Foam stability in the presence and absence of hydrocarbons: From bubble- to bulk-scale

Osei-Bonsu, Kofi; Shokri, Nima; Grassia, Paul

doi:10.1016/j.colsurfa.2015.06.023

Cited by 221 publications

(113 citation statements)

References 51 publications

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“…These results are different from the Osei-Bonsu et al study [18]. In their work, the higher the viscosity and the density, the more stable the foam, and consequently the better the foam performance.…”

Section: Effect Of Oilcontrasting

confidence: 77%

“…They also pointed out that foam in the presence of oil was more sensitive to oil saturation than to oil type. However, according to Osei-Bonsu's work [18], both surfactant type and oil type play significant roles in foam performance when oil is present. Many studies have reported that light components are detrimental to foam while heavy components benefited foam stability [8,11,19,20].…”

Section: Introductionmentioning

confidence: 99%

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Experimental investigation of foam performance in the presence of crude oil

Pang

Wang

2017

J Surfact & Detergents

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The foam performance in the presence of oil plays an important role in foam application in enhancing oil recovery. The present study systematically investigated the effect of oil type, oil content, surfactant type, surfactant concentration, alkane chain length, salinity, and polymer concentration on foam performance in both the absence and presence of oil. The results showed that oil viscosity and oil density as well as oil component all contributed to foam performance in the presence of oil. Within a certain oil content, both light oil and heavy oil had a positive effect on foam, but heavy oil had a higher tendency to stabilize the foam. The order of foam performance by different surfactants was changed by the oil. It is noteworthy that heavy oil is detrimental to sodium dibutyl naphthalene sulfonate (BM) foam. Light oil can improve foam performance while heavy oil can harm foam in some specific cases. Lower salinity, longer alkane chain length, higher surfactant concentration and the presence of a polymer all benefited foam in the presence of crude oil.

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Section: Effect Of Oilcontrasting

confidence: 77%

Section: Introductionmentioning

confidence: 99%

Experimental investigation of foam performance in the presence of crude oil

Pang

Wang

2017

J Surfact & Detergents

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“…In fact, TX-100 foam with crude oil decayed in less than 5 min. The electrostatic double-layer effect resulting from charge interactions at the film interface is suppressed in nonionic surfactants, which was why the stability of TX-100 was very low (Osei-Bonsua et al 2015). Figure 3a shows the effect of the crude oil saturation on F q values at 0.7 wt% SDS.…”

Section: Effect Of Crude Oil and Its Saturationmentioning

confidence: 99%

Enhanced oil recovery by alkaline-surfactant-alternated-gas/CO2 flooding

Phukan

Gogoi

Tiwari

2018

J Petrol Explor Prod Technol

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The volumetric sweep efficiencies of CO 2 flooding for enhanced oil recovery (EOR) are generally low due to problems of viscous fingering and gravity override. This paper attempts to study a relatively new and promising method to reduce the mobility of CO 2 flooding and increase oil recovery under reservoir conditions. Referred to as alkaline-surfactant-alternatedgas/CO 2 (ASAG) flooding, this method is essentially the synergic combination of chemical and immiscible CO 2 flooding. In this work, chemical formulations were identified through foam stability tests based on their foaming ability coefficients.The selected formulations were further tested for their capabilities to reduce oil-water interfacial tensions (IFT) to ultra-low value. With the best performing formulations, the laboratory-scale core flooding experiments were conducted to evaluate their EOR potential. The core flooding experiments were performed with sandstone reservoir core samples from two different depths of a major depleted oil field of Upper Assam Basin, India. This study reports the successful application of a natural anionic surfactant (black liquor) as a co-surfactant and foaming agent during ASAG flooding. It was observed that higher oil recovery of 14.26% original oil in place (OOIP) was obtained by surfactant-alternated-gas (SAG) flooding compared to 12.03% OOIP by immiscible CO 2 alternated with brine (WAG) flooding. The highest residual oil recovery of 20% OOIP was obtained for ASAG flooding with the alkali, surfactant and black liquor in the chemical slug. Oil recovery performances during SAG and ASAG flooding were found to be better for core samples with lower porosity-permeability due to stronger foam formation in lower permeability cores.

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“…to downward migration of surfactant solution under gravity [11] or perhaps due to surfactant adsorbing onto pore walls), then the extent of the low mobility zone should be smaller than in the case of constant surfactant concentration: such complications are not however considered here. The presence of oil also helps to favour foam collapse [12], again tending to imply a low mobility zone of smaller extent.…”

Section: Introductionmentioning

confidence: 99%

Foam front propagation in anisotropic oil reservoirs

Grassia¹,

Torres-Ulloa

Berres

et al. 2016

Eur. Phys. J. E

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Abstract. The pressure-driven growth model is considered, describing the motion of a foam front through an oil reservoir during foam improved oil recovery, foam being formed as gas advances into an initially liquid-filled reservoir. In the model, the foam front is represented by a set of so-called "material points" that track the advance of gas into the liquid-filled region. According to the model, the shape of the foam front is prone to develop concave sharply curved concavities, where the orientation of the front changes rapidly over a small spatial distance: these are referred to as "concave corners". These concave corners need to be propagated differently from the material points on the foam front itself. Typically the corner must move faster than those material points, otherwise spurious numerical artifacts develop in the computed shape of the front. A propagation rule or "speed up" rule is derived for the concave corners, which is shown to be sensitive to the level of anisotropy in the permeability of the reservoir and also sensitive to the orientation of the corners themselves. In particular if a corner in an anisotropic reservoir were to be propagated according to an isotropic speed up rule, this might not be sufficient to suppress spurious numerical artifacts, at least for certain orientations of the corner. On the other hand, systems that are both heterogeneous and anisotropic tend to be well behaved numerically, regardless of whether one uses the isotropic or anisotropic speed up rule for corners. This comes about because, in the heterogeneous and anisotropic case, the orientation of the corner is such that the "correct" anisotropic speed is just very slightly less than the "incorrect" isotropic one. The anisotropic rule does however manage to keep the corner very slightly sharper than the isotropic rule does.

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Foam stability in the presence and absence of hydrocarbons: From bubble- to bulk-scale

Cited by 221 publications

References 51 publications

Experimental investigation of foam performance in the presence of crude oil

Experimental investigation of foam performance in the presence of crude oil

Enhanced oil recovery by alkaline-surfactant-alternated-gas/CO2 flooding

Foam front propagation in anisotropic oil reservoirs

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