A comparative study of dual-porosity model and discrete fracture network model

Lee, J.; Choi, Sung-Uk; Cho, Woncheol

doi:10.1007/bf02829057

Cited by 34 publications

(7 citation statements)

References 19 publications

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“…During the 1970s, the inability of technology produced challenges for scientists to obtain detailed information on subsurface fractures, and this deficiency led to the development of the Equivalent Porous Continuum concept (EPM) (Bear, 1972;Freeze and Cherry, 1979;Blessent et al, 2013). The large contrast in the volume between fractures and the matrix pores along with their hydraulic properties resulted in the dual porosity/mass transfer model (Moench, 1984;Lee et al, 1999;Cornaton and Perrochet, 2002;Worthington and Smart, 2017;Tao et al, 2019). The dual porosity model conceptualizes that groundwater takes place only in the fractures, but can be stored in both fractures and the matrix.…”

Section: Introductionmentioning

confidence: 99%

The importance of fracture geometry and matrix data on transient hydraulic tomography in fractured rocks: Analyses of synthetic and laboratory rock block experiments

Zhao

Luo

Illman

2021

Journal of Hydrology

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Section: Introductionmentioning

confidence: 99%

The importance of fracture geometry and matrix data on transient hydraulic tomography in fractured rocks: Analyses of synthetic and laboratory rock block experiments

Zhao

Luo

Illman

2021

Journal of Hydrology

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“…Flow models estimating the flow in fractured porous media mainly include the equivalent continuum model [1], dual continuum model [2], discrete fracture model [3], and discrete fracture network model [4,5]. These models fall into two categories: continuum models and discrete fracture models.…”

Section: Introductionmentioning

confidence: 99%

An Extended Finite Element Model for Fluid Flow in Fractured Porous Media

Liu

Zhao

Liu

et al. 2015

Mathematical Problems in Engineering

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This paper proposes a numerical model for the fluid flow in fractured porous media with the extended finite element method. The governing equations account for the fluid flow in the porous medium and the discrete natural fractures, as well as the fluid exchange between the fracture and the porous medium surrounding the fracture. The pore fluid pressure is continuous, while its derivatives are discontinuous on both sides of these high conductivity fractures. The pressure field is enriched by the absolute signed distance and appropriate asymptotic functions to capture the discontinuities in derivatives. The most important advantage of this method is that the domain can be partitioned as nonmatching grid without considering the presence of fractures. Arbitrarily multiple, kinking, branching, and intersecting fractures can be treated with the new approach. In particular, for propagating fractures, such as hydraulic fracturing or network volume fracturing in fissured reservoirs, this method can process the complex fluid leak-off behavior without remeshing. Numerical examples are presented to demonstrate the capability of the proposed method in saturated fractured porous media.

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“…Eventhough the cracks have grown, they remain non-connected. This observation suggests the permeability changes from before to after the test are not related to flow paths enhancement, or at least they would be very difficult to explain using a continuum media approach (Lee et al, 1999). Grain scale arching effects are also present (Fig.…”

Section: Hydro-mechanical Interpretationmentioning

confidence: 95%

Transport properties of saline CO2 storage reservoirs with unconnected fractures from brine-CO2 flow-through tests

Muñoz‐Ibáñez

Falcón-Suarez

Marín‐Moreno

et al. 2020

Journal of Petroleum Science and Engineering

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CO 2 storage in fractured reservoirs may lead to fast CO 2 flow through interconnected fracture networks; but the role of isolated fractures on brine-CO 2 multiphase flow systems remains unclear. We present the results of a brine-CO 2 flow-through experiment in which we assess the change in transport properties of a synthetic sandstone plug (a surrogate of a saline siliciclastic CO 2 reservoir) containing non-connected fractures aligned 45 � from its axis. The test was performed at 40 MPa of constant hydrostatic confining pressure and ~11 MPa of pore pressure, at room temperature (~19.5 � C), using pure liquid-CO 2 and 35 g L À 1 NaCl salt solution. The injected CO 2-brine volume fraction was increased from 0 to 1 in 0.2 units-steps (drainage). Upon achievement of the maximum CO 2 saturation (S CO2 ~0.6), the plug was flushed-back with the original brine (imbibition). During the test, we monitored simultaneously pore pressure, temperature, axial and radial strains, and bulk electrical resistivity. The fractured sample showed lower values of cross-and end-points in the relative permeability curves to CO 2 compared to non-fractured samples, from comparable experiments performed at similar pressure and brine salinity conditions, but different temperature. Our results suggest that a non-connected fracture network affects the mobility of the individual phases, favouring the trapping of CO 2 in the porous medium and improving the storage efficiency of the reservoir. These evidences show the need of a better understanding of fracture connectivity prior to discard fractured reservoirs as unsuitable geological formations for CO 2 storage.

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A comparative study of dual-porosity model and discrete fracture network model

Cited by 34 publications

References 19 publications

The importance of fracture geometry and matrix data on transient hydraulic tomography in fractured rocks: Analyses of synthetic and laboratory rock block experiments

The importance of fracture geometry and matrix data on transient hydraulic tomography in fractured rocks: Analyses of synthetic and laboratory rock block experiments

An Extended Finite Element Model for Fluid Flow in Fractured Porous Media

Transport properties of saline CO2 storage reservoirs with unconnected fractures from brine-CO2 flow-through tests

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