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Статті в журналах з теми "Ultra-low interfacial tension":

1

Wu, Wen Xiang, Li Min Wang, and Dong Zhang. "Study on Interface Behaviour of the Weak Alkali Ternary System." Advanced Materials Research 524-527 (May 2012): 1905–9. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1905.

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Interfacial tensions between the weak alkali ternary system with surfactant SHSA-HN6 and Henan crude oil were measured. The effects of adding Na2CO3 and Na2CO3 concentration, SHSA-HN6 and polymer concentration on interfacial tensions were examined. The results showed that the interfacial tension reduction effect of the weak alkali ternary system was better than that of the alkali-free binary system, and the ultra-low interfacial tension (10-3 mN/m order of magnitude)for weak alkali ternary system could be reached more rapidly; the influence of polymer concentration changes on static interfacial tension of the weak alkali ternary system was small and the higher the polymer concentration was,the longer the time to reach ultra-low interfacial tension was; the interfacial tension can still be ultra-low when concentration of every component was reduced simultaneously in the weak alkali ternary system; adding Na2CO3 not only can reduce the interfacial tension and but also plays a role of sacrificial agent.
2

Lv, Peng, Ming Yuan Li, and Mei Qin Lin. "Optimization of Surfactant and Polymer for SP Flooding of Zahra Oil." Applied Mechanics and Materials 535 (February 2014): 701–4. http://dx.doi.org/10.4028/www.scientific.net/amm.535.701.

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Producing ultra-low interfacial tensions and maintaining high viscosity is the most important mechanism relating to SP flooding for enhanced oil recovery. The interfacial tension between surfactant (PJZ-2 and BE)/polymer solution and Zahra oil was evaluated in the work. Based on the evaluatiojn of interfacial tension, the polymer FP6040s/surfactant BE system was selected as the SP flooding system for Zahra oil field.
3

Verhoeff, A. A., F. A. Lavergne, D. Bartolo, D. G. A. L. Aarts, and R. P. A. Dullens. "Optical trapping of interfaces at ultra-low interfacial tension." Soft Matter 11, no. 16 (2015): 3100–3104. http://dx.doi.org/10.1039/c5sm00192g.

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We actively control interfacial phenomena by optically trapping the interface in phase separated colloid–polymer mixtures using the gradient forces of a strongly focussed laser beam parallel to the interface.
4

Liang, Xin, Ming Hui Xiang, Yong Yang, Qi Hua Chen, and Zeng Rong Shu. "The Laboratory Research on Ultra-Low Interfacial Tension Foam Flooding System with High-Temperature and High-Salinity." Applied Mechanics and Materials 71-78 (July 2011): 2163–68. http://dx.doi.org/10.4028/www.scientific.net/amm.71-78.2163.

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To obtain the ultra-low interfacial tension foam flooding system for the real reservoir condition of high-temperature and high-salinity, foam properties and dynamic interfacial tension had been performed by Ross-miles test and spin drop tension meter respectively. Ten types of surfactants were screened by foamability, stability and interfacial tension (IFT) at 85°C, high-salinity with 800 mg/L divalent cations and 30000 mg/L total mineralization. The AOS, AESO and 20YB were selected to compose further anion-nonionic mixture system. Due to AOS had excellent foam properties, AESO could achieve low interfacial tension and 20YB could improve the film quality. Through series complex study, the ultra-low interfacial tension (10-4 mN/m order of magnitude) foam system was obtained with the composition of 0.15% wt AOS+0.15% wt AESO+0.11%~0.012% wt 20YB for high-temperature and high-salinity, which V foam was 240-235 mL and t 0.5 was 180-190 min. In addition, the synergistic effect of these surfactants had been described.
5

Liu, Qi, Shuangxing Liu, Dan Luo, and Bo Peng. "Ultra-Low Interfacial Tension Foam System for Enhanced Oil Recovery." Applied Sciences 9, no. 10 (May 2019): 2155. http://dx.doi.org/10.3390/app9102155.

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The liquid phase of foam systems plays a major role in improving the fluidity of oil, by reducing oil viscosity and stripping oil from rock surfaces during foam-flooding processes. Improving the oil displacement capacity of the foam’s liquid phase could lead to significant improvement in foam-flooding effects. Oil-liquid interfacial tension (IFT) is an important indicator of the oil displacement capacity of a liquid. In this study, several surfactants were used as foaming agents, and polymers were used as foam stabilizers. Foaming was induced using a Waring blender stirring method. Foam with an oil-liquid IFT of less than 10–3 mN/m was prepared after a series of adjustments to the liquid composition. This study verified the possibility of a foam system with both an ultra-low oil-liquid IFT and high foaming properties. Our results provide insight into a means of optimizing foam fluids for enhanced oil recovery.
6

Hou, Zhenshan, Zhiping Li, and Hanqing Wang. "Ultra-Low Interfacial Tension in Oil-Water-Mixed Surfactant Systems." Journal of Dispersion Science and Technology 22, no. 2-3 (March 2001): 255–59. http://dx.doi.org/10.1081/dis-100105212.

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7

Chen, Tao Ping, Biao Qiu, and Qi Hao Hu. "Modification and Application of Capillary Number to Oil Displacement in Low Permeability Reservoirs." Advanced Materials Research 868 (December 2013): 522–28. http://dx.doi.org/10.4028/www.scientific.net/amr.868.522.

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As concerning the limitations of the classic capillary number theory in the applications to the oil displacement with the ultra low interfacial intension system in low permeability reservoirs, considering the flow velocity of water/oil displacement through pores in low permeability reservoirs and the mechanism of displacement of the remaining oil in the parallel pores, and considering the influences of ultra low interfacial intension on oil/water relative permeability and the influences of non-homogeneity on the recovery, the expression of modification of the capillary number was given. The relation curves of recovery and capillary number were plotted through the displacement experiments with the ultra low interfacial intension system in low permeability cores. Some points on the application of capillary number to the oil displacement with the ultra low interfacial tension system were given, and the reasonable ways of enhancing the recovery of water flooding low permeability reservoirs with ultra low interfacial intension system were shown.
8

Li, Zhe, Hairong Wu, Yu Hu, Xin Chen, Yongjie Yuan, Yinglin Luo, Jirui Hou, Baojun Bai, and Wanli Kang. "Ultra-low interfacial tension biobased and catanionic surfactants for low permeability reservoirs." Journal of Molecular Liquids 309 (July 2020): 113099. http://dx.doi.org/10.1016/j.molliq.2020.113099.

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9

Bolognesi, Guido, Alex Hargreaves, Andrew D. Ward, Andrew K. Kirby, Colin D. Bain, and Oscar Ces. "Microfluidic generation of monodisperse ultra-low interfacial tension oil droplets in water." RSC Advances 5, no. 11 (2015): 8114–21. http://dx.doi.org/10.1039/c4ra14967j.

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10

Sun, Li Mei, Guo Qiang Gao, Lu Shan Wang, Zhong Qiang Tian, Jie Cui, and Arne Skauge. "Ultra-Low Interfacial Tension and Retention of Internal Olefin Sulfonate (IOS) for EOR." Advanced Materials Research 550-553 (July 2012): 36–39. http://dx.doi.org/10.4028/www.scientific.net/amr.550-553.36.

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Surfactant ultra-low interfacial tension (IFT) for internal olefin sulfonate with iso-amylalcohol (IAA) as co-solvent against heptane, octane and decane at 20 °C, 50 °C, and 90 °C respectively have been systematically investigated, as well as the dynamic retention in porous media. The results show for oils with alkane carbon number from 7 to 10 and temperature from 20 °C to 90 °C, optimal salinity starts from 6.5 wt% to 11.6 wt% NaCl, where ultra-low IFT occurs. While at high salinity (at least from 6 wt% NaCl ), the retention is too high for surfactant flooding to be applicable. Only internal olefin sulfonate with co-solvent alone can not provide a perfect formulation with ultra-low IFT and low retention.

Дисертації з теми "Ultra-low interfacial tension":

1

Gagnon, Yancie. "Étude de l’extraction des huiles végétales en milieu aqueux assistée par des tensioactifs." Electronic Thesis or Diss., Compiègne, 2021. http://www.theses.fr/2021COMP2654.

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L’une des préoccupations actuelles majeures des acteurs de la trituration repose sur l’identification d’une alternative au procédé utilisant l’hexane en raison de son impact sur l’environnement, la qualité des produits et la santé humaine. L’utilisation de l’eau comme solvant de substitution présente plusieurs avantages, mais cette piste a été longtemps écartée en raison de la non miscibilité de l’eau et des huiles. La solution proposée suggère d’utiliser une solution aqueuse de tensioactifs permettant la réduction de la tension interfaciale entre l’eau et l’huile sous les 10-2 mN/m (i.e. la formation de microémulsion). Cette thèse vise donc à étudier l’extraction des huiles végétales à partir de graines oléagineuses en milieux aqueux en présence de tensioactifs. L’objectif principal est d’acquérir une meilleure compréhension des mécanismes mis en jeu et notamment des interactions physicochimiques entre les différents composés du système. Différentes questions ont été abordées dans cette thèse de façon à prendre en considération pas à pas le rôle et l’impact de chaque constituant du système. D’abord, la caractérisation physicochimique de différents types de tensioactifs, en particulier les tensioactifs dits rallongés et les tensioactifs biosourcés largement moins étudiés dans la littérature, a permis de sélectionner ceux capables de solubiliser un maximum d’huile végétale dans l’eau. Ensuite, les systèmes étudiés se complexifient par la prise en compte des graines oléagineuses, et donc de l’interface solide-liquide jamais étudiée dans la littérature. Des hypothèses quant aux mécanismes d’action des tensioactifs sur la modification de la mouillabilité des surfaces oléagineuses ont pu être proposées. Finalement, l’étude du procédé d’extraction a été abordée. L’influence des paramètres opératoires sur les rendements d’extraction a été appréhendée. Les résultats obtenus offrent des perspectives de poursuite, dans le but d’envisager l’émergence de cette technologie à l’échelle industrielle
One of the major current concerns in the crushing industry is to identify an alternative to the processthat uses hexane because of its impact on the environment, product quality, and human health. Theuse of water as a substitute solvent has several advantages, but this path has long been set apart dueto the immiscibility of water and oils. The proposed solution suggests using an aqueous solution ofsurfactants allowing the reduction of the interfacial tension between water and oil below 10-2 mN/m(i.e., the formation of microemulsion). This thesis, therefore, aims to study the extraction of vegetable oils from oilseeds in aqueous media in the presence of surfactants. The main objective is to acquire a better understanding of the mechanisms involved, in particular, the physicochemical interactions between the different compounds of the system. Different questions have been addressed in this thesis to consider step by step the role and the impact of each constituent of the system. First, the physicochemical characterization of different types of surfactants, in particular, the so-called extended surfactants and bio-based surfactants that are largely less studied in the literature, which made it possible to select those capable of solubilizing a maximum of vegetable oil in water. Then, the studied systems become more complex by considering the oilseeds, therefore the solid-liquid interface, which has never been studied inthe literature. Hypotheses as to the mechanisms of action of surfactants on the wettabilitymodification of oleaginous surfaces have been proposed. Finally, the study of the extractionprocess was approached. The influence of the operating parameters on the extraction yields hasbeen apprehended. The results obtained offer prospects for further action to consider the emergenceof this technology on an industrial scale
2

Huang, Hai Feng, and 黃海峰. "A new technique for the measurement of ultra-low interfacial tension." 學位論文 ; thesis, 1994. http://ndltd.ncl.edu.tw/handle/90062017446702305469.

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Тези доповідей конференцій з теми "Ultra-low interfacial tension":

1

Wang, Demin, Jiecheng Cheng, Li Qun, Junzheng Wu, Wenxiang Wu, and Yanqing Zhang. "First Ultra-Low Interfacial Tension Foam Flood Field Test Is Successful." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/71491-ms.

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2

Bolognesi, Guido, Alex Hargreaves, Andrew D. Ward, Andrew K. Kirby, Mark Neil, Colin D. Bain, and Oscar Ces. "Microfluidic generation and optical manipulation of ultra-low interfacial tension droplets." In SPIE Microtechnologies, edited by Jean-Marc Fédéli. SPIE, 2015. http://dx.doi.org/10.1117/12.2178964.

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3

Wang, Demin, Jiecheng Cheng, Zhenyu Yang, Li Qun, Wenxiang Wu, and Huiyu Yu. "Successful Field Test of the First Ultra-Low Interfacial Tension Foam Flood." In SPE Asia Pacific Improved Oil Recovery Conference. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/72147-ms.

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4

Xu, Derong, Baojun Bai, Ziyu Meng, Qiong Zhou, Zhe Li, Yao Lu, Hairong Wu, Jirui Hou, and Wanli Kang. "A Novel Ultra-Low Interfacial Tension Nanofluid for Enhanced Oil Recovery in Super-Low Permeability Reservoirs." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/192113-ms.

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5

Kang, Wanli, Shuren Liu, Ling Wei Meng, Dongqing Cao, and Haiming Fan. "A Novel Ultra-low Interfacial Tension Foam Flooding Agent to Enhance Heavy Oil Recovery." In SPE Improved Oil Recovery Symposium. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/129175-ms.

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6

Liu, Mingyan, Kwanghoon Baek, Fransico Argüelles Vivas, Gayan Aruna Abeykoon, and Ryosuke Okuno. "Effects of Surfactant Partitioning Coefficient and Interfacial Tension on the Oil Displacement in Low-Tension Polymer Flooding." In SPE Annual Technical Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/206220-ms.

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Abstract Complex surfactant formulations have been applied to generate an ultra-low interfacial tension (IFT) (e.g., 10-3 dyne/cm) between the displacing water phase and the displaced oil phase in chemical enhanced oil recovery (CEOR), where the residual oil after waterflooding can be largely recovered as an oil bank. This paper is concerned with a simpler, lower-cost CEOR, in which a sole additive of surface active solvent (SAS) makes low-tension displacement fronts in polymer flooding (e.g., 10-2 dyne/cm) without involving ultra-low IFT microemulsion phase behavior. The main objective of this research is to technically verify such low-tension polymer (LTP) flooding for a secondary-mode oil displacement through a sandpack of 9.5 Darcy. Previous research found that 2-ethylhexanol-7PO-15EO (2-EH-7PO-15EO, or "7-15") as SAS was able to reduce the IFT between polymer solution and the reservoir oil from 15.8 dyne/cm to 0.025 dyne/cm. In this research, the effect of SAS partition coefficient on LTP flooding was studied as an additional factor for SAS optimization. In particular, the comparison between two SAS species, 2-EH-4PO-15EO (4-15) and 2-EH-7PO-25EO (7-25), was important, because they had similar IFT values, but markedly different partition coefficients. The IFT was 0.18 dyne/cm with 4-15 and 0.20 dynes/cm with 7-25; and the partition coefficients were 1.61 with 4-15 and 0.68 with 7-25 at the experimental temperature, 61°C. These two SAS species were compared in secondary-mode LTP flooding with a slug of 0.5 wt% SAS for 0.5 pore-volumes injected (PVI). The oil recovery factor at 1.0 PVI was 65% with 4-15 and 67% with 7-25. At 5.0 PVI, it was 74% with 4-15 and 84% with 7-25. Although these two SAS species gave comparable IFT values, their oil-displacement efficiencies were quite different because 7-25 propagated more efficiently in the sandpack with the smaller partition coefficient. The smaller partition coefficient helped the SAS flow more efficiently in the aqueous phase with less retention in the remaining oil. Optimization of SAS likely requires taking a balance between lowering the partition coefficient and lowering the IFT. The SAS recovery at the effluent was 61% for the 4-15 SAS and 78% for the 7-25 SAS. The propagation of the 4-15 SAS was retarded approximately by 1.0 PVI in comparison to that of the 7-25 SAS. The adsorption of the 4-15 and 7-25 SAS were 0.019 mg/g sandpack and 0.020 mg/g sandpack. With a similar IFT reduction, the SAS with a smaller partition coefficient (i.e., 7-25) resulted in less retention, less retardation, and more oil production for a given amount of injection.
7

Chen, Shaohua, Ming Han, Abdulkareem AlSofi, and Alhasan Fuseni. "Non-Ionic Surfactant Formulation with Ultra-Low Interfacial Tension at High-Temperature and High-Salinity Conditions." In SPE Conference at Oman Petroleum & Energy Show. SPE, 2022. http://dx.doi.org/10.2118/200273-ms.

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Abstract Non-ionic alkyl polyglucoside (APG) surfactants have been considered as eco-friendly, nontoxic and biodegradable surfactants. In this study, the physicochemical properties of two APG surfactants under high-temperature and high-salinity conditions were evaluated. The effectiveness of the surfactants as imbibition agents on improving oil production in carbonate reservoirs was investigated. A formulation with ultra-low interfacial tension (IFT) was introduced and the mechanisms resulting in such low IFT were probed and discussed. Two APG surfactants were studied. Compatibility was evaluated by the transparency in brine solutions after aging. IFT was measured with the formulations of surfactant/additives. The morphology of network formed by surfactant/additives was observed via scanning electron microscope (SEM). The static adsorption of the APGs onto carbonate powder was determined by total organic carbon (TOC) analyzer. The contact angle of oil droplet on surface of carbonate core was measured in surfactant solution. The oil production via spontaneous imbibition of water in carbonate core was obtained using Amott cell. An imbibition simulation model was validated by the experimental results using UTCHEM simulator. Both surfactants APG-1 and APG-2 exhibited excellent compatibility with the simulated high salinity water at reservoir temperature. They also demonstrated low static adsorption on carbonate reservoir. The surfactant containing larger hydrophobic carbons (APG-1) showed more incremental oil production potential than the other one bearing shorter hydrophobic chain (APG-2). At a concentration of 0.2 wt%, APG-1 yielded a low IFT in the order of 10-2 mN/m and an ultra-low IFT in the order of 10-3 mN/m was obtained upon addition of a small amount of additives. SEM pictures indicated that APG-1 and the additives synergistically generated a more compact structure via interaction between hydrophobic moieties of the chemicals compared to the aggregated structure formed by APG-1 alone. Such an effect could eventually lead to a decrease in IFT between oil and water. APG-1 slightly altered the wettability of carbonate core surface toward water-wet. The experimental results of spontaneous imbibition tests showed an oil production of 28% and 21% by APG-1 and APG-2, respectively. After parameter tuning, the yielded curves from numerical simulation by UTCHEM simulator perfectly matched the experimental data. A new APG-based formulation was designed with an ultra-low IFT resulting in a much more compact amphiphilic structure along the oil-water interface. This study shows a great potential of APG surfactants and the relevant derivative formulations in improving oil production application for high-temperature and high-salinity carbonate reservoirs.
8

Janjua, Aneeq Nasir, Abdullah S. Sultan, and Muhammad Shahzad Kamal. "Ultra-Low Interfacial Tension, Thermal Stability and Static Adsorption of Novel Viscoelastic Surfactant With Heavy Reservoir Oil." In SPE Kingdom of Saudi Arabia Annual Technical Symposium and Exhibition. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/192322-ms.

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9

Hargreaves, Alexander L., Andrew K. Kirby, Colin D. Bain, Gordon D. Love, Guido Bolognesi, Oscar Ces, Mark Neil, and Andrew D. Ward. "An optical platform for the production, trapping, manipulation and visualization of ultra-low interfacial tension emulsion droplets." In SPIE NanoScience + Engineering, edited by Kishan Dholakia and Gabriel C. Spalding. SPIE, 2013. http://dx.doi.org/10.1117/12.2027105.

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Hou, Jirui, Zhongchun Liu, and Huifen Xia. "Viscoelasticity of ASP Solution is a More Important Factor of Enhancing Displacement Efficiency than Ultra-low Interfacial Tension in ASP Flooding." In SPE Rocky Mountain Petroleum Technology Conference. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/71061-ms.

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