Surfactant adsorption behaviors onto shale from Malaysian formations: Influence of silicon dioxide nanoparticles, surfactant type, temperature, salinity and shale lithology

Yekeen, Nurudeen; Padmanabhan, Eswaran; Idris, Ahmad Kamal; Ibad, Syed Muhammad

doi:10.1016/j.petrol.2019.04.096

Cited by 77 publications

(40 citation statements)

References 42 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The samples were then shaken for 1 h using an Orbital shaker and afterward sonicated for 1 h in a sonicator (QSonica, Q500) at a frequency of 20 kHz and 500 watts. Similar methods have been employed in previous studies (Yekeen et al 2019b). All the solutions were prepared with 3 wt% NaCl solution to simulate the formation water.…”

Section: Methodsmentioning

confidence: 99%

“…Generally, surfactant-stabilized foam generation and stability depends on the CMC of the surfactant (Kumar and Mandal 2017). The CMC is the surfactant concentration at which aggregation of surfactant molecules and formation of micelles occur (Yekeen et al 2019b). Any extra surfactant molecules added to the system beyond the CMC are involves in micelle formation.…”

Section: Critical Micelle Concentration (Cmc) Of the Surfactantmentioning

confidence: 99%

See 1 more Smart Citation

Characterization of lauryl betaine foam in the Hele-Shaw cell at high foam qualities (80%–98%)

et al. 2020

Self Cite

View full text Add to dashboard Cite

Lauryl betaine (LB) as an amphoteric surfactant carries both positive and negative charges and should be able to generate stable foam through electrostatic interaction with nanoparticles and co-surfactants. However, no previous attempts have been made to investigate the influence of nanoparticles and other co-surfactants on the stability and apparent viscosity of LB-stabilized foam. In this study, a thorough investigation on the influence of silicon dioxide (SiO2) nanoparticles, alpha olefin sulfonate (AOS) and sodium dodecyl sulfate (SDS), on foam stability and apparent viscosity was carried out. The experiments were conducted with the 2D Hele-Shaw cell at high foam qualities (80%–98%). Influence of AOS on the interaction between the LB foam and oil was also investigated. Results showed that the SiO2-LB foam apparent viscosity decreased with increasing surfactant concentration from 0.1 wt% to 0.3 wt%. 0.1 wt% SiO2 was the optimum concentration and increased the 0.1 wt% LB foam stability by 108.65% at 96% foam quality. In the presence of co-surfactants, the most stable foam, with the highest apparent viscosity, was generated by AOS/LB solution at a ratio of 9:1. The emulsified crude oil did not imbibe into AOS-LB foam lamellae. Instead, oil was redirected into the plateau borders where the accumulated oil drops delayed the rate of film thinning, bubble coalescence and coarsening.

show abstract

Section: Methodsmentioning

confidence: 99%

Section: Critical Micelle Concentration (Cmc) Of the Surfactantmentioning

confidence: 99%

Characterization of lauryl betaine foam in the Hele-Shaw cell at high foam qualities (80%–98%)

et al. 2020

Self Cite

View full text Add to dashboard Cite

show abstract

“…The 2 wt. % KCl concentration was used to verify the better interaction of the displacing fluid solution with the reservoir's rock, since the reservoir water presents salinity, and this interferes with the CMC value of the surfactant by the competition of salt with the hydrophilic group of surfactants in water solubility, as well as rock wettability [10,[20][21][22][23].…”

Section: Surfactant Solutions Propertiesmentioning

confidence: 99%

“…The experiments concerning the dynamic adsorption were carried out in 200 mL Erlenmeyer flasks at 28 • C, 40 • C and 60 • C, on a continuously stirred Dubnoff shaker bath for 24 h to reach equilibrium [20]. Each batch was performed with 8 sample flasks, with constant adsorbent mass of 1 g and constant volume of 90 mL of solution, with varying concentrations of surfactant solution and glycerol.…”

Section: Adsorption Testmentioning

confidence: 99%

Study of Enhanced Oil Recovery and Adsorption Using Glycerol in Surfactant Solution

et al. 2020

View full text Add to dashboard Cite

Over time, oil production in a reservoir tends to decrease, which makes it difficult to flow through the reservoir to the well, making its production increasingly difficult and costly. Due to their physical properties, such as reducing the water/oil interfacial tension, surfactants have been used in enhanced oil recovery (EOR) processes, however, their adsorption presents as an undesirable and inevitable factor and can decrease the efficiency of the method. This work’s main objective is to evaluate the effect of glycerol in the adsorption of surfactants in sandstones, as well as in the recovery factor during EOR. Brine solutions containing the nonionic surfactant saponified coconut oil (SCO), with and without glycerol, were used in the adsorption and oil recovery tests in sandstone. Adsorption, recovery, rheological, and thermogravimetric analysis were carried out. Regarding the surfactant/glycerol/brine solution, there was an improvement in the oil mobility, as the glycerol contributed to an increase in the viscosity of the solution, thereby increasing the sweep efficiency. The recovery factor obtained for the surfactant solution with glycerol was satisfactory, being 53% higher than without glycerol, because it simultaneously provided an increase in viscosity and a decrease in interfacial tension, both of which are beneficial for the efficiency of the process.

show abstract

“…1) (Wu et al 2017;De Avila et al 2016;Venancio et al 2020). Yekeen et al (2019) studied the amount of adsorption of different surfactants (CTAB, SDBS, Triton X-100) on Malaysia shale rock in the presence and absence of SiO 2 NPs. Maximum 49.83% and 81.33% reduction in the adsorbed surfactant on pore walls was reported at 3 wt% NaCl salinity and high temperature (80 °C), respectively.…”

Section: Introductionmentioning

confidence: 99%

Nanomaterials for subsurface application: study of particles retention in porous media

Nourafkan

Garum

et al. 2021

Appl Nanosci

View full text Add to dashboard Cite

The ability to transport nanoparticles through porous media has interesting engineering applications, notably in reservoir capacity exploration and soil remediation. A series of core-flooding experiments were conducted for quantitative analysis of functionalized TiO2 nanoparticles transport through various porous media including calcite, dolomite, silica, and limestone rocks. The adsorption of surfactants on the rock surface and nanoparticle retention in pore walls were evaluated by chemical oxygen demand (COD) and UV–Vis spectroscopy. By applying TiO2 nanoparticles, 49.3 and 68.0 wt.% of surfactant adsorption reduction were observed in pore walls of dolomite and silica rock, respectively. Not surprisingly, the value of nanoparticle deposition for dolomite and silica rocks was near zero, implying that surfactant adsorption is proportional to nanoparticle deposition. On the other hand, surfactant adsorption was increased for other types of rock in presence of nanoparticles. 5.5, 13.5, and 22.4 wt.% of nanoparticle deposition was estimated for calcite, black and red limestone, respectively. By making a connection between physicochemical rock properties and nanoparticle deposition rates, we concluded that the surface roughness of rock has a significant influence on mechanical trapping and deposition of nanoparticles in pore-throats.

show abstract

Surfactant adsorption behaviors onto shale from Malaysian formations: Influence of silicon dioxide nanoparticles, surfactant type, temperature, salinity and shale lithology

Cited by 77 publications

References 42 publications

Characterization of lauryl betaine foam in the Hele-Shaw cell at high foam qualities (80%–98%)

Characterization of lauryl betaine foam in the Hele-Shaw cell at high foam qualities (80%–98%)

Study of Enhanced Oil Recovery and Adsorption Using Glycerol in Surfactant Solution

Nanomaterials for subsurface application: study of particles retention in porous media

Contact Info

Product

Resources

About