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Journal articles on the topic "Multiphase flow in porous media environment":
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Reynolds, David A., and Bernard H. Kueper. "Multiphase flow and transport through fractured heterogeneous porous media." Journal of Contaminant Hydrology 71, no. 1-4 (July 2004): 89–110. http://dx.doi.org/10.1016/j.jconhyd.2003.09.008.
Kueper, Bernard H., Wesley Abbott, and Graham Farquhar. "Experimental observations of multiphase flow in heterogeneous porous media." Journal of Contaminant Hydrology 5, no. 1 (December 1989): 83–95. http://dx.doi.org/10.1016/0169-7722(89)90007-7.
Phase change energy storage materials are widely used in the field of renewable energy. Paraffin is one of the common phase change energy storage materials. As a multi-component hydrocarbon mixture, the melting of paraffin is different from that of pure substance. In addition to the solid and liquid zones, there is also a fuzzy zone in which solid and liquid coexist. In this paper, the melting characteristics of paraffin in phase transition zone are studied by multi-scale experiments. Through the visualization experiment of square cavity paraffin melting, the solid zone, fuzzy zone and liquid zone are determined, and the moving process of phase interface is tracked by digital pictures and infrared heat maps. The evolution process of the pore structure in the fuzzy zone under different temperatures is photographed by means of the micro experiment, and it is revealed that there are two areas in the fuzzy zone, porous media area and multiphase flow area. The results show that the melting process of paraffin can be divided into four zones: liquid zone, multiphase flow zone, porous media zone and solid phase zone. According to the polarizing optical microscopy (POM) picture, the continuous phase and discrete phase transition relationship between solid wax crystal and liquid paraffin is captured. The POM picture is statistically analyzed, and the critical liquid phase ratio of the transition from porous media area to multiphase flow area is given under experimental conditions.
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Papamichos, Euripides. "Erosion and multiphase flow in porous media. Application to sand production." European Journal of Environmental and Civil engineering 14, no. 8-9 (September 28, 2010): 1129–54. http://dx.doi.org/10.3166/ejece.14.1129-1154.
Abdin, A., J. J. Kalurachchi, M. W. Kemblowski, and C. M. Chang. "Stochastic analysis of multiphase flow in porous media: II. Nummerical simulations." Stochastic Hydrology and Hydraulics 11, no. 1 (February 1997): 94. http://dx.doi.org/10.1007/bf02428427.
Abin, A., J. J. Kalurachchi, M. W. Kemblowski, and C. M. Chang. "Stochastic analysis of multiphase flow in porous media: II. Numerical simulations." Stochastic Hydrology and Hydraulics 10, no. 3 (August 1996): 231–51. http://dx.doi.org/10.1007/bf01581465.
Yan, Guanxi, Zi Li, Thierry Bore, Sergio Andres Galindo Torres, Alexander Scheuermann, and Ling Li. "Discovery of Dynamic Two-Phase Flow in Porous Media Using Two-Dimensional Multiphase Lattice Boltzmann Simulation." Energies 14, no. 13 (July 5, 2021): 4044. http://dx.doi.org/10.3390/en14134044.
The dynamic two-phase flow in porous media was theoretically developed based on mass, momentum conservation, and fundamental constitutive relationships for simulating immiscible fluid-fluid retention behavior and seepage in the natural geomaterial. The simulation of transient two-phase flow seepage is, therefore, dependent on both the hydraulic boundaries applied and the immiscible fluid-fluid retention behavior experimentally measured. Many previous studies manifested the velocity-dependent capillary pressure–saturation relationship (Pc-S) and relative permeability (Kr-S). However, those works were experimentally conducted on a continuum scale. To discover the dynamic effects from the microscale, the Computational Fluid Dynamic (CFD) is usually adopted as a novel method. Compared to the conventional CFD methods solving Naiver–Stokes (NS) equations incorporated with the fluid phase separation schemes, the two-phase Lattice Boltzmann Method (LBM) can generate the immiscible fluid-fluid interface using the fluid-fluid/solid interactions at a microscale. Therefore, the Shan–Chen multiphase multicomponent LBM was conducted in this study to simulate the transient two-phase flow in porous media. The simulation outputs demonstrate a preferential flow path in porous media after the non-wetting phase fluid is injected until, finally, the void space is fully occupied by the non-wetting phase fluid. In addition, the inter-relationships for each pair of continuum state variables for a Representative Elementary Volume (REV) of porous media were analyzed for further exploring the dynamic nonequilibrium effects. On one hand, the simulating outcomes reconfirmed previous findings that the dynamic effects are dependent on both the transient seepage velocity and interfacial area dynamics. Nevertheless, in comparison to many previous experimental studies showing the various distances between the parallelly dynamic and static Pc-S relationships by applying various constant flux boundary conditions, this study is the first contribution showing the Pc-S striking into the nonequilibrium condition to yield dynamic nonequilibrium effects and finally returning to the equilibrium static Pc-S by applying various pressure boundary conditions. On the other hand, the flow regimes and relative permeability were discussed with this simulating results in regards to the appropriateness of neglecting inertial effects (both accelerating and convective) in multiphase hydrodynamics for a highly pervious porous media. Based on those research findings, the two-phase LBM can be demonstrated to be a powerful tool for investigating dynamic nonequilibrium effects for transient multiphase flow in porous media from the microscale to the REV scale. Finally, future investigations were proposed with discussions on the limitations of this numerical modeling method.
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Chang, C., M. W. Kemblowski, J. Kaluarachchi, and A. Abdin. "Stochastic analysis of multiphase flow in porous media: 1. Spectral/perturbation approach." Stochastic Hydrology and Hydraulics 9, no. 3 (September 1995): 239–67. http://dx.doi.org/10.1007/bf01581722.
Li, Guihe, and Jia Yao. "Snap-Off during Imbibition in Porous Media: Mechanisms, Influencing Factors, and Impacts." Eng 4, no. 4 (November 17, 2023): 2896–925. http://dx.doi.org/10.3390/eng4040163.
The phenomenon of snap-off during imbibition in porous media, a fundamental two-phase fluid flow phenomenon, plays a crucial role in both crude oil production and carbon dioxide (CO2) utilization and storage. In porous media where two phases coexist, the instability of the phase interface may give rise to various displacement phenomena, including pore–body filling, piston-like displacement, and snap-off. Snap-off, characterized by the generation of discrete liquid droplets or gas bubbles, assumes paramount significance. This study provides a comprehensive overview of snap-off mechanisms, influencing factors, and impacts. Snap-off initiation arises from variations in the curvature radius at the interface between two phases within narrow regions, primarily influenced by capillary pressure. It can be influenced by factors such as the characteristics of multiphase fluids, the wettability of porous media, as well as the pore–throat geometry and topology within porous media. In turn, snap-off exerts a discernible influence on the fluid dynamics within the porous medium, resulting in impacts that encompass unrecoverable oil droplet formation, the oil bridging effect, drainage–imbibition hysteresis, strong foam generation and transient/dynamic effects. Although the snap-off phenomenon exerts detrimental effects during the conventional waterflooding in oil production, its potential is harnessed for beneficial outcomes in CO2-EOR and CO2 storage. This study significantly advances our understanding of snap-off and its multifaceted roles in multiphase fluid dynamics, offering vital insights for the precise prediction of fluid flow behavior and strategic control. These valuable insights can serve as a theoretical foundation to guide our deliberate modulation of snap-off phenomena, aiming at optimizing oil-recovery processes and enhancing the safety and stability of CO2 storage.
Dissertations / Theses on the topic "Multiphase flow in porous media environment":
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Jacobs, Bruce Lee. "Effective properties of multiphase flow in heterogeneous porous media." Thesis, Massachusetts Institute of Technology, 1998. http://hdl.handle.net/1721.1/9697.
Thesis (Ph.D.)--Massachusetts Institute of Technology, Dept. of Civil and Environmental Engineering, February 1999. Includes bibliographical references (leaves 218-224). The impact of heterogeneity on multiphase fl.ow is explored using a spectral perturbation technique employing a stationary, stochastic representation of the spatial variability of soil properties. A derivation of the system's effective properties - nonwetting phase moisture content, capillary pressure, normalized saturation and permeability - was developed which is not specific as to the form of the permeability dependence on saturation or capillary pressure. This lack of specificity enables evaluation and comparison of effective properties with differing characterization forms. Conventional characterization techniques are employed to parameterize the saturation, capillary pressure, relative permeability relationships and applied to the Cape Cod and Borden aquifers. An approximate solution for the characteristic width of a dense nonaqueous phase liquid (DNAPL) plume or air sparging contributing area is derived to evaluate the sensitivity of system behavior to properties of input processes. Anisotropy is predicted for uniform, vertical flow in the Borden Aquifer consistent with both prior experimental observations and Monte Carlo simulations. Increases of the mean capillary pressure (increasing nonwetting phase saturation) is accompanied by reductions in nonwetting phase anisotropy. Similar levels of anisotropy are not found in the case of the Cape Cod aquifer; the difference is attributed largely to the mean value of the log of the characteristic pressure which is shown to control the rate of return to asymptotic permeability and hence system uniformity. A positive relation between anisotropy and interfacial tension was observed, consistent with prior numerical simulations. Positive dependence of lateral spreading on input fl.ow rate is predicted for Cape Cod Aquifer with reverse response at Borden Aquifer due to capillary pressure dependent anisotropy of Borden Aquifer. The effective permeability for horizontal fl.ow with core scale heterogeneity was found to be velocity dependent with features qualitatively similar to experimental observations and numerical experiments. Application of Leverett scaling as generally implemented in Monte Carlo simulations under represents aquifer hetero geneity and for the Borden Aquifer, van Genuchten characterization reduces system anisotropy by several orders of magnitude. Anisotropy of the effective properties proved to be less sensitive to Leverett scaling if the Brooks-Corey characterization was used due to insensitivity in this case to the variance of the slope parameter. by Bruce L. Jacobs. Ph.D.
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Fu, Xiaojing Ph D. Massachusetts Institute of Technology. "Multiphase flow in porous media with phase transitions : from CO₂ sequestration to gas hydrate systems." Thesis, Massachusetts Institute of Technology, 2017. http://hdl.handle.net/1721.1/111445.
Thesis: Ph. D., Massachusetts Institute of Technology, Department of Civil and Environmental Engineering, 2017. Cataloged from PDF version of thesis. Includes bibliographical references (pages 159-175). Ongoing efforts to mitigate climate change include the understanding of natural and engineered processes that can impact the global carbon budget and the fate of greenhouse gases (GHG). Among engineered systems, one promising tool to reduce atmospheric emissions of anthropogenic carbon dioxide (CO₂) is geologic sequestration of CO₂ , which entails the injection of CO₂ into deep geologic formations, like saline aquifers, for long-term storage. Among natural contributors, methane hydrates, an ice-like substance commonly found in seafloor sediments and permafrost, hold large amounts of the world's mobile carbon and are subject to an increased risk of dissociation due to rising temperatures. The dissociation of methane hydrates releases methane gas-a more potent GHG than CO₂-and potentially contributes to a positive feedback in terms of climatic change. In this Thesis, we explore fundamental mechanisms controlling the physics of geologic CO₂ sequestration and natural gas hydrate systems, with an emphasis on the interplay between multiphase flow-the simultaneous motion of several fluid phases and phase transitions-the creation or destruction of fluid or solid phases due to thermodynamically driven reactions. We first study the fate of CO₂ in saline aquifers in the presence of CO₂ -brine-carbonate geochemical reactions. We use high-resolution simulations to examine the interplay between the density-driven convective mixing and the rock dissolution reactions. We find that dissolution of carbonate rock initiates in regions of locally high mixing, but that the geochemical reaction shuts down significantly earlier than shutdown of convective mixing. This early shutdown reflects the important role that chemical speciation plays in this hydrodynamics-reaction coupled process. We then study hydrodynamic and thermodynamic processes pertaining to a gas hydrate system under changing temperature and pressure conditions. The framework for our analysis is that of phase-field modeling of binary mixtures far from equilibrium, and show that: (1) the interplay between phase separation and hydrodynamic instability can arrest the Ostwald ripening process characteristic of nonflowing mixtures; (2) partial miscibility exerts a powerful control on the degree of viscous fingering in a gas-liquid system, whereby fluid dissolution hinders fingering while fluid exsolution enhances fingering. We employ this theoretical phase-field modeling approach to explain observations of bubble expansion coupled with gas dissolution and hydrate formation in controlled laboratory experiments. Unraveling this coupling informs our understanding of the fate of hydrate-crusted methane bubbles in the ocean water column and the migration of gas pockets in hydrate-bearing sediments. by Xiaojing Fu. Ph. D.
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Zhao, Benzhong. "Multiphase flow in porous media: the impact of capillarity and wettability from field-scale to pore-scale." Thesis, Massachusetts Institute of Technology, 2017. http://hdl.handle.net/1721.1/109644.
Thesis: Ph. D., Massachusetts Institute of Technology, Department of Civil and Environmental Engineering, 2017. Cataloged from PDF version of thesis. Includes bibliographical references (pages 95-104). Multiphase flow in the context of this Thesis refers to the simultaneous flow of immiscible fluids. It differs significantly from single-phase flow due to the existence of fluid-fluid interfaces, which are subject to capillary forces. Multiphase flow in porous media is important in many natural and industrial processes, including geologic carbon dioxide (CO₂) sequestration, enhanced oil recovery, and water infiltration into soil. Despite its importance, much of our current description of multiphase flow in porous media is based on semi-empirical extensions of single-phase flow theories, which miss key physical mechanisms that are unique to multiphase systems. One challenging aspect of solving this problem is visualization-flow typically occurs inside opaque media and hence eludes direct observation. Another challenging aspect of multiphase flow in porous media is that it encompasses a wide spectrum of length scales-while capillary force is active at the pore-scale (on the order of microns), it can have a significant impact at the field-scale (on the order of kilometers). In this Thesis, we employ novel laboratory experiments and mathematical modeling to study multiphase flow in porous media across scales. The field-scale portion of this Thesis focuses on gravity-driven flows in the subsurface, with an emphasis on application to geological CO₂ storage. We find that capillary forces can slow and stop the migration of a CO₂ plume. The meso-scale portion of this Thesis demonstrates the powerful control of wettability on multiphase flow in porous media, which is manifested in the markedly different invasion protocols that emerge when one fluid displaces another in a patterned microfluidic cell. The pore-scale portion of this Thesis focuses on the impact of wettability on fluid-fluid displacement inside a capillary tube. We show that the contact line movement is strongly affected by wettability, even in regimes where viscous forces dominate capillary forces. by Benzhong Zhao. Ph. D.
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Little, Sylvia Bandy. "Multiphase flow through porous media." Thesis, Georgia Institute of Technology, 2002. http://hdl.handle.net/1853/11779.
Ha, Quoc Dat. "Modélisation multiéchelle du couplage adsorption-transport-mécanique dans les réservoirs de gaz de charbon : récupération assistée par injection de CO₂." Electronic Thesis or Diss., Université de Lorraine, 2022. http://www.theses.fr/2022LORR0194.
Le gaz de charbon est une ressource énergétique dont l'exploitation peut être accélérée par injection de gaz carbonique (CO₂) combinant ainsi production de méthane (CH₄) et stockage du gaz carbonique produit par sa combustion. La structure du réservoir est considérée comme un milieu à double porosité avec des fractures naturelles (cleats) et une matrice contenant une phase solide et des nanopores (de taille inférieure à 2 nm) où le gaz est stocké par adsorption sur la paroi solide. Le CO₂ est plus facilement adsorbé que le CH₄. Un modèle théorique multiéchelle combinant adsorption, transport et poromécanique du réservoir est développé. À la plus petite échelle, les molécules de gaz sont considérées comme des sphères dures interagissant par un potentiel de Lennard-Jones. Une nouvelle méthode numérique utilise la théorie de la fonctionnelle de densité (DFT) et la théorie fondamentale de la mesure (FMT) pour calculer la distribution des densités moléculaires d'un mélange de gaz pour une géométrie quelconque des nanopores. La paroi solide exerce un potentiel extérieur répulsif à très courte distance et attractif à plus grande distance sur les molécules de gaz. À partir des distributions moléculaires des gaz, la force de solvatation exercée par la phase fluide sur la surface des nanopores est calculée précisément. La méthode de l'homogénéisation asymptotique permet de passer de l'échelle du nanopore à l'échelle microscopique et d'obtenir la réponse de la matrice de charbon. Le modèle poroélastique de Biot est modifié par la force de solvatation qui agit comme le principal facteur gouvernant le gonflement ou la contraction de la matrice. Les équations moyennes de conservation de la masse des deux gaz (CH₄ et CO₂) dans la matrice prennent en compte les phénomènes d'adsorption caractérisés par des coefficients de partition et une diffusion effective de type Knudsen. Une seconde homogénéisation vise à obtenir la loi macroscopique à l'échelle du réservoir en combinant le réseau de cleats et la matrice solide. Le contact à l'interface matrice-cleats est caractérisé par la loi hyperbolique de Barton-Bandis qui modifie la rigidité effective ainsi que la perméabilité du réservoir. Après homogénéisation, le réservoir est un milieu hétérogène et anisotrope du fait de la structure des cleats et de la variation spatiale de la pression du fluide. Une équation moyenne macroscopique pour la diffusion des gaz dans la matrice et le transport gaz-eau dans les cleats est développée en considérant l'échange de masse entre la matrice et les cleats gouverné par l'approximation de Warren et Root. Des simulations numériques démontrent la corrélation cruciale entre les distributions de pression de gaz, l'ouverture des cleats et la rigidité du réservoir. L'injection de CO₂ améliore significativement la production de CH₄. Elle permet le stockage souterrain de CO₂ contribuant à réduire les émissions de gaz à effet de serre Coal seam gas is an energy resource whose exploitation can be enhanced by injectingcarbon dioxide (CO₂), thus combining the production of methane (CH₄) and the storage of carbon dioxide produced by its combustion. The structure of the reservoir is considered to be a double-porosity medium with natural fractures (cleats) and a matrix containing a solid phase and nanopores (less than 2 nm in size) where the gas is stored by adsorption on the solid wall. CO₂ is more easily adsorbed than CH₄. A multiscale theoretical model combining adsorption, transport and reservoir poro-mechanics is developed. At the smallest scale, the gas molecules are considered as hard spheres interacting through a Lennard-Jones potential. A new numerical method uses Density Functional Theory (DFT) and Fundamental Measure Theory (FMT) to calculate the distribution of molecular densities of a mixture of gases for any nanopore geometry. The solid wall exerts an external potential that is repulsive at very short distances and attractive at longer distances on the gas molecules. From the molecular distributions of the gases, the solvation force exerted by the fluid phase on the surface of the nanopores is precisely calculated. The asymptotic homogenization method is performed to upscale the nanopore-scale model and to obtain the response of the coal matrix at the microscale. The Biot poroelastic model is modified by the solvation force, which acts as the main factor governing matrix swelling or contraction. The average mass conservation equations for the two gases (CH₄ and CO₂) in the matrix take into account adsorption phenomena characterized by partition coefficients and an effective Knudsen-type diffusion. A second homogenization aims at obtaining the macroscopic law at the reservoir scaleby combining the cleats network and the solid matrix. The joint stiffness at the matrix-cleats interface is characterized by the hyperbolic Barton-Bandis law, which modifies the effective stiffness and the permeability of the reservoir. After homogenization, the reservoir is a heterogeneous and anisotropic medium due to the structure of the cleats and the spatial variation of the fluid pressure. A macroscopic average equation for gas diffusion in the matrix and gas-water transport in the cleats is developed by considering the mass exchange between the matrix and the cleats governed by the Warren and Root approximation. Numerical simulations illustrate the crucial correlation between gas pressure distributions, cleat opening and reservoir stiffness. CO₂ injection significantly improves CH₄ production and enables a underground storage of CO₂, which contributes to reducing green-house gas emissions
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Sheng, Jopan. "Multiphase immiscible flow through porous media." Diss., Virginia Polytechnic Institute and State University, 1986. http://hdl.handle.net/10919/53630.
A finite element model is developed for multiphase flow through soil involving three immiscible fluids: namely air, water, and an organic fluid. A variational method is employed for the finite element formulation corresponding to the coupled differential equations governing the flow of the three fluid phase porous medium system with constant air phase pressure. Constitutive relationships for fluid conductivities and saturations as functions of fluid pressures which may be calibrated from two-phase laboratory measurements, are employed in the finite element program. The solution procedure uses iteration by a modified Picard method to handle the nonlinear properties and the backward method for a stable time integration. Laboratory experiments involving soil columns initially saturated with water and displaced by p-cymene (benzene-derivative hydrocarbon) under constant pressure were simulated by the finite element model to validate the numerical model and formulation for constitutive properties. Transient water outflow predicted using independently measured capillary head-saturation data agreed well with observed outflow data. Two-dimensional simulations are presented for eleven hypothetical field cases involving introduction of an organic fluid near the soil surface due to leakage from an underground storage tank. The subsequent transport of the organic fluid in the variably saturated vadose and ground water zones is analysed. Ph. D.
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Suo, Si. "Modelling Multiphase Flow in Heterogeneous Porous Media." Thesis, The University of Sydney, 2021. https://hdl.handle.net/2123/27362.
Multiphase flows in porous media, featured by distributed fluid-fluid interfaces, are commonly seen in nature and daily life. In this dissertation, we focus on effects of the heterogeneity in porous media on multiphase flow processes with the purpose of obtaining further knowledge regarding flow patterns to benefit a range of engineering applications, such as enhanced oil recovery, CO2 sequestration, and transfer printing. Followed by the background introduction and related literature review in Chapters 1 and 2, the main body of this dissertation is composed of three parallel parts investigating multiphase flow processes in porous media with different types of heterogenous structures.
Chapter 3 focuses on continuum modelling of spontaneous imbibition in porous media containing heterogeneous features. We firstly develop a numerical framework aiming to handle porous material heterogeneity at continuum scale by combining a new interface integral method and the classical Richard’s equation. After validating against some experimental results, the spontaneous imbibition processes in various heterogeneous porous media, e.g., layered and mixed one, are investigated and we emphasise the movement of the liquid front when crossing the material interfaces.
In Chapter 4, we study fluid displacement and fingering instability in hierarchical porous media. We provide a further understanding on how geometric heterogeneity influences the fluid-fluid displacement processes in porous media at pore scale, and moreover indicate a possible way to suppress the interfacial instability by adjusting the hierarchical geometry. Through numerical and theoretical analysis, we demonstrate and quantify the combined effects of wettability and hierarchical geometry highlighting the crossover of displacement patterns from fingering to compact mode.
In Chapter 5, we focus on the spreading and imbibition of droplets adhered on porous surfaces, as a typical scenario coupling free surface flow and porous media flow. Both flows are dominated by capillary effects and thus strongly depend on the characteristic length of the respective domain. In this study, we characterise the droplet spreading on and imbibition into fixing or moving porous tips, with special focus on such interaction between two flows with distinct physical lengths.
In summary, this dissertation provides a fundamental research on the multiphase flows in porous media highlighting the heterogeneity effects across various length scales. The acquired results can shed light on the design of microfluidic devices of high flow controllability and optimising configuration of geothermal energy systems.
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Snyder, Kevin P. "Multiphase flow and mass transport through porous media." Thesis, Virginia Tech, 1993. http://hdl.handle.net/10919/40658.
Amooie, Mohammad Amin. "Fluid Mixing in Multiphase and Hydrodynamically Unstable Porous-Media Flows." The Ohio State University, 2018. http://rave.ohiolink.edu/etdc/view?acc_num=osu1532012791497784.
Allen, Myron Bartlett, Grace Alda Behie, and John Arthur Trangenstein. Multiphase Flow in Porous Media. New York, NY: Springer US, 1988. http://dx.doi.org/10.1007/978-1-4613-9598-0.
Das, D. B., and S. M. Hassanizadeh, eds. Upscaling Multiphase Flow in Porous Media. Berlin/Heidelberg: Springer-Verlag, 2005. http://dx.doi.org/10.1007/1-4020-3604-3.
Pinder, George F., and William G. Gray. Essentials of Multiphase Flow and Transport in Porous Media. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2008. http://dx.doi.org/10.1002/9780470380802.
Lagendijk, Vincent, Axel Braxein, Christian Forkel, and Gerhard Rouvé. "The Modelling of Multiphase Flow and Transport Processes in Porous Media." In Soil & Environment, 221–22. Dordrecht: Springer Netherlands, 1995. http://dx.doi.org/10.1007/978-94-011-0415-9_46.
Wheeler, Mary F. "Computational Environments for Coupling Multiphase Flow, Transport, and Mechanics in Porous Media." In High Performance Computing - HiPC 2008, 3–4. Berlin, Heidelberg: Springer Berlin Heidelberg, 2008. http://dx.doi.org/10.1007/978-3-540-89894-8_3.
Wilkinson, David. "Multiphase Flow in Porous Media." In Springer Proceedings in Physics, 280–88. Berlin, Heidelberg: Springer Berlin Heidelberg, 1985. http://dx.doi.org/10.1007/978-3-642-93301-1_34.
Dracos, Th. "Multiphase Flow in Porous Media." In Modelling and Applications of Transport Phenomena in Porous Media, 195–220. Dordrecht: Springer Netherlands, 1991. http://dx.doi.org/10.1007/978-94-011-2632-8_2.
Park, Chan-Hee, Joshua Taron, Ashok Singh, Wenqing Wang, and Chris McDermott. "Multiphase Flow Processes." In Thermo-Hydro-Mechanical-Chemical Processes in Porous Media, 247–68. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-27177-9_12.
King, M. J., P. R. King, C. A. McGill, and J. K. Williams. "Effective Properties for Flow Calculations." In Multiphase Flow in Porous Media, 169–96. Dordrecht: Springer Netherlands, 1995. http://dx.doi.org/10.1007/978-94-017-2372-5_7.
Keyfitz, Barbara Lee. "Multiphase Saturation Equations, Change of Type and Inaccessible Regions." In Flow in Porous Media, 103–16. Basel: Birkhäuser Basel, 1993. http://dx.doi.org/10.1007/978-3-0348-8564-5_10.
Ferréol, Bruno, and Daniel H. Rothman. "Lattice-Boltzmann Simulations of Flow Through Fontainebleau Sandstone." In Multiphase Flow in Porous Media, 3–20. Dordrecht: Springer Netherlands, 1995. http://dx.doi.org/10.1007/978-94-017-2372-5_1.
Hazlett, R. D. "Simulation of Capillary-Dominated Displacements in Microtomographic Images of Reservoir Rocks." In Multiphase Flow in Porous Media, 21–35. Dordrecht: Springer Netherlands, 1995. http://dx.doi.org/10.1007/978-94-017-2372-5_2.
Conference papers on the topic "Multiphase flow in porous media environment":
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Zhang, Ruihua, Guohua Chen, and Si Huang. "A Multiphase Mixture Flow Model and Numerical Simulation for the Release of LPG Underground Storage Tank in Porous Environment." In ASME 2007 Pressure Vessels and Piping Conference. ASMEDC, 2007. http://dx.doi.org/10.1115/pvp2007-26415.
A physical process and mechanism of liquefied petroleum gas (LPG) flow dispersion in porous media for the releases at vapor and liquid region of Underground Storage Tank (UST) was analyzed. On the basis of the mixture model principle, a mathematical model was developed to simulate LPG flow dispersion in porous media. The gravity, capillary force, viscous force, interior resistance of porous media and gas-liquid interaction were incorporated into this model. And the non-Darcy coefficient of multiphase flow which is variable with Reynolds number was taken into account in the model, which was according with actual flow state. For LPG is insoluble in water, the formulation of LPG volumetric concentration was deduced, which simplifies computation process. The model was carried out to simulate a propane gas migration process in sand pond for UST release. From the simulation results, a detailed analysis was performed to investigate the effect of various influencing factors on infiltration flow: the direction of gas infiltration diffusion is influenced distinctly by gravity, release direction and the position of outlet in tank pond; the flow about release site and outlet is more active where the non-Darcy effect is obvious; the pressure drive is crucial for LPG infiltration; the gravity is a main factor to water infiltration; the saturation and viscous force of water can restrain the infiltration speed of propane. The model can lead to a good understanding of flow development and field effects of LPG in unsaturated porous media and can offer boundary conditions for modeling the subsequent fire explosion accidents.
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Li, Yaofa, Gianluca Blois, Farzan Kazemifar, and Kenneth T. Christensen. "Quantifying the Dynamics of Water-CO2 Multiphase Flow in Microfluidic Porous Media Using High-Speed Micro-PIV." In ASME 2020 International Mechanical Engineering Congress and Exposition. American Society of Mechanical Engineers, 2020. http://dx.doi.org/10.1115/imece2020-24545.
Abstract Multiphase flow in porous media is central to a large range of applications in the energy and environmental sectors, such as enhanced oil recovery, groundwater remediation, and geologic CO2 storage and sequestration (CCS). Herein we present an experimental study of pore-scale flow dynamics of liquid CO2 and water in two-dimensional (2D) heterogeneous porous micromodels employing high-speed microscopic particle image velocimetry (micro-PIV). This novel technique allowed us to spatially and temporally resolve the dynamics of multiphase flow of CO2 and water under reservoir-relevant conditions for varying wettabilities and thus to evaluate the impact of wettability on the observed physics and dynamics. The preliminary results show that multiphase flow of liquid CO2 and water in hydrophilic micromodels is strongly dominated by successive pore-scale burst events, resulting in velocities of two orders of magnitude larger than the bulk velocity. When the surface wettability was altered such that imbibtion takes place, capillarity and instability are significantly suppressed, leading to more compact and axi-symmetric displacement of water by liquid CO2 with generally low flow velocities. To our knowledge, this work represents the first of its kind, and will be useful for advancing our fundamental understanding and facilitating pore-scale model development and validation.
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Keilegavlen, E., E. Fonn, K. Johannessen, T. Tegnander, K. Eikehaug, J. W. Both, M. A. Fernø, et al. "A Digital Twin for Reservoir Simulation." In SPE Norway Subsurface Conference. SPE, 2024. http://dx.doi.org/10.2118/218461-ms.
Abstract We have developed a physical room-scale porous media flow rig for operating, measuring, and visualizing reservoir flows in real time – the FluidFlower. The flow rig scale is large enough to achieve true multiphase flow effects (including phase mixture, gravity segregation and geological heterogeneities), while small enough to work on weekly time-scales, and allow for repeatable experiments. Mirroring the FluidFlower, we have constructed a prototype of a digital twin for porous media flow – the PoroTwin. Essentially, we demonstrate that it is possible to achieve real-time transmissions of laboratory data from the FluidFlower to a cloud-based simulation- and machine learning environment, and complete the loop with applying optimal control algorithms to steer the experiment. As part of the proof of concept, we also demonstrate that the machine learning environment can identify, and learn to correct for, incomplete physical descriptions within a reservoir simulator. The PoroTwin thus shows the potential of a fully integrated experimental and automated learning environment.
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Oliver, Michael J., Jaikrishnan R. Kadambi, Beverly Saylor, Martin Ferer, Grant S. Bromhal, and Duane H. Smith. "An Experimental Investigation of the Motion of Gas-Liquid Displacement Interface in an Artificial Porous Medium." In ASME 2004 Heat Transfer/Fluids Engineering Summer Conference. ASMEDC, 2004. http://dx.doi.org/10.1115/ht-fed2004-56685.
The study of flow and transport in porous media has relevance in many industrial, environmental (Geologic sequestration of CO2) and biological disciplines. In many engineering applications we require the knowledge of the velocity field for flow through porous objects. Historically, simplified models such as Darcy’s law [1,2], provide a reasonable description of the flow in the interior for single phase flow but require empirical coefficients to match the boundary conditions with the outer flow. The scientific basis for understanding flow and transport phenomena in porous media has largely been developed from experimental and theoretical studies in “bulk” or macroscopic systems in which coupled behavior at the pore scale is not measured or observed directly. To understand the flow behavior at the pore scale, flow characterization in porous media is very important. Multiphase, immiscible, low Re flow through a simulated porous media is studied experimentally. The experimental test cell, Figure 1, designed in collaboration with the Department of Energy, National Energy Technology Laboratory (DOE NETL), was manufactured from an optically clear polycarbonate material. It has a lattice type pattern of 2.5 mm pores bodies interconnected by angular capillary throats varying in size from 200 μm to 1000 μm. The experimental flow loop (Figure 2), utilizes air as the displacing fluid and sodium iodide (NaI) solution in water as the defending fluid. Air is provided at a constant pressure at the inlet. The refractive indices of the NaI solution and the optically clear test cell are matched to facilitate the observance of the air-liquid interface motion. Experimental data recorded with respect to time are the inlet gage pressure, delta pressure, inlet to outlet, across the test cell, volume flow rate at the outlet and the position of the displacement interface as the invading fluid, air, displaces the defending fluid, NaI solution. Parameters that can be varied in the experiment are viscosity ratio, micro and macro capillary number, the bond number and the volume flow rate. The details of the test loop are provided in Figure 2. The figure shows the piping arrangement to fill the test cell with the NaI solution and supplying the air for the tests. A CCD camera (Redlake ES 1.0 cross-correlation camera; resolution: 1008 × 1018 pixels) equipped with a 20 mm Micro Nikkor lens (Nikon) and a data acquisition system consisting of a PC and a PIXCI D2X frame grabber card (EPIX) is utilized to obtain a series of digital images as the invading air enters the test cell through the inlet manifold and makes way through the liquid until the breakthrough to the exit manifold. The pore scale velocity of the displacement interface is determined using a “Difference Threshold Technique” developed at Case Western Reserve University (CWRU), Laser Flow Diagnostics Lab (LFDL), Department of Mechanical and Aerospace Engineering. The difference threshold technique developed to processing the images is described in the next section.
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Pawar, Gorakh, Ilija Miskovic, and Manjunath Basavarajappa. "Evaluation of Fluid Behaviour and Mixing Efficiency in Predefined Serpentine Micro-Fracture System." In ASME 2013 International Mechanical Engineering Congress and Exposition. American Society of Mechanical Engineers, 2013. http://dx.doi.org/10.1115/imece2013-65124.
Scientific research and development in the field of microfluidics and nanofluidics technology has witnessed a rapid expansion in recent years. Microfluidic and nanofluidic systems are finding increasing application in wide spectrum of biomedical and engineering fields, including oil and gas technology. Fluid flow characterization in porous geologic media is an important factor for predicting and improving oil and gas recovery. By developing understanding about the propagation of hydraulic fracturing fluid constituents in irregular micro- and nano-structures, and their multiphase interaction with reservoir fluids (e.g. mixing of supercritical CO2 with oil or gas) we can significantly improve efficiency of the current oil and gas (O&G) extraction process and reduce associated environmental impacts. In present paper, mixing of hydraulic fracturing fluid constituents in three dimensional serpentine microchannel system is simulated in CFD environment and results are used to evaluate mixing efficiency for different fracturing fluid compositions. In addition, pressure drop along the length of serpentine micro-channel is evaluated. Serpentine micro-channels considered in this study consist of periodic symmetrical and asymmetrical proppant particles, placed on both sides of the channel over the full length of the channel, to simulate realistic geometrical constraints usually seen in geological fractures. The fluid flow is characterized as a function of the proppant particle radius by varying size of adjacent proppant particles. Further, the flow is characterized by varying distance between adjacent proppant particles. Overall, this study will be primarily helpful to gain fundamental understanding of fracturing fluid mixing in micro-fractures, similar to real geologic media. In addition, this study will provide an insight into variations of fracturing fluid mixing efficiency, and pressure drop in micro-fracture systems as a function of geometry of the proppant particles at different flow rates.
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Suekane, T., T. Izumi, and K. Okada. "Capillary trapping of supercritical CO2in porous media at the pore scale." In MULTIPHASE FLOW 2011. Southampton, UK: WIT Press, 2011. http://dx.doi.org/10.2495/mpf110261.
Rangel-German, E., S. Akin, and L. Castanier. "Multiphase-Flow Properties of Fractured Porous Media." In SPE Western Regional Meeting. Society of Petroleum Engineers, 1999. http://dx.doi.org/10.2118/54591-ms.
Torno, S., J. Toraño, I. Diego, M. Menéndez, M. Gent, and J. Velasco. "CFD simulation with multiphase flows in porous media and open mineral storage pile." In MULTIPHASE FLOW 2009. Southampton, UK: WIT Press, 2009. http://dx.doi.org/10.2495/mpf090361.
Berning, T., and S. K. Kær. "Modelling multiphase flow inside the porous media of a polymer electrolyte membrane fuel cell." In MULTIPHASE FLOW 2011. Southampton, UK: WIT Press, 2011. http://dx.doi.org/10.2495/mpf110251.
Chen, Songhua, Fangfang Qin, K.-H. Kim, and A. T. Watson. "NMR Imaging of Multiphase Flow in Porous Media." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 1992. http://dx.doi.org/10.2118/24760-ms.
Reports on the topic "Multiphase flow in porous media environment":
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Firoozabadi, A. Multiphase flow in fractured porous media. Office of Scientific and Technical Information (OSTI), February 1995. http://dx.doi.org/10.2172/10117349.
Wingard, J. S., and F. M. Jr Orr. Multicomponent, multiphase flow in porous media with temperature variation. Office of Scientific and Technical Information (OSTI), October 1990. http://dx.doi.org/10.2172/6200807.
Martinez, M. J. Formulation and numerical analysis of nonisothermal multiphase flow in porous media. Office of Scientific and Technical Information (OSTI), June 1995. http://dx.doi.org/10.2172/80978.
Martinez, Mario J., and Charles Michael Stone. Considerations for developing models of multiphase flow in deformable porous media. Office of Scientific and Technical Information (OSTI), September 2008. http://dx.doi.org/10.2172/940539.
Juanes, Ruben. Nonequilibrium Physics of Multiphase Flow in Porous Media: Wettability and Disorder. Office of Scientific and Technical Information (OSTI), December 2021. http://dx.doi.org/10.2172/1859674.
Juanes, Ruben. Nonequilibrium Physics and Phase-Field Modeling of Multiphase Flow in Porous Media. Office of Scientific and Technical Information (OSTI), September 2016. http://dx.doi.org/10.2172/1332323.
Martinez, M. J., P. L. Hopkins, and J. N. Shadid. LDRD final report: Physical simulation of nonisothermal multiphase multicomponent flow in porous media. Office of Scientific and Technical Information (OSTI), July 1997. http://dx.doi.org/10.2172/552791.
Schiegg, H. O. Laboratory setup and results of experiments on two-dimensional multiphase flow in porous media. Edited by J. F. McBride and D. N. Graham. Office of Scientific and Technical Information (OSTI), October 1990. http://dx.doi.org/10.2172/6174404.
Wheeler, Mary F., Ivan Yotov, Benjamin Ganis, Gergina Pencheva, Omar Al Hinai, Sangyun Lee, Baehyun Min, et al. Multiscale Modeling and Simulation of Multiphase Flow in Porous Media Coupled with Geomechanics (Final Report). Office of Scientific and Technical Information (OSTI), April 2019. http://dx.doi.org/10.2172/1509810.
Akin, Serhat, Louis M. Castanier, and Edgar Rene Rangel German. Experimental and Theoretical Investigation of Multiphase Flow in Fractured Porous media, SUPRI TR-116, Topical Report. Office of Scientific and Technical Information (OSTI), August 1999. http://dx.doi.org/10.2172/9328.
