Gas Flow Models of Shale: A Review

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

Research output: Contribution to journalArticlepeer-review


Conventional flow models based on Darcy's flow physics fail to model shale gas production data accurately. The failure to match field data and laboratory-scale evidence of non-Darcy flow has led researchers to propose various gas-flow models for the shale reservoirs. There is extensive evidence that suggests the size of the pores in shale is microscopic in the range of a few to hundreds of nanometers (also known as nanopores). These small pores are mostly associated with the shale's organic matter portion, resulting in a dual pore system that adds to the gas flow complexity. Unlike Darcy's law, which assumes that a dominant viscous flux determines a rock's permeability, shale's permeability leads to other flow processes besides viscous flow such as gas slippage and Knudsen diffusion. This paper reviews the dominant gas-flow processes in a single nanopore based on theoretical models and molecular dynamics simulations, and Lattice Boltzmann modeling. We extend the review to pore network models used to study the gas permeability of shale.
Original languageEnglish
JournalEnergy & Fuels
Publication statusAccepted/In press - 18 Jan 2021


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