Multiscale random pore network modeling of oil-water two-phase slip flow in shale matrix

Cui, Ronghao; Feng, Qihong; Chen, Hongwei; Zhang, Wei; Wang, Sen

doi:10.1016/j.petrol.2018.12.026

Cited by 60 publications

(31 citation statements)

References 74 publications

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“…They revealed that the gas and water relative permeability in nanoscale pore network is mainly determined by the total organic carbon (TOC) and wettability of inorganic throats. Apart from the gas and water two-phase flow, the water and oil two-component liquid flow in the pore network was simulated by Cui et al, 298 where the pore network was randomly generated by fitting the pore size distribution (PSD) frequency. The corner film model and bulk fluid models with different slip lengths are utilized to depict the liquid flow behaviors.…”

Section: Pore-scale Simulationsmentioning

confidence: 99%

Transport of Shale Gas in Microporous/Nanoporous Media: Molecular to Pore-Scale Simulations

Fan

et al. 2020

Energy Fuels

136

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As the typical unconventional reservoir, shale gas is believed to be the most promising alternative for the conventional resources in future energy patterns, attracting more and more attention throughout the world. Generally, the majority of shale gas is trapped within the tight shale rock with ultralow porosity (<10%) and ultrasmall pore size (as less as several nanometers). Thus, the accurate understanding of gas transport characteristic and its underlying mechanism through these microporous/nanoporous media is critical for the effective exploitation of shale reservoir. In this context, we present a comprehensive review on the current advances of multiscale transport simulations of shale gas in microporous/nanoporous media from molecular to pore-scale. For the gas transport in shale nanopores using molecular dynamics (MD) simulations, the structure and force parameters of various nanopore models, including organic models (graphene, carbon nanotubes, and kerogen) and inorganic models (clays, carbonate, and quartz), and flow simulation strategies (such as nonequilibrium molecular dynamics (NEMD) and Grand Canonical Monte Carlo simulations) are systematically introduced and clarified. The significant MD simulation results about gas transport characteristic in shale nanopores then are elaborated respectively for different factors, including pore size, ambient pressure, nanopore type, atomistic roughness, and pore structure, as well as multicomponent. Besides, the two-phase transport characteristic of gas and water is also discussed, considering the ubiquity of water in shale formation. For the lattice Boltzmann method (LBM) and pore network model (PNM) approaches to conduct pore-scale simulations, we briefly review its origins, modifications, and applications for gas transport simulations in a microporous/nanoporous shale matrix. Particularly, the upscaling methods to incorporate MD simulation into LBM and PNM frameworks are emphatically expounded in the light of recent attempts of MD-based pore-scale simulations. It is hoped that this Review would be helpful for the readers to build a systematical overview on the transport characteristic of shale gas in microporous/nanoporous media and subsequently accelerate the development of the shale industry.

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Section: Pore-scale Simulationsmentioning

confidence: 99%

Transport of Shale Gas in Microporous/Nanoporous Media: Molecular to Pore-Scale Simulations

Fan

et al. 2020

Energy Fuels

136

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“…However, the calculated oil phase permeability has deviation with the experimental data. The main reason is that the difference in the rock structure is not considered in this model . In conclusion, the relative permeability curves calculated by this model fit well with the experimental values, but it needs further study.…”

Section: Mathematical Modelingmentioning

confidence: 79%

New Model of Relative Permeability for Two-Phase Flow in Mixed-Wet Nanoporous Media of Shale

Tian

Chen

et al. 2021

Energy Fuels

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Oil−water relative permeability can be regarded as one of the important parameters to study the flow characteristics in the nanoporous media of shale. Considering the slip boundary and the difference of viscosity between the near-wall fluid and bulk fluid, the flow equation in the nanotube is established based on the Hagen−Poiseuille equation. The fractal theory is used to upgrade the relative permeability model in a single nanotube to that in shale porous media. The proposed model considers slip length, viscosity of the near-wall fluid, pore structure, total organic carbon (TOC) content, wettability, and capillary pressure. This is the first model that predicts the relative permeability for the oil−water two-phase flow in mixed-wet shale. In addition, the proposed model can identify the difference of flow mechanism in inorganic and organic pores. The model of the two-phase relative permeability in nanoporous shale is validated by experimental data. The results show that the influence of slip length on the relative permeability is greater than that of the viscosity of the near-wall fluid. The oil relative permeability decreases with the increase of the TOC content. The relative permeability of oil phase reduces with the decrease of the contact angle for oil in the inorganic pore. At the same saturation, with the increase of the fractal dimension of pore size distribution (D f ), the oil relative permeability increases, while the water relative permeability reduces. The increase of capillary force can improve the relative permeability of the oil phase. When the pore size is larger than 100 nm, the effect of nanoscale on improving the oil relative permeability can be negligible.

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“…Compared to the LSCM, FIB-SEM, and X-ray CT methods, the MRI method is limited by a very obvious disadvantage: an excessively low imaging resolution [74,75]. For tight sandstones and shale rocks, obtaining a large amount of microscopic information with the MRI method is difficult.…”

Section: Magnetic Resonance Imaging (Mri)mentioning

confidence: 99%

Challenges and Prospects of Digital Core-Reconstruction Research

et al. 2019

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The simulation of various rock properties based on three-dimensional digital cores plays an increasingly important role in oil and gas exploration and development. The accuracy of 3D digital core reconstruction is important for determining rock properties. In this paper, existing 3D digital core-reconstruction methods are divided into two categories: 3D digital cores based on physical experiments and 3D digital core stochastic reconstructions based on two-dimensional (2D) slices. Additionally, 2D slice-based digital core stochastic reconstruction techniques are classified into four types: a stochastic reconstruction method based on 2D slice mathematical-feature statistical constraints, a stochastic reconstruction method based on statistical constraints that are related to 2D slice morphological characteristics, a physics process-based stochastic reconstruction method, and a hybrid stochastic reconstruction method. The progress related to these various stochastic reconstruction methods, the characteristics of constructed 3D digital cores, and the potential of these methods are analysed and discussed in detail. Finally, reasonable prospects are presented based on the current state of this research area. Currently, studies on digital core reconstruction, especially for the 3D digital core stochastic reconstruction method based on 2D slices, are still very rough, and much room for improvement remains. In particular, we emphasize the importance of evaluating functions, multiscale 3D digital cores, multicomponent 3D digital cores, and disciplinary intersection methods in the 3D construction of digital cores. These four directions should provide focus, alongside challenges, for this research area in the future. This review provides important insights into 3D digital core reconstruction.

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Multiscale random pore network modeling of oil-water two-phase slip flow in shale matrix

Cited by 60 publications

References 74 publications

Transport of Shale Gas in Microporous/Nanoporous Media: Molecular to Pore-Scale Simulations

Transport of Shale Gas in Microporous/Nanoporous Media: Molecular to Pore-Scale Simulations

New Model of Relative Permeability for Two-Phase Flow in Mixed-Wet Nanoporous Media of Shale

Challenges and Prospects of Digital Core-Reconstruction Research

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