Effect of nano-SiO2 and surfactants on the oil-water interfacial properties

Jiang, Ping; Zhang, Lei; Tang, Dengyu; Li, Longjie; Ge, Jijiang; Zhang, Guicai; Pei, Haihua

doi:10.1007/s00396-019-04514-5

Cited by 13 publications

(5 citation statements)

References 41 publications

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“…Studying the response of the interfacial layer to compression and dilatation could provide additional information beyond the IFT measurements. Specifically, it can provide information regarding how the particles are assembled at the interface and the “strength” of the interfacial layer. , Figure A shows the equilibrium dilatational modulus at different pHs. At pH 2, there are no significant changes to the interfacial modulus from that in pure water, irrespective of the concentration used.…”

Section: Resultsmentioning

confidence: 99%

Probing the Interfacial Properties of Oil–Water Interfaces Decorated with Ionizable, pH Responsive Silica Nanoparticles

et al. 2023

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Particle-stabilized emulsions (Pickering emulsions) have recently attracted significant attention in scientific studies and for technological applications. The interest stems from the ease of directly assembling the particles at interfaces and modulating the interfacial properties. In this paper, we demonstrate the formation of stable, practical emulsions leveraging the assembly of ionizable, pH responsive silica nanoparticles, surface-functionalized by a mixture of silanes containing amine/ammonium groups, which renders them positively charged. Using pH as the trigger, the assembly and the behavior of the emulsion are controlled by modulating the charges of the functional groups of the nanoparticle and the oil (crude oil). In addition to their tunable charge, the particular combination of silane coupling agents leads to stable particle dispersions, which is critical for practical applications. Atomic force microscopy and interfacial tension (IFT) measurements are used to monitor the assembly, which is controlled by both the electrostatic interactions between the particles and oil and the interparticle interactions, both of which are modulated by pH. Under acidic conditions, when the surfaces of the oil and the nanoparticles (NPs) are positively charged, the NPs are not attracted at the interface and there is no significant reduction in the IFT. In contrast, under basic conditions in which the oil carries a high negative charge and the amine groups on the silica are deprotonated while still positively charged because of the ammonium groups, the NPs assemble at the interface in a closely packed configuration yielding a jammed state with a high dilatational modulus. As a result, two oil droplets do not coalesce even when pushed against each other and the emulsion stability improves significantly. The study provides new insights into the directed assembly of nanoparticles at fluid interfaces relevant to several applications, including environmental remediation, catalysis, drug delivery, food technology, and oil recovery.

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Section: Resultsmentioning

confidence: 99%

Probing the Interfacial Properties of Oil–Water Interfaces Decorated with Ionizable, pH Responsive Silica Nanoparticles

et al. 2023

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“…Testing the change in material surface wettability is crucial as it relates to the interaction between the material and the rock surface in subsurface environments. In some studies, the reduction in wettability angle after using nanosilica materials ranges between 20 • and 60 • , demonstrating significant improvement in wettability [52][53][54][55]. Additionally, Hendraningrat and Torsaeter achieved a change in contact angle from 54 • to 21 • using metal oxides such as TiO 2 .…”

Section: Materials Characterizationmentioning

confidence: 99%

The Role of Amphiphilic Nanosilica Fluid in Reducing Viscosity in Heavy Oil

Wang,

Zheng,

Zhang

et al. 2024

Energies

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Heavy oil accounts for a considerable proportion of the world’s petroleum resources, and its exploitation helps to mitigate reliance on conventional oil resources and diversify energy supply. However, due to the high viscosity and high adhesion characteristics of heavy oil, conventional methods such as thermal recovery, emulsification, and dilution have significant limitations and cannot meet the growing demands for heavy oil production. In this study, 3-propyltrimethoxysilane (MPS) was used to modify and graft amphiphilic surfactants (AS) onto nanosilica to prepare a salt-resistant (total mineralization > 8000 mg/L, Ca2+ + Mg2+ > 1000 mg/L) and temperature-resistant (250 °C) nanosilicon viscosity reducer (NSD). This article compares amphiphilic surfactants (AS) as conventional viscosity-reducing agents with NSD. FTIR and TEM measurements indicated successful bonding of 3-propyltrimethoxysilane to the surface of silica. Experimental results show that at a concentration of 0.2 wt% and a mineralization of 8829 mg/L, the viscosity reduction rates of thick oil (LD-1) before and after aging were 85.29% and 81.36%, respectively, from an initial viscosity of 38,700 mPa·s. Contact angle experiments demonstrated that 0.2 wt% concentration of NSD could change the surface of reservoir rock from oil-wet to water-wet. Interfacial tension experiments showed that the interfacial tension between 0.2 wt% NSD and heavy oil was 0.076 mN/m. Additionally, when the liquid-to-solid ratio was 10:1, the dynamic and static adsorption amounts of 0.2 wt% NSD were 1.328 mg/g-sand and 0.745 mg/g-sand, respectively. Furthermore, one-dimensional displacement experiments verified the oil recovery performance of NSD at different concentrations (0.1 wt%, 0.15 wt%, 0.2 wt%, 0.25 wt%) at 250 °C and compared the oil recovery efficiency of 0.2 wt% NSD with different types of demulsifiers. Experimental results indicate that the recovery rate increased with the increase in NSD concentration, and 0.2 wt% NSD could improve the recovery rate of heavy oil by 22.8% at 250 °C. The study of nano-demulsification oil recovery systems can effectively improve the development efficiency of heavy oil.

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“…In the pastes with SS and CTAB, the adsorption of emulsifier molecule at the oil-water interface between the aluminosilicate particles and the oil droplet surface would decrease the oil-water interfacial tension and the required energy for emulsification, which results in the decreased size of emulsion droplets and the average pore sizes in the geopolymers. It is worth noting that compared to the anionic surfactant SS, the cationic surfactant CTAB shows a stronger ability to reduce the oil-water interface tension [33], resulting in a smaller average pore size. Unlike the SS or CTAB, the addition of PAM does not bring about significant changes to the interfacial tension, the pore size of PAM is closely related to the size of solid particles.…”

Section: The Pore Structure Of Geopolymermentioning

confidence: 99%

Study on the effect of emulsifiers on the pore structures of geopolymer prepared by emulsion templating

Wang

2020

Mater. Res. Express

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The metakaolin-based porous geopolymer were prepared by emulsion templating method with sunflower oil as the template agent. The effects of the type of emulsifiers with different ionic properties, including sodium stearate (SS), polyacrylamide (PAM), and cetyltrimethylammonium bromide (CTAB), which are respectively belonging to anionic, nonionic and cationic emulsifiers, on the paste viscosity, mechanical strength and pore structure of geopolymer were studied. Fourier transform infrared spectroscopy (FTIR) was used to characterize the influence of emulsion template on the geopolymerization. Scanning electron microscope (SEM) and Image-Pro Plus (IPP) software were used to examine the pore structure of geopolymers, including pore size distribution, average size and roundness of pores. Results indicate that geopolymerization is not significantly affected by the incorporation of emulsion template, while the average size, shape and connectivity of pores in geopolymer were significantly influenced by the type of emulsifiers. With the addition of SS, PAM, and CTAB, the average pore size were 18.1, 27.4, and 11.7 μm, respectively, while the control is 18.9 μm. Both the shape regularity and open porosity of pores were increased with SS and PAM, while no significant changes with CTAB. It is promising to make geopolymer with controllable macro pore structure by adjusting the types of emulsifiers in emulsion templating method by adjusting the oilwater interfacial tension and the particle dispersion.

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Effect of nano-SiO2 and surfactants on the oil-water interfacial properties

Cited by 13 publications

References 41 publications

Probing the Interfacial Properties of Oil–Water Interfaces Decorated with Ionizable, pH Responsive Silica Nanoparticles

Probing the Interfacial Properties of Oil–Water Interfaces Decorated with Ionizable, pH Responsive Silica Nanoparticles

The Role of Amphiphilic Nanosilica Fluid in Reducing Viscosity in Heavy Oil

Study on the effect of emulsifiers on the pore structures of geopolymer prepared by emulsion templating

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