Study of the confined behavior of hydrocarbons in organic nanopores by the potential theory

Dong, Xiaohu; Liu, Huiqing; Guo, Wei; Hou, Jirui; Chen, Zhangxin; Wu, Keliu

doi:10.1016/j.fluid.2016.09.008

Cited by 23 publications

(8 citation statements)

References 50 publications

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“…When the limited adsorption volume and BET specific surface area values were combined, the average thickness of adsorbed layer was calculated to be around 0.47 nm, which is comparable to the collision diameter of methane (0.38 nm). These results suggest that no evidence of multilayer adsorption was found in supercritical methane sorption on gas shales and agree with the unimodal density profile of methane in organic nanopores. , …”

Section: Resultssupporting

confidence: 76%

Supercritical Methane Sorption on Organic-Rich Shales over a Wide Temperature Range

Yang

Xie

et al. 2017

Energy Fuels

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Methane sorption on organic-rich shales over wide temperature and pressure ranges (30–120 °C, up to 25 MPa) is analyzed by the pore filling/potential theory. The supercritical Dubinin–Astakhov (SDA) sorption model using a density term instead of the pseudosaturation vapor term is extended to methane sorption isotherms of shales with high accuracy. A modified adsorption potential approach is suggested to analyze the temperature dependence of supercritical methane sorption on shales. The temperature-invariant characteristic curves are obtained using the modified adsorption potential approach. A characteristic curve equation derived from the SDA model is provided to predict sorption isotherms at other temperatures using one isotherm. The physical meaning of the characteristic curve has been discussed, and it comprehensively reflects the available pore space for methane sorption and the affinity between methane molecules and organic matter. According to methane characteristic curves of shales and clay minerals, shales in the gas window show higher affinity than shales in the oil window and clay minerals, though the clay minerals may provide comparable adsorbed volume. The adsorption characteristic energy shows a parabola-like shape with a minimum of approximately R eq = 1.1%, which is related to the evolution of the porosity of the shales. This study advanced the fundamental understanding of the dynamic process of methane sorption on shales.

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Section: Resultssupporting

confidence: 76%

Supercritical Methane Sorption on Organic-Rich Shales over a Wide Temperature Range

Yang

Xie

et al. 2017

Energy Fuels

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“…According to the previous discussion, CO 2 can usually extract the light components from crude oil . The closest film-like oil to a pore wall is a heavy component, and the other side is a light component. , It is also the result of a contact between CO 2 and light components in crude oil. Therefore, it is shown that CO 2 can extract light components more effectively and thus further unlock an oil film in a porous medium.…”

Section: Results and Discussionmentioning

confidence: 99%

Pore-Scale Movability Evaluation for Tight Oil Enhanced Oil Recovery Methods Based on Miniature Core Test and Digital Core Construction

Dong

Chen

Hou

et al. 2020

Ind. Eng. Chem. Res.

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The movability of micro-remaining oil in microscale pores in tight reservoirs directly affects the recoverability of a reservoir fluid. Currently, core displacement and digital cores have been applied for the reservoir fluid movability and microstructure visualization. In this study, we present a practical framework for the pore-scale movability of tight oil, which combines core displacement tests and digital cores on real tight core samples. In this framework, the core displacement tests and miniature core displacement tests using three different displacement methods (water flooding, CH 4 flooding, and CO 2 flooding) are first performed. Then, through a series of CT (computed tomography) scanning results on the core displacement tests, a digital core model is constructed, and a distribution of micro-remaining oil is experimentally investigated. By combining the results of the miniature core displacement tests and the digital core model, the types and movability of tight oil at different times for the three methods are obtained. These results indicate that the remaining tight oil at pore scale can be classified into three different categories according to a shape factor (S) of the remaining oil, including block-like oil (4.85 > S > 1), flat-like oil (12.22 > S > 4.85) and film-like oil (S > 12.22). From CT scanning results, the method of water flooding can effectively unlock the type of block-like oil, while CH 4 flooding and CO 2 flooding can produce flat-like and film-like oil. Furthermore, CO 2 flooding can significantly unlock more film-like oil than CH 4 flooding.

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“…To accurately model the fluids in nanopores, the EOS needs to be developed with the effects of confinement in mind. Recently, there have been a number of attempts to model fluids under confinement using an EOS [63][64][65][66][67][68][69][70][71][72][73][74][75][76][77][78][79][80]. However, none of those works have been developed for the elastic properties.…”

Section: Local Elastic Propertiesmentioning

confidence: 99%

Elastic properties of confined fluids from molecular modeling to ultrasonic experiments on porous solids

Dobrzanski

Gurevich

Gor

2021

Applied Physics Reviews

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Fluids confined in nanopores are ubiquitous in nature and technology. In recent years, the interest in confined fluids has grown, driven by research on unconventional hydrocarbon resources -shale gas and shale oil, much of which are confined in nanopores. When fluids are confined in nanopores, many of their properties differ from those of the same fluid in the bulk. These properties include density, freezing point, transport coefficients, thermal expansion coefficient, and elastic properties. The elastic moduli of a fluid confined in the pores contribute to the overall elasticity of the fluid-saturated porous medium and determine the speed at which elastic waves traverse through the medium. Wave propagation in fluid-saturated porous media is pivotal for geophysics, as elastic waves are used for characterization of formations and rock samples. In this paper, we present a comprehensive review of experimental works on wave propagation in fluid-saturated nanoporous media, as well as theoretical works focused on calculation of compressibility of fluids in confinement. We discuss models that bridge the gap between experiments and theory, revealing a number of open questions that are both fundamental and applied in nature. While some results were demonstrated both experimentally and theoretically (e.g. the pressure dependence of compressibility of fluids), others were theoretically predicted, but not verified in experiments (e.g. linear scaling of modulus with the pore size). Therefore, there is a demand for the combined experimental-modeling studies on porous samples with various characteristic pore sizes. The extension of molecular simulation studies from simple model fluids to the more complex molecular fluids is another open area of practical interest.

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Study of the confined behavior of hydrocarbons in organic nanopores by the potential theory

Cited by 23 publications

References 50 publications

Supercritical Methane Sorption on Organic-Rich Shales over a Wide Temperature Range

Supercritical Methane Sorption on Organic-Rich Shales over a Wide Temperature Range

Pore-Scale Movability Evaluation for Tight Oil Enhanced Oil Recovery Methods Based on Miniature Core Test and Digital Core Construction

Elastic properties of confined fluids from molecular modeling to ultrasonic experiments on porous solids

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