Synthesis and Solution Properties of a Double‐Tailed Quaternary Ammonium Surfactant with a Protrudent Head Group

Modification of the molecular structure of surfactants is an effective method for exploring their self‐assembly. A double‐tailed quaternary ammonium surfactant with a protrudent head group, namely 2‐octyldecyltrimethylammonium bromide (2‐ODTAB) was synthesized, and the solution properties were investigated by surface tension, dynamic light scattering, and cryogenic TEM. A comparative study was also performed on the traditional double‐tailed homologue surfactants dioctyldimethylammonium bromide (8–8), didecyldimethylammonium bromide (10–10), and didodecyldimethylammonium bromide (12–12). The results showed that 2‐ODTAB was more effective at lowering surface tension and in forming stable vesicles than traditional double‐tailed surfactants with similar alkyl chain length. The reason is attributed to the improved structure of 2‐ODTAB, in which the two alkyl tails are connected to the ionic head group by one carbon atom. This structure imparts more freedom to the head group and thus favors formation of more stable aggregates at low concentration. In addition, the lower limit of the alkyl chain length of the double‐tailed surfactants for forming stable vesicles was illustrated.     

Nanovesicles Based on Mixtures of a Biantennary Glycolipid with Ionic Co‐Surfactants

A biantennary surfactant based on a synthetic C₁₆‐maltoside was chosen to prepare vesicles for a potential vesicular drug delivery system. The synthesis comprised of three stages: Initial synthesis of β‐d ‐maltose octaacetate was followed by glycosidation of 2‐hexyl‐decanol and final glycolipid deacetylation. Both α‐ and β‐anomers were prepared and their anomeric purity was evaluated by ¹H NMR. Owing to the low water solubility of the glycolipid, addition of ionic co‐surfactants was believed to promote the surfactant distribution, thus leading to smaller and more uniform vesicles. The assembly behavior of the surfactant systems was studied by contact penetration under an optical polarizing microscope, while interfacial properties were determined by surface tension measurements. Vesicles were prepared by injection of an ethanolic solution into bulk water and investigated by dynamic light scattering and field emission scanning electron microscopy. Contact of the surfactant mixtures with water indicated a high tendency to exhibit the lamellar phase and confirmed the expected low molecular solubility. These findings suggest a potential of the surfactant to form stable vesicles. Injection of an ethanolic surfactant solution into bulk water gave sub‐micrometer sized vesicles with a narrow size distribution. Application of ionic co‐surfactants reduced the vesicle size. In particular ～20 % of anionic SDS proved highly effective, lowering the vesicle size by nearly one decade, thus accessing nano‐sized vesicles. Encapsulation of a water‐soluble drug was achieved in a 76 ± 10 % efficiency.     

一种疏水缔合聚合物稠化剂的合成及压裂液性能评价

以AM、AMPS和阳离子疏水单体MD-18为单体,采用水溶液自由基聚合法合成了疏水缔合聚合物压裂液稠化剂HAPAM-18。研究了HAPAM-18的增黏性能、与表面活性剂的相互作用以及压裂液体系的相关性能。结果表明,HAPAM-18的表观黏度随质量浓度增加而增大,临界缔合浓度为0.15g/L;HAPAM-18与表面活性剂的相互作用符合三阶段模型,且SDBS与HAPAM-18的相互作用强于CTAB;ρ(HAPAM-18)0.6g/L+c(SDBS)0.5mmol/L+ρ(KCl)2g/L配制的压裂液体系的耐温性能达到101℃。耐剪切性实验和动态频率扫描表明,该压裂液体系具有良好的耐剪切性和黏弹性;过硫酸铵能使压裂液彻底破胶,破胶液残渣含量低至未检出,该压裂液是一种清洁压裂液。     

复合体系各组分对油水界面剪切粘弹性的影响规律

为了探究复合体系各组分(碱、表面活性剂、聚合物)对油水界面剪切粘弹性的影响规律,利用Physica MCR301型流变仪测量了不同化学驱油体系与原油的界面剪切粘弹性。结果表明,原油和去离子水可以形成较坚固的界面膜,有较高的界面剪切粘弹性;少量表面活性剂(如质量浓度为100 mg/L)的加入就会大幅度降低油水界面剪切粘弹性,在考察的质量浓度范围内,表面活性剂溶液的质量浓度越大,界面剪切粘弹性越低,在较高的质量浓度(如3 000 mg/L)和较高的振荡角频率(如1 rad/s)下,界面储能模量超出仪器测量下限;碱会严重破坏油水界面膜,使界面的损耗模量大幅度降低,界面的储能模量超出仪器测量下限,但是有机碱对界面膜的伤害要小于无机碱;聚合物的加入也会对油水界面剪切粘弹性产生影响,形成的界面膜抗剪切性能减弱。     

碱性Cu抛光液中非离子表面活性剂和氧化剂作用的研究

化学机械抛光是集成电路制造工艺中十分精密的技术。在本文中,为了改善抛光效果,分表讨论了非离子表面活性剂和氧化剂在CMP过程中作用。我们主要分析了非离子表面活性剂对片内非均匀性和表面粗糙度的影响。同时,我们从静态腐蚀速率、电化学曲线和剩余高低差的角度,讨论了在不加BTA条件下,不同氧化剂浓度的抛光液的钝化特性。实验结果明显地表明：加入了非离子表面活性剂的抛光液,更有利于改善抛光后的片内非均匀性和表面粗糙度,并确定2vol%体积分数是比较合适的浓度。当抛光液中氧化剂浓度超过3vol%,抛光液拥有较好的钝化能力,能够有效减小高低差,并有助于获得平整和光滑的表面。根据这些实验结果,非离子表面活性剂和氧化剂的作用进一步被了解,将有助于抛光液性能的改善。     

水体系下两步法SiO2纳米多孔材料的制备与表征

以去离子水为溶剂,低成本工业硅溶胶为硅源,在纯水体系下制备低成本的SiO₂纳米多孔材料,使用酸碱两步法催化,添加表面活性剂来降低溶剂的表面张力,从而减少样品在干燥过程中的开裂。最后经过常压老化干燥制备得到 SiO₂纳米多孔材料。制备得到的SiO₂块体密度为150~400mg/cm₃,室内热导率约为0.04~0.07W/(m.K)。这种方法制备的SiO₂纳米多孔材料大幅缩减制备成本,采用HCl作为酸性催化剂提高了工业生产安全,将很大程度上推动纳米多孔材料的工业化生产和应用。     

C60 fullerene promotes lung monolayer collapse

Airborne nanometre-sized pollutants are responsible for various respiratory diseases. Such pollutants can reach the gas-exchange surface in the alveoli, which is lined with a monolayer of lung surfactant. The relationship between physiological effects of pollutants and molecular-level interactions is largely unknown. Here, we determine the effects of carbon nanoparticles on the properties of a model of lung monolayer using molecular simulations. We simulate phase-separated lipid monolayers in the presence of a model pollutant nanoparticle, C₆₀ fullerene. In the absence of nanoparticles, the monolayers collapse only at very low surface tensions (around 0 mN m⁻¹). In the presence of nanoparticles, instead, monolayer collapse is observed at significantly higher surface tensions (up to ca 10 mN m⁻¹). Collapse at higher tensions is related to lower mechanical rigidity of the monolayer. It is possible that similar mechanisms operate on lung surfactant in vivo, which suggests that health effects of airborne carbon nanoparticles may be mediated by alterations of the mechanical properties of lung surfactant.     

聚氧乙烯型非离子表面活性剂在细水雾灭火中的应用

以几种O系列聚氧乙烯型非离子表面活性剂为添加剂,利用表面张力仪、激光粒度分析仪、乳化性能实验等详细研究了它们对水的物理性质(表面张力、喷雾粒径、乳化性能)的影响.根据测试结果,以O-8为细水雾添加剂,利用灭汽油油盆火实验研究了含O-8细水雾的灭火性能,并用烟气分析仪分析了灭火过程中的烟气(氧气、一氧化碳和二氧化碳)浓度.实验结果表明:O系列聚氧乙烯型非离子表面活性剂的加入能显著降低水的表面张力、减小细水雾的粒径分布、增强水的乳化性能.与纯水细水雾相比,含O-8的细水雾具有更好的灭火性能,并有利于抑制汽油燃烧过程中一氧化碳和二氧化碳的产生.     

Investigation the impact of additives on the displacement of the onset point of asphaltene precipitation using interfacial tension measurement

The purpose of this study is to explore the impact of additives on the displacement of the onset point of asphaltene precipitation in crude oil using the interfacial tension measurement method, based on the examined oil has been taken from Iran reservoirs. The experimental results suggest that the addition of surfactants of dodecyl benzene sulfonic acid (DBSA) and coconut diethanolamide (CDEA) to the oil has triggered the onset of asphaltene precipitation. These findings imply that CDEA has a more effective role in preventing asphaltene precipitation. Also, it was observed that increasing the concentration of the surfactants has led to obtaining greater results. Finally, critical micelle concentration was calculated to be 5000 and 4700 ppm in the cases of CDEA and DBSA, respectively.     

Impact of Divalent Ions on Heavy Oil Recovery by in situ Emulsification

Many reservoir formation brines are characterized by high salinity and contain high concentrations of divalent ions such as calcium, magnesium, and potassium. These challenging conditions can render the surfactants ineffective during chemical flooding for enhanced heavy oil recovery. Various brine types can have an impact on the stability of emulsions generated with chemicals as chemicals have various resistant levels toward hard divalent ions and salinities. To investigate the impact of brine hardness on heavy oil-in-water emulsion stability, glass tube experiments, microscopic visualization and sandpack flooding experiments, and Hele-Shaw visualization experiments were conducted in this study under low-salinity/hard-brine, high-salinity/hard-brine conditions using commercial chemicals, which are designed for specific reservoir brine conditions. Recovery results demonstrated that complex colloidal solution introduced in the previous study with silica and Dodecyltrimethylammonium bromide (DTAB) along with screened chemicals from glass tube tests in this study can enhance heavy oil recovery significantly with an addition of low concentration of xanthan gum (Lee and Babadagli 2018). The results confirmed the robustness of the complex colloidal solution formula to enhance oil recovery with low concentration of polymer under any reservoir brine conditions. The study also demonstrates the potential of polymer as an emulsion stabilization additive for enhanced heavy oil recovery by in situ emulsion generation. Polymer effects seemed to be particularly dominant under the low-salinity conditions than high-salinity conditions.