Design and analysis of different models of microfluidic devices evaluated in Enhanced Oil Recovery (EOR) assays

Rosero, Gustavo; Peñaherrera, Ana; Olmos, Carol M.; Boschan, Alejandro; Granel, P.; Golmar, F.; Lasorsa, Carlos; Lerner, Betiana; Pérez, Maximiliano

doi:10.1590/s1517-707620180002.0463

Cited by 5 publications

(3 citation statements)

References 25 publications

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“…A Canon T3-I Rebel digital camera was used to capture the images of the oil displacement tests. The images were created from a stack of multiple acquisitions over the area of the device (Avendaño et al, 2019;Rosero et al, 2018)…”

Section: Displacement Testsmentioning

confidence: 99%

A microfluidic study to investigate the effect of magnetic iron core-carbon shell nanoparticles on displacement mechanisms of crude oil for chemical enhanced oil recovery

Betancur

Olmos

Pérez

et al. 2020

Journal of Petroleum Science and Engineering

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Section: Displacement Testsmentioning

confidence: 99%

A microfluidic study to investigate the effect of magnetic iron core-carbon shell nanoparticles on displacement mechanisms of crude oil for chemical enhanced oil recovery

Betancur

Olmos

Pérez

et al. 2020

Journal of Petroleum Science and Engineering

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“…To overcome these limitations, pore-scale measurements have gained popularity in recent years. These measurements can be conducted through micromodel flooding experiments or pore network modeling simulations. ,− Microscale approaches operate at a scale that is similar to the dimensions of the pores in an actual porous medium. These methods account for the influence of pore geometry and are applicable for visualizing flow in single or multiple phases. ,, Building upon this approach, Vogel and Roth found, using 3D pore network modeling, that the shape and connectivity of the pores in the pore space are both critical factors.…”

Section: Introductionmentioning

confidence: 99%

Real-Time Pore-Scale Investigation of the Effects of Uniform, Random, and Heterogenous Porous Structures on Intrinsic Permeability Using Two-Dimensional Microfluidic Chips

Boumedjane,

Al-Maamari,

Rabbani

et al. 2024

Energy Fuels

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Permeability is a significant fluid flow property that is essential for the evaluation of oil recovery methods. The intrinsic permeability of a porous medium is influenced by factors such as the size distribution of pores and pore throats, the connectivity between pores, the topology of the pores, and the geometry of individual pores. Yet, it is not well understood how multiple elements of pore geometry interact to affect permeability due to the complex and heterogeneous nature of porous structures. This study examines the real-time porescale effects of uniform, random, and heterogeneous porous structures on intrinsic permeability, considering the broader complexity of the pore network as a single unit. The intrinsic permeability exhibited a negative correlation with increasing heterogeneity of the porous structure regardless of whether the porosities were the same or different. At a porosity of 0.59, the uniform pattern exhibited a permeability of 4.07 Darcy, while the heterogeneous pattern had a permeability of 2.37 Darcy. The random pattern demonstrated greater permeability (2.57 Darcy) at a lower porosity (0.47) in comparison to that of the heterogeneous network. Pore-scale experiments and simulations have demonstrated the significant influence of the pore network topology on the intrinsic permeability. As the complexity and heterogeneity of porous structures increase, the combined effect of morphological characteristics on intrinsic permeability becomes more significant than the individual influence of each morphological property. The differences in permeability observed in the experiments were attributed to the presence of stagnant water zones, which could be permanent or temporary. Stagnant water is more likely to be permanent in homogeneous patterns than in heterogeneous patterns. Heterogeneity appeared to promote water movement and redistribution because of variations in local pressure due to variations in pore sizes. The presence of dead-end pores in the random pattern led to a slight fluctuation in the experimental permeability. However, this effect was more prominent in the simulated permeability. Our study found experimental and numerical evidence that the broader heterogeneity of the porous structure significantly impacts permeability. Moreover, it highlights the importance of accounting for the actual microscopic porous structure of the reservoir being targeted when microfluidic devices are employed for enhanced oil recovery techniques.

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“…Moreover, such studies can be both experimental and numerical. However, at the moment all this remains at the level of an idea, and there are not very many such works [5][6][7][8]. There is also a large number of works that show enhanced oil recovery when using nanofluids as a displacing agent.…”

Section: Introductionmentioning

confidence: 99%

The investigation of the efficiency of oil displacing from the pore in the rock formation depending on the width and height of the pore using nanosuspension as a displacing agent

Lobasov

Минаков

2021

J. Phys.: Conf. Ser.

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The numerical investigation of the two-phase fluid flow in a microchannel was carried out. The effect of the pore width and height on the oil displacing efficiency by nanofluids for various Reynolds numbers was studied. The computational domain was a T-shaped microchannel with a horizontal main flow channel and a vertical channel that imitated the pore in the rock formation, called a pore channel. The main channel width and height were 200 µm, and the pore channel width and height were varied in the range from 100 µm to 800 µm. The Reynolds number was varied from 0.1 to 100. The main studied characteristic was the oil recovery coefficient, defined as the ratio of the volume of oil remaining in the pore to the volume of the pore. That characteristic, obtained for a case, when the nanofluid was used as a displacing agent, was compared to the similar one obtained for a case, when pure water was used as a displacing agent. A single-phase fluid with properties, determined experimentally, was considered the nanofluid. The mass concentrations of SiO2 nanoparticles were 0.25% and 0.5%. The average diameter of nanoparticles was equal to 5 nm. It was found, that the oil recovery coefficient increased with an increase in width of the pore channel and a decrease in its height. It was obtained that the nanofluid can enhance the oil recovery in several times as compared to pure water. It was also found that the main factor affecting the efficiency of oil recovery is the contact angle of wetting.

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Design and analysis of different models of microfluidic devices evaluated in Enhanced Oil Recovery (EOR) assays

Cited by 5 publications

References 25 publications

A microfluidic study to investigate the effect of magnetic iron core-carbon shell nanoparticles on displacement mechanisms of crude oil for chemical enhanced oil recovery

A microfluidic study to investigate the effect of magnetic iron core-carbon shell nanoparticles on displacement mechanisms of crude oil for chemical enhanced oil recovery

Real-Time Pore-Scale Investigation of the Effects of Uniform, Random, and Heterogenous Porous Structures on Intrinsic Permeability Using Two-Dimensional Microfluidic Chips

The investigation of the efficiency of oil displacing from the pore in the rock formation depending on the width and height of the pore using nanosuspension as a displacing agent

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