Partitioning behaviour of novel surfactant mixture for high reservoir temperature and high salinity conditions

Belhaj, Ahmed Fatih; Shuhli, Juhairi Aris B M; Elraies, Khaled Abdalla; Mahmood, Syed Mohammad; Maulianda, Belladonna; Alnarabiji, Mohamad Sahban

doi:10.1016/j.energy.2020.117319

Cited by 37 publications

(19 citation statements)

References 59 publications

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“…These outcomes were ascribed to the interactions between nonionic and anionic surfactants on the silica/solution interface and the competitive adsorption. This explanation is also in line with our previous partitioning study [81] where it was found that there are interactions between APG and AEC in the APG/AEC mixture. Therefore, this clarifies that the presence of AEC in a mixture contributes in reducing the adsorption of APG and the predicted results from MEL model are in line with the experimental results in the literature.…”

Section: Resultssupporting

confidence: 92%

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Experimental investigation, binary modelling and artificial neural network prediction of surfactant adsorption for enhanced oil recovery application

Belhaj

Elraies

Alnarabiji

et al. 2021

Chemical Engineering Journal

108

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Section: Resultssupporting

confidence: 92%

“…The experimental uncertainty in the measurements using the HPLC method was approximately ± 0.01 wt.%. The method details, the process conditions, the detailed mobile phase gradients and the calibration curves were explained in details in our previous study [81] .…”

Section: Methodsmentioning

confidence: 99%

Experimental investigation, binary modelling and artificial neural network prediction of surfactant adsorption for enhanced oil recovery application

Belhaj

Elraies

Alnarabiji

et al. 2021

Chemical Engineering Journal

108

View full text Add to dashboard Cite

show abstract

“…High temperatures increase solubility of the surfactants hydrophobic tail in the water and move the surfactant to the oil-water interface causing a reduction in IFT [5,46]. Besides, high temperature makes easier for surfactant enter to the oil phase, because of oil viscosity reduction [4]. According to the above data criteria obtained by the authors, substantial foaming-agent loss was observed at the beginning of each experiment and partition coefficient tends to increase its value as temperature increases.…”

Section: Phase Partitioning and Temperaturementioning

confidence: 85%

“…They also evaluated phase partitioning behavior of anionic tensoactive, after one day of exposure, known as alkyl ether carboxylate (AEC) with some initial surfactant concentrations at different brine/oil ratios, high temperatures and atmospheric pressure, one example is shown in figure 12. Kp values for all scenarios were higher at 106°C as compared with 80°C after one day of exposure [4]. High temperatures increase solubility of the surfactants hydrophobic tail in the water and move the surfactant to the oil-water interface causing a reduction in IFT [5,46].…”

Section: Phase Partitioning and Temperaturementioning

confidence: 90%

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Study of mechanisms responsible for foaming-agent loss in porous media at high-temperature conditions

Pantoja

Vargas

Navarro

2020

Rev.Fac.Ing.Univ.Antioquia

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Steam-foam processes require the correct selection of a surfactant agent resistant to high temperatures, stable over time, and capable of producing mobility reduction of the steam. A state-of-the-art revision allows identifying the main phenomena that could cause surfactant loss in porous medium. These phenomena are phase partitioning, adsorption, and thermal degradation, where phase partitioning could cause higher loss. Additionally, adsorption and phase partitioning have a direct relationship with the surfactant concentration below its critical micellar concentration. Reservoir conditions such as temperature, salinity and presence of clay are parameters that influence surfactant solution behavior. High temperatures in porous medium could reduce tensoactive loss by adsorption due to exothermic reactions. However, the foaming agent could be partitioned into oleic phase owing to viscosity reduction and molecules motion improvement towards crude oil. High concentrations of salt could increase adsorption measurements, produce surfactant preference to oil or even precipitation. Surfactant solution should be formed by a mixture of components that provides stability during the steam injection process. Generally, the solution is composed mainly of an anionic surfactant. Some widely used surfactants are alkyl aryl sulfonates and alpha olefin sulfonates, suitable for steam procedures up to 300°C. Despite, non-ionic surfactants, and pH adjustment substance could be added to give foaming agent an improved performance.

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Advanced polymer‐based surfactant for improved heat and salinity stability in enhanced oil recovery processes

Soleimani,

Abdalisousan,

Manshad

et al. 2024

J Surfact & Detergents

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Enhancing oil recovery through surfactants has proven to be a successful strategy in recent times. However, traditional surfactants have their limitations, particularly in terms of stability under high temperatures and salinity levels. This study delved into a groundbreaking macromolecular polymeric surfactant, S‐AV, which holds the unique ability to transform rock surface characteristics, effectively stripping away residual oil while maintaining resilience against elevated temperatures and salinity. S‐AV was synthesized through a free‐radical copolymerization process, incorporating benzyl, perfluoroalkyl, alkyl‐, benzyl‐, ethylene glycol, and amide‐alkyl‐sulfonate groups, ultimately yielding a comb‐like molecular structure. S‐AV demonstrated exceptional prowess, swiftly reducing the underwater oil contact angle to 53.4° in just 48 h. This synthesized surfactant also retained its phase stability up to salinity levels of 36,000 ppm, with temperature having no disruptive impact on its phase stability performance. Furthermore, S‐AV showcased remarkable viscosity reduction in conditions of high temperature and salinity. The core flooding experiments underscored the potential of S‐AV, as its injection led to a significant oil recovery rate of up to 83%. These findings position S‐AV as a promising candidate for practical enhanced oil recovery applications.

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Partitioning behaviour of novel surfactant mixture for high reservoir temperature and high salinity conditions

Cited by 37 publications

References 59 publications

Experimental investigation, binary modelling and artificial neural network prediction of surfactant adsorption for enhanced oil recovery application

Experimental investigation, binary modelling and artificial neural network prediction of surfactant adsorption for enhanced oil recovery application

Study of mechanisms responsible for foaming-agent loss in porous media at high-temperature conditions

Advanced polymer‐based surfactant for improved heat and salinity stability in enhanced oil recovery processes

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