Multi-scale modelling of gas transport and production evaluation in shale reservoir considering crisscrossing fractures

Micheal, Marembo; Xu, Wenlong; Xu, HengYu; Zhang, Jianing; Hong-jie, Jin; Yu, Hao; Wu, HengAn

doi:10.1016/j.jngse.2021.104156

Cited by 30 publications

(25 citation statements)

References 69 publications

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Section: Gas Transport Prediction With Numerical Methodsmentioning

confidence: 99%

“…Fully coupled gas transport mechanisms were considered, and the gas production behaviors in the whole depletion period were obtained. Taking the scale of individual fractures and fracture networks into consideration, Micheal et al 102 conducted multiscale modeling of gas transport and shale formation production. They combined fracture-scale and fieldscale models, as shown in Figure 9d, and the production performance of shale reservoirs under different matrix, hydraulic fracture, and natural fracture properties were evaluated.…”

Section: Multiscale Modeling Of Gas Transport In the Shalementioning

confidence: 99%

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Review of Shale Gas Transport Prediction: Basic Theory, Numerical Simulation, Application of AI Methods, and Perspectives

et al. 2023

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The gas transport mechanism in shale reservoirs is extremely complex and is a typical multiscale and multiphysics coupled transport process, considering the complex shale rock structure, wide distribution of micropores and nanopores in shale gas reservoirs, diverse gas occurrence forms, and large pore size spans. An accurate understanding of the shale gas transport process and mechanism is important for effective exploration of shale gas reservoirs. In this work, a review of the recent progress in the prediction of shale gas transport in porous media is presented. The basic theory of gas transport in nanopores is discussed. The gas transport in organic and inorganic matter and the gas adsorption effect are covered. Then, gas transport simulations with conventional multiscale numerical methods, including molecular dynamics and lattice Boltzmann simulations, are reviewed, and the multiscale modeling methods are discussed. Furthermore, the application of artificial intelligence (AI) methods in shale gas transport research is discussed. The focus is on the characterization of the shale porous geometry, including porosity, tortuosity, pore size distribution, and reconstruction of the shale porous medium. The application of AI-based methods such as neural networks and machine learning for the prediction of porous flow properties is discussed. This study intends to provide a comprehensive review of shale gas transport characteristics and to enable the accessibility of AI tools in the research of shale gas.

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Section: Gas Transport Prediction With Numerical Methodsmentioning

confidence: 99%

Section: Multiscale Modeling Of Gas Transport In the Shalementioning

confidence: 99%

Review of Shale Gas Transport Prediction: Basic Theory, Numerical Simulation, Application of AI Methods, and Perspectives

et al. 2023

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“…Therefore, the chance of gas molecules colliding with the pore walls is lower than that of intermolecular collision . In essence, the transport of gas in the natural fracture is governed by the non-Darcy flow. − According to Micheal et al, the natural fracture domain is surrounded by the inorganic matrix and the hydraulic fracture. Thus, two transfer terms attribute to the exchange in the natural fracture.…”

Section: Storage and Transport Mechanism Of Gas In Shale Reservoirsmentioning

confidence: 99%

“…The workflow of Liu et al 135 is depicted in Figure 13b. Micheal et al 119 established an exchange between a matrix and fracture by considering a crisscrossing fracture and catered for flow from the matrix through the fracture to the production well, as shown in Figure 13c.…”

Section: Multiscale Storage and Transport Of Gas In Shalementioning

confidence: 99%

Hydraulic Fracturing and Enhanced Recovery in Shale Reservoirs: Theoretical Analysis to Engineering Applications

et al. 2023

Energy Fuels

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Shale reservoirs are extensively exploited using hydraulic fracturing, which forms multiple cracks that connect with the existing natural fractures to create a continuous path for the gas stored in the kerogen to flow to the production well. Apart from the tedious nature of hydraulic fracturing, the mechanism of the storage and flow of gas is equally complex since multiple phases and scales are involved. An accurate understanding of hydraulic fracturing coupled with a strategy of analyzing the flow and overall recovery of gas is paramount to ensure efficient exploitation. In this work, a comprehensive review of the recent strategies used in analyzing the hydraulic fracturing, storage, flow, and recovery of gas is presented. To begin with, the experimental, analytical, and numerical approaches pertinent to hydraulic fracturing are deeply explored. Additionally, the flow of gas through the newly opened channels is accounted for by using a quadruple-domain approach where the mechanisms of flow in shale reservoirs at the nanoscale, microscale, mesoscale, and macroscale are considered. Furthermore, a strategy to capture the multiple phases, including gas, oil, and water, and recover both carbon dioxide and methane is explored through thermal and enhanced gas recovery approaches. This review provides a baseline for understanding how the hydraulic fracture evolves and propagates to create new channels that contribute to the flow of gas, how the gas flows through the created channels across the many scales of the shale reservoir, and how to improve recovery from shale reservoirs.

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“…One is the continuous medium model, , including the dual medium model, multiple medium model, and equivalent continuous medium model. The other is the discrete fracture model (DFM). − Some researchers combine the advantages of both continuous and discrete models to establish a hybrid model. − The dual medium model has good applicability to reservoirs with more fractures, but it will cause large errors for the reservoirs with less fractures. Although the discrete fracture model can accurately describe the fracture geometry, it is difficult to solve due to a large number of calculations when there is large fracture density or large difference between fracture grid size and matrix grid size.…”

Section: Introductionmentioning

confidence: 99%

Study on Multiscale Fluid–Solid Coupling Theoretical Model and Productivity Analysis of Horizontal Well in Shale Gas Reservoirs

et al. 2023

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In order to study the productivity dynamic evolution laws of shale gas horizontal well, a multiscale seepage theoretical model considering the fluid–solid coupling effect is proposed first in this paper, which introduces an anisotropic matrix permeability model that comprehensively considers multiple flow regimes and an artificial hydraulic fracture conductivity model that considers proppant deformation and embedment. Then the reliability of the theoretical model is verified by the field production data obtained from the Marcellus shale. Based on the established productivity model, the evolution laws of pore pressure and permeability in different areas of the reservoir with different production periods are studied first, and then the shale gas production rate and cumulative production under different physical mechanisms, different shale gas flow regimes, and different reservoir parameters are quantified and analyzed. The simulation results show that the pore pressure in the hydraulic fracture area decreases rapidly at the initial stage of production, resulting in large deformation, and the fracture conductivity tends to be stable gradually at the later stage of production. The desorption effect will increase shale gas production, while the stress sensitivity is just the opposite. When only real gas flow is considered, the gas cumulative production is the highest. The fluid–solid coupling of hydraulic fractures has a great impact on the production, while the fluid–solid coupling in the matrix area has a small impact on the production, which can be ignored if appropriate. During the sensitivity analysis of reservoir parameters, it is observed that the influence of parameters of hydraulic fractures on production is much higher than that of matrix regional parameters. During the production process, these influencing factors can be adjusted according to the change of production data to achieve the optimization of shale gas production. In a word, the new model proposed in this paper provides a more accurate method to estimate the impact of multiple physical mechanisms, especially the fluid–solid coupling effect, on shale gas production compared with the existing model. The research results of this study can provide some reference and guidance for the dynamic prediction of shale gas production and optimization of production parameters.

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Multi-scale modelling of gas transport and production evaluation in shale reservoir considering crisscrossing fractures

Cited by 30 publications

References 69 publications

Review of Shale Gas Transport Prediction: Basic Theory, Numerical Simulation, Application of AI Methods, and Perspectives

Review of Shale Gas Transport Prediction: Basic Theory, Numerical Simulation, Application of AI Methods, and Perspectives

Hydraulic Fracturing and Enhanced Recovery in Shale Reservoirs: Theoretical Analysis to Engineering Applications

Study on Multiscale Fluid–Solid Coupling Theoretical Model and Productivity Analysis of Horizontal Well in Shale Gas Reservoirs

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