Research of the heavy oil displacement mechanism by using alkaline/surfactant flooding system

Chen, Lifeng; Zhang, Guicai; Ge, Jijiang; Jiang, Ping; Jin-yu, Tang; Liu, Yueliang

doi:10.1016/j.colsurfa.2013.05.035

Cited by 98 publications

(57 citation statements)

References 18 publications

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“…Chen et al (2013) indicated that alkyl polyglucosides have strong potential to create stable, high dispersed emulsions. Figure 1 shows the results obtained for tested Glucopons in an emulsification test.…”

Section: Surfactants Characteristicmentioning

confidence: 98%

Alkyl polyglucosides as cell surface modification factors: influence of the alkyl chain length

Smułek

Zdarta

Milewska

et al. 2015

Toxicological & Environmental Chemistry

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The use of surfactants in a bioremediation process is aimed at increasing the efficiency of the removal of hydrophobic contaminants from the environment. The subject of the study were three alkyl polyglucosides of different alkyl chain length: Glucopon 215 CS UP, Glucopon 600 CS UP and Glucopon 650 EC. The impact of these surfactants on the surface properties of the test strain Pseudomonas fluorescens ATCC 14700, as well as on the biodegradation of diesel was tested.It was observed, that the length of alkyl chain has an influence on the cell surface properties. The modification of the cell surface hydrophobicity and the electrokinetic potential on the bacteria cells is dependent on the structure of Glucopon molecules. The elongation of alkyl chains in surfactant molecule caused an increase of the hydrophobic properties and a reduction of the electrokinetic potential on the bacteria cells. Moreover, the use of alkyl polyglucosides below critical micelle concentration caused an increase of diesel oil biodegradation, especially in the case Glucopons with longer alkyl chain (Glucopon 600 CS UP and 650 EC). The better diesel oil removal by tested strain after surfactant addition was correlated with the hydrophobic properties of bacteria strain.

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Section: Surfactants Characteristicmentioning

confidence: 98%

Alkyl polyglucosides as cell surface modification factors: influence of the alkyl chain length

Smułek

Zdarta

Milewska

et al. 2015

Toxicological & Environmental Chemistry

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“…The relative permeability curve is essential to describe the complicated multiphase flow characteristics in porous media (Masihi et al 2011;Chen et al 2013). In general, water-oil or oil-gas relative permeability data can be obtained from steady-or unsteady-state displacement experiments with core samples.…”

Section: Introductionmentioning

confidence: 99%

Estimation of the water–oil–gas relative permeability curve from immiscible WAG coreflood experiments using the cubic B-spline model

Wang

Sun

et al. 2016

Pet. Sci.

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Immiscible water-alternating-gas (WAG) flooding is an EOR technique that has proven successful for water drive reservoirs due to its ability to improve displacement and sweep efficiency. Nevertheless, considering the complicated phase behavior and various multiphase flow characteristics, gas tends to break through early in production wells in heterogeneous formations because of overriding, fingering, and channeling, which may result in unfavorable recovery performance. On the basis of phase behavior studies, minimum miscibility pressure measurements, and immiscible WAG coreflood experiments, the cubic B-spline model (CBM) was employed to describe the three-phase relative permeability curve. Using the Levenberg-Marquardt algorithm to adjust the vector of unknown model parameters of the CBM sequentially, optimization of production performance including pressure drop, water cut, and the cumulative gas-oil ratio was performed. A novel numerical inversion method was established for estimation of the water-oil-gas relative permeability curve during the immiscible WAG process. Based on the quantitative characterization of major recovery mechanisms, the proposed method was validated by interpreting coreflood data of the immiscible WAG experiment. The proposed method is reliable and can meet engineering requirements. It provides a basic calculation theory for implicit estimation of oil-water-gas relative permeability curve.

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“…Following on from the research into chemical flooding in light-oil reservoirs, the IFT behavior of heavy oil-chemical systems has been much investigated, and ultralow IFT has also been suggested for heavy oil recovery applications by some researchers (as it is for light oil). [10][11][12][13][14] Nevertheless, a progressive understanding of the heavy oil recovery mechanism is gradually formed such that the role of the emulsification mechanism should be more emphasized in extending the sweep volume 16,17 and recovering heavy oil compared to conventional ultralow IFT. It is believed that, as the heavy oil is very vicious, the poor sweep efficiency (caused by the consequent adverse water-oil mobility ratio) is the primary problem needing to be resolved by SP flooding instead of the conventional displacement efficiency (for light oil).…”

Section: Introductionmentioning

confidence: 99%

“…[7][8][9] Adding alkali is cheap and can significantly contribute to water-oil interfacial tension (IFT) reduction, oil-in-water (O/W), or water-in-oil (W/O) emulsification when recovering heavy oil. [10][11][12][13][14] Nevertheless, a progressive understanding of the heavy oil recovery mechanism is gradually formed such that the role of the emulsification mechanism should be more emphasized in extending the sweep volume 16,17 and recovering heavy oil compared to conventional ultralow IFT. Hence, alkali flooding has not yet been used industrially.…”

mentioning

confidence: 99%

Performance of a good‐emulsification‐oriented surfactant‐polymer system in emulsifying and recovering heavy oil

Wang

Ding

et al. 2019

Energy Science & Engineering

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Considering the significant importance of emulsification for heavy oil recovery, a good‐emulsification‐oriented (GEO) (rather than the conventional ultralow interfacial tension (IFT) oriented) surfactant‐polymer (SP) system was employed to remove heavy oil. Specifically, the emulsification behavior and viscosity‐reduction property of heavy oil in porous media were first studied by flood tests. Then, such a GEO SP was used to displace heavy oil for recovery measurement. It is found that first, as migration increases in porous media, the in situ emulsified oil droplets evolve into smaller and more uniform droplets (without coalescence), thus, exhibit self‐adjustment ability to match with, and plug, the pores. An increase in surfactant content and seepage velocity also makes the emulsion's particles smaller and more uniformly distributed. Second, such oil‐in‐water emulsification indeed helps to reduce heavy oil viscosity in porous media and there is an optimal surfactant content for such viscosity reduction: The lower the water cut, the greater the optimal surfactant content, the worse the viscosity‐reduction effect. Third, on its own, the GEO surfactant performs very poorly in recovering heavy oil and is even worse than the single polymer; therefore, such a surfactant should be jointly used with a polymer in an SP system instead of on its own, but an excessive surfactant content in the SP seems to hinder the recovery, while the large slug size tends to contribute significantly to an improved oil recovery.

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Research of the heavy oil displacement mechanism by using alkaline/surfactant flooding system

Cited by 98 publications

References 18 publications

Alkyl polyglucosides as cell surface modification factors: influence of the alkyl chain length

Alkyl polyglucosides as cell surface modification factors: influence of the alkyl chain length

Estimation of the water–oil–gas relative permeability curve from immiscible WAG coreflood experiments using the cubic B-spline model

Performance of a good‐emulsification‐oriented surfactant‐polymer system in emulsifying and recovering heavy oil

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