Anisotropic porothermoelastic solution and hydro‐thermal effects on fracture width in hydraulic fracturing

Abousleiman, Younane N.; Hoang, Son K.; Liu, Chao

doi:10.1002/nag.2216

Cited by 46 publications

(16 citation statements)

References 24 publications

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“…The response of a cylindrical dual‐porosity dual‐permeability shale sample with dimensions of R 0 = 2.54 cm (1 inch) and H = 10.16 cm (4 inches) will be simulated in this section. The poroelastic parameters of matrix is selected from a Woodford Shale with some modification and listed as follows: k I = 50 nD, ϕ I = 0.18, v I = 0.25,

E_{1}^{I}

= 7.2 GPa,

E_{3}^{I}

= 5.2 GPa. For the natural fractures system, a number of methods to estimate the poroelastic parameters were proposed by Cook, on the basis of the individual fracture characteristics, spacing, and orientation.…”

Section: Numerical Examplementioning

confidence: 99%

“…The response of a cylindrical dual-porosity dual-permeability shale sample with dimensions of R 0 = 2.54 cm (1 inch) and H = 10.16 cm (4 inches) will be simulated in this section. The poroelastic parameters of matrix is selected from a Woodford Shale 86 Furthermore, open natural fractures should be softer than the matrix and also have higher porosity, which might be close to 1, because most of the fractures might be the porous flow channels. Therefore, the poroelastic parameters of fractures system is assumed as follows: k II = 5 mD, ϕ II = 0.95, v II = 0.25, E II 1 = 0.5 GPa, E II 3 = 0.4 GPa, where the difference of Poisson's ratio is neglected.…”

Section: Numerical Examplementioning

confidence: 99%

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Responses of chemically active and naturally fractured shale under time‐dependent mechanical loading and ionic solution exposure

Liu

Hoang

Abousleiman

2017

Num Anal Meth Geomechanics

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SummaryIn this paper, the analytical dual-porosity dual-permeability poromechanics solution for saturated cylinders is extended to account for electrokinetic effects and material transverse isotropy, which simulate the responses of chemically active naturally fractured shale under time-dependent mechanical loading and ionic solution exposure.The solution addresses the stresses, fracture pore pressure, matrix pore pressure, fluid fluxes, ion concentration evolution, and displacements due to the applied stress, pore pressure, and solute concentration difference between the sample and the circulation fluid. The presented solution will not only help validate numerical simulations but also assist in calibrating and interpreting laboratory results on dual-porosity dual-permeability shale. It is recommended that the analytical solutions of radial and axial displacements be used to match the corresponding laboratory-recorded data to determine shale dual permeability and chemo-electrical parameters including membrane coefficient, ions diffusion coefficients, and electro-osmotic permeability.KEYWORDS chemically active, dual-poro-chemo-electro-elasticity, electro-osmotic permeability, natural fractures, shale | INTRODUCTIONThe recent boom in oil and gas production from shale reservoirs around the world has produced a tectonic shift in the global energy landscape. However, despite the promising potentials, there are still many challenges in understanding, analyzing, and predicting the behaviors of these unconventional reservoirs during drilling, stimulation, and production. Some of these challenges come from the complex geomechanics properties of shale. Most shales have higher degree of mechanical anisotropy than conventional reservoir rocks. In addition, shale displays swelling and shrinking behaviors when exposed to aqueous drilling and stimulation fluids because of the electrochemical interaction between its clay content and the solutions. Furthermore, many shales are naturally fractured, as illustrated in Figure 1, resulting in complex pore pressure distribution and evolution in the dual-porosity dual-permeability system. It is noted that shales with dual-porosity system that might result from different scales of pore structures 1 can be also modeled using the current approach.This study aims to investigate the behavior of dual-porosity dual-permeability shale rocks under laboratory conditions. The original dual-porosity dual-permeability concept for fractured/fissured rocks was proposed by Barenblatt et al. 2 The 2 overlapping continua, primary porosity and secondary porosity, possess their own fluid pressure fields. Warren and Root 3 proposed an idealized dual-porosity model, assuming that the secondary porosity consists of an orthogonal system of uniform fractures and that fluid can communicate between primary and secondary porosities, but not among the primary porosity elements. Later on,

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E_{1}^{I}

= 7.2 GPa,

E_{3}^{I}

Section: Numerical Examplementioning

confidence: 99%

Section: Numerical Examplementioning

confidence: 99%

Responses of chemically active and naturally fractured shale under time‐dependent mechanical loading and ionic solution exposure

Liu

Hoang

Abousleiman

2017

Num Anal Meth Geomechanics

Self Cite

View full text Add to dashboard Cite

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“…It is also common in engineered geotechnical structures such as compacted soils and landfills (Feda 1998;Li and Zhang 2009;Najser et al 2010Najser et al , 2012Romero et al 2011;Della Vecchia and Romero 2013;Musso et al 2013;Burton et al 2014). It is well recognized that all natural reservoir rocks possess fissures to some extent (Barenblatt et al 1960;Warren and Root 1963;Kazemi et al 1976;Moench 1984;Lewandowska and Auriault 2013;Katsuki et al 2014;Vu et al 2014;Bennett et al 2015), and additional fissures may be induced by engineering activities (Abousleiman et al 2014;Carneiro 2009;Weng et al 2011;Foster and Mohammad Nejad 2013;Lamb et al 2013;Li et al 2013;Rahman and Rahman 2013a, b;Mohammadnejad and Khoei 2013;Zhang et al 2015;Yin 2013;White et al 2014;Tjioe and Borja 2015). Fissures have been observed in a variety of natural soils as well (Hu et al 2013;Vitone et al 2013a, b).…”

Section: Introductionmentioning

confidence: 99%

Hydromechanical Modeling of Unsaturated Flow in Double Porosity Media

2016

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Geomaterials with aggregated structure or containing fissures often exhibit a bimodal pore size distribution that can be viewed as two coexisting pore regions of different scales. The double-porosity concept enables continuum modeling of such materials by considering two interacting pore scales satisfying relevant conservation laws. This paper develops a thermodynamically consistent framework for hydromechanical modeling of unsaturated flow in double-porosity media. With an explicit treatment of the two pore scales, conservation laws are formulated incorporating an effective stress tensor that is energy-conjugate to the rate of deformation tensor of the solid matrix. A constitutive framework is developed on the basis of energy-conjugate pairs identified in the first law of thermodynamics, which is then incorporated into a three-field mixed finite-element formulation for double-porosity media. Numerical simulations of laboratory-and field-scale problems are presented to demonstrate the impact of double porosity on the resulting hydromechanical responses.

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“…Many natural geomaterials such as aggregated soils and fissured rocks exhibit pore size distributions with two dominant values of porosity [1,2,26,28,31,55]. In fissured rocks the two scales of porosity are those of the rock matrix and fractures [11,61,64,68,74,77,79,83], whereas in aggregated soils, © 2016.…”

Section: Introductionmentioning

confidence: 99%

Cam-Clay plasticity, Part VIII: A constitutive framework for porous materials with evolving internal structure

Borja

Choo

2016

Computer Methods in Applied Mechanics and Engineering

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Natural geomaterials often exhibit pore size distributions with two dominant porosity scales. Examples include fractured rocks where the dominant porosities are those of the fractures and rock matrix, and aggregated soils where the dominant porosities are those of the micropores and macropores. We develop a constitutive framework for this type of materials that covers both steady-state and transient fluid flow responses. The framework relies on a thermodynamically consistent effective stress previously developed for porous media with two dominant porosity scales. We show that this effective stress is equivalent to the weighted sum of the individual effective stresses in the micropores and macropores, with the weighting done according to the pore fractions. This partitioning of the effective stress into two single-porosity effective stresses allows fluid pressure dissipation at the macropores and micropores to be considered separately, with important implications for individual characterization of the hardening responses at the two pore scales. Experimental data suggest that the constitutive framework captures the laboratory responses of aggregated soils more accurately than other models previously reported in the literature. Numerical simulations of boundary-value problems reveal the capability of the framework to capture the effect of secondary compression as the micropores discharge fluids into the macropores.

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Anisotropic porothermoelastic solution and hydro‐thermal effects on fracture width in hydraulic fracturing

Cited by 46 publications

References 24 publications

Responses of chemically active and naturally fractured shale under time‐dependent mechanical loading and ionic solution exposure

Responses of chemically active and naturally fractured shale under time‐dependent mechanical loading and ionic solution exposure

Hydromechanical Modeling of Unsaturated Flow in Double Porosity Media

Cam-Clay plasticity, Part VIII: A constitutive framework for porous materials with evolving internal structure

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