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Energies
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Pore-Scale Multiphase Fluid Flow and Transport in Porous Media
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Pore-Scale Multiphase Fluid Flow and Transport in Porous Media

A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "H1: Petroleum Engineering".

Deadline for manuscript submissions: closed (20 July 2022) | Viewed by 17695

Special Issue Editor

Prof. Dr. Patrice Creux

E-Mail Website
Guest Editor
CNRS/TOTAL/UNIV PAU & PAYS ADOUR, Laboratoire des Fluides Complexes et leurs Réservoirs IPRA, UMR5150, 64000 Pau, France
Interests: multiphase flow; experimental imaging techniques; image processing and image-based analysis; capillarity; experimental; transport characterization and modeling

Special Issue Information

Dear Colleagues,

We invite submissions to a Special Issue of the journal Energies on the topic of “Pore‐Scale Multiphase Fluid Flow and Transport in Porous Media”.

Despite the substantial progress in the development of tools for probing and analyzing porous media, the potential of pore-scale tools has not been fully realized in the energy sector. This is especially the case in processes involving multiphase flow in porous media, which presents a particularly challenging complexity as it involves a wide range of physical mechanisms and complex interactions with the solid microstructure.

These flows have attracted the attention of an impressive group of researchers and have spawned a number of theoretical and applied solutions in fluid dynamics. However, important challenges remain in both experimentally characterizing (MRI or X-ray imaging, etc.) and computationally predicting static and dynamic properties of porous materials (lattice Boltzmann method, direct numerical simulation, pore network modeling) to mimic real mechanisms.

Translating this information, however, across multiple spatial and temporal scales connected to the object of interest is a great challenge in the field. 

This Special Issue would like to encourage both experimental and computational contributions as well as theoretical analysis, image processing, and new advanced technologies with a scientific potential, regarding the multidisciplinary scientific challenges in multiphase flow in porous media at the pore scale.

Prof. Dr. Patrice Creux
Guest Editor

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 100 words) can be sent to the Editorial Office for announcement on this website.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Energies is an international peer-reviewed open access semimonthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2600 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

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Published Papers (7 papers)

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Research

14 pages, 2079 KiB  
Article
Influence of Standard Image Processing of 3D X-ray Microscopy on Morphology, Topology and Effective Properties
by Romain Guibert, Marfa Nazarova, Marco Voltolini, Thibaud Beretta, Gerald Debenest and Patrice Creux
Energies 2022, 15(20), 7796; https://doi.org/10.3390/en15207796 - 21 Oct 2022
Cited by 4 | Viewed by 1818
Abstract
Estimating porous media properties is a vital component of geosciences and the physics of porous media. Until now, imaging techniques have focused on methodologies to match image-derived flows or geomechanical parameters with experimentally identified values. Less emphasis has been placed on the compromise [...] Read more.
Estimating porous media properties is a vital component of geosciences and the physics of porous media. Until now, imaging techniques have focused on methodologies to match image-derived flows or geomechanical parameters with experimentally identified values. Less emphasis has been placed on the compromise between image processing techniques and the consequences on topological and morphological characteristics and on computed properties such as permeability. The effects of some of the most popular image processing techniques (filtering and segmentation) available in open source on 3D X-ray Microscopy (micro-XRM) images are qualitatively and quantitatively discussed. We observe the impacts of various filters such as erosion-dilation and compare the efficiency of Otsu’s method of thresholding and the machine-learning-based software Ilastik for segmentation. Full article
(This article belongs to the Special Issue Pore-Scale Multiphase Fluid Flow and Transport in Porous Media)
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10 pages, 2572 KiB  
Article
Sensitivity Analysis of Fluid–Fluid Interfacial Area, Phase Saturation and Phase Connectivity on Relative Permeability Estimation Using Machine Learning Algorithms
by Sanchay Mukherjee and Russell T. Johns
Energies 2022, 15(16), 5893; https://doi.org/10.3390/en15165893 - 14 Aug 2022
Cited by 1 | Viewed by 1706
Abstract
Recent studies have shown that relative permeability can be modeled as a state function which is independent of flow direction and dependent upon phase saturation (S), phase connectivity (X), and fluid–fluid interfacial area (A). This study evaluates [...] Read more.
Recent studies have shown that relative permeability can be modeled as a state function which is independent of flow direction and dependent upon phase saturation (S), phase connectivity (X), and fluid–fluid interfacial area (A). This study evaluates the impact of each of the three state parameters (S, X, and A) in the estimation of relative permeability. The relative importance of the three state parameters in four separate quadrants of S-X-A space was evaluated using a machine learning algorithm (out-of-bag predictor importance method). The results show that relative permeability is sensitive to all the three parameters, S, X, and A, with varying magnitudes in each of the four quadrants at a constant value of wettability. We observe that the wetting-phase relative permeability is most sensitive to saturation, while the non-wetting phase is most sensitive to phase connectivity. Although the least important, fluid–fluid interfacial area is still important to make the relative permeability a more exact state function. Full article
(This article belongs to the Special Issue Pore-Scale Multiphase Fluid Flow and Transport in Porous Media)
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17 pages, 14503 KiB  
Article
Fractal Characterization of Multimodal, Multiscale Images of Shale Rock Fracture Networks
by Bolivia Vega and Anthony R. Kovscek
Energies 2022, 15(3), 1012; https://doi.org/10.3390/en15031012 - 29 Jan 2022
Cited by 9 | Viewed by 2088
Abstract
An array of multimodal and multiscale images of fractured shale rock samples and analogs was collected with the aim of improving the numerical representation of fracture networks. 2D and 3D reconstructions of fractures and matrices span from 10−6 to 100 m. [...] Read more.
An array of multimodal and multiscale images of fractured shale rock samples and analogs was collected with the aim of improving the numerical representation of fracture networks. 2D and 3D reconstructions of fractures and matrices span from 10−6 to 100 m. The origin of the fracture networks ranged from natural to thermal maturation to hydraulically induced maturation. Images were segmented to improve fracture identification. Then, the fractal dimension and length distribution of the fracture networks were calculated for each image dataset. The resulting network connectivity and scaling associations are discussed at length on the basis of scale, sample and order of magnitude. Fracture network origin plays an important role in the resulting fracture systems and their scaling. Rock analogs are also evaluated using these descriptive tools and are found to be faithful depictions of maturation-induced fracture networks. Full article
(This article belongs to the Special Issue Pore-Scale Multiphase Fluid Flow and Transport in Porous Media)
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20 pages, 7585 KiB  
Article
Pore-Scale Characterization and PNM Simulations of Multiphase Flow in Carbonate Rocks
by Haiyang Zhang, Hamid Abderrahmane, Mohammed Al Kobaisi and Mohamed Sassi
Energies 2021, 14(21), 6897; https://doi.org/10.3390/en14216897 - 21 Oct 2021
Cited by 14 | Viewed by 2303
Abstract
This paper deals with pore-scale two-phase flow simulations in carbonate rock using the pore network method (PNM). This method was used to determine the rock and flow properties of three different rock samples, such as porosity, capillary pressure, absolute permeabilities, and oil–water relative [...] Read more.
This paper deals with pore-scale two-phase flow simulations in carbonate rock using the pore network method (PNM). This method was used to determine the rock and flow properties of three different rock samples, such as porosity, capillary pressure, absolute permeabilities, and oil–water relative permeabilities. The pore network method was further used to determine the properties of rock matrices, such as pore size distribution, topological structure, aspect ratio, pore throat shape factor, connected porosity, total porosity, and absolute permeability. The predicted simulation for the network-connected porosity, total porosity, and absolute permeability agree well with those measured experimentally when the image resolution is appropriate to resolve the relevant pore and throat sizes. This paper also explores the effect of the wettability and fraction of oil-wet pores on relative permeabilities, both in uniform and mixed wet systems. Full article
(This article belongs to the Special Issue Pore-Scale Multiphase Fluid Flow and Transport in Porous Media)
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11 pages, 3698 KiB  
Article
Inertia Effects in the Dynamics of Viscous Fingering of Miscible Fluids in Porous Media: Circular Hele-Shaw Cell Configuration
by Hamid Ait Abderrahmane, Shahid Rabbani and Mohamed Sassi
Energies 2021, 14(19), 6432; https://doi.org/10.3390/en14196432 - 8 Oct 2021
Viewed by 2165
Abstract
We present a numerical study of viscous fingering occurring during the displacement of a high viscosity fluid by low viscosity fluid in a circular Hele-Shaw cell. This study assumes that the fluids are miscible and considers the effects of inertial forces on fingering [...] Read more.
We present a numerical study of viscous fingering occurring during the displacement of a high viscosity fluid by low viscosity fluid in a circular Hele-Shaw cell. This study assumes that the fluids are miscible and considers the effects of inertial forces on fingering morphology, mixing, and displacement efficiency. This study shows that inertia has stabilizing effects on the fingering instability and improves the displacement efficiency at a high log-mobility-viscosity ratio between displacing and displaced fluids. Under certain conditions, inertia slightly reduces the finger-split phenomenon and the mixing between the two fluids. Full article
(This article belongs to the Special Issue Pore-Scale Multiphase Fluid Flow and Transport in Porous Media)
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20 pages, 7256 KiB  
Article
Characterization of Pore Structures and Implications for Flow Transport Property of Tight Reservoirs: A Case Study of the Lucaogou Formation, Jimsar Sag, Junggar Basin, Northwestern China
by Yang Su, Ming Zha, Keyu Liu, Xiujian Ding, Jiangxiu Qu and Jiehua Jin
Energies 2021, 14(5), 1251; https://doi.org/10.3390/en14051251 - 25 Feb 2021
Cited by 5 | Viewed by 1976
Abstract
Quantitate characterization of pore structures is fundamental to elucidate fluid flow in the porous media. Pore structures of the Lucaogou Formation in the Jimsar Sag were investigated using petrography, mercury intrusion capillary porosimetry (MICP) and X-ray computed tomography (X-ray μ-CT). MICP analyses demonstrate [...] Read more.
Quantitate characterization of pore structures is fundamental to elucidate fluid flow in the porous media. Pore structures of the Lucaogou Formation in the Jimsar Sag were investigated using petrography, mercury intrusion capillary porosimetry (MICP) and X-ray computed tomography (X-ray μ-CT). MICP analyses demonstrate that the pore topological structure is characterized by segmented fractal dimensions. Fractal dimension of small pores (r < Rapex) ranges from 2.05 to 2.37, whereas fractal dimension of large pores (r > Rapex) varies from 2.91 to 5.44, indicating that fractal theory is inappropriate for the topological characterization of large pores using MICP. Pore volume of tight reservoirs ranges over nine orders of magnitude (10−1–108 μm3), which follows a power-law distribution. Fractal dimensions of pores larger than a lower bound vary from 1.66 to 2.32. Their consistence with MICP results suggests that it is an appropriate indicator for the complex and heterogeneous pore network. Larger connected pores are primary conductive pathways regardless of lithologies. The storage capacity depends largely on pore complexity and heterogeneity, which is negatively correlated with fractal dimension of pore network. The less heterogeneous the pore network is, the higher storage capability it would have; however, the effect of pore network heterogeneity on the transport capability is much more complicated. Full article
(This article belongs to the Special Issue Pore-Scale Multiphase Fluid Flow and Transport in Porous Media)
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18 pages, 6416 KiB  
Article
Geometrical and Topological Analysis of Pore Space in Sandstones Based on X-ray Computed Tomography
by Linxian Gong, Lei Nie and Yan Xu
Energies 2020, 13(15), 3774; https://doi.org/10.3390/en13153774 - 23 Jul 2020
Cited by 27 | Viewed by 3933
Abstract
The pore geometry and topology properties of pore space in rocks are significant for a better understanding of the complex hydrologic and elastic properties. However, geometry and topology information about the sandstone pore structures is not fully available. In this study, we obtained [...] Read more.
The pore geometry and topology properties of pore space in rocks are significant for a better understanding of the complex hydrologic and elastic properties. However, geometry and topology information about the sandstone pore structures is not fully available. In this study, we obtained the topological and geometrical pore parameters from a representative elementary volume (REV) for fluid flow in sandstone samples. For comparison, eight types of sandstones with various porosities were studied based on the X-ray micro-computed tomography technique. In this study, the REV size was selected based on the parameters from the respective pore network models (PNM), not just the porosity. Our analysis indicates that despite different porosity, all the sandstone samples have highly triangular-shaped pores and a high degree of pore structural isotropy. The high porosity group sandstones exhibit wider ranges of pore sizes than the low porosity group sandstones. Compared to the high porosity group sandstones, the low porosity group sandstones samples showing a higher global aspect ratio, indicating some pores exist in the form of bottlenecks. The pore topological properties of different sandstones show a high dependence of the porosity. The high porosity group sandstones obtain large coordination numbers, large connectivity densities and low tortuosities. The results from this study will help better understand the complex pore structure and the fluid flow in sandstone. Full article
(This article belongs to the Special Issue Pore-Scale Multiphase Fluid Flow and Transport in Porous Media)
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