Carbon dioxide sequestration in saline formations: Part 2—Review of multiphase flow modeling

Cinar, Yildiray; Riaz, Amir

doi:10.1016/j.petrol.2014.07.023

Cited by 55 publications

(29 citation statements)

References 145 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Changes in pore structure, together with the feedback between dissolution and flow that creates preferential flow paths in carbonate systems, directly affect permeability and other continuum‐scale transport properties . In carbonate‐rich cores, CO 2 injection often results in carbonate dissolution, pore widening, and increased permeability .…”

Section: Geochemical Alteration Of Reservoir Structure and Transport mentioning

confidence: 99%

A review of geochemical–mechanical impacts in geological carbon storage reservoirs

et al. 2019

View full text Add to dashboard Cite

Geological carbon storage (GCS) refers to the technology of capturing man‐made carbon dioxide (CO2) emissions, typically from stationary power sources, and storing such emissions in deep underground reservoirs. GCS is an approach being explored globally as a defense mechanism against climate change projections, although it is not without its critics. An important focus has been recently placed on understanding the coupling between rock–fluid geochemical alterations and mechanical changes for CO2 storage schemes in saline aquifers. This article presents a review of the current state of knowledge regarding CO2‐induced geochemical reactions in subsurface reservoirs, and their potential impact on mechanical properties and microseismic events at CO2 storage sites. This review focuses, in particular, on the current state of the art in fluid–rock interactions within the GCS context. Key issues to be addressed include geochemical reactions and the alteration of transport and mechanical properties. Specific review topics include the swelling of clays, the prediction of dissolution and precipitation reaction rates, CO2‐induced changes in porosity and permeability, constitutive models of chemo–mechanical interactions in rock, and correlations between geochemical reactions and induced seismicity. The open questions in the field are emphasized, and new research needs are highlighted. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

show abstract

Section: Geochemical Alteration Of Reservoir Structure and Transport mentioning

confidence: 99%

A review of geochemical–mechanical impacts in geological carbon storage reservoirs

et al. 2019

View full text Add to dashboard Cite

show abstract

“…Despite the fact that the two‐phase Darcy's law is extensively used for routine macroscopic calculations, to the best of our knowledge, a rigorous definition of its applicability regimes has not yet been provided in the literature, except for the experimental classification presented by (Cinar & Riaz, ). Here, differently from previous analyses (e.g., Auriault, ; Auriault et al, ; Hornung, ), we reformulated the derivation in terms of dimensionless variables, see Appendix for all the details, obtaining the filtration laws

(〈〉, {bold-italicu}_{1}) = - K_{11} \nabla p_{1} - K_{12} \nabla p_{2}, bold-italicx \in normalΩ,

(〈〉, {bold-italicu}_{2}) = - K_{21} \nabla p_{1} - K_{22} \nabla p_{2}, bold-italicx \in normalΩ,

along with the relation between the macroscopic pressures of the two phases

p_{1} - p_{2} = 〈 κ 〉

and the conservation laws for the saturation

ϕ \frac{\partial S_{i}}{∂t} + \nabla \cdot 〈 {bold-italicu}_{i} 〉 = 0 with i = 1, 2 and S_{1} + S_{2} = 1 .

Equations ‐ are recovered only if the following conditions are met: ϵ ≪ 1; R e < ϵ −1 and R · R e < ϵ −1 ; R e / F r 2 > ϵ −2 and R · R e / F r 2 > ϵ −2 ; O ( M ) = 1;

O ((), 〈 κ 〉 false/ Ca) = ϵ^{- 1}

; the interface Γ 12 is almost stationary. …”

Section: Homogenization Via Multiple‐scale Expansionsmentioning

confidence: 99%

The Impact of Pore‐Scale Flow Regimes on Upscaling of Immiscible Two‐Phase Flow in Porous Media

Picchi

Battiato

2018

Water Resources Research

View full text Add to dashboard Cite

Empirical or theoretical extensions of Darcy's law for immiscible two‐phase flow have shown significant limitations in properly modeling the flow at the continuum scale. We tackle this problem by proposing a set of upscaled equations based on pore‐scale flow regimes, that is, the topology of flowing phases. The incompressible Navier‐Stokes equation is upscaled by means of multiple‐scale expansions and its closures derived from the mechanical energy balance for different flow regimes at the pore scale. We also derive the applicability conditions of the upscaled equations based on the order of magnitude of relevant dimensionless numbers, that is, Eotvos, Reynolds, capillary, Froude numbers, and the viscosity and density ratio of the system, as well as a set of closures valid for the basic flow regimes of low Eotvos number systems, that is, core‐annular and plug and drop traffic flows. We provide analytical expressions for the relative permeability of the wetting and nonwetting phases in different flow regimes and demonstrate that the effect of the flowing‐phases topology on the relative permeabilities is significant. Finally, we show that the classical two‐phase Darcy law is recovered for a limited range of operative conditions, while specific terms accounting for interfacial and wall interactions should be incorporated to accurately model ganglia or drop traffic flow.

show abstract

“…In the meantime, as vaporization progresses, the concentration of dissolved salt in the brine builds up. When the salt concentration exceeds its solubility limit under the thermodynamic state of a given reservoir, the excess salt will precipitate out of the aqueous phase (salting-out) and alter the porosity and permeability of the formation (Cinar and Riaz, 2014;Hurter et al, 2007). Strong evidences on the occurrence of salt precipitation primarily have come from field observations of gas injections or storage (Bette and Heinemann, 1989;Jasinski et al, 1997;Kleinitz et al, 2001).…”

Section: Introductionmentioning

confidence: 99%

Salt precipitation during CO 2 storage—A review

Miri

Hellevang

2016

International Journal of Greenhouse Gas Control

164

127

View full text Add to dashboard Cite

Carbon dioxide sequestration in saline formations: Part 2—Review of multiphase flow modeling

Cited by 55 publications

References 145 publications

A review of geochemical–mechanical impacts in geological carbon storage reservoirs

A review of geochemical–mechanical impacts in geological carbon storage reservoirs

The Impact of Pore‐Scale Flow Regimes on Upscaling of Immiscible Two‐Phase Flow in Porous Media

Salt precipitation during CO 2 storage—A review

Contact Info

Product

Resources

About