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Molecular dynamics of methane flow behavior through realistic organic nanopores under geologic shale condition: Pore size and kerogen types

干酪根 油页岩 甲烷 纳米孔 石墨烯 吸附 化学工程 材料科学 比表面积 分子动力学 矿物学 化学 纳米技术 化学物理 地质学 有机化学 烃源岩 计算化学 古生物学 构造盆地 工程类 催化作用
作者
Zheng Sun,Xiangfang Li,Wenyuan Liu,Tao Zhang,Minxia He,Hadi Nasrabadi
出处
期刊:Chemical Engineering Journal [Elsevier BV]
卷期号:398: 124341-124341 被引量:218
标识
DOI:10.1016/j.cej.2020.124341
摘要

Up to date, for the purpose of simplicity, graphene-based structures, like nano-porous carbons or carbon nanotubes, have been widely utilized to investigate methane flow behavior inside shale organic nanopores. However, realistic shale organic matrix is composed of kerogen molecules, possessing complex amorphous structures and apparently different surface attributes compared with graphene-based nanopore surface, which will inevitably have a great impact on surface-methane interactions and methane flow behavior. Current research works in terms of the graphene-based material fails to capture the influence of kerogen surface, and therefore cannot accurately characterize nano-confined methane flow behavior through realistic shale organic matter. Also, shale organic nanopores with different kerogen types contain different surface compositions, while its impact on methane flow capacity has not been reported yet. To bridge this knowledge gap, this paper simulates the methane flow behavior through authentic kerogen-based circular nanopores with the use of molecular dynamics (MD) for the first time. And a novel construction method was developed to generate kerogen-based organic nanopores with desirable pore size and different kerogen types for MD simulation. Main results show that a) decrease in pore size will contribute to the enhancement of adsorption capacity for nanopores and type-III kerogen > type-II kerogen > type-I kerogen in terms of methane adsorption capacity; b) ratio of average methane density confined in nanopores to bulk-gas density ranges from 1.2 to 2.6, which will decrease with the increase of the pressure and increase with decreasing pore size; c) Under shale geological condition, the conventional theoretical model for nanoconfined gas flow will underestimate that of 0.41 time for type-I kerogen-based nanopores, 0.59 time for type-II kerogen-based nanopores, and 0.88 time for type-III kerogen-based nanopores.
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