Triple-Porosity Modelling for the Simulation of Multiscale Flow Mechanisms in Shale Reservoirs

• Published in: Geofluids 2018-01, Vol.2018 (2018), p.1-11
• Main Authors: Wang, Enyuan, Elsworth, Derek, Liu, Jishan, Wei, Ming-Yao
• Format: Article
• Language: English
• Subjects: Analysis; Coal; Computer simulation; Flow; Fracture permeability; Fractured reservoirs; Gas flow; Gas production; Gas transport; Geomechanics; Hydraulics; Kerogen; Modelling; Natural gas; Permeability; Porosity; Real gases; Reservoirs; Sedimentary rocks; Sensitivity analysis; Shale; Shale gas; Shale oils; Transport
• ISSN: 1468-8115; 1468-8123
• DOI: 10.1155/2018/6948726

Shale gas reservoir is a typical type of unconventional gas reservoir, primarily because of the complex flow mechanism from nanoscale to macroscale. A triple-porosity model (M3 model) comprising kerogen system, matrix system, and natural fracture system was presented to describe the multispace scale, multitime scale, and multiphysics characteristic of gas flows in shale reservoir. Apparent permeability model for real gas transport in nanopores, which covers flow regime effect and geomechanical effect, was used to address multiscale flow in shale matrix. This paper aims at quantifying the shale gas in different scales and its sequence in the process of gas production. The model results used for history matching also showed consistency against gas production data from the Barnett Shale. It also revealed the multispace scale process of gas production from a single well, which is supplied by gas transport from natural fracture, matrix, and kerogen sequentially. Sensitivity analysis on the contributions of shale reservoir permeability in different scales gives some insight as to their importance. Simulated results showed that free gas in matrix contributes to the main source of gas production, while the performance of a gas shale well is strongly determined by the natural fracture permeability.