Multiphase flow simulation with gravity effect in anisotropic porous media using multipoint flux approximation

Negara, Ardiansyah; Salama, Amgad; Sun, Shuyu

doi:10.1016/j.compfluid.2015.02.012

Cited by 13 publications

(12 citation statements)

References 39 publications

(51 reference statements)

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“…This approach generates a set of predefined pressure fields in such a way that the undetermined coefficients are calculated from the experimenting pressure fields. The experimenting pressure field approach has been successfully implemented to solve incompressible single and two-phase flow problems Negara 2015;Negara et al 2013Negara et al , 2014Negara et al , 2015Salama et al 2013. In this paper, we extend the application of experimenting pressure field approach to solve the compressible single-phase gas flow in shale reservoirs.…”

Section: Experimenting Pressure Field Approachmentioning

confidence: 99%

“…27, respectively. Using the same concept of implementation of experimenting pressure field approach to construct the matrix of coefficients in the incompressible flow model Negara 2015;Negara et al 2013Negara et al , 2014Negara et al , 2015Salama et al 2013), the matrix of coefficients A 5 is constructed as follows:…”

Section: Experimenting Pressure Field Approachmentioning

confidence: 99%

“…In other words, the matrix of coefficients is constructed automatically within the solver. This approach has been implemented successfully in recent years Negara 2015;Negara et al 2013Negara et al , 2014Negara et al , 2015Salama et al, 2013.…”

Section: Introductionmentioning

confidence: 99%

“…MPFA method was first introduced by Aavatsmark et al (1998) and Aavatsmark (2002). MPFA method has been widely implemented in many engineering applications (Keilegavlen et al 2012;Osman et al 2012;Negara 2015;Negara et al 2013Negara et al , 2014Negara et al , 2015Salama et al 2013. As indicated by its name, MPFA involves more point stencils than TPFA, e.g., 9-point stencil and 27-point stencil for 2-D and 3-D problems, respectively.…”

Section: Introductionmentioning

confidence: 99%

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Numerical Simulation of Natural Gas Flow in Anisotropic Shale Reservoirs

Negara

Salama

Sun

et al. 2015

Day 3 Wed, November 11, 2015

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Shale gas resources have received great attention in the last decade due to the decline of the conventional gas resources. Unlike conventional gas reservoirs, the gas flow in shale formations involves complex processes with many mechanisms such as Knudsen diffusion, slip flow (Klinkenberg effect), gas adsorption and desorption, strong rock-fluid interaction, etc. Shale formations are characterized by the tiny porosity and extremely low-permeability such that the Darcy equation may no longer be valid. Therefore, the Darcy equation needs to be revised through the permeability factor by introducing the apparent permeability. With respect to the rock formations, several studies have shown the existence of anisotropy in shale reservoirs, which is an essential feature that has been established as a consequence of the different geological processes over long period of time. Anisotropy of hydraulic properties of subsurface rock formations plays a significant role in dictating the direction of fluid flow. The direction of fluid flow is not only dependent on the direction of pressure gradient, but it also depends on the principal directions of anisotropy. Therefore, it is very important to take into consideration anisotropy when modeling gas flow in shale reservoirs. In this work, the gas flow mechanisms as mentioned earlier together with anisotropy are incorporated into the dual-porosity dual-permeability model through the full-tensor apparent permeability. We employ the multipoint flux approximation (MPFA) method to handle the full-tensor apparent permeability. We combine MPFA method with the experimenting pressure field approach, i.e., a newly developed technique that enables us to solve the global problem by breaking it into a multitude of local problems. This approach generates a set of predefined pressure fields in the solution domain in such a way that the undetermined coefficients are calculated from these pressure fields. In other words, the matrix of coefficients is constructed automatically within the solver. We ran a numerical model with different scenarios of anisotropy orientations and compared the results with the isotropic model in order to show the differences between them. We investigated the effect of anisotropy in both the matrix and fracture systems. The numerical results show anisotropy plays a crucial role in dictating the pressure fields as well as the gas flow streamlines. Furthermore, the numerical results clearly show the effects of anisotropy on the production rate and cumulative production. Incorporating anisotropy together with gas flow mechanisms in shale formations into the reservoir model is essential particularly for predicting maximum gas production from shale reservoirs.

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Section: Experimenting Pressure Field Approachmentioning

confidence: 99%

Section: Experimenting Pressure Field Approachmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Numerical Simulation of Natural Gas Flow in Anisotropic Shale Reservoirs

Negara

Salama

Sun

et al. 2015

Day 3 Wed, November 11, 2015

Self Cite

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“…Salama et al [145,146] also developed what they called the experimenting field algorithm in which the matrix of coefficients of a linear system is constructed automatically, rather than being inputted manually. This technique has been tested in various cases and shows to be very effective (Salama et al [147][148][149], Wu et al [150], Negara et al [151,152], and El-Amin et al [153]). Furthermore, Salama et al [154] and Salama [155] developed a technique that numerically solves the problem of flow towards a well in an efficient manner.…”

Section: Numerical Methods For Solving the Governing Lawsmentioning

confidence: 99%

Flow and Transport in Tight and Shale Formations: A Review

et al. 2017

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A review on the recent advances of the flow and transport phenomena in tight and shale formations is presented in this work. Exploration of oil and gas in resources that were once considered inaccessible opened the door to highlight interesting phenomena that require attention and understanding. The length scales associated with transport phenomena in tight and shale formations are rich. From nanoscale phenomena to field-scale applications, a unified frame that is able to encounter the varieties of phenomena associated with each scale may not be possible. Each scale has its own tools and limitations that may not, probably, be suitable at other scales. Multiscale algorithms that effectively couple simulations among various scales of porous media are therefore important. In this article, a review of the different length scales and the tools associated with each scale is introduced. Highlights on the different phenomena pertinent to each scale are summarized. Furthermore, the governing equations describing flow and transport phenomena at different scales are investigated. In addition, methods to solve these equations using numerical techniques are introduced. Cross-scale analysis and derivation of linear and nonlinear Darcy's scale laws from pore-scale governing equations are described. Phenomena occurring at molecular scales and their thermodynamics are discussed. Flow slippage at the nanosize pores and its upscaling to Darcy's scale are highlighted. Pore network models are discussed as a viable tool to estimate macroscopic parameters that are otherwise difficult to measure. Then, the environmental aspects associated with the different technologies used in stimulating the gas stored in tight and shale formations are briefly discussed.

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Nanoparticles transport in anisotropic porous media

El-Amin

2023

Numerical Modeling of Nanoparticle Transport in Porous Media

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Multiphase flow simulation with gravity effect in anisotropic porous media using multipoint flux approximation

Cited by 13 publications

References 39 publications

Numerical Simulation of Natural Gas Flow in Anisotropic Shale Reservoirs

Numerical Simulation of Natural Gas Flow in Anisotropic Shale Reservoirs

Flow and Transport in Tight and Shale Formations: A Review

Nanoparticles transport in anisotropic porous media

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