Foam stability in the presence of oil: Effect of surfactant concentration and oil type

Simjoo, Mohammad; Rezaei, T.; Andrianov, Alexey; Zitha, Pacelli L.J.

doi:10.1016/j.colsurfa.2013.05.062

Cited by 243 publications

(135 citation statements)

References 40 publications

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“…Recall that the FC coefficient was defined as a ratio of foam volume at the end of gas sparging, to total volume of gas injected. This inferrs injection of a larger volume of gas, and resulting a smaller value of the FC coefficient (Simjoo et al, 2013). From the data in Fig.…”

Section: Foamability and Foam Stability Tests 421 Effect Of Surfacmentioning

confidence: 97%

“…When the generated foam is not stable during the foaming process, the FC coefficient is less than unity, meaning that part of the injected gas has not been retained in the foam column. The MD coefficient was used to characterize the liquid retention in the generated foam and defined as a ratio of the liquid volume in the foam to the final foam volume (Simjoo et al, 2013).…”

Section: Static Foamscan Testsmentioning

confidence: 99%

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Systematic Phase Behaviour Study and Foam Stability Analysis for Optimal Alkaline/Surfactant/Foam Enhanced Oil Recovery

Nasab¹,

Zitha²

2015

Proceedings

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SUMMARYAlkaline-Surfactant-Foam (ASF) flooding is a recently introduced enhanced oil recovery (EOR) method. This paper presents laboratory study of this ASF to better understand its mechanisms. The focus is on the interaction of ASF chemical agents with oil and in the presence and absence of naphthenic component and in-situ soap generation. The impact of alkali, IFT reduction, in-situ soap generation and oil acid number were systematically studied by measurement of phase behaviour, interfacial tension and foam stability. Phase behaviour results indicate the synergistic effect between the generated soap and synthetic surfactant, which gives wider range of optimal salinity in terms of IFT reduction. The novel alkali-surfactant formulation lowered IFT between oil and aqueous phase from nearly 30 mN/m to 10-1 -10-3 mN/m. This means that chemical formulation can create low tension foam flooding with higher capillary number than conventional foam for displacing oil from porous media. In the foam stability analysis of ASF agent in the presence and absence of oil, several characteristics such as foam volume evolution, foam half decay time, liquid fraction of foam were measured over a wide range of surfactant, alkali, electrolyte and naphthenic acid concentration. Bulk foam stability tests demonstrated that stability of foam diminishes in presence of oil with high in-situ soap generation. The obtained results for foam stability in the presence of oil were successfully interpreted in terms of phenomenological theory of entering/spreading/bridging coefficient, lamella number and pseudo-emulsion film. The discussed method in this paper can be successfully applied to formulate high performance chemical agents for achievement of improved foam flooding according to reservoir fluid condition, i.e. properties of crude oil and formation water.

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Section: Foamability and Foam Stability Tests 421 Effect Of Surfacmentioning

confidence: 97%

Section: Static Foamscan Testsmentioning

confidence: 99%

Systematic Phase Behaviour Study and Foam Stability Analysis for Optimal Alkaline/Surfactant/Foam Enhanced Oil Recovery

Nasab¹,

Zitha²

2015

Proceedings

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“…Foamulsions with longer alkanes have been shown to be more stable [1,19] than those made from more soluble oils. The dual nature of the drops as stabilisers and antifoamobjects has even been used to make stimulable foamed emulsions, where they have been destroyed using UV-light or temperature [18,20].…”

Section: Introductionmentioning

confidence: 99%

“…The stability of foamed emulsions can be modulated by changing the type of stabilizer [17][18][19], as in oilfree foams, and by the choice of oil. Foamulsions with longer alkanes have been shown to be more stable [1,19] than those made from more soluble oils.…”

Section: Introductionmentioning

confidence: 99%

Foamed emulsion drainage: flow and trapping of drops

et al. 2017

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: Foamed emulsions are ubiquitous in our daily life but the ageing of such systems is still poorly understood. In this study we investigate foam drainage and measure the evolution of the gas, liquid and oil volume fractions inside the foam. We evidence three regimes of ageing. During an initial period of fast drainage, both bubbles and drops are very mobile. As the foam stabilises drainage proceeds leading to a gradual decrease of the liquid fraction and slowing down of drainage. Clusters of oil drops are less sheared, their dynamic viscosity increases and drainage slows down even further, until the drops become blocked. At this point the oil fraction starts to increase in the continuous phase. The foam ageing leads to an increase of the capillary pressure until the oil acts as an antifoaming agent and the foam collapses.

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“…There have been several studies on static and dynamic performance of foam-oil systems [12][13][14][15][16][17]. These studies have mainly focused on performing foam stability experiments (bulk tests) in the presence of different types of light oils and measuring the foam half-life.…”

Section: Introductionmentioning

confidence: 99%

Static and Dynamic Performance of Wet Foam and Polymer-Enhanced Foam in the Presence of Heavy Oil

Telmadarreie

Trivedi

2018

Colloids and Interfaces

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Abstract:Inadequate sweep efficiency is one of the main concerns in conventional heavy oil recovery processes. Alternative processes are therefore needed to increase heavy oil sweep efficiency. Foam injection has gained interest in conventional oil recovery in recent times as it can control the mobility ratio and improve the sweep efficiency over chemical or gas flooding. However, most of the studies have focused on light crude oil. This study aims to investigate the static and dynamic performances of foam and polymer-enhanced foam (PEF) in the presence of heavy oil. Static and dynamic experiments were conducted to investigate the potential of foam and PEF for heavy oil recovery. Static analysis included foam/PEF stability, decay profile, and image analysis. A linear visual sand pack was used to visualize the performance of CO 2 foam and CO 2 PEF in porous media (dynamic experiments). Nonionic, anionic, and cationic surfactants were used as the foaming agents. Static stability results showed that the anionic surfactant generated relatively more stable foam, even in the presence of heavy oil. Slower liquid drainage and collapse rates for PEF compared to that of foam were the key observations through foam static analyses. Besides improving heavy oil recovery, the addition of polymer accelerated foam generation and propagation in porous media saturated with heavy oil. Visual analysis demonstrated more stable frontal displacement and higher sweep efficiency of PEF compared to conventional foam flooding. Unlike foam injection, lesser channeling (foam collapse) was observed during PEF injection. The results of this study will open a new insight on the potential of foam, especially polymer-enhanced foam, for oil recovery of those reservoirs with viscous oil.

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Foam stability in the presence of oil: Effect of surfactant concentration and oil type

Cited by 243 publications

References 40 publications

Systematic Phase Behaviour Study and Foam Stability Analysis for Optimal Alkaline/Surfactant/Foam Enhanced Oil Recovery

Systematic Phase Behaviour Study and Foam Stability Analysis for Optimal Alkaline/Surfactant/Foam Enhanced Oil Recovery

Foamed emulsion drainage: flow and trapping of drops

Static and Dynamic Performance of Wet Foam and Polymer-Enhanced Foam in the Presence of Heavy Oil

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