Gas Flow Models of Shale: A Review

Javadpour, Farzam; Singh, Harpreet; Rabbani, Arash; Babaei, Masoud; Enayati, Samira

doi:10.1021/acs.energyfuels.0c04381

Cited by 53 publications

(31 citation statements)

References 166 publications

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“…Models adopted to quantify gas migration in low-permeability media can be classified according to their complexity, in terms of, e.g., conceptualization and mathematical rendering of the embedded processes, as well as number of their characteristic parameters. Among existing models associated with a high degree of complexity and including multiple transport processes jointly contributing to the total gas migration across the system (Mehmani et al 2013;Wu et al 2015aWu et al , 2016Wu et al , 2017Sun et al 2017;Zhang et al 2018;Javadpour et al 2021), here we consider the model of Wu et al (2016). The selected model allows considering mechanical deformation as well as relevant features associated with real gases such as variations in the gas viscosity ( ), and the effects of the compressibility ( C g ) and gas deviation (Z) factors caused by pressure and temperature changes.…”

Section: Gas Flow In Low-permeability Mediamentioning

confidence: 99%

“…Due to our still incomplete knowledge of the critical mechanisms driving gas movement in low-permeability media (Singh and Myong 2018;Javadpour et al 2021) and the complexities associated with the estimation of model parameters, model outputs should be carefully analyzed considering all possible (aleatoric and epistemic) sources of uncertainty. In this sense, sensitivity analysis approaches are important tools enabling us to (i) quantify uncertainty, (ii) enhance our understanding of the relationships between model inputs and outputs, and (iii) tackle the challenges of model-and data-driven design of experiments (Dell'Oca et al 2017).…”

Section: Introductionmentioning

confidence: 99%

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Sensitivity Analysis and Quantification of the Role of Governing Transport Mechanisms and Parameters in a Gas Flow Model for Low-Permeability Porous Media

Sandoval

Riva

Colombo³

et al. 2022

Transp Porous Med

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Recent models represent gas (methane) migration in low-permeability media as a weighted sum of various contributions, each associated with a given flow regime. These models typically embed numerous chemical/physical parameters that cannot be easily and unambiguously evaluated via experimental investigations. In this context, modern sensitivity analysis techniques enable us to diagnose the behavior of a given model through the quantification of the importance and role of model input uncertainties with respect to a target model output. Here, we rely on two global sensitivity analysis approaches and metrics (i.e., variance-based Sobol’ indices and moment-based AMA indices) to assess the behavior of a recent interpretive model that conceptualizes gas migration as the sum of a surface diffusion mechanism and two weighted bulk flow components. We quantitatively investigate the impact of (i) each uncertain model parameter and (ii) the type of their associated probability distribution on the evaluation of methane flow. We then derive the structure of an effective diffusion coefficient embedding all complex mechanisms of the model considered and allowing quantification of the relative contribution of each flow mechanism to the overall gas flow.

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Section: Gas Flow In Low-permeability Mediamentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Sensitivity Analysis and Quantification of the Role of Governing Transport Mechanisms and Parameters in a Gas Flow Model for Low-Permeability Porous Media

Sandoval

Riva

Colombo³

et al. 2022

Transp Porous Med

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“…Furthermore, the analysis based on the derived productivity equation and actual data of production wells demonstrates that the productivity of gas wells with a certain water cut is considerably lower than that of gas wells with no water production; the non-Darcy effect of productivity of gas wells declines after water production starts. Javadpour et al (2021) considered the non-Darcy flow of shale gas, and reviewed the dominant gas-flow processes in a single nanopore based on theoretical models and molecular dynamics simulations, and Lattice Boltzmann modeling.…”

Section: Introductionmentioning

confidence: 99%

Two-phase Flow Model and Productivity Evaluation of Gas and Water for Dual-Medium Carbonate Gas Reservoirs

et al. 2022

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Fluid flow in the dual-medium carbonate gas reservoir is characterized by stress sensitivity and non-Darcy flow effect. In order to accurately describe the unsteady flow of gas and water in the dual-medium gas reservoir, a two-phase flow model of gas and water is built. First, reservoir space and fluid flow characteristics of carbonate gas reservoirs are investigated, and the flow model that considers both the stress sensitivity and non-Darcy flow is built based on the fundamental flow theory, after fully investigating the reservoir space and fluid flow characteristics of carbonate gas reservoirs. Then, the perturbation theory is introduced, and the model is solved in the Laplace space, after which the obtained Laplace space analytical solution is converted into the real-space solution. Finally, the productivity evaluation model for the dual-medium gas reservoir with the gas-water two-phase flow is built, based on the flowing material balance method and Newton iteration. The presented productivity evaluation model is applied to analyze the effects of stress sensitivity and non-Darcy flow on the two-phase flow model of gas and water for the dual-medium gas reservoir and the reservoir productivity. The results indicate that a higher stress sensitivity coefficient is demonstrated to indicate higher stress sensitivity and accelerated production decline of the reservoir, while a lower non-Darcy flow effect coefficient represents a stronger non-Darcy effect and boosted drop of initial production of the reservoir. Hence, it is not reasonable to neglect the effects of stress sensitivity and non-Darcy flow during the evaluation of the productivity of a dual-medium carbonate gas reservoir. The model presented in this research provides important references for improving the recovery performance of dual-medium gas reservoirs.

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“…In addition to adsorption/desorption and dissolution, the discrepancy between transport capacity of isotopic gases during transport through shale pores also results in isotope fractionation. − Multiple flow mechanisms (e.g., viscous flow, slip flow, Knudsen diffusion, and surface diffusion) coexist in shale reservoirs because of the multiscale flow paths [micropores (<2 nm), mesopores (2–50 nm), and macropores (>50 nm)] and the complex pore structures in them. − In the early stage of shale gas production, the pressure in pores is high and viscous flow is dominant . The mean free path of methane isotopes is small (i.e., intermolecular collision is dominant), and the isotope fractionation is not obvious .…”

Section: Introductionmentioning

confidence: 99%

Carbon Isotope Fractionation during Shale Gas Transport through Organic and Inorganic Nanopores from Molecular Simulations

Wang

Zhao

et al. 2021

Energy Fuels

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Carbon isotope fractionation is a promising method to predict gas-in-place content and evaluate the shale gas production stage. In this study, molecular simulations are conducted to investigate fractionation characteristics of 12CH4 and 13CH4 in high-Kn (Knudsen number) flows (Kn > 0.1) within organic and inorganic pores under shale reservoir conditions (353 K, 5–25 MPa). The results show that isotope fractionation is more obvious (i.e., the difference in transport capacities between 12CH4 and 13CH4 is larger) in organic pores than in inorganic pores. Methane adsorption capacity and surface roughness of pore walls are two major reasons. High-coverage adsorption in organic pores reduces the effective pore size, and the Knudsen diffusion becomes significant. Moreover, the specular reflection of molecules occurs frequently on the smooth surfaces of organic pores, which enlarges the difference in isotope diffusion capacity. Indeed, the difference in energy (specific enthalpy) transport of methane isotopes in organic and inorganic pores is the intrinsic reason for fractionation. Furthermore, the fractionation level is positively correlated with Kn due to the enhanced contribution of Knudsen diffusion and surface diffusion in high-Kn flows. In addition, the isotope fractionation level decreases as pore size increases because Kn and the contribution of the adsorbed phase to the total molar flux reduce in a large pore. Our findings and related analyses may help us to understand isotope fractionation in different pore types and sizes from the atomic level and assist future applications in engineering.

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Gas Flow Models of Shale: A Review

Cited by 53 publications

References 166 publications

Sensitivity Analysis and Quantification of the Role of Governing Transport Mechanisms and Parameters in a Gas Flow Model for Low-Permeability Porous Media

Sensitivity Analysis and Quantification of the Role of Governing Transport Mechanisms and Parameters in a Gas Flow Model for Low-Permeability Porous Media

Two-phase Flow Model and Productivity Evaluation of Gas and Water for Dual-Medium Carbonate Gas Reservoirs

Carbon Isotope Fractionation during Shale Gas Transport through Organic and Inorganic Nanopores from Molecular Simulations

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