Auswahl der wissenschaftlichen Literatur zum Thema „Multiphase flow in porous media environment“
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Zeitschriftenartikel zum Thema "Multiphase flow in porous media environment"
Reynolds, David A., und Bernard H. Kueper. „Multiphase flow and transport through fractured heterogeneous porous media“. Journal of Contaminant Hydrology 71, Nr. 1-4 (Juli 2004): 89–110. http://dx.doi.org/10.1016/j.jconhyd.2003.09.008.
Der volle Inhalt der QuelleKueper, Bernard H., Wesley Abbott und Graham Farquhar. „Experimental observations of multiphase flow in heterogeneous porous media“. Journal of Contaminant Hydrology 5, Nr. 1 (Dezember 1989): 83–95. http://dx.doi.org/10.1016/0169-7722(89)90007-7.
Der volle Inhalt der QuelleCai, Jianchao, Reza Rezaee und Victor Calo. „Recent Advances in Multiscale Petrophysics Characterization and Multiphase Flow in Unconventional Reservoirs“. Energies 15, Nr. 8 (14.04.2022): 2874. http://dx.doi.org/10.3390/en15082874.
Der volle Inhalt der QuelleLi, Xiaoqing, Renqiang Liu, Tianyu Zhang, Peng Yu und Xiaoyan Liu. „Division of paraffin melting zone based on multiscale experiments“. Thermal Science, Nr. 00 (2021): 140. http://dx.doi.org/10.2298/tsci200818140l.
Der volle Inhalt der QuellePapamichos, Euripides. „Erosion and multiphase flow in porous media. Application to sand production“. European Journal of Environmental and Civil engineering 14, Nr. 8-9 (28.09.2010): 1129–54. http://dx.doi.org/10.3166/ejece.14.1129-1154.
Der volle Inhalt der QuelleAbdin, A., J. J. Kalurachchi, M. W. Kemblowski und C. M. Chang. „Stochastic analysis of multiphase flow in porous media: II. Nummerical simulations“. Stochastic Hydrology and Hydraulics 11, Nr. 1 (Februar 1997): 94. http://dx.doi.org/10.1007/bf02428427.
Der volle Inhalt der QuelleAbin, A., J. J. Kalurachchi, M. W. Kemblowski und C. M. Chang. „Stochastic analysis of multiphase flow in porous media: II. Numerical simulations“. Stochastic Hydrology and Hydraulics 10, Nr. 3 (August 1996): 231–51. http://dx.doi.org/10.1007/bf01581465.
Der volle Inhalt der QuelleYan, Guanxi, Zi Li, Thierry Bore, Sergio Andres Galindo Torres, Alexander Scheuermann und Ling Li. „Discovery of Dynamic Two-Phase Flow in Porous Media Using Two-Dimensional Multiphase Lattice Boltzmann Simulation“. Energies 14, Nr. 13 (05.07.2021): 4044. http://dx.doi.org/10.3390/en14134044.
Der volle Inhalt der QuelleChang, C., M. W. Kemblowski, J. Kaluarachchi und A. Abdin. „Stochastic analysis of multiphase flow in porous media: 1. Spectral/perturbation approach“. Stochastic Hydrology and Hydraulics 9, Nr. 3 (September 1995): 239–67. http://dx.doi.org/10.1007/bf01581722.
Der volle Inhalt der QuelleLi, Guihe, und Jia Yao. „Snap-Off during Imbibition in Porous Media: Mechanisms, Influencing Factors, and Impacts“. Eng 4, Nr. 4 (17.11.2023): 2896–925. http://dx.doi.org/10.3390/eng4040163.
Der volle Inhalt der QuelleDissertationen zum Thema "Multiphase flow in porous media environment"
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.
Der volle Inhalt der QuelleIncludes 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.
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.
Der volle Inhalt der QuelleCataloged 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.
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.
Der volle Inhalt der QuelleCataloged 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.
Little, Sylvia Bandy. „Multiphase flow through porous media“. Thesis, Georgia Institute of Technology, 2002. http://hdl.handle.net/1853/11779.
Der volle Inhalt der QuelleHa, 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.
Der volle Inhalt der QuelleCoal 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
Sheng, Jopan. „Multiphase immiscible flow through porous media“. Diss., Virginia Polytechnic Institute and State University, 1986. http://hdl.handle.net/10919/53630.
Der volle Inhalt der QuellePh. D.
Suo, Si. „Modelling Multiphase Flow in Heterogeneous Porous Media“. Thesis, The University of Sydney, 2021. https://hdl.handle.net/2123/27362.
Der volle Inhalt der QuelleSnyder, Kevin P. „Multiphase flow and mass transport through porous media“. Thesis, Virginia Tech, 1993. http://hdl.handle.net/10919/40658.
Der volle Inhalt der QuelleAmooie, 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.
Der volle Inhalt der QuelleReichenberger, Volker. „Numerical simulation of multiphase flow in fractured porous media“. [S.l. : s.n.], 2004. http://deposit.ddb.de/cgi-bin/dokserv?idn=970266049.
Der volle Inhalt der QuelleBücher zum Thema "Multiphase flow in porous media environment"
Adler, Pierre M., Hrsg. Multiphase Flow in Porous Media. Dordrecht: Springer Netherlands, 1995. http://dx.doi.org/10.1007/978-94-017-2372-5.
Der volle Inhalt der QuelleAllen, Myron Bartlett, Grace Alda Behie und 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.
Der volle Inhalt der QuelleM, Adler Pierre, Hrsg. Multiphase flow in porous media. Dordrecht: Kluwer Academic Publishers, 1995.
Den vollen Inhalt der Quelle findenDas, D. B., und S. M. Hassanizadeh, Hrsg. Upscaling Multiphase Flow in Porous Media. Berlin/Heidelberg: Springer-Verlag, 2005. http://dx.doi.org/10.1007/1-4020-3604-3.
Der volle Inhalt der QuellePinder, George Francis. Essentials of multiphase flow in porous media. Hoboken, N.J: J. Wiley, 2008.
Den vollen Inhalt der Quelle findenEne, Horia I. Thermal flow in porous media. Dordrecht, Holland: D. Reidel Pub. Co., 1987.
Den vollen Inhalt der Quelle findenPinder, George F. Essentials of Multiphase Flow and Transport in Porous Media. Hoboken: John Wiley & Sons, 2008.
Den vollen Inhalt der Quelle findenPinder, George F., und 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.
Der volle Inhalt der QuelleSha, William T. Novel porous media formulation for multiphase flow conservation equations. New York: Cambridge University Press, 2011.
Den vollen Inhalt der Quelle findenAllen, Myron B. Multiphase flow in porous media: Mechanics, mathematics, and numerics. Berlin: Springer-Verlag, 1988.
Den vollen Inhalt der Quelle findenBuchteile zum Thema "Multiphase flow in porous media environment"
Kolditz, Olaf. „Multiphase Flow in Deformable Porous Media“. In Computational Methods in Environmental Fluid Mechanics, 333–72. Berlin, Heidelberg: Springer Berlin Heidelberg, 2002. http://dx.doi.org/10.1007/978-3-662-04761-3_15.
Der volle Inhalt der QuelleLagendijk, Vincent, Axel Braxein, Christian Forkel und 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.
Der volle Inhalt der QuelleWheeler, 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.
Der volle Inhalt der QuelleWilkinson, 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.
Der volle Inhalt der QuelleDracos, 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.
Der volle Inhalt der QuellePark, Chan-Hee, Joshua Taron, Ashok Singh, Wenqing Wang und 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.
Der volle Inhalt der QuelleKing, M. J., P. R. King, C. A. McGill und 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.
Der volle Inhalt der QuelleKeyfitz, 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.
Der volle Inhalt der QuelleFerréol, Bruno, und 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.
Der volle Inhalt der QuelleHazlett, 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.
Der volle Inhalt der QuelleKonferenzberichte zum Thema "Multiphase flow in porous media environment"
Zhang, Ruihua, Guohua Chen und 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.
Der volle Inhalt der QuelleLi, Yaofa, Gianluca Blois, Farzan Kazemifar und 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.
Der volle Inhalt der QuelleKeilegavlen, 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.
Der volle Inhalt der QuelleOliver, Michael J., Jaikrishnan R. Kadambi, Beverly Saylor, Martin Ferer, Grant S. Bromhal und 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.
Der volle Inhalt der QuellePawar, Gorakh, Ilija Miskovic und 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.
Der volle Inhalt der QuelleSuekane, T., T. Izumi und 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.
Der volle Inhalt der QuelleRangel-German, E., S. Akin und 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.
Der volle Inhalt der QuelleTorno, S., J. Toraño, I. Diego, M. Menéndez, M. Gent und 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.
Der volle Inhalt der QuelleBerning, T., und 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.
Der volle Inhalt der QuelleChen, Songhua, Fangfang Qin, K.-H. Kim und 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.
Der volle Inhalt der QuelleBerichte der Organisationen zum Thema "Multiphase flow in porous media environment"
Firoozabadi, A. Multiphase flow in fractured porous media. Office of Scientific and Technical Information (OSTI), Februar 1995. http://dx.doi.org/10.2172/10117349.
Der volle Inhalt der QuelleWingard, J. S., und F. M. Jr Orr. Multicomponent, multiphase flow in porous media with temperature variation. Office of Scientific and Technical Information (OSTI), Oktober 1990. http://dx.doi.org/10.2172/6200807.
Der volle Inhalt der QuelleMartinez, M. J. Formulation and numerical analysis of nonisothermal multiphase flow in porous media. Office of Scientific and Technical Information (OSTI), Juni 1995. http://dx.doi.org/10.2172/80978.
Der volle Inhalt der QuelleMartinez, Mario J., und 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.
Der volle Inhalt der QuelleJuanes, Ruben. Nonequilibrium Physics of Multiphase Flow in Porous Media: Wettability and Disorder. Office of Scientific and Technical Information (OSTI), Dezember 2021. http://dx.doi.org/10.2172/1859674.
Der volle Inhalt der QuelleJuanes, 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.
Der volle Inhalt der QuelleMartinez, M. J., P. L. Hopkins und J. N. Shadid. LDRD final report: Physical simulation of nonisothermal multiphase multicomponent flow in porous media. Office of Scientific and Technical Information (OSTI), Juli 1997. http://dx.doi.org/10.2172/552791.
Der volle Inhalt der QuelleSchiegg, H. O. Laboratory setup and results of experiments on two-dimensional multiphase flow in porous media. Herausgegeben von J. F. McBride und D. N. Graham. Office of Scientific and Technical Information (OSTI), Oktober 1990. http://dx.doi.org/10.2172/6174404.
Der volle Inhalt der QuelleWheeler, 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.
Der volle Inhalt der QuelleAkin, Serhat, Louis M. Castanier und 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.
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