scholarly journals Stagnation points control chaotic fluctuations in viscoelastic porous media flow

2021 ◽  
Vol 118 (38) ◽  
pp. e2111651118
Author(s):  
Simon J. Haward ◽  
Cameron C. Hopkins ◽  
Amy Q. Shen

Viscoelastic flows through porous media become unstable and chaotic beyond critical flow conditions, impacting widespread industrial and biological processes such as enhanced oil recovery and drug delivery. Understanding the influence of the pore structure or geometry on the onset of flow instability can lead to fundamental insights into these processes and, potentially, to their optimization. Recently, for viscoelastic flows through porous media modeled by arrays of microscopic posts, Walkama et al. [D. M. Walkama, N. Waisbord, J. S. Guasto, Phys. Rev. Lett. 124, 164501 (2020)] demonstrated that geometric disorder greatly suppressed the strength of the chaotic fluctuations that arose as the flow rate was increased. However, in that work, disorder was only applied to one originally ordered configuration of posts. Here, we demonstrate experimentally that, given a slightly modified ordered array of posts, introducing disorder can also promote chaotic fluctuations. We provide a unifying explanation for these contrasting results by considering the effect of disorder on the occurrence of stagnation points exposed to the flow field, which depends on the nature of the originally ordered post array. This work provides a general understanding of how pore geometry affects the stability of viscoelastic porous media flows.

Author(s):  
Clément Cancès

Many problems arising in the context of multiphase porous media flows that take the form of degenerate parabolic equations have a dissipative structure, so that the energy of an isolated system is decreasing along time. In this paper, we discuss two approaches to tune a rather large family of numerical method in order to ensure a control on the energy at the discrete level as well. The first methodology is based on upwinding of the mobilities and leads to schemes that are unconditionally positivity preserving but only first order accurate in space. We present a second methodology which is based on the construction of local positive dissipation tensors. This allows to recover a second order accuracy w.r.t. space, but the preservation of the positivity is conditioned to some additional assumption on the nonlinearities. Both methods are based on an underlying numerical method for a linear anisotropic diffusion equation. We do not suppose that this building block is monotone.


SPE Journal ◽  
2019 ◽  
Vol 25 (01) ◽  
pp. 416-431 ◽  
Author(s):  
Songyan Li ◽  
Qun Wang ◽  
Zhaomin Li

Summary Foam flooding is an important method used to protect oil reservoirs and increase oil production. However, the research on foam fluid is generally focused on aqueous foam, and there are a few studies on the stability mechanism of oil-based foam. In this paper, a compound surfactant consisting of Span® 20 and a fluorochemical surfactant is determined as the formula for oil-based foam. The foam volume and half-life in the bulk phase are measured to be 275 mL and 302 seconds, respectively, at room temperature and atmospheric pressure. The stability mechanism of oil-based foam is proposed by testing the interfacial tension (IFT) and interfacial viscoelasticity. The lowest IFT of 18.5 mN/m and the maximum viscoelasticity modulus of 16.8 mN/m appear at the concentration of 1.0 wt%, resulting in the most-stable oil-based foam. The effect of oil viscosity and temperature on the properties of oil-based foam is studied. The foam stability increases first and then decreases with the rising oil viscosity, and the stability decreases with rising temperature. The apparent viscosity of oil-based foam satisfies the power-law non-Newtonian properties, and this viscosity is much higher than that of the phases of oil and CO2. The flow of oil-based foam in porous media is studied through microscopic-visualization experiments. Bubble division, bubble merging, and bubble deformation occur during oil-based-foam flow in porous media. The oil-recovery efficiency of the oil-based-foam flooding is 78.3%, while the oil-recovery efficiency of CO2 flooding is only 28.2%. The oil recovery is enhanced because oil-based foam reduces CO2 mobility, inhibits gas channeling, and improves sweep efficiency. The results are meaningful for CO2 mobility control and for the application of foam flooding for enhanced oil recovery (EOR).


2020 ◽  
Vol 26 ◽  
pp. 145-156 ◽  
Author(s):  
Chinedu Nwaigwe ◽  
Oluwole Daniel Makinde

We extend previous studies of channel flows to porous media flows with combined effects ofboth heat and mass transfer. We consider a temperaturedependent viscosity fluid and a concentrationdependent diffusivity in an unsteady and pressuredriven nonisothermal Brinkman flow. This leads to the governing equations for velocity, concentration and temperature. By lagging nonlinear coefficients, in time, a convergent finite difference scheme is formulated. We adopt the method of manufactured solutions to verify the convergence and second order spatial accuracy of the scheme. The impact of the flow parameters on the flow fields are numerically investigated. The results show that increase in the Darcy number and temperature parameter both increase the velocity while the increase in the pollutant diffusion parameter decreases the pollutant concentration.


Author(s):  
Jianlong Xiu ◽  
Tianyuan Wang ◽  
Ying Guo ◽  
Qingfeng Cui ◽  
Lixin Huang ◽  
...  

2019 ◽  
Vol 6 (6) ◽  
pp. 181902 ◽  
Author(s):  
Junchen Lv ◽  
Yuan Chi ◽  
Changzhong Zhao ◽  
Yi Zhang ◽  
Hailin Mu

Reliable measurement of the CO 2 diffusion coefficient in consolidated oil-saturated porous media is critical for the design and performance of CO 2 -enhanced oil recovery (EOR) and carbon capture and storage (CCS) projects. A thorough experimental investigation of the supercritical CO 2 diffusion in n -decane-saturated Berea cores with permeabilities of 50 and 100 mD was conducted in this study at elevated pressure (10–25 MPa) and temperature (333.15–373.15 K), which simulated actual reservoir conditions. The supercritical CO 2 diffusion coefficients in the Berea cores were calculated by a model appropriate for diffusion in porous media based on Fick's Law. The results show that the supercritical CO 2 diffusion coefficient increases as the pressure, temperature and permeability increase. The supercritical CO 2 diffusion coefficient first increases slowly at 10 MPa and then grows significantly with increasing pressure. The impact of the pressure decreases at elevated temperature. The effect of permeability remains steady despite the temperature change during the experiments. The effect of gas state and porous media on the supercritical CO 2 diffusion coefficient was further discussed by comparing the results of this study with previous study. Based on the experimental results, an empirical correlation for supercritical CO 2 diffusion coefficient in n -decane-saturated porous media was developed. The experimental results contribute to the study of supercritical CO 2 diffusion in compact porous media.


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