Foams: Basic Principles

Schramm, Laurier L.; Wassmuth, F.R.

doi:10.1021/ba-1994-0242.ch001

Cited by 119 publications

(122 citation statements)

References 20 publications

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“…Foams are employed for mobility control in situations where polymers, gas or water alternating gas injection schemes are not feasible due to unfavorable conditions, such as low permeability, formation heterogeneity and high temperature-high salinity conditions beyond the polymer stability window. Foam injection has advantages over simple gas injection, and it is demonstrated that the use of foam can mitigate gas channeling, improve apparent gas density and hinder gas escape through high-permeability zones to achieve good oil recovery (Julio and Emanuel 1989;Huh and Rossen 2008;Lee et al 1991;Schramm and Wassmuth 1994). Foams are reviewed in detail in Sect.…”

Section: Foams Wettability Alteration and Lowering Of Interfacial Tementioning

confidence: 99%

Review of surfactant-assisted chemical enhanced oil recovery for carbonate reservoirs: challenges and future perspectives

et al. 2017

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Section: Foams Wettability Alteration and Lowering Of Interfacial Tementioning

confidence: 99%

Review of surfactant-assisted chemical enhanced oil recovery for carbonate reservoirs: challenges and future perspectives

et al. 2017

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“…Several of these techniques involve injection of gas (CO 2 , hydrocarbon gas, steam or N 2 ), which face the additional challenge that they are less dense than the oil; they tend to rise to the top of the reservoir and override most of the oil. Foam improved oil recovery (abbreviated here as 'foam IOR') can address the problems of viscous instability, geological heterogeneity and gravity override (Kovscek & Radke 1994;Rossen 1996;Schramm & Wassmuth 1994), with gravity segregation (i.e. override) being worst if the reservoir is relatively homogeneous (Shan & Rossen 2004).…”

Section: Introductionmentioning

confidence: 99%

Analysis of a model for foam improved oil recovery

et al. 2014

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(Received ?; revised ?; accepted ?. -To be entered by editorial office)During improved oil recovery, gas may be introduced into a porous reservoir filled with surfactant solution in order to form foam. A model for the evolution of the resulting foam front known as 'pressure-driven growth' is analysed. An asymptotic solution of this model for long times is derived that shows that foam can propagate indefinitely into the reservoir without gravity override. Moreover 'pressure-driven growth' is shown to correspond to a special case of the more general 'viscous froth' model. In particular, it is a singular limit of the viscous froth, corresponding to the elimination of a surface tension term, permitting sharp corners and kinks in the predicted shape of the front. Sharp corners tend to develop from concave regions of the front. The principal solution of interest has a convex front, however, so that although this solution itself has no sharp corners (except for some kinks that develop spuriously owing to errors in a numerical scheme), it is found nevertheless to exhibit milder singularities in front curvature, as the long-time asymptotic analytical solution makes clear. Numerical schemes for the evolving front shape which perform robustly (avoiding the development of spurious kinks) are also developed. Generalisations of this solution to geologically heterogeneous reservoirs should exhibit concavities and/or sharp corner singularities as an inherent part of their evolution: propagation of fronts containing such 'inherent' singularities can be readily incorporated into these numerical schemes.

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“…In the last three decades, foam has been widely used as a mobility control agent in Enhanced Oil Recovery (EOR) (Schramm 1994;Rossen 1996;Heller 1987), gas blocking (Hanssen and Dalland 1994), and acid diversion during matrix stimulation (Rossen 1996). Foam remains one of the most attractive EOR options, especially in maturing oil fields.…”

Section: Introductionmentioning

confidence: 99%

Numerical Analysis of Foam Motion in Porous Media Using a New Stochastic Bubble Population Model

Zitha

Vermolen

2010

Transp Porous Med

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We present a numerical analysis of the stochastic population balance (SPB) theory for foam motion in porous media. The theory condenses into a set of non-linear partial differential equations in the saturation, pressure, and bubble density. We solve the equations using the IMPES method and perform sensitivity and parametric analysis. Finally, we compare the saturation profiles obtained numerically with those obtained from CT scan foam experiments. The agreement between the theory and experiments confirms that the stochastic population balance model describes adequately foam dynamics in porous media.

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Foams: Basic Principles

Cited by 119 publications

References 20 publications

Review of surfactant-assisted chemical enhanced oil recovery for carbonate reservoirs: challenges and future perspectives

Review of surfactant-assisted chemical enhanced oil recovery for carbonate reservoirs: challenges and future perspectives

Analysis of a model for foam improved oil recovery

Numerical Analysis of Foam Motion in Porous Media Using a New Stochastic Bubble Population Model

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