TY - JOUR
T1 - Influence of gas hydrate saturation and pore habits on gas relative permeability in gas hydrate-bearing sediments
T2 - Theory, experiment and case study
AU - Liu, Xuefeng
AU - Dong, Huaimin
AU - Yan, Weichao
AU - Arif, Muhammad
AU - Zhang, Yihuai
AU - Golsanami, Naser
N1 - Funding Information:
This work was supported by the National Natural Science Foundation of China (grant numbers 41874138 and 41874152 ), China Postdoctoral Science Foundation Funded Project (grant number 2019M662463 ), Youth Program of National Natural Science Foundation of China (grant number 42004098 ), Fundamental Research Funds for the Central Universities (grant numbers 20CX05013A and 20CX06026A ).
Publisher Copyright:
© 2021 Elsevier B.V.
PY - 2021/11
Y1 - 2021/11
N2 - Gas relative permeability characterization is of key significance to model the behavior of gas flow in gas hydrate-bearing sediments. The present study proposes a novel model to relate gas relative permeability to gas hydrate saturation based on X-ray micro-CT imaging information of xenon hydrate pore-scale distribution in sand sediments. Lattice Boltzmann method (LBM) was used to obtain permeability values of xenon hydrate-bearing sediments via micro-CT data. The results showed that gas relative permeability (Kr) versus gas hydrate saturation (Sh) data are consistent with the new model and the imitative effect is relatively better than that of the simple Corey model. Besides, we calculated gas relative permeability versus gas hydrate saturation curves for various pore habits via idealized models. Experimental measurements and simulation results showed that the grain-coating gas hydrate exhibits the highest gas relative permeability, while pore-filling gas hydrate exhibits the lowest values of gas relative permeability, and the cementing gas hydrate ranges in between. We validated the new gas relative permeability calculation model by applying it to the well logging data of gas hydrate reservoirs. Our results showed that the novel model is beneficial for permeability characterization of gas hydrate reservoirs and gas relative permeability calculations.
AB - Gas relative permeability characterization is of key significance to model the behavior of gas flow in gas hydrate-bearing sediments. The present study proposes a novel model to relate gas relative permeability to gas hydrate saturation based on X-ray micro-CT imaging information of xenon hydrate pore-scale distribution in sand sediments. Lattice Boltzmann method (LBM) was used to obtain permeability values of xenon hydrate-bearing sediments via micro-CT data. The results showed that gas relative permeability (Kr) versus gas hydrate saturation (Sh) data are consistent with the new model and the imitative effect is relatively better than that of the simple Corey model. Besides, we calculated gas relative permeability versus gas hydrate saturation curves for various pore habits via idealized models. Experimental measurements and simulation results showed that the grain-coating gas hydrate exhibits the highest gas relative permeability, while pore-filling gas hydrate exhibits the lowest values of gas relative permeability, and the cementing gas hydrate ranges in between. We validated the new gas relative permeability calculation model by applying it to the well logging data of gas hydrate reservoirs. Our results showed that the novel model is beneficial for permeability characterization of gas hydrate reservoirs and gas relative permeability calculations.
KW - Gas hydrate saturation
KW - Gas hydrate-bearing sediments
KW - Gas relative permeability
KW - Nuclear magnetic resonance well logging
KW - Pore habits
UR - http://www.scopus.com/inward/record.url?scp=85111538026&partnerID=8YFLogxK
U2 - 10.1016/j.jngse.2021.104171
DO - 10.1016/j.jngse.2021.104171
M3 - Article
AN - SCOPUS:85111538026
SN - 1875-5100
VL - 95
JO - Journal of Natural Gas Science and Engineering
JF - Journal of Natural Gas Science and Engineering
M1 - 104171
ER -