TY - JOUR
T1 - Triple-porosity modelling for the simulation of multiscale flow mechanisms in shale reservoirs
AU - Wei, Mingyao
AU - Liu, Jishan
AU - Elsworth, Derek
AU - Wang, Enyuan
N1 - Funding Information:
This work is a partial result of funding by the National Key R&D Program of China (Grant no. 2017YFC0804203) and the Natural Science Foundation of China (51504235, 51474204). These supports are gratefully acknowledged. The authors would like to thank Dr. Liu Liu and Professor Pengzhi Pan for their immense polishing skills and contribution to this paper.
Publisher Copyright:
Copyright © 2018 Mingyao Wei et al.
PY - 2018
Y1 - 2018
N2 - 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.
AB - 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.
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U2 - 10.1155/2018/6948726
DO - 10.1155/2018/6948726
M3 - Article
AN - SCOPUS:85056270605
SN - 1468-8115
VL - 2018
JO - Geofluids
JF - Geofluids
M1 - 6948726
ER -