Effect of Sodium Salicylate on the Properties of Gemini Surfactant Solutions

Ye, Zhongbin; Han, Lijuan; Chen, Hong; Shi, Leiting; Luo, Peng

doi:10.1007/s11743-009-1176-9

Cited by 10 publications

(4 citation statements)

References 30 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The addition of the surfactants up to 5 wt % can increase the temperature resistance of the systems to above 140 °C. However, it is obvious that the counterion salt also is of vital importance to the self-assembly behavior and system performances for the surfactants. − Therefore, the influence mechanism for counterions on the aggregation behavior of the surfactant micelles has been studied.…”

Section: High-temperature-resistant Ves Fracturing Fluidsmentioning

confidence: 99%

Review on High-Temperature-Resistant Viscoelastic Surfactant Fracturing Fluids: State-of-the-Art and Perspectives

Liu

et al. 2023

Energy Fuels

View full text Add to dashboard Cite

A viscoelastic surfactant (VES) fluid is an important part of a water-based fracturing fluid. As oil and gas exploration expands into deep, high-temperature, low-permeability reservoirs, the conventional VES fracturing fluid has shown great limitations. The high-temperature-resistance mechanisms of the high-temperature-resistant VES fracturing fluids in publicly available literature were analyzed from five aspects: single-chain surfactant system, oligomeric surfactant system, counterion effect, blended surfactant system, and nano-enhanced VES system. The friction-reduction performance, sand-carrying performance, gel-breaking performance, and core-damage performance of these systems were summarized. The results show that oligomeric surfactants with a monounsaturated hydrophobic long chain (>C21) are most likely to be used for VES fracturing fluids in high-temperature reservoirs, but the loading of the surfactants is still relatively high (3–5 wt %). By reducing the repulsion among polar headgroups to effectively decrease the area of head groups, or/and penetrating into the nonpolar cores based on hydrophobic interaction to increase the average hydrophobic volume of hydrophobic tails, counterions affect the performance of VESs. The aromatic counterion salts are preferred choices for improving the temperature resistance, friction reduction, and suspended sand performance of VES fluids. The blended surfactant/synthetic polymer systems based on noncovalent interaction improve the temperature resistance of VES fluids and reduce the loading of the surfactants to a certain extent. Based on the “pseudo-cross-linking” of nanomaterials and wormlike micelles, a very small amount of nanomaterials can improve the temperature resistance of VES fluids and reduce the loading of the surfactants. The most essential and effective method to improve the temperature resistance of VES fluids for fracturing is the molecular structure design based on the packing parameter theory. However, the synthesis process or route still needs further optimization to reduce production costs. In addition, given the excellent performance of VES fluids enhanced by nanomaterials, further research should be conducted on the influence mechanism of nanomaterial type and geometric features on the performance of VESs, as well as the potential harmfulness of nanomaterials, to promote the field-scale application of nano-enhanced VES fluids.

show abstract

Section: High-temperature-resistant Ves Fracturing Fluidsmentioning

confidence: 99%

Review on High-Temperature-Resistant Viscoelastic Surfactant Fracturing Fluids: State-of-the-Art and Perspectives

Liu

et al. 2023

Energy Fuels

View full text Add to dashboard Cite

show abstract

“…The reason for this phenomenon is possibly relevant to morphology of micelle. As temperature rises, the linear micelle gradually transform to other shapes (such as spherical micelle), and spherical micelle makes little contribution to viscosity which lead to decrease of solution viscosity [10].…”

Section: Effect Of Temperaturementioning

confidence: 99%

“…8.It shows that viscosity of C 12-2-12 .2Na + solution decreases as shear rate increases, which indicates that anion gemini surfactant solution has shear-thinning rheological characteristic. There are two reasons: for one thing [10], with the increase of shear rate, the linear micelle transform to spherical micelle which make little contribution to solution viscosity; for another [13], with the increase of shear rate, the linear micelle which used to tangled in net shape rearrange to flow direction (parallel), solution viscosity decreases either.…”

Section: Effect Of Shear Ratementioning

confidence: 99%

Research on Rheological Behavior of Anion Gemini Surfactant Solution

Tang

Liu

et al. 2010

AMR

View full text Add to dashboard Cite

The effects of the hydrocarbon chains and spacer groups of a series of sulfate anion Gemini surfactants(Cm-s-m.2Na+) on the rheological behavior are investigated in this paper. Results show that either length of carbon chain increases or length of linking group decreases, solution viscosity increases, C12-2-12.2Na+ has the best viscosifying ability. Then variation of viscosity of C12-2-12.2Na+ solution with concentration, pH, shear rate, temperature, and hydrolyzed polyacrylamide (HPAM) are observed. Results indicate that viscosity increases as concentration increases; single-chain cationic surfactants make viscosity increases first then decreases; concentration of multivalent ion increases or temperature raises or shear rate increases, corresponding viscosity decreases; while pH increases, corresponding viscosity rises first and decreases later; HPAM can enhance the viscosity of C12-2-12. 2Na+ solution, showing that gemini surfactant has a good synergism with HPAM.

show abstract

“…In general, the high salinity is always regarded as an adverse factor for chemical flooding (Asadabadi and Saien, 2016;Cao et al, 2012;Kamal et al, 2017;Liu et al, 2013;Mukerjee and Chan, 2002;Sharma and Sangwai, 2015;Tichelkamp et al, 2014Tichelkamp et al, , 2015a. Meanwhile, the electrolyte is also used as a powerful tool to control the surfactant phase behavior in aqueous solution from the aspect of colloid chemistry (Li et al, 2016;Lu et al, 2008;Shang et al, 2007;Singh and Tyagi, 2017;Ye et al, 2010). Li et al found that the NaCl could suppress the effective area of charged head groups to induce the phase transition of an ionic surfactant self-assembly (Li et al, 2016).…”

Section: Introductionmentioning

confidence: 99%

Salt‐Induced Constructions of Gemini‐like Surfactants at the Interface and Their Effects on the Interfacial Tension of a Water/Model Oil System

Jia

Huang

et al. 2018

J Surfact & Detergents

View full text Add to dashboard Cite

It is an urgent issue to enhance oil recovery for unconventional reservoirs with high salinity. Focused on this topic, salt addition is a powerful tool to motivate the surfactant assembly at the water/oil interface and improve the interfacial activity. We used a cationic surfactant cetyltrimethylammonium bromide (CTAB) and an anionic salt dicarboxylic acid sodium (CnDNa) to construct gemini-like surfactants at the interface and evaluated their ability to reduce the interfacial tension (IFT) between model oil (toluene and n-decane, v:v = 1:1) and water. Interestingly, the fabrication of a (CTAB) 2 /C4DNa gemini-like surfactant was hardly achieved at the fresh water/model oil interface, but accomplished at the brine/model oil interface. At a high NaCl concentration (100,000 mg L −1 ), the IFT value is reduced to 10 −3 mN m −1 order of magnitude, which is generally desired in practical applications. The control experiments displacing the surfactant type and the spacer length further confirmed the NaCl effects on the interfacial assembly.

show abstract

Effect of Sodium Salicylate on the Properties of Gemini Surfactant Solutions

Cited by 10 publications

References 30 publications

Review on High-Temperature-Resistant Viscoelastic Surfactant Fracturing Fluids: State-of-the-Art and Perspectives

Review on High-Temperature-Resistant Viscoelastic Surfactant Fracturing Fluids: State-of-the-Art and Perspectives

Research on Rheological Behavior of Anion Gemini Surfactant Solution

Salt‐Induced Constructions of Gemini‐like Surfactants at the Interface and Their Effects on the Interfacial Tension of a Water/Model Oil System

Contact Info

Product

Resources

About