modelsmentioning
confidence: 99%