Nanoconfinement Effect on <i>n</i>-Alkane Flow

Wu, Keliu; Chen, Zhangxin; Li, Jing; Lei, Zhengdong; Wang, Kun; Li, Ran; Dong, Xiaohu; Peng, Yan; Yang, Sheng; Zhang, Feng; Chen, Zhongliang; Gao, Yanling

doi:10.1021/acs.jpcc.9b03903

Cited by 50 publications

(33 citation statements)

References 67 publications

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“…The diffusion of hydrocarbons within kerogen pores is essential for shale gas transport. − Collell et al studied the light hydrocarbon diffusion behavior in type II kerogen, and the results indicated that as the molecular weight increases, the diffusion coefficient decreases. The light hydrocarbon diffusion coefficient in kerogen is one order of magnitude lower than that in bulk.…”

Section: Introductionmentioning

confidence: 99%

Effect of Kerogen Maturity, Water Content for Carbon Dioxide, Methane, and Their Mixture Adsorption and Diffusion in Kerogen: A Computational Investigation

et al. 2020

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The adsorption behavior of CO 2 , CH 4 , and CO 2 /CH 4 mixtures in four different mature kerogens in the absence/ presence of water was studied using grand canonical Monte Carlo and classical molecular dynamics methods. The results exhibit that the adsorption isotherms of single-component CO 2 or CH 4 in kerogen present similar trends and show type I Langmuir adsorption behavior according to the IUPAC classification; the total adsorbed amount of both gases follows the order of type II-A < type II-B < type II-C < type II-D kerogen under the same conditions. The changing behavior of isosteric heat decreases first and then increases, which can explain the heterogeneous characteristic of the kerogen pore surface. The Coulombic and van der Waals interactions between CO 2 and kerogens play an important role on adsorption, while for CH 4 adsorption, the electrostatic effect is very small, even negligible. The N-, S-, and O-containing groups in kerogen have more remarkable influence on adsorption of CO 2 than CH 4 because of their strong adsorption energy, therefore notably improving the selectivity of CO 2 over CH 4 and following the order of type II-A > type II-B > type II-C > type II-D, which is beneficial to carbon capture and storage. Both pressure and temperature have an obvious impact on gas molecule diffusion, and low pressure and high temperature correspond to a large diffusion coefficient. In addition, preabsorbed water has a negative effect on the adsorption of CO 2 /CH 4 , and for the same amount of water molecules, the effect follows the order of type II-A > type II-B > type II-C > type II-D kerogens. The binding energy of water−kerogen is stronger than that of pure CH 4 or CO 2 −kerogen. The selectivity of CO 2 over CH 4 on kerogen increases with an increasing water content.

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Section: Introductionmentioning

confidence: 99%

Effect of Kerogen Maturity, Water Content for Carbon Dioxide, Methane, and Their Mixture Adsorption and Diffusion in Kerogen: A Computational Investigation

et al. 2020

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“…With the inorganic (quartz) surface energy equal to 61.24 mJ/m, 2,73,74 l o = 0.19 nm and μ oeff = 8.53μ bo for C 8 H 18 are used in this study. 34 Due to the entrance effect, an additional pressure drop Δp ent caused by an extra hydrodynamic resistance is introduced for the flow in a cylindrical pore 40,75…”

Section: Introductionmentioning

confidence: 99%

“…For the oil phase, Wu et al studied the nanoconfinement effect on n -alkane flow behaviors and the results showed that the interfacial oil viscosity governed the velocity. They also found the dependence of the interfacial n -alkane viscosity on the nanopore wall energy and the length of n -alkane . With the oil/water system in the inorganic nanopores, the viscosity of the interfacial water/oil phase can be several times smaller or greater than that of the bulk water/oil phase; therefore, the complex and diverse interfacial fluid viscosity would affect the imbibition behaviors strongly and should be considered.…”

Section: Introductionmentioning

confidence: 99%

Investigations on Water Imbibing into Oil-Saturated Nanoporous Media: Coupling Molecular Interactions, the Dynamic Contact Angle, and the Entrance Effect

Wang

2021

Ind. Eng. Chem. Res.

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Spontaneous imbibition of hydraulic fracturing fluids into the water-wet inorganic media is a ubiquitous phenomenon, which has an important influence on tight/shale oil recovery and groundwater contamination. However, in nanoscale space, the fluid–solid (water–wall and oil-wall) molecular interactions, which can result in the nanoscale effects of the slip boundary and the varying interfacial fluid viscosity, will make the fluid flow behaviors be more complex and difficult to characterize. In this work, a new generalized imbibition model in inorganic nanopores and porous media is established by the theoretical analysis and a nanoscale Shan–Chen lattice Boltzmann method (LBM). The effects of pore dimensions and shapes in porous media, the nanoscale effects, the dynamic contact angle, and the entrance effect are considered and discussed. The results show that the proposed model can accurately characterize the oil/water imbibition mechanisms and be adapted to different nanoscale effects. Based on discussions, this study can provide microscopic basics of water imbibing into nanopores and provide guiding information and theoretical model for the oil recovery from tight/shale reservoirs by hydraulic fracturing, the groundwater remediation by restricting imbibition rate, and other relevant applications.

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“…However, validation of this extension is in need because the structure of oil components, like n-alkanes, is very different from water. Recently, based on the different mobility between the first-layer molecules and those in the bulk, Wu et al (2019) derived the slip length when n-alkanes flow in nanotubes. However, parameters in their equations, like natural relaxation time, are difficult to determine.…”

Section: Introductionmentioning

confidence: 99%

Stochastic-based liquid apparent permeability model of shale oil reservoir considering geological control

Wang

Ma³

et al. 2021

J Petrol Explor Prod Technol

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Shale is a complex porous medium composed of organic matter (OM) and inorganic minerals (iOM). Because of its widespread nanopores, using Darcy’s law is challenging. In this work, a two-fluid system model is established to calculate the oil flow rate in a single nanopore. Then, a spatial distribution model of shale components is constructed with a modified quartet structure generation set algorithm. The stochastic apparent permeability (AP) model of shale oil is finally established by combining the two models. The proposed model can consider the effects of various geological controls: the content and grain size distribution of shale components, pore size distribution, pore types and nanoconfined effects (slip length and spatially varying viscosity). The results show that slip length in OM nanopores is far greater than that in iOM. However, when the total organic content is less than 0.3 ~ 0.4, the effect of the OM slip on AP increases first and then decreases with the decrease in mean pore size, resulting in that the flow enhancement in shale is much smaller than that in a single nanopore. The porosity distribution and grain size distribution are also key factors affecting AP. If we ignore the difference of porosity between shale components, the error of permeability estimation is more than 200%. Similarly, the relative error can reach 20% if the effect of grain size distribution is ignored. Our model can help understand oil transport in shale strata and provide parameter characterization for numerical simulation.

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Nanoconfinement Effect on n-Alkane Flow

Cited by 50 publications

References 67 publications

Effect of Kerogen Maturity, Water Content for Carbon Dioxide, Methane, and Their Mixture Adsorption and Diffusion in Kerogen: A Computational Investigation

Effect of Kerogen Maturity, Water Content for Carbon Dioxide, Methane, and Their Mixture Adsorption and Diffusion in Kerogen: A Computational Investigation

Investigations on Water Imbibing into Oil-Saturated Nanoporous Media: Coupling Molecular Interactions, the Dynamic Contact Angle, and the Entrance Effect

Stochastic-based liquid apparent permeability model of shale oil reservoir considering geological control

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