Stress-dependent fluid dynamics of shale gas reservoirs: A pore network modeling approach

Foroozesh, Jalal; Abdalla, Amr Ibrahim Mohamed; Zivar, Davood; Douraghinejad, Jalal

doi:10.1016/j.jngse.2021.104243

Cited by 9 publications

(7 citation statements)

References 49 publications

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“…Subsequently, Song et al comprehensively considered the free gas sliding, adsorption gas surface diffusion, and adsorption/desorption transport mechanisms to study the gas flow in shale and explained the dynamic flow process of shale gas . Foroozesh et al studied the flow behavior of gas slip and desorption considering different effective stress conditions of shale reservoir . The gas phase transition in nano/micropores of shale is significantly affected by interfacial capillary force and wall forces.…”

Section: Multiscale Flow Simulationmentioning

confidence: 99%

“…158 Foroozesh et al studied the flow behavior of gas slip and desorption considering different effective stress conditions of shale reservoir. 159 The gas phase transition in nano/ micropores of shale is significantly affected by interfacial capillary force and wall forces. 163 As the interaction between gas, water and wall molecules in shale nano pores cannot be ignored, the influence of wettability and adsorption on the flow should be accurately considered in shale gas and water flow simulations.…”

Section: Diffusion and Flowmentioning

confidence: 99%

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Recent Advances in Multiscale Digital Rock Reconstruction, Flow Simulation, and Experiments during Shale Gas Production

Yang

Zhang

et al. 2023

Energy Fuels

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The complex and multiscale nature of shale gas transport imposes new challenges to the already well-developed techniques for conventional reservoirs, especially digital core analysis. Multiscale complicated pore systems and distinctive properties limit most reconstruction methods not applicable. High-precision imaging experiments play a key role in the characterization of pore structures and mineral components. While the exhilarating breakthroughs in physical experimental methods and hybrid superposition methods have made significant achievements in shale digital rock reconstruction, rapidly evolving deep learning methods also present a promising option. Benefiting from the digital rock techniques, the pore-scale flow of shale gas can be directly simulated based on digital rock or indirectly modeled using the pore network model. It is precise and realistic to investigate the shale gas flow at the pore scale considering the desorption, surface diffusion, and slippage in nanopores. In this paper, we reviewed the recent advances in off-mentioned methods and processes and presented a hand for the research in this field.

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Section: Multiscale Flow Simulationmentioning

confidence: 99%

Section: Diffusion and Flowmentioning

confidence: 99%

Recent Advances in Multiscale Digital Rock Reconstruction, Flow Simulation, and Experiments during Shale Gas Production

Yang

Zhang

et al. 2023

Energy Fuels

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“…The procedure was discussed in more detail in previous works. 42,53 Equation 7 is used to calculate the amount of adsorbed gas at a stabilized pore pressure (P s ). The Langmuir parameters fitted to the experimental data points resulted in a Langmuir adsorption volume of 0.595 cm 3 /gr and a constant of 0.00015 1/kPa.…”

Section: Evaluation Of Methane Sorptionmentioning

confidence: 99%

Experimental and Modeling Study of Water Imbibition and Flowback in Shale: Prediction of Relative Permeability and Capillary Pressure Curves

et al. 2023

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Understanding the invasion and flowback processes of water, as the main source of hydraulic fracking fluid, is crucial for the proper evaluation and development of complex gas shale formations. Direct measurements of full gas−water relative permeability and capillary pressure curves by steady-state or unsteady-state techniques are not feasible in ultralow permeability shales. Therefore, the objective of this study is to investigate the dynamic rock−fluid properties of a Mancos shale sample by mimicking water imbibition and flowback experiments. To do so, a water injection experiment was done and tried to measure the flowback. After that, history matching on the experimental data of the water injection and flowback process was done to predict gas− water relative permeability data and capillary pressure curves. Low water flowback was observed, which insists on water entrapment in shale rocks. The results show a high threshold pressure and meaningful relative permeability of water, which can reduce the gas production rate dramatically. The saturation profiles show a high percentage of water in the invaded zone (>75%); however, the continuous imbibition of water with time (increase in shut-in time) helps the front of the invasion zone to move further deep into the shale, which enhances gas production. The S-shape gas relative permeability curve most likely represents the actual trend of the curve. An optimum shut-in time was predicted, which enables us to avoid delays in starting production operations.

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“…Currently, the methods to analyze the stress sensitivity of fractured reservoirs include indoor experiments, theoretical research, and micro-scale analysis (Zhang et al, 2014;Zhang et al, 2015a;Zhang et al, 2015b;Duan et al, 2017;Foroozesh et al, 2021;Wu et al, 2022). Evaluation methods by indoor experiment mainly include the changes in confining pressure and pore pressure.…”

Section: Introductionmentioning

confidence: 99%

Influence of geomechanics parameters on stress sensitivity in fractured reservoir

Feng

Tang

et al. 2023

Front. Earth Sci.

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The complex fractures aggravate stress sensitivity and heterogeneity of the reservoir and seriously restrict effective development. Therefore, it is of great significance to study and quantitatively evaluate the stress sensitivity of the fractured reservoir. Taking the typical block of the Longmaxi shale reservoir in southern Sichuan as the engineering background, one uses the finite element method to develop a numerical model of a two-dimensional fracture closure variation subjected to the non-hydrostatic stress field. It explores the influence of different fracture occurrences and rock mechanical parameters on stress sensitivity. The theoretical model verifies the numerical simulation results to reveal the stress sensitivity mechanism of the fractured reservoir. The results show that the influence of the dip angle of fracture on the stress sensitivity depends on the anisotropy of applied in-situ stresses. The stronger stress sensitivity occurs in low-dip angles where the lateral pressure coefficient is less than 1. One defines the lateral pressure coefficient. On the contrary, the stronger stress sensitivity occurs in high-dip angles where the lateral pressure coefficient is more significant than 1. It is because the normal stress differences under different stress fields apply to the fracture. Under a given stress condition, the stress sensitivity of fracture negatively correlates with aspect ratio, elastic modulus, and Poisson’s ratio. Pressure maintenance may be more critical in a reservoir with a low aspect ratio and rich in soft minerals. The theoretical predicting model of fracture permeability under different conditions is established based on the linear elastic theory. The relative error between theoretically predicted results and numerical simulation ones is less than 10%, which verifies the accuracy of numerical simulation results. The fundamental reason for stress sensitivity in the fractured reservoir is the fracture geometry and mineral deformation change. The research results are of great significance for establishing the productivity equation considering the stress sensitivity, accurately evaluating the variation of reservoir seepage capacity, and formulating reasonable drainage and production system.

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Stress-dependent fluid dynamics of shale gas reservoirs: A pore network modeling approach

Cited by 9 publications

References 49 publications

Recent Advances in Multiscale Digital Rock Reconstruction, Flow Simulation, and Experiments during Shale Gas Production

Recent Advances in Multiscale Digital Rock Reconstruction, Flow Simulation, and Experiments during Shale Gas Production

Experimental and Modeling Study of Water Imbibition and Flowback in Shale: Prediction of Relative Permeability and Capillary Pressure Curves

Influence of geomechanics parameters on stress sensitivity in fractured reservoir

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