Fluid phase equilibria of triangle-well fluids confined inside slit pores: A transition matrix Monte Carlo simulation study

Sengupta, Angan; Adhikari, Jhumpa

doi:10.1016/j.molliq.2016.06.100

Cited by 7 publications

(3 citation statements)

References 42 publications

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“…The commonly used methods for characterizing the complex pore-throat structure of porous media are digital cores [5][6][7][8][9][10] and pore network models [11][12][13][14][15][16][17]. Direct flow simulation methods based on digital cores (such as the lattice Boltzmann method [18][19][20][21], computational fluid dynamics method [22,23], and Monte Carlo simulation [24,25]) take a long time to calculate, require a large amount of memory, and are powerless for large-scale flow simulation and parameter sensitivity analysis.…”

Section: Introductionmentioning

confidence: 99%

Characterization of Flow Parameters in Shale Nano-Porous Media Using Pore Network Model: A Field Example from Shale Oil Reservoir in Songliao Basin, China

et al. 2023

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The pore-throat radius of the shale oil reservoir is extremely small, and it is difficult to accurately obtain the absolute permeability and oil–water two-phase relative permeability of the actual oil reservoir through conventional core experiments. However, these parameters are very important for reservoir numerical simulation. In this paper, a method for characterizing flow parameters based on a pore network model that considers differential pressure flow and diffusion flow is proposed. Firstly, a digital core was reconstructed using focused ion beam scanning electron microscopy (FIB-SEM) from the Gulong shale reservoir in the Songliao Basin, China, and a pore network model was extracted. Secondly, quasi-static single-phase flow and two-phase flow equations considering diffusion were established in the pore network model. Finally, pore-throat parameters, absolute permeability, and oil–water two-phase permeability curves were calculated, respectively. The results show that the pore-throat distribution of the Gulong shale reservoir is mainly concentrated in the nanometer scale; the mean pore radius is 87 nm, the mean throat radius is 41 nm, and the mean coordination number is 3.97. The calculated permeability considering diffusion is 0.000124 mD, which is approximately twice the permeability calculated without considering diffusion. The irreducible water saturation of the Gulong shale reservoir is approximately 0.4, and the residual oil saturation is approximately 0.35. The method proposed in this paper can provide an important approach for characterizing the flow parameters of similar shale oil reservoirs.

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Section: Introductionmentioning

confidence: 99%

Characterization of Flow Parameters in Shale Nano-Porous Media Using Pore Network Model: A Field Example from Shale Oil Reservoir in Songliao Basin, China

et al. 2023

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show abstract

“…The commonly used methods for characterizing the complex pore-throst structure of porous media are digital cores [5][6][7][8][9][10] and pore network models [11][12][13][14][15][16][17]. Direct flow simulation methods based on digital cores (such as lattice Boltzmann method [18][19][20][21], computational fluid dynamics method [22,23] and Monte Carlo simulation [24,25]) take a long time to calculate, require a large amount of memory, and are powerless for largescale flow simulation and parameter sensitivity analysis. Considering the extremely small pore-Disclaimer/Publisher's Note: The statements, opinions, and data contained in all publications are solely those of the individual author(s) and contributor(s) and not of MDPI and/or the editor(s).…”

Section: Introductionmentioning

confidence: 99%

Characterization of Flow Parameters in Shale Nano-Porous Media Using Pore Network Model: A Field Example from Shale Oil Reservoir in Songliao Basin, China

Wang¹,

Jia²,

Cheng³

et al. 2023

Preprint

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The pore-throat radius of shale oil reservoir is extremely small, and it is difficult to accurately obtain the absolute permeability and oil-water two-phase relative permeability of actual oil reservoir through conventional core experiments. However, these parameters are very important for reservoir numerical simulation. In this paper, a method for characterizing flow parameters based on pore network model that considers differential pressure flow and diffusion flow is proposed. Firstly, a digital core was reconstructed using focused ion beam scanning electron microscopy (FIB-SEM) from the Gulong shale reservoir in the Songliao Basin, China, and a pore network model was extracted. Secondly, quasi-static single-phase flow and two-phase flow equations considering diffusion were established in the pore network model. Finally, pore throat parameters, absolute permeability, and oil-water two-phase permeability curves were calculated, respectively. The results show that the pore throat distribution of Gulong shale reservoir is mainly concentrated in the nanometer scale, the mean pore radius is 87 nm, the mean throat radius is 41 nm, and the mean coordination number is 3.97; The calculated permeability considering diffusion is 0.000124mD, which is approximately twice the permeability calculated without considering diffusion; The irreducible water saturation of the Gulong shale reservoir is approximately 0.26, and the residual oil saturation is approximately 0.73. The method proposed in this paper can provide an important approach for characterizing the flow parameters of similar shale oil reservoirs.

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“…Because of the occurrence of critical shift in confined media, applying the bulk properties of matters undoubtedly leads to poor results when calculating vapor-liquid equilibrium (VLE) properties of their confined state. Various analytical and numerical methods have been examined to predict and model the above theory for pure normal fluids, e.g., developed microscopic van der Waals (vdW) equation of state (EOS) in a similar previous study 6 , molecular dynamics simulation (MD) 7 , density functional theory 8 , lattice Boltzmann method (LBM) 9 , scaled particle theory (SPT or RFL) 10 , and different classes of Monte Carlo simulations [11][12][13][14][15][16][17][18][19] .…”

mentioning

confidence: 99%

Critical temperature shift modeling of confined fluids using pore-size-dependent energy parameter of potential function

Humand

Movaghar

2023

Sci Rep

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The behavior and critical properties of fluids confined in nanoscale porous media differ from those of bulk fluids. This is well known as critical shift phenomenon or pore proximity effect among researchers. Fundamentals of critical shift modeling commenced with developing equations of state (EOS) based on the Lennard–Jones (L–J) potential function. Although these methods have provided somewhat passable predictions of pore critical properties, none represented a breakthrough in basic modeling. In this study, a cubic EOS is derived in the presence of adsorption for Kihara fluids, whose attractive term is a function of temperature. Accordingly, the critical temperature shift is modeled, and a new adjustment method is established in which, despite previous works, the bulk critical conditions of fluids are reliably met with a thermodynamic basis and not based on simplistic manipulations. Then, based on the fact that the macroscopic and microscopic theories of corresponding states are related, an innovative idea is developed in which the energy parameter of the potential function varies with regard to changes in pore size, and is not taken as a constant. Based on 94 available data points of critical shift reports, it is observed that despite L–J, the Kihara potential has sufficient flexibility to properly fit the variable energy parameters, and provide valid predictions of phase behavior and critical properties of fluids. Finally, the application of the proposed model is examined by predicting the vapor–liquid equilibrium properties of a ternary system that reduced the error of the L–J model by more than 6%.

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Fluid phase equilibria of triangle-well fluids confined inside slit pores: A transition matrix Monte Carlo simulation study

Cited by 7 publications

References 42 publications

Characterization of Flow Parameters in Shale Nano-Porous Media Using Pore Network Model: A Field Example from Shale Oil Reservoir in Songliao Basin, China

Characterization of Flow Parameters in Shale Nano-Porous Media Using Pore Network Model: A Field Example from Shale Oil Reservoir in Songliao Basin, China

Characterization of Flow Parameters in Shale Nano-Porous Media Using Pore Network Model: A Field Example from Shale Oil Reservoir in Songliao Basin, China

Critical temperature shift modeling of confined fluids using pore-size-dependent energy parameter of potential function

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