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Artículos de revistas sobre el tema "Immiscible multiphase flows in heterogeneous porous media"

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Publicado: 25 de mayo de 2024

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1

Dashtbesh, Narges, Guillaume Enchéry, and Benoît Noetinger. "A dynamic coarsening approach to immiscible multiphase flows in heterogeneous porous media." Journal of Petroleum Science and Engineering 201 (June 2021): 108396. http://dx.doi.org/10.1016/j.petrol.2021.108396.

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2

Cancès, Clément, Thomas O. Gallouët, and Léonard Monsaingeon. "Incompressible immiscible multiphase flows in porous media: a variational approach." Analysis & PDE 10, no. 8 (2017): 1845–76. http://dx.doi.org/10.2140/apde.2017.10.1845.

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3

Chaouche, M., N. Rakotomalala, D. Salin, and Y. C. Yortsos. "Capillary Effects in Immiscible Flows in Heterogeneous Porous Media." Europhysics Letters (EPL) 21, no. 1 (1993): 19–24. http://dx.doi.org/10.1209/0295-5075/21/1/004.

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4

Ghommem, Mehdi, Eduardo Gildin, and Mohammadreza Ghasemi. "Complexity Reduction of Multiphase Flows in Heterogeneous Porous Media." SPE Journal 21, no. 01 (2016): 144–51. http://dx.doi.org/10.2118/167295-pa.

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Summary In this paper, we apply mode decomposition and interpolatory projection methods to speed up simulations of two-phase flows in heterogeneous porous media. We propose intrusive and nonintrusive model-reduction approaches that enable a significant reduction in the size of the subsurface flow problem while capturing the behavior of the fully resolved solutions. In one approach, we use the dynamic mode decomposition. This approach does not require any modification of the reservoir simulation code but rather post-processes a set of global snapshots to identify the dynamically relevant struct
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5

Sandrakov, G. V. "HOMOGENIZED MODELS FOR MULTIPHASE DIFFUSION IN POROUS MEDIA." Journal of Numerical and Applied Mathematics, no. 3 (132) (2019): 43–59. http://dx.doi.org/10.17721/2706-9699.2019.3.05.

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Non-stationary processes of mutual diffusion for multiphase flows of immiscible liquids in porous media with a periodic structure are considered. The mathematical model for such processes is initial-boundary diffusion problem for media formed by a large number of «blocks» having low permeability and separated by a connected system of «cracks» with high permeability. Taking into account such a structure of porous media during modeling leads to the dependence of the equations of the problem on two small parameters of the porous medium microscale and the block permeability. Homogenized initial-bo
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6

Èiegis, R., O. Iliev, V. Starikovièius, and K. Steiner. "NUMERICAL ALGORITHMS FOR SOLVING PROBLEMS OF MULTIPHASE FLOWS IN POROUS MEDIA." Mathematical Modelling and Analysis 11, no. 2 (2006): 133–48. http://dx.doi.org/10.3846/13926292.2006.9637308.

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In this paper we discuss numerical algorithms for solving the system of nonlinear PDEs, arising in modelling of two‐phase flows in porous media, as well as the proper object oriented implementation of these algorithms. Global pressure model for isothermal two‐phase immiscible flow in porous media is considered in this paper. Finite‐volume method is used for the space discretization of the system of PDEs. Different time stepping discretizations and linearization approaches are discussed. The main concepts of the PDE software tool MfsolverC++ are given. Numerical results for one realistic proble
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7

Parmigiani, A., C. Huber, O. Bachmann, and B. Chopard. "Pore-scale mass and reactant transport in multiphase porous media flows." Journal of Fluid Mechanics 686 (September 30, 2011): 40–76. http://dx.doi.org/10.1017/jfm.2011.268.

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AbstractReactive processes associated with multiphase flows play a significant role in mass transport in unsaturated porous media. For example, the effect of reactions on the solid matrix can affect the formation and stability of fingering instabilities associated with the invasion of a buoyant non-wetting fluid. In this study, we focus on the formation and stability of capillary channels of a buoyant non-wetting fluid (developed because of capillary instabilities) and their impact on the transport and distribution of a reactant in the porous medium. We use a combination of pore-scale numerica
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8

Doorwar, Shashvat, and Kishore K. Mohanty. "Viscous-Fingering Function for Unstable Immiscible Flows." SPE Journal 22, no. 01 (2016): 019–31. http://dx.doi.org/10.2118/173290-pa.

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Summary Displacement of viscous oils often involves unstable immiscible flow. Viscous instability and its influence on relative permeability were studied in this work at different viscosity ratios, injection rates, and domain widths. Micromodels and pore-scale models were used to visually inspect the interplay of viscous and capillary forces in the viscous-dominated regime. A new dimensionless scaling parameter, NI=(vwμwσow)(μoμw)2(D2/K), was developed that is useful in predicting the recoveries of unstable displacements at various viscosity ratios and injection rates. The scaling parameter sh
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9

Zakirov, T. R., O. S. Zhuchkova, and M. G. Khramchenkov. "Mathematical Model for Dynamic Adsorption with Immiscible Multiphase Flows in Three-dimensional Porous Media." Lobachevskii Journal of Mathematics 45, no. 2 (2024): 888–98. http://dx.doi.org/10.1134/s1995080224600134.

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10

Kozdon, J., B. Mallison, M. Gerritsen, and W. Chen. "Multidimensional Upwinding for Multiphase Transport in Porous Media." SPE Journal 16, no. 02 (2011): 263–72. http://dx.doi.org/10.2118/119190-pa.

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Summary Multidimensional transport for reservoir simulation is typically solved by applying 1D numerical methods in each spatial-coordinate direction. This approach is simple, but the disadvantage is that numerical errors become highly correlated with the underlying computational grid. In many real-field applications, this can result in strong sensitivity to grid design not only for the computed saturation/composition fields but also for critical integrated data such as breakthrough times. Therefore, to increase robustness of simulators, especially for adverse-mobility-ratio flows that arise i
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11

Mozolevski, I., and L. Schuh. "Numerical simulation of two-phase immiscible incompressible flows in heterogeneous porous media with capillary barriers." Journal of Computational and Applied Mathematics 242 (April 2013): 12–27. http://dx.doi.org/10.1016/j.cam.2012.09.045.

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12

Monteagudo, Jorge E. P., and Abbas Firoozabadi. "Control-Volume Model for Simulation of Water Injection in Fractured Media: Incorporating Matrix Heterogeneity and Reservoir Wettability Effects." SPE Journal 12, no. 03 (2007): 355–66. http://dx.doi.org/10.2118/98108-pa.

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Summary The control-volume discrete-fracture (CVDF) model is extended to incorporate heterogeneity in rock and in rock-fluid properties. A novel algorithm is proposed to model strong water-wetting with zero capillary pressure in the fractures. The extended method is used to simulate:oil production in a layered faulted reservoir,laboratory displacement tests in a stack of matrix blocks with a large contrast in fracture and matrix capillary pressure functions, andwater injection in 2D and 3D fractured media with mixed-wettability state. Our results show that the algorithm is suitable for the sim
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13

Filimonov, Sergey A., Maxim I. Pryazhnikov, Andrey I. Pryazhnikov, and Andrey V. Minakov. "Development and Testing of a Mathematical Model for Dynamic Network Simulation of the Oil Displacement Process." Fluids 7, no. 9 (2022): 311. http://dx.doi.org/10.3390/fluids7090311.

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Multiphase flows in porous media are widespread in nature and various technologies. One of the most common examples of this kind of task is the task of recovering oil from the rock. This article describes a mathematical model of the flow of a two-phase (immiscible) liquid based on a new approach of network hydrodynamics for a highly branched microchannel medium (simulating a porous space in the rock). The coupling of the flow and pressure fields in the network is performed using a well-proven SIMPLE algorithm in CFD problems; this approach allows us to use effective approaches to modeling 3D t
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14

Rasaei, M. Reza, and Muhammad Sahimi. "Upscaling of the permeability by multiscale wavelet transformations and simulation of multiphase flows in heterogeneous porous media." Computational Geosciences 13, no. 2 (2008): 187–214. http://dx.doi.org/10.1007/s10596-008-9111-0.

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15

Pinilla, Andrés, Miguel Asuaje, Camila Pantoja, Luis Ramirez, Jessica Gomez, and Nicolás Ratkovich. "CFD study of the water production in mature heavy oil fields with horizontal wells." PLOS ONE 16, no. 10 (2021): e0258870. http://dx.doi.org/10.1371/journal.pone.0258870.

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Excessive water production in mature heavy oil fields causes incremental costs, energy consumption, and inefficiency. Understanding multiphase flows near the wellbore is an alternative to improve production efficiency. Therefore, this study conducts a series of numerical experiments based on the full set of the Navier-Stokes equations in 3D to simulate multiphase flows in porous media for heavy oil production horizontal wells. The solution given by this advanced mathematical formulation led to the description of the movement of the fluids near the wellbore with unprecedented detail. A sensitiv
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16

Ding, Yun-Xiao, An-Feng Shi, Hai-Shan Luo, and Xiao-Hong Wang. "Adaptive mesh refinement for non-isothermal multiphase flows in heterogeneous porous media comprising different rock types with tensor permeability." Numerical Heat Transfer, Part A: Applications 69, no. 1 (2015): 31–50. http://dx.doi.org/10.1080/10407782.2015.1023081.

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17

Wheeler, Mary F., Guangri Xue, and Ivan Yotov. "Accurate Cell-Centered Discretizations for Modeling Multiphase Flow in Porous Media on General Hexahedral and Simplicial Grids." SPE Journal 17, no. 03 (2012): 779–93. http://dx.doi.org/10.2118/141534-pa.

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Summary We introduce an accurate cell-centered method for modeling Darcy flow on general quadrilateral, hexahedral, and simplicial grids. We refer to these discretizations as the multipoint-flux mixed-finite-element (MFMFE) method. The MFMFE method is locally conservative with continuous fluxes and can be viewed within a variational framework as a mixed finite-element method with special approximating spaces and quadrature rules. We study two versions of the method: with a symmetric quadrature rule on smooth grids and a nonsymmetric quadrature rule on rough grids. The framework allows for hand
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18

Sorbie, K. S., A. Y. Al Ghafri, A. Skauge, and E. J. Mackay. "On the Modelling of Immiscible Viscous Fingering in Two-Phase Flow in Porous Media." Transport in Porous Media 135, no. 2 (2020): 331–59. http://dx.doi.org/10.1007/s11242-020-01479-w.

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Abstract Viscous fingering in porous media is an instability which occurs when a low-viscosity injected fluid displaces a much more viscous resident fluid, under miscible or immiscible conditions. Immiscible viscous fingering is more complex and has been found to be difficult to simulate numerically and is the main focus of this paper. Many researchers have identified the source of the problem of simulating realistic immiscible fingering as being in the numerics of the process, and a large number of studies have appeared applying high-order numerical schemes to the problem with some limited su
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19

Le Blay, Marine, Mokhtar Adda-Bedia, and Denis Bartolo. "Emergence of scale-free smectic rivers and critical depinning in emulsions driven through disorder." Proceedings of the National Academy of Sciences 117, no. 25 (2020): 13914–20. http://dx.doi.org/10.1073/pnas.2000681117.

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During the past 60 min, oil companies have extracted 6 trillion liters of oil from the ground, thereby giving a striking illustration of the impact of multiphase flows on the world economy. From a fundamental perspective, we largely understand the dynamics of interfaces separating immiscible fluids driven through heterogeneous environments. In stark contrast, the basic mechanisms ruling the transport of fragmented fluids, such as foams and emulsions, remain elusive with studies mostly limited to isolated droplets and bubbles. Here, we demonstrate that the mobilization of emulsion driven throug
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20

Beaude, L., R. Masson, S. Lopez, and P. Samier. "Combined face based and nodal based discretizations on hybrid meshes for non-isothermal two-phase Darcy flow problems." ESAIM: Mathematical Modelling and Numerical Analysis 53, no. 4 (2019): 1125–56. http://dx.doi.org/10.1051/m2an/2019014.

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In the last 20 years many discretization schemes have been developed to approximate the Darcy fluxes on polyhedral cells in heterogeneous anisotropic porous media. Among them, we can distinguished cell based approaches like the Two Point Flux Approximation (TPFA) or the Multi Point Flux Approximation (MPFA) schemes, face based approaches like the Hybrid Finite Volume (HFV) scheme belonging to the family of Hybrid Mimetic Mixed methods and nodal based discretizations like the Vertex Approximate Gradient (VAG) scheme. They all have their own drawbacks and advantages which typically depend on the
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21

Zhou, Hui, and Hamdi A. Tchelepi. "Operator-Based Multiscale Method for Compressible Flow." SPE Journal 13, no. 02 (2008): 267–73. http://dx.doi.org/10.2118/106254-pa.

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Summary Multiscale methods have been developed for accurate and efficient numerical solution of flow problems in large-scale heterogeneous reservoirs. A scalable and extendible Operator-Based Multiscale Method (OBMM) is described here. OBMM is cast as a general algebraic framework. It is natural and convenient to incorporate more physics in OBMM for multiscale computation. In OBMM, two operators are constructed: prolongation and restriction. The prolongation operator is constructed by assembling the multiscale basis functions. The specific form of the restriction operator depends on the coarse
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22

Carpenter, Chris. "Artificial Neural Network Models and Predicts Reservoir Parameters." Journal of Petroleum Technology 73, no. 01 (2021): 44–45. http://dx.doi.org/10.2118/0121-0044-jpt.

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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper IPTC 19854, “Modeling and Prediction of Resistivity, Capillary Pressure, and Relative Permeability Using Artificial Neural Network,” by Mustafa Ba alawi, SPE, King Fahd University of Petroleum and Minerals; Salem Gharbi, SPE, Saudi Aramco; and Mohamed Mahmoud, King Fahd University of Petroleum and Minerals, prepared for the 2020 International Petroleum Technology Conference, Dhahran, Saudi Arabia, 13–15 January. The paper has not been peer reviewed. Copyright 2020 International Petroleum Technology Con
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23

Pedretti, Daniele, and Marco Bianchi. "Preliminary results from the use of entrograms to describe transport in fractured media." Acque Sotterranee - Italian Journal of Groundwater, December 18, 2019. http://dx.doi.org/10.7343/as-2019-421.

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Fractured media are heterogeneous systems in which water flows primarily across rock fractures. Flow dynamics and transport of dissolved substances are controlled by the topological distribution and hydraulic properties of the fracture network (including aperture , hydraulic conductivity K and porosity). These topological and hydrodynamic properties are usually insufficiently characterized in field applications, generating uncertainty in the predictions of flow and solute transport. This paper explores a possible application of the concept of geological entropy, in particular the entrogram, as
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24

Mathiesen, Joachim, Gaute Linga, Marek Misztal, François Renard, and Tanguy Le Borgne. "Dynamic Fluid Connectivity Controls Solute Dispersion in Multiphase Porous Media Flow." Geophysical Research Letters 50, no. 16 (2023). http://dx.doi.org/10.1029/2023gl105233.

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AbstractSolute transport in multiphase flow through porous media plays a central role in many natural systems and geoengineering applications. The interplay between fluid flow and capillary forces leads to transient flow dynamics and phase distributions. However, it is not known how such dynamic flow affects the dispersion of transported species. Here, we use highly resolved numerical simulations of immiscible two‐phase flow to investigate dispersion in multiphase flows. We show that repeated activation and deactivation of different flow pathways under the effect of capillary forces accelerate
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25

"Optimal displacement of immiscible two-phase fluids in a pore doublet." Physics of Fluids 35, no. 5 (2023). http://dx.doi.org/10.1063/5.0149182.

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Multiphase fluid flow in a pore doublet is a fundamental problem and is important for understanding the transport mechanisms of multiphase flows in porous media. During the displacement of immiscible two-phase fluids in a pore doublet, the transport process is influenced not only by the capillary and viscous forces, but also the channel geometry. In this paper, a mathematical model is presented of the two-phase fluid displacement in a pore doublet considering the effects of capillary force, viscous force, and the geometric structure. This leads to a new and more general analytical solution for
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26

Rajabi, Farzaneh, and Hamdi A. Tchelepi. "Probabilistic Forecast of Multiphase Transport Under Viscous and Buoyancy Forces in Heterogeneous Porous Media." Water Resources Research 60, no. 3 (2024). http://dx.doi.org/10.1029/2023wr034449.

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AbstractWe develop a probabilistic approach to map parametric uncertainty to output state uncertainty in first‐order hyperbolic conservation laws. We analyze this problem for nonlinear immiscible two‐phase transport in heterogeneous porous media in the presence of a stochastic velocity field. The uncertainty in the velocity field can arise from incomplete descriptions of either porosity field, injection flux, or both. This uncertainty leads to spatiotemporal uncertainty in the saturation field. Given information about spatial/temporal statistics of spatially correlated heterogeneity, we levera
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27

Rabbani, Harris Sajjad, and Saideep Pavuluri. "Semi-analytical Model to Predict Dynamic Capillary Pressure–Saturation Relationship for Flows in Heterogeneous Porous Media." Transport in Porous Media, February 20, 2024. http://dx.doi.org/10.1007/s11242-024-02058-z.

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AbstractThe capillary pressure defines pressure difference between non-wetting and wetting fluids. The capillary pressure is part of the flow governing equations, and its definition can have a profound impact on the nature of fluids displacement in a multiphase flow environment. Conventionally, capillary pressure–saturation relationships are determined under equilibrium conditions which signify that all the fluid–fluid interfaces that exist at the pore scale maintain a static configuration at a certain instant in time. However, there exist experimental and numerical evidences that state that t
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28

Ahmed, E., Ø. Klemetsdal, X. Raynaud, O. Møyner, and H. M. Nilsen. "Adaptive Timestepping, Linearization, and A Posteriori Error Control for Multiphase Flow of Immiscible Fluids in Porous Media with Wells." SPE Journal, October 1, 2022, 1–21. http://dx.doi.org/10.2118/203974-pa.

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Summary This work focuses on the development of adaptive timesteps, stopping criteria, and error control strategies for reservoir simulations with fully implicit (FIM) solvers. Using a rigorous error control framework, an adaptive time selector combined with nonlinear stopping criteria is used to control nonlinear iterations as well as to balance accuracy and robustness for challenging nonlinear simulations. In reservoir simulation, efficiently solving a system of nonlinear equations arising from the FIM method can be computationally burdensome for complex recovery processes. Theoretically, an
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