Numerical analysis of thermal fracturing in subsurface cold water injection by finite element methods

Yin, Shunde

doi:10.1002/nag.2148

Cited by 17 publications

(7 citation statements)

References 38 publications

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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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Section: Introductionmentioning

confidence: 99%

Hydromechanical Modeling of Unsaturated Flow in Double Porosity Media

2016

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“…Due to the significant difference in pore sizes, the two pore regions exhibit highly contrasting hydromechanical responses. For example, fissures in rocks serve as conduits for fluid flow that can significantly influence the preferential flow patterns, whereas the pores in the matrix can also provide substantial space for fluid transport and storage [9,35,48,64,94]. In aggregated soils, the interaggregate pores form the primary pathways for rapid infiltration, but fluids can also migrate through the contact surfaces between the aggregates, as well as within the aggregates [22,47,75].…”

Section: Introductionmentioning

confidence: 99%

Stabilized mixed finite elements for deformable porous media with double porosity

Choo

Borja

2015

Computer Methods in Applied Mechanics and Engineering

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Natural geomaterials such as fissured rocks and aggregated soils often exhibit a pore size distribution with two dominant pore scales, usually termed macropores and micropores. High-fidelity descriptions of these materials require an explicit treatment of the two pore regions as double porosity. In this paper, we present stabilized mixed finite elements for coupled flow and deformation in porous media with double porosity based on a thermodynamically consistent modeling framework. Mixed finite elements that interpolate the solid displacement and pore pressures in the macropores and micropores are used for this purpose. In the limit of undrained deformation, the two pore pressures become incompressibility constraints that cause an inf-sup instability in the form of spurious oscillation at the two pore scales. To circumvent this instability we develop a variant of the polynomial pressure projection technique for a twofold saddle point problem. The proposed stabilization allows the use of equal-order (linear) interpolations of the displacement and two pore pressure variables throughout the entire range of drainage condition.

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“…There was no obvious difference in the pressure sweep range of displacement fluid in reservoirs with different permeability, and the pressure and sweep range of each layer were close [36,37]. However, the stress condition the core matrix was obviously different according to poroelasticity or thermo-poroelasticity theory [38,39]. It is planned in the next phase of the project, with additional experimental modules to be added, it will be possible to monitor the changes of stress in the matrix.…”

Section: Resultsmentioning

confidence: 99%

Experimental Study on Optimization of Polymer Preslug Viscosity of ASP Flooding in Interlayer Heterogeneous Well Group Artificial Sandstone Core

Sun

Ke-sen

et al. 2021

Geofluids

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An artificial sandstone core model of large well group of positive rhythmic heterogeneous reservoir was designed and made for the simulation of ASP flooding experiment in the moderate heterogeneous reservoir. The well layout of one injection and one production was employed for the core model, to simulate the influence of polymer preslugs with different viscosity on ASP flooding effect. The experimental results show that the injectability of the polymer preslug and the effect of relieving the conflict of remaining oil production in each layer are related to the viscosity of the system. In the heterogeneous core model with the coefficient of variation of 0.65, under the constraint of the same amount of polymer agent, the ASP flooding effect of the 0.075 PV, 60 mPa·s polymer preslug was better than that of the 0.093 PV, 40 mPa·s and 0.064 PV, 80 mPa·s polymer preslugs. The change in the viscosity of the polymer preslug did not enable the ASP system to effectively exploit the low-permeability layer though. As the viscosity increased, the pressure difference between injection and production increased; the remaining oil could be exploited effectively at the bottom of the high-permeability layer and the medium-permeability layer as well as the injection end of the medium-permeability layer. If the viscosity is too small, the high-permeability area cannot be effectively blocked by the injected chemical agent, and if the viscosity is too large, the injected chemical agent cannot produce good elastic displacement relationship, which will lead to ineffective chemical agent flow. Therefore, the polymer preslug viscosity of the ASP flooding system should be moderate, and cores with different heterogeneity should have a reasonable viscosity matching range.

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Numerical analysis of thermal fracturing in subsurface cold water injection by finite element methods

Cited by 17 publications

References 38 publications

Hydromechanical Modeling of Unsaturated Flow in Double Porosity Media

Hydromechanical Modeling of Unsaturated Flow in Double Porosity Media

Stabilized mixed finite elements for deformable porous media with double porosity

Experimental Study on Optimization of Polymer Preslug Viscosity of ASP Flooding in Interlayer Heterogeneous Well Group Artificial Sandstone Core

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