Application of Fractional Flow Theory for Analytical Modeling of Surfactant Flooding, Polymer Flooding, and Surfactant/Polymer Flooding for Chemical Enhanced Oil Recovery

Ding, Lianhui; Wu, Qianhui; Zhang, Lei; Guérillot, Dominique

doi:10.3390/w12082195

Cited by 32 publications

(8 citation statements)

References 66 publications

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“…The saturation vs the length curves from the interacting multi-capillary system are consistent with the observations from the imbibition phenomena in porous media described by Dong et al, Ding et al, Debbabi et al, and Akbari et al, 47,[55][56][57] . Further, it was also experimentally shown by Bico and Quéré that, the propagating fluid front in a porous medium has two fronts; a leading microscopic front and a lagging macroscopic front 58 .…”

Section: Comparison Of Bundle-of-tubes Model and Interacting Multi-ca...supporting

confidence: 88%

Spontaneous imbibition dynamics in interacting multi-capillary systems: A generalized model

Ashraf,

Méheust,

Phirani

2020

Preprint

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Bundle-of-tubes model was previously used to understand the flow behaviour in a porous medium. The interacting nature of the pores within a porous medium can be well depicted by an interacting capillary model. However, the arrangement of pores is crucial in understanding the flow behaviour in an interacting capillary system, which also leads to different governing equations of spontaneous imbibition. To this end, in the present work, we first develop a generalized one-dimensional lubrication approximation model to predict the imbibition behaviour in an interacting multi-capillary system. Using our generalized model, we observe that the flow dynamics, the capillary having the leading meniscus and the breakthrough time are governed by the contrast in the radii and the arrangement of the capillaries. We also show that during breakthrough, the saturation of the multi-capillary system depends on the arrangement of the capillaries. We show that the breakthrough in the bundle-of-tubes model occurs at a dimensionless time of 0.5, while the breakthrough in the interacting capillary system occurs between the dimensionless times 0.31 and 0.42, for the capillary system considered in this study. Comparing the interacting multi-capillary system with the bundle-of-tubes model, we present substantial deviations and show that the interacting capillary system is closer to the real porous medium.

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Section: Comparison Of Bundle-of-tubes Model and Interacting Multi-ca...supporting

confidence: 88%

Spontaneous imbibition dynamics in interacting multi-capillary systems: A generalized model

Ashraf,

Méheust,

Phirani

2020

Preprint

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“…As the interface is a moving boundary, the effect of interfacial tension is considered in the equation of motion. The equation of motion is expressed as follows:

where σ represents the interfacial tension between the polymer solution and the oil (mN/m; considered as a constant value in this study);

represents the remaining oil surface including point x B ;

represents the curvature of the remaining oil surface; n represents the external method of the remaining oil surface to the unit vector; δ (x−x B ) represents the second-order δ function; and T represents the stress tensor [ 43 ].…”

Section: Methodsmentioning

confidence: 99%

Influence of Polymer Viscoelasticity on Microscopic Remaining Oil Production

et al. 2022

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To investigate the impact of polymer viscoelasticity on microscopic remaining oil production, this study used microscopic oil displacement visualisation technology, numerical simulations in PolyFlow software, and core seepage experiments to study the viscoelasticity of polymers and their elastic effects in porous media. We analysed the forces affecting the microscopic remaining oil in different directions, and the influence of polymer viscoelasticity on the displacement efficiency of microscopic remaining oil. The results demonstrated that the greater the viscosity of the polymer, the greater the deformation and the higher the elasticity proportion. In addition, during the creep recovery experiment at low speed, the polymer solution was mainly viscous, while at high speed it was mainly elastic. When the polymer viscosity reached 125 mPa·s, the core effective permeability reached 100 × 10−3 μm2, and the equivalent shear rate exceeded 1000 s−1, the polymer exhibited an elastic effect in the porous medium and the viscosity curve displayed an ‘upward’ phenomenon. Moreover, the difference in the normal deviatoric stress and horizontal stress acting on the microscopic remaining oil increased exponentially as the viscosity of the polymer increased. The greater the viscosity of the polymer, the greater the remaining oil deformation. During the microscopic visualisation flooding experiment, the viscosity of the polymer, the scope of the mainstream line, and the recovery factor all increased. The scope of spread in the shunt line area significantly increased, but the recovery factor was significantly lower than that in the mainstream line. The amount of remaining oil in the unaffected microscopic area also decreased.

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“…However, the residual oil saturations for foam and water–gas flooding may be identical. This is probably because the increase in viscous force and capillary number during FF may not be sufficient to decrease the residual oil saturation. , Note that the interfacial tension between 0.5 wt % APG (in SSB) and crude oil is 0.879 mN/m at 131 °F. The oil recovery during continuous surfactant injection was only 0.6% OOIP under oil-wet conditions (Section S.6).…”

Section: Resultsmentioning

confidence: 99%

Probing the Effect of Wettability on Transport Behavior of Foam for Enhanced Oil Recovery in a Carbonate Reservoir

Ding

et al. 2021

Energy Fuels

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Foam for enhanced oil recovery in carbonate reservoirs is generally challenging because the oil-wet formation is not favorable for generating and stabilizing the lamellae. With an alkyl-polyglucoside surfactant, a series of foam core flooding experiments both in the absence and in the presence of crude oil were performed on Estaillades limestone, a dual porosity and heterogeneous carbonate presenting reasonable similarities with the reservoir formation. The effects of wettability, surfactant concentration, and foam quality on foam strength were systematically investigated. It is found that the foam strength in the presence of oil is generally smaller than that in the absence of oil, and the foam strength in the oil-wet condition is typically lower than that in the water-wet condition. However, for the water-wet condition, the foam strength can be greatly improved by increasing the surfactant concentration, which is getting closer to that in the absence of crude oil at a sufficiently high surfactant concentration. The combined effect of a high remaining oil saturation and the disadvantageous wettability can further destabilize foam, thereby greatly reducing the foam strength at oil-wet conditions. As a result, the foam flooding under the water-wet condition outperforms that at the oil-wet condition. Furthermore, it is found that the foam behavior at a high gas fraction is more sensitive to the wettability of rock and the foam hysteresis effect.

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Application of Fractional Flow Theory for Analytical Modeling of Surfactant Flooding, Polymer Flooding, and Surfactant/Polymer Flooding for Chemical Enhanced Oil Recovery

Cited by 32 publications

References 66 publications

Spontaneous imbibition dynamics in interacting multi-capillary systems: A generalized model

Spontaneous imbibition dynamics in interacting multi-capillary systems: A generalized model

Influence of Polymer Viscoelasticity on Microscopic Remaining Oil Production

Probing the Effect of Wettability on Transport Behavior of Foam for Enhanced Oil Recovery in a Carbonate Reservoir

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