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Effect of Pore Size Heterogeneity on Hydrocarbon Fluid Distribution, Transport, and Primary and Secondary Recovery in Nano-Porous Media

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dc.contributor Mining and Minerals Engineering
dc.creator Zhang, Kaiyi
dc.creator Du, Fengshuang
dc.creator Nojabaei, Bahareh
dc.date 2020-04-15T14:04:05Z
dc.date 2020-04-15T14:04:05Z
dc.date 2020-04-03
dc.date 2020-04-15T13:18:21Z
dc.date.accessioned 2023-03-01T18:53:16Z
dc.date.available 2023-03-01T18:53:16Z
dc.identifier Zhang, K.; Du, F.; Nojabaei, B. Effect of Pore Size Heterogeneity on Hydrocarbon Fluid Distribution, Transport, and Primary and Secondary Recovery in Nano-Porous Media. Energies 2020, 13, 1680.
dc.identifier http://hdl.handle.net/10919/97623
dc.identifier https://doi.org/10.3390/en13071680
dc.identifier.uri http://localhost:8080/xmlui/handle/CUHPOERS/281706
dc.description In this paper, we investigate the effect of pore size heterogeneity on fluid composition distribution of multicomponent-multiphase hydrocarbons and its subsequent influence on mass transfer in shale nanopores. The change of multi-contact minimum miscibility pressure (MMP) in heterogeneous nanopores was investigated. We used a compositional simulation model with a modified flash calculation, which considers the effect of large gas–oil capillary pressure on phase behavior. Different average pore sizes for different segments of the computational domain were considered and the effect of the resulting heterogeneity on phase change, composition distributions, and production was investigated. A two-dimensional formulation was considered here for the application of matrix–fracture cross-mass transfer and the rock matrix can also consist of different segments with different average pore sizes. Both convection and molecular diffusion terms were included in the mass balance equations, and different reservoir fluids such as ternary mixture syntactic oil, Bakken oil, and Marcellus shale condensate were considered. The simulation results indicate that oil and gas phase compositions vary in different pore sizes, resulting in a concentration gradient between the two adjacent pores of different sizes. Given that shale permeability is extremely small, we expect the mass transfer between the two sections of the reservoir/core with two distinct average pore sizes to be diffusion-dominated. This observation implies that there can be a selective matrix–fracture component mass transfer as a result of confinement-dependent phase behavior. Therefore, the molecular diffusion term should be always included in the mass transfer equations, for both primary and gas injection enhanced oil recovery (EOR) simulation of heterogeneous shale reservoirs.
dc.description Published version
dc.format application/pdf
dc.format application/pdf
dc.language en
dc.publisher MDPI
dc.rights Creative Commons Attribution 4.0 International
dc.rights http://creativecommons.org/licenses/by/4.0/
dc.subject pore size heterogeneity
dc.subject multicomponent-multiphase hydrocarbons
dc.subject mass transfer
dc.subject shale
dc.subject minimum miscibility pressure (MMP)
dc.subject large oil-gas capillary pressure
dc.title Effect of Pore Size Heterogeneity on Hydrocarbon Fluid Distribution, Transport, and Primary and Secondary Recovery in Nano-Porous Media
dc.title Energies
dc.type Article - Refereed
dc.type Text
dc.type StillImage


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