Matrix diffusivity
is vital for developing tight sandstone and
shale gas reservoirs. This study proposes a method to test the diffusivities
of a core under confining pressure conditions using the gas diffusion
technique. The diffusivities of methane and helium were examined in
fine-grained rocks (sandy shale, silty sandstone, tight sandstone,
and shale) under specific stress conditions. The results revealed
that the gas diffusivities varied among the samples. The tight sandstones
exhibited diffusivity higher than that of silty sandstone, sandy mudstone,
and shale. Helium diffusivities in shales and sandy mudstones were
1 order of magnitude smaller, while methane diffusivities were 2 orders
of magnitude smaller than those in tight sandstones. A positive correlation
was observed between the stress sensitivity factor and the clay mineral
content, indicating the influence of the clay minerals’ mechanical
properties. Additionally, the shale gas diffusivities exhibited significant
anisotropy due to slit-like gas channels parallel to laminae in shale.
It was found that the impact of adsorption on diffusivity was positively
correlated to the amount of adsorption. While the adsorption effect
was negligible in tight sandstones, organic-rich shales and sandy
mudstones experienced an order-of-magnitude reduction in methane diffusivities
compared to helium. This study presents a method to evaluate the diffusion
coefficient of a core matrix under a confining pressure. It provides
insights into gas diffusion behavior in different fine-grained rocks,
considering the effects of stress, clay mineral content, and adsorption.
These findings contribute to understanding tight sandstone gas and
shale gas reservoirs, aiding in the optimization of gas production
strategies.