A dual-porosity dual-permeability model for acid gas injection process evaluation in hydrogen-carbonate reservoirs

Luo, Erhui; Fan, Zifei; Hu, Yongle; Zhao, Lun; Zhao, Hu; Wang, Jianjun; He, Congge; Zeng, Xing

doi:10.1016/j.ijhydene.2019.03.147

Cited by 9 publications

(6 citation statements)

References 23 publications

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“…However, these results highlight the fact that the value of this parameter significantly depends on the boundary condition. Moreover, in order to simplify the simulation procedure, it is conventional to use a constant shape factor, such as those listed in Table 1, for the whole transfer period 64–69 . However, the obtained results show that even for a specific block, the constant PSS value of the hydraulic shape factor is not unique and depends on the boundary condition and the fracture pressure changing regime.…”

Section: Resultsmentioning

confidence: 99%

“…Moreover, in order to simplify the simulation procedure, it is conventional to use a constant shape factor, such as those listed in Table 1, for the whole transfer period. [64][65][66][67][68][69] However, the obtained results show that even for a specific block, the constant PSS value of the hydraulic shape factor is not unique and depends on the boundary condition and the fracture pressure changing regime. The other important aspect observed from Figure 4 is that the pressure changing regime can affect the duration of the transient period.…”

Section: Hydraulic Shape Factormentioning

confidence: 92%

“…For the sake of simplicity, it is conventional in the literature to use a geometry-based well-known model for computing the shape factor, for example, 34,35,[39][40][41][42] which is constant in the whole transfer duration ignoring the boundary conditions and the physical properties of the domain. [64][65][66][67][68][69] On the other side, this approach may lead to significant errors, particularly in the transient stage, as it will be shown in the numerical examples. To overcome this issue, a two-step computational dual-porosity algorithm is proposed in which the appropriate time-varying shape factor is calculated according to the current boundary conditions and the physical properties of the problem.…”

Section: Computational Algorithm For Field-scale Problemsmentioning

confidence: 96%

“…For the sake of simplicity, it is conventional in the literature to use a geometry‐based well‐known model for computing the shape factor, for example, 34,35,39–42 which is constant in the whole transfer duration ignoring the boundary conditions and the physical properties of the domain 64–69 . On the other side, this approach may lead to significant errors, particularly in the transient stage, as it will be shown in the numerical examples.…”

Section: Computational Algorithm For Field‐scale Problemsmentioning

confidence: 99%

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A computational dual‐porosity approach for the coupled hydro‐mechanical analysis of fractured porous media

Khoei,

Taghvaei

2024

Num Anal Meth Geomechanics

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Dual‐porosity simulation is one of the most used and efficient approaches in modeling fractured porous media. The performance of this approach is highly dependent on the accuracy of the definition of matrix‐fracture transfer shape factor. In this paper, a two‐step computational algorithm is developed to enhance the accuracy of the dual‐porosity method in modeling large‐scale deformable porous media, particularly in the transient stage when the conventional dual‐porosity models are associated with some errors. Moreover, in the proposed finite element method (FEM)‐based algorithm, the interaction between the fluid and solid phases is taken into account using a modified expression for the conventional shape factor. To this end, an extended relationship is derived to calculate the hydro‐mechanical shape factor for deformable saturated porous media. An appropriate unit cell along with the consistent boundary conditions is introduced, and the corresponding hydro‐mechanical shape factor is numerically evaluated for the unit cell at each time step. Finally, the calculated time‐varying shape factors are employed in a dual‐porosity framework to simulate various case studies and investigate the influence of different parameters, including the boundary conditions, the fracture to matrix permeability ratio, and the fracture compressibility coefficient on the hydraulic and hydro‐mechanical time‐varying shape factors. Numerical simulations are carried out by employing the proposed dual‐porosity algorithm through two general problems and the results are compared with the fine‐grid direct numerical simulation. The results are promising and show that the present algorithm effectively and efficiently increases the precision of the dual‐porosity method in modeling large‐scale deformable problems.

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Section: Resultsmentioning

confidence: 99%

Section: Hydraulic Shape Factormentioning

confidence: 92%

Section: Computational Algorithm For Field-scale Problemsmentioning

confidence: 96%

Section: Computational Algorithm For Field‐scale Problemsmentioning

confidence: 99%

See 2 more Smart Citations

A computational dual‐porosity approach for the coupled hydro‐mechanical analysis of fractured porous media

Khoei,

Taghvaei

2024

Num Anal Meth Geomechanics

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“…The results show that CO 2 -water injection after water flooding is an effective method to improve the recovery efficiency of a tight reservoir, which can significantly reduce the water production and improve the recovery efficiency of a tight reservoir. Vidiuk [96][97][98] established a component model for the injection of H 2 S-CO 2 to study the mechanism related to the improvement of oil recovery by CO 2 injection, in which the increase in H 2 S component can reduce the precipitation of asphaltene components in the reservoir and improve the fluid flow capacity in the reservoir. Heller [99][100][101][102] conducted supercritical CO 2 long core flooding experiments in gas reservoirs and the CO 2 injection desorption experiments in shale.…”

Section: Rencent Research On Co 2 Injection To Enhance Oil Recovery M...mentioning

confidence: 99%

Review on the Mechanism of CO2 Storage and Enhanced Gas Recovery in Carbonate Sour Gas Reservoir

et al. 2023

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Carbonate gas reservoirs in the Sichuan Basin have many complex characteristics, such as wide distribution, strong heterogeneity, high temperature, high pressure, high H2S and CO2 content and an active edge or bottom water. In the late stage of exploitation of carbonate sour gas reservoirs, the underground depleted reservoirs can provide a broad and favorable space for CO2 storage. If CO2 is injected into the depleted carbonate sour reservoirs for storage, it will help to achieve the goal of carbon neutrality, and the CO2 stored underground can perform as “cushion gas” to prevent the advance of edge or bottom water, to achieve the purpose of enhanced natural gas recovery. Injecting CO2 into low permeability reservoirs for oil displacement has become an important means to enhance oil recovery (EOR). However, the mechanism of EOR by injecting CO2 into carbonate sour gas reservoirs is not clear and the related fundamental research and field application technology are still in the exploration stage. This paper reviews the main scientific and technical perspectives in the process of injecting CO2 into carbonate sour gas reservoirs for storage and enhancing gas recovery.

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Impact of gas composition and reservoir heterogeneity on miscible sour gas flooding — A simulation study

Koyanbayev

Wang

et al. 2023

Fuel

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A dual-porosity dual-permeability model for acid gas injection process evaluation in hydrogen-carbonate reservoirs

Cited by 9 publications

References 23 publications

A computational dual‐porosity approach for the coupled hydro‐mechanical analysis of fractured porous media

A computational dual‐porosity approach for the coupled hydro‐mechanical analysis of fractured porous media

Review on the Mechanism of CO2 Storage and Enhanced Gas Recovery in Carbonate Sour Gas Reservoir

Impact of gas composition and reservoir heterogeneity on miscible sour gas flooding — A simulation study

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