Thematische Bibliographien / Immiscible multiphase flows in heterogeneous porous media

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Auswahl der wissenschaftlichen Literatur zum Thema „Immiscible multiphase flows in heterogeneous porous media“

Autor: Grafiati

Veröffentlicht am 25. Mai 2024

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Zeitschriftenartikel zum Thema "Immiscible multiphase flows in heterogeneous porous media"

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

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Cancès, Clément, Thomas O. Gallouët und Léonard Monsaingeon. „Incompressible immiscible multiphase flows in porous media: a variational approach“. Analysis & PDE 10, Nr. 8 (18.08.2017): 1845–76. http://dx.doi.org/10.2140/apde.2017.10.1845.

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Chaouche, M., N. Rakotomalala, D. Salin und Y. C. Yortsos. „Capillary Effects in Immiscible Flows in Heterogeneous Porous Media“. Europhysics Letters (EPL) 21, Nr. 1 (01.01.1993): 19–24. http://dx.doi.org/10.1209/0295-5075/21/1/004.

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Ghommem, Mehdi, Eduardo Gildin und Mohammadreza Ghasemi. „Complexity Reduction of Multiphase Flows in Heterogeneous Porous Media“. SPE Journal 21, Nr. 01 (18.02.2016): 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 structures associated with the flow behavior. In the second approach, we project the governing equations of the velocity and the pressure fields on the subspace spanned by their proper-orthogonal-decomposition modes. Furthermore, we use the discrete empirical interpolation method to approximate the mobility-related term in the global-system assembly and then reduce the online computational cost and make it independent of the fine grid. To show the effectiveness and usefulness of the aforementioned approaches, we consider the SPE-10 benchmark permeability field, and present a numerical example in two-phase flow. One can efficiently use the proposed model-reduction methods in the context of uncertainty quantification and production optimization.

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Sandrakov, G. V. „HOMOGENIZED MODELS FOR MULTIPHASE DIFFUSION IN POROUS MEDIA“. Journal of Numerical and Applied Mathematics, Nr. 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-boundary value problems will be obtained. Solutions of the problems are approximated for the solutions of the initial-boundary value problem under consideration.

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Èiegis, R., O. Iliev, V. Starikovièius und K. Steiner. „NUMERICAL ALGORITHMS FOR SOLVING PROBLEMS OF MULTIPHASE FLOWS IN POROUS MEDIA“. Mathematical Modelling and Analysis 11, Nr. 2 (30.06.2006): 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 problem are presented.

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Parmigiani, A., C. Huber, O. Bachmann und B. Chopard. „Pore-scale mass and reactant transport in multiphase porous media flows“. Journal of Fluid Mechanics 686 (30.09.2011): 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 numerical calculations based on a multiphase reactive lattice Boltzmann model (LBM) and scaling laws to quantify (i) the effect of dissolution on the preservation of capillary instabilities, (ii) the penetration depth of reaction beyond the dissolution/melting front, and (iii) the temporal and spatial distribution of dissolution/melting under different conditions (concentration of reactant in the non-wetting fluid, injection rate). Our results show that, even for tortuous non-wetting fluid channels, simple scaling laws assuming an axisymmetrical annular flow can explain (i) the exponential decay of reactant along capillary channels, (ii) the dependence of the penetration depth of reactant on a local Péclet number (using the non-wetting fluid velocity in the channel) and more qualitatively (iii) the importance of the melting/reaction efficiency on the stability of non-wetting fluid channels. Our numerical method allows us to study the feedbacks between the immiscible multiphase fluid flow and a dynamically evolving porous matrix (dissolution or melting) which is an essential component of reactive transport in porous media.

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Doorwar, Shashvat, und Kishore K. Mohanty. „Viscous-Fingering Function for Unstable Immiscible Flows“. SPE Journal 22, Nr. 01 (15.07.2016): 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 showed excellent fit with experimental data of 68 corefloods. A lumped finger model was developed to modify multiphase flow equations and to yield pseudorelative permeability functions that account for viscous fingering. The parameters of the lumped model can be estimated from the new dimensionless number, NI. This pseudorelative permeability function could be applied at each gridblock on the basis of the local NI to simulate large-scale unstable floods in water-wet porous media.

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Zakirov, T. R., O. S. Zhuchkova und M. G. Khramchenkov. „Mathematical Model for Dynamic Adsorption with Immiscible Multiphase Flows in Three-dimensional Porous Media“. Lobachevskii Journal of Mathematics 45, Nr. 2 (Februar 2024): 888–98. http://dx.doi.org/10.1134/s1995080224600134.

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Kozdon, J., B. Mallison, M. Gerritsen und W. Chen. „Multidimensional Upwinding for Multiphase Transport in Porous Media“. SPE Journal 16, Nr. 02 (13.01.2011): 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 in a variety of enhanced-oil-recovery (EOR) processes, it is of much interest to design truly multidimensional schemes for transport that remove, or at least strongly reduce, the sensitivity to grid design. We present a new upstream-biased truly multidimensional family of schemes for multiphase transport capable of handling countercurrent flow arising from gravity. The proposed family of schemes has four attractive properties: applicability within a variety of simulation formulations with varying levels of implicitness, extensibility to general grid topologies, compatibility with any finite-volume flow discretization, and provable stability (monotonicity) for multiphase transport. The family is sufficiently expressive to include several previously developed multidimensional schemes, such as the narrow scheme, in a manner appropriate for general-purpose reservoir simulation. A number of waterflooding problems in homogeneous and heterogeneous media demonstrate the robustness of the method as well as reduced transverse (cross-wind) diffusion and grid-orientation effects.

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Dissertationen zum Thema "Immiscible multiphase flows in heterogeneous porous media"

Dashtbeshbadounak, Narges. „Changement d'échelle de déplacements de fronts en milieux hétérogènes et application à l'EOR“. Electronic Thesis or Diss., Sorbonne université, 2021. http://www.theses.fr/2021SORUS084.

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Construire un modèle numérique robuste pour les écoulements multiphasiques dans les milieux poreux tout en atteignant une approximation satisfaisante de la solution exacte est difficile en raison de l'hétérogénéité du milieu à plusieurs échelles, du couplage et de la non-linéarité des équations mises en jeu, et enfin de la nécessité de capturer toutes ces échelles dans un modèle numérique macroscopique d'une manière numériquement efficace. Une approche séquentielle pour accélérer la modélisation des ces écoulements non miscibles dans les milieux hétérogènes a été développée en utilisant des méthode de Galerkin discontinues et un grossissement dynamique du maillage. Cette approche, en utilisant un critère rapidement évalué, implique une décomposition du domaine dynamique et différentes stratégies de solution appliquées suivant les régions d'écoulement établies. Un maillage haute résolution et des méthodes d'ordre bas sont utilisées dans les régions d'écoulement proches de la discontinuité de saturation tandis qu'une méthode de Galerkin discontinue et une grille basse résolution sont utilisées dans les régions monophasiques. Une technique rapide pour estimer la position du front de saturation et identifier les zones d'écoulement qui nécessitent un maillage fin est présentée. L'efficacité de cette approche est démontrée au travers de cas tests et comparée avec des méthodes standard
Numerical modelling is a widely used tool in applied geoscience for quantifying flow in porous media, that is necessary to predict performance and optimize prospect exploitation at minimal environmental risk and cost. Reaching a satisfactory approximation of the exact solution and a robust numerical model of multiphase flows is particularly challenging because of the heterogeneity of the porous medium across a wide range of length scales, the coupling and nonlinearity of the driving equations, and the necessity of capturing all scales in the macroscale numerical model in a computationally efficient way. We have developed a sequential approach to accelerate immiscible multiphase flow modelling in heterogeneous porous media using discontinuous Galerkin methods and dynamic mesh coarsening. This approach involves dynamic domain decomposition and different solution strategies in the different flow regions, using a criterion that can be fastly evaluated. We use high-resolution grids and low order methods in regions near the saturation discontinuity and a discontinuous Galerkin method along with low-resolution grids in single-phase flow regions of the domain. We present a fast technique to estimate the position of the saturation front and identify the flow zones that need high-resolution gridding and eventually, we demonstrate the accuracy of our approach through test cases from the second SPE10 model by comparing our results with fine-scale simulations

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Buchteile zum Thema "Immiscible multiphase flows in heterogeneous porous media"

„Immiscible Displacements and Multiphase Flows: Network Models“. In Flow and Transport in Porous Media and Fractured Rock, 575–632. Weinheim, Germany: Wiley-VCH Verlag GmbH & Co. KGaA, 2011. http://dx.doi.org/10.1002/9783527636693.ch15.

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„Immiscible Displacements and Multiphase Flows: Experimental Aspects and Continuum Modeling“. In Flow and Transport in Porous Media and Fractured Rock, 519–73. Weinheim, Germany: Wiley-VCH Verlag GmbH & Co. KGaA, 2011. http://dx.doi.org/10.1002/9783527636693.ch14.

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Amaziane, B. „Numerical simulation of multiphase flows in heterogeneous porous media“. In Poromechanics II, 321–26. CRC Press, 2020. http://dx.doi.org/10.1201/9781003078807-50.

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Konferenzberichte zum Thema "Immiscible multiphase flows in heterogeneous porous media"

Zhou, Dengen, F. J. Fayers und F. M. Orr. „Scaling of Multiphase Flow in Simple Heterogeneous Porous Media“. In SPE/DOE Improved Oil Recovery Symposium. SPE, 1994. http://dx.doi.org/10.2118/27833-ms.

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The nature of flow in porous media is determined by the interaction of the physical properties of the medium and fluids, and by the interplay of various forces involved in the displacement process. Identifying flow regions at a given reservoir operating condition is a key issue in forecasting reservoir performance and hence of optimizing operations. This work identifies dominant flow regions at various conditions. Three dimensionless groups, NgvM/(1 + M) (gravity/viscous ratio), NcvM/(1 + M) (capillary/viscous ratio) and Ri2 (shape factor), are defined and used to resolve flow regions. The analysis shows that the relative magnitudes of forces involved in the system combined with the reservoir properties determine the flow region and fluid distribution in the medium. By choosing appropriate ranges for the dimensionless numbers, recovery processes can be specified from the general theory, and the boundaries to flow regions confirmed by comparison with existing experimental and simulation results. Three commonly studied flow systems have been investigated, which are miscible displacements without dispersion (Ncv ≈ 0) in layered reservoirs, immiscible displacements (Ngv ≈ 0) in layered and homogeneous media, and flow in highly fractured reservoirs.

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Cusini, M. C., C. van Kruijsdijk und H. Hajibeygi. „Algebraic Dynamic Multilevel (ADM) Method for Immiscible Multiphase Flow in Heterogeneous Porous Media with Capillarity“. In ECMOR XV - 15th European Conference on the Mathematics of Oil Recovery. Netherlands: EAGE Publications BV, 2016. http://dx.doi.org/10.3997/2214-4609.201601901.

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Al-bayati, Duraid, Ali Saeedi, Ipek Ktao, Matthew Myers, Cameron White, Ali Mousavi, Quan Xie und Christopher Lagat. „X-Ray Computed Tomography Assisted Investigation of Flow Behaviour of Miscible CO2 to Enhance Oil Recovery in Layered Sandstone Porous Media“. In SPE Conference at Oman Petroleum & Energy Show. SPE, 2022. http://dx.doi.org/10.2118/200103-ms.

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Abstract Reservoir heterogeneity reflected by permeability variation in the vertical direction is expected to significantly impact on the subsurface multiphase flow behaviour. In this context, we have shown previously that during immiscible flooding the crossflow between low and high permeability zones plays a significant role in determining the reservoir performance in terms of the hydrocarbon yield. In this manuscript, the contribution of crossflow to oil recovery in layered sandstone porous media during miscible CO2 flooding is explored. We conducted core flooding experiments using a core sample constructed by attaching two axially split half sandstone plugs each with a different permeability (0.008 and 0.1 (μm)2). The crossflow between the two layers was controlled by placing either a lint-free tissue paper or an impermeable Teflon sheet to represent a layered heterogeneity with and without communication, respectively. Additionally, to better understand the underpinning mechanisms influencing the flood performance, we imaged the samples during flooding using a high-resolution medical X-Ray computed tomography (XCT) scanner. Our results show that core-scale heterogeneity would indeed play an important role in determining the spatial distribution of the injected CO2during miscible flooding, consequently the oil recovery factor. For instance, our results confirm that permeability heterogeneity in vertical direction would lead to CO2 establishing a prefrential flow path through the high permeability layer leading to its early breakthrough. The above-mentioned CO2 channeling is clearly evident from the X-ray images captured during flooding. However, a reasonble amount of CO2 would still enter the low permeability layer contributing positively to the ultimate oil recovery factor. In fact, the post-processing of the XCT data confirmed the above to take place when cross-layer communication was allowed. The diversion of CO2 from the high to low permeablity layer is believed to be due to the crossflow phenomenon (induced by the viscous and dispersion forces) resulting in a subtle increase (i.e. 1.7%) in the ultimate oil recovery. In a similar study we have done about immiscible flooding, the contribution of crossflow to the overall recovery was found to be about 5%. The less pronounced effect of crossflow under miscible conditions is believed to be due to the absence of capillarity as a more effective driving force behind crossflow. To the best of our knowledge, our core-flooding results as presented in this manuscript and backed by X-ray CT visualisation, are the first set of their kind. They are insightful and would be of interest to the scientific community in revealing how crossflow may control flow behaviour in heterogeneous sandstone reservoirs, with important implications for numerical modelling of CO2 injection.

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Verdiere, S., D. Guérillot und J. -M. Thomas. „Dual Mesh Method for Multiphase Flows in Heterogeneous Porous Media“. In ECMOR V - 5th European Conference on the Mathematics of Oil Recovery. European Association of Geoscientists & Engineers, 1996. http://dx.doi.org/10.3997/2214-4609.201406903.

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Dashtbesh, N., B. Noetinger und G. Enchéry. „An Efficient Implementation of the Discontinuous Galerkin Method for Multiphase Flows through Heterogeneous Porous Media“. In ECMOR XVII. European Association of Geoscientists & Engineers, 2020. http://dx.doi.org/10.3997/2214-4609.202035120.

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Ahmadi, G., D. Crandall und D. H. Smith. „Gas-Liquid Flows in Flow Cells and Fracture Models“. In ASME 2008 Fluids Engineering Division Summer Meeting collocated with the Heat Transfer, Energy Sustainability, and 3rd Energy Nanotechnology Conferences. ASMEDC, 2008. http://dx.doi.org/10.1115/fedsm2008-55253.

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Gas-liquid multiphase flows in porous media and fractured rock is of importance when carbon-dioxide displaces brine within geological reservoirs during CO2 sequestration activities. In this paper, experimental and computational modeling of multiphase flows in a porous flow cell and a modeled fracture are described. The experiments performed with the laboratory-scale flow models are described in detail. Experimental data concerning the displacement of two immiscible fluids in the lattice-like flow cell are presented. The flow pattern and the residual saturation of the displaced fluid during the displacement are discussed. It was shown that the gas-liquid flows generate fractal interfaces, with lower fractal dimensions and higher residual saturations at low injection rates. This phenomenon corresponds to viscous and capillary fingering, and is discussed. Numerical simulations of the experimental flow cell are also presented. These are shown to be similar to the experimental results, and then varied to included different surface-fluid interactions not easily studied with the experimental equipment. Numerical simulation results for single and multiphase flows through rock fractures are also presented. A fracture geometry was obtained from a series of CT scans of fractured sandstone and used to construct a laboratory scale model and a computational domain. Computational results showed that the major losses occur in the regions with smallest apertures. These computational results are compared to flows through the experimental model. An empirical expression for the fracture friction factor was also described.

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Daripa, Prabir. „Fluid Dynamical and Modeling Issues of Chemical Flooding for Enhanced Oil Recovery“. In ASME 2013 32nd International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2013. http://dx.doi.org/10.1115/omae2013-11516.

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This paper evaluates the relevance of Hele-Shaw (HS) model based linear stability results to fully developed flows in enhanced oil recovery (EOR). In a recent exhaustive study [Transport in Porous Media, 93, 675–703 (2012)] of the linear stability characteristics of unstable immiscible three-layer “Hele-Shaw” flows involving regions of varying viscosity, an optimal injection policy corresponding to the smallest value of the highest rate of growth of instabilities was identified among several injection policies. Relevance of this HS model based result to EOR is established by performing direct numerical simulations of fully developed tertiary displacement in porous media. Results of direct numerical simulation are succinctly summarized including characterization of the optimal flooding scheme that leads to maximum oil recovery. These results have been compared with the HS model based linear stability results. The scope for potential application of the HS model based results to the development of fast methods for optimization of various chemical flooding schemes is discussed. Numerical experiments with more complex flooding schemes in both homogeneous and heterogeneous reservoir are also performed and results analyzed to test the universality of the generic optimal viscous families in a broader setting.

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Lanetc, Zakhar, Aleksandr Zhuravljov, Artur Shapoval, Ryan T. Armstrong und Peyman Mostaghimi. „Inclusion of Microporosity in Numerical Simulation of Relative Permeability Curves“. In International Petroleum Technology Conference. IPTC, 2022. http://dx.doi.org/10.2523/iptc-21975-ms.

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Abstract Advances in high-resolution micro computed tomography (micro-CT) allow obtaining high-quality rock images with a resolution of up to a few micrometres. Novel direct numerical simulation methods provide the opportunity to precisely predict the flow properties in the resolved pore space. However, a large fraction of porosity lies below the resolution of modern micro-CT scanners. These, so called, micro-pores may significantly affect the physics of flow in geologically complex dual-porosity heterogeneous formations (carbonates, shales, and coals) and are currently not accounted for in traditional micro-CT based simulations. In this work, we have employed a multiphase multi-scale Darcy-Brinkman approach to simulate immiscible two-phase flow in a hybrid system containing both macro-porous solid-free regions and a micro-porous permeable matrix. This approach solves the Navier-Stokes based volume of fluid equations system in macro-pores and accounts for multiphase Darcy equations in micro-porous regions. By combining available information on micro-porosity with relative permeability curves estimated from the synthetically generated image with both macro- and micro-porous regions fully resolved, we solve the inverse problem to account for micro-porous contribution in our Darcy-Brinkman simulation. This approach allows us to estimate relative-permeability curves in the micro-porous region and correct the multi-scale simulation so it coincides with the data from the fully-resolved image. As a result, we were able to account for the impact of micro-porosity on the residual saturation and correct the shape of relative permeability curves and their end-points in the micro-porous domain. The proposed approach provides a workflow which can be used to history-match the Darcy-Brinkman pore-scale simulation with core-scale petrophysical data with respect to the relative permeability. Thus, it is possible to account for heterogeneity in complex rock formations by incorporating the whole range of porosity. The inclusion of micro-porosity in pore-scale image-based simulations for predicting relative permeability curves may help in a more reliable modelling and estimation of filed-scale subsurface flows, production profiles, recoverable reserves and carbon capture and storage mechanisms.

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