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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 27, 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 31, 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.
11

Sauret, Alban, Constantinos Spandagos, and Ho Cheung Shum. "Fluctuation-induced dynamics of multiphase liquid jets with ultra-low interfacial tension." Lab on a Chip 12, no. 18 (2012): 3380. http://dx.doi.org/10.1039/c2lc40524e.

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12

Li, Na, Guicai Zhang, Jijiang Ge, Li Zhang, Xiaoling Liu, and Jing Wang. "Ultra-Low Interfacial Tension Between Heavy Oil and Betaine-Type Amphoteric Surfactants." Journal of Dispersion Science and Technology 33, no. 2 (February 2012): 258–64. http://dx.doi.org/10.1080/01932691.2011.561177.

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13

Zhang, Shuo, Guan-Cheng Jiang, Le Wang, Hai-Tao Guo, Xin-guo Tang, and Dian-Gang Bai. "Foam Flooding with Ultra-Low Interfacial Tension to Enhance Heavy Oil Recovery." Journal of Dispersion Science and Technology 35, no. 3 (March 4, 2014): 403–10. http://dx.doi.org/10.1080/01932691.2013.792272.

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14

Xiong, Sheng Chun, Ying He, and Mao Lei Cui. "Petroleum Sulfonates as Oil Displacement Agent and Application." Advanced Materials Research 529 (June 2012): 512–16. http://dx.doi.org/10.4028/www.scientific.net/amr.529.512.

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In terms of the condition of injection water after polymer flooding of Gudao oilfield, the following water quickly broke though the bank to the production wells, while most of residual oil remains in the formation. To solve the problem, two kind of petroleum sulfonates made in China are selected to form oil displacement agent (ODA) solution. The petroleum sulfonate available for crude oil of Gudao oilfield with the ultra-low interfacial tension is found by drawing an oil/water interfacial tension contour diagram. The results show that the interfacial tension can be lower than 3.6×10-4mN/m when the active agent contained with 0.25%KPS+0.225%APS, and the agent reduces water resistance of entering the hole to improve sweep coefficient and oil displacement efficiency. The existence of the polymer has no influence on the balanced value of interfacial tension, but just delays the interfacial tension to reach the balance. Pouring into 0.3 pore volume (PV) high-efficient ODA can improve 17% oil recovery. Synergistic effect of two kind of petroleum sulfonate with low cost to enhance oil recovery will have a great prospect for enhanced oil recovery (EOR)
15

Wu, Wen Xiang, and Zhong Qi Yu. "Research on Oil-Water Interfacial Properties Effect of Polymer / Surfactant Binary Flooding System." Advanced Materials Research 201-203 (February 2011): 2558–61. http://dx.doi.org/10.4028/www.scientific.net/amr.201-203.2558.

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The formula of surfactant(QY-3、SHSA-HN6、SS) and polymer compound system, and the interfacial characteristics between oil and water of Henan oil field were evaluated, the binary composite system formula adapt to the field was explored. The results show that the binary composite system (surfactant QY-3 and polymer 1630S) and oil-water in Henan can achieve ultra-low interfacial tension(<10-3mN/m); If the addition agent NaCl was added to the composite system (Surfactant Ss and polymer ZL-Ⅱ or Surfactant Ss and polymer KYPAM) that the interfacial tension between oil and water can be reduced effectively.
16

Cui, Shi Cai. "Synthesis and Performance Evaluation on Amphoteric Surfactant of Dodecyl/Tetradecyl Phosphobetain." Applied Mechanics and Materials 541-542 (March 2014): 134–40. http://dx.doi.org/10.4028/www.scientific.net/amm.541-542.134.

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The phosphobetaine amphoteric surfactant of N, N-dimethyl-tridecane hydroxyethyl ammonium phosphate (PBET-13), was synthesized by using epichlorohydrin, NaH2PO4 and dodecyl/tetradecyl dimethyl amine and cetyl/octadecyl dimethyl ammonium as raw materials. The scale inhibition, interfacial tension and foaming performance of PBET-13 were studied. The results show that the surfactant has higher scale inhibition efficiency to CaSO4 than that of CaCO3. PBET-13 solution with the appropriate concentration of NaCl could reach to the ultra-low value of interfacial tension, and PBET-13 shows good foam performance.
17

Wang, Qunyi, Yongbin Bi, Tongfeng Cao, Yang Zhang, Dong Liu, Haiyan He, and Xuena Zhang. "Performance evaluation of temperature-resistant nano-surfactants." E3S Web of Conferences 338 (2022): 01009. http://dx.doi.org/10.1051/e3sconf/202233801009.

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Surfactant flooding is a common technique in tertiary oil recovery. However, due to the high temperature of some reservoirs and the strong heterogeneity caused by their own geological conditions, the use of common surfactants in high-temperature reservoirs is limited. Temperature - resistant surfactants can reduce interfacial tension, improve conformance and increase oil washing efficiency In this paper, a temperature-resistant nano-type surface active JCN-001 was developed in the laboratory. By testing its particle size distribution, the experimental results can determine that the average particle size range of the system is 34.29nm, so that it can play a better role in low permeability reservoir recovery. Due to its unique nano properties, JCN at 0.2% concentration can still maintain a good effect at about 110, and the oil/water interfacial tension can reach 10-4nm/m, and can also reach ultra-low interfacial tension at high temperature, and the higher the temperature, the more significant the effect According to the changes of surface tension and oil-water interfacial tension, the critical micelle concentration was determined to be about 0.2%. The static adsorption experiments and dynamic adsorption experiments were carried out. The results show that the temperature resistant nano-surfactants have strong adsorption resistance and can effectively reduce the consumption of surfactants on rocks.
18

Zhang, Qiqi, Shanmeiyu Zhang, Hui Yang, Guangling Pei, Ming Yang, Wei Zhang, Rui Chen, and Jinben Wang. "Imidazole-Based Ionic Liquids with BF4 as the Counterion Perform Outstanding Abilities in Both Inhibiting Clay Swelling and Lowing Water Cluster Size." International Journal of Molecular Sciences 22, no. 12 (June 16, 2021): 6465. http://dx.doi.org/10.3390/ijms22126465.

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Promoting fluid transportation in porous media has important applications in energy, pedology, bioscience, etc. For this purpose, one effective way is to prevent swelling through surface modification; however, it is far from enough in real cases, such as ultra-low permeability reservoirs and tight oils. In this study, we considered the comprehensive effects of inhibiting clay swelling, flocculation performance, reducing water clusters and interfacial tension and developed a series of imidazole-based tetrafluoroborate ionic liquids (ILs) with different lengths of alkyl chains. Through measurements of anti-swelling rates, XRD, SEM, 17O NMR, molecular dynamics simulation, zeta potential, flocculation evaluation, interfacial tension and a core flooding experiment based on ultra-low permeability reservoirs, the relationships between the molecular structure and physicochemical properties of ILs have been revealed. Interestingly, one of the selected ILs, imidazole-based tetrafluoroborate ILs (C8-OMImBF4), shows excellent performance, which is helpful to design an effective strategy in promoting fluid transportation in narrow spaces.
19

Wazir, Norhidayah Ahmad, Wasan Saphanuchart, Anita Ramli, and Nurida Yusof. "Improved As-Synthesized Oleic Amido Propyl Betaine Surfactant Mixture for Stable Ultra-Low Interfacial Tension: Effect of Mixed Co-Solvents." Colloids and Interfaces 5, no. 1 (January 6, 2021): 2. http://dx.doi.org/10.3390/colloids5010002.

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As-synthesized oleic amido propyl betaine surfactant mixture, that was produced through a “direct formulation through synthesis” process, exhibited ultra-low oil/water interfacial tension (IFT) values as low as 3.5 × 10−4 mN/m when dissolved in seawater at a reservoir temperature of 96 °C. The as-synthesized surfactant, which was left untreated, had a slightly cloudy appearance when mixed with seawater. Polar solvents were introduced to this surfactant to improve its aqueous solubility by changing its overall hydrophilicity, particularly on the oil/water interface. In this study, two types of glycol ether co-solvent, i.e., ethylene glycol monobutyl ether and diethylene glycol monobutyl ether, were used at different concentrations in a single application and as a mixture of co-solvents at a certain ratio. The behavior of the as-synthesized surfactant with the presence of these co-solvents was investigated. As a result, it showed that the co-solvent helps in solubility improvement and alters the interfacial tension behavior of the surfactant. Ethylene glycol monobutyl ether was found to be efficient in maintaining an ultra-low IFT value of the surfactant. However, the aqueous solubility of the surfactant was not significantly improved. In contrast, the addition of diethylene glycol monobutyl ether showed improvement of the aqueous solubility of the surfactant, but it tends to increase the IFT above ultra-low value. Based on this understanding, a set of co-solvent mixing ratios were tested, and the results showed further improvement in both the oil/water interfacial tension behavior and surfactant aqueous solubility. The most stable oil/water IFT of 3.36 × 10−3 mN/m and clearer surfactant solutions were obtained for ratio C at 35 wt.% presence of co-solvent.
20

Du, Quan Wei, and Kun Liu. "Study on Oil-Water Interfacial Behaviour of Henan Oilfield." Applied Mechanics and Materials 700 (December 2014): 602–6. http://dx.doi.org/10.4028/www.scientific.net/amm.700.602.

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In order to decide the formula of ASP system to be used in Henan oilfield, the weak base ternary composite system compounded with petroleum sulfonate(Ss), polymer and weak base; the alkali ASP system compounded with alkylbenzene sulfonates(Sy), polymer and alkali were studied, and the oil-water interface behaviour of Henan oilfield with weak base ASP system compounded with surfactant SHSA-HN6 and ZL-Ⅱ polymer was evaluated. The results showed that the interfacial tension reduction effect of Weak base ternary system is better than that of Alkali ternary system; the interfacial tension between oil and water can be reduced significantly by the weak base ternary system compounded with surfactant (Ss) and polymer (ZL-Ⅱand KYPAM). After adding 1.2% Na2CO3 to the mixture of surfactant (SHSA-HN6) and polymer, the interfacial tension of Henan oil-water was reduced to the ultra-low level(>10-3mN/m).
21

Youssef, Noha H., Thu Nguyen, David A. Sabatini, and Michael J. McInerney. "Basis for formulating biosurfactant mixtures to achieve ultra low interfacial tension values against hydrocarbons." Journal of Industrial Microbiology & Biotechnology 34, no. 7 (May 3, 2007): 497–507. http://dx.doi.org/10.1007/s10295-007-0221-9.

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22

Zhang, Jianmei, Gang Li, Fang Yang, Nian Xu, Hongxian Fan, Tao Yuan, and Lin Chen. "Hydrophobically modified sodium humate surfactant: Ultra-low interfacial tension at the oil/water interface." Applied Surface Science 259 (October 2012): 774–79. http://dx.doi.org/10.1016/j.apsusc.2012.07.120.

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23

Gowda. V, Krishne, Christophe Brouzet, Thibault Lefranc, L. Daniel Söderberg, and Fredrik Lundell. "Effective interfacial tension in flow-focusing of colloidal dispersions: 3-D numerical simulations and experiments." Journal of Fluid Mechanics 876 (August 14, 2019): 1052–76. http://dx.doi.org/10.1017/jfm.2019.566.

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An interface between two miscible fluids is transient, existing as a non-equilibrium state before complete molecular mixing is reached. However, during the existence of such an interface, which typically occurs at relatively short time scales, composition gradients at the boundary between the two liquids cause stresses effectively mimicking an interfacial tension. Here, we combine numerical modelling and experiments to study the influence of an effective interfacial tension between a colloidal fibre dispersion and its own solvent on the flow in a microfluidic system. In a flow-focusing channel, the dispersion is injected as core flow that is hydrodynamically focused by its solvent as sheath flows. This leads to the formation of a long fluid thread, which is characterized in three dimensions using optical coherence tomography and simulated using a volume of fluid method. The simulated flow and thread geometries very closely reproduce the experimental results in terms of thread topology and velocity flow fields. By varying the interfacial tension numerically, we show that it controls the thread development, which can be described by an effective capillary number. Furthermore, we demonstrate that the applied methodology provide the means to measure the ultra-low but dynamically highly significant effective interfacial tension.
24

Xia, HAN, CHENG Xin-Hao, WANG Jiang, and HUANG Jian-Bin. "Application of Anion-Cation Pair Surfactant Systems to Achieve Ultra-Low Oil-Water Interfacial Tension." Acta Physico-Chimica Sinica 28, no. 01 (2012): 146–53. http://dx.doi.org/10.3866/pku.whxb201228146.

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25

Weng, Zhan, Peng-Yuan Zhang, Guang-Wen Chu, Wei Wang, Jimmy Yun, and Jian-Feng Chen. "Performance of alkali-free natural petroleum sulfonates: Ultra-low interfacial tension on oil/water interface." Canadian Journal of Chemical Engineering 93, no. 8 (June 25, 2015): 1410–15. http://dx.doi.org/10.1002/cjce.22234.

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26

Liu, Peisong, Huanhuan Yu, Liyong Niu, Dongdong Ni, Qianyu Zhao, Xiaohong Li, and Zhijun Zhang. "Utilization of Janus-silica/surfactant nanofluid without ultra-low interfacial tension for improving oil recovery." Chemical Engineering Science 228 (December 2020): 115964. http://dx.doi.org/10.1016/j.ces.2020.115964.

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27

Ahmad Wazir, Norhidayah, Anita Ramli, Nurida M. Yusof, Wasan Saphanuchart, and Emily S. Majanun. "As-Synthesized Oleic Amido Propyl Betaine Surfactant Mixture and the Effect on the Crude Oil–Seawater Interfacial Tension." Processes 8, no. 8 (August 11, 2020): 965. http://dx.doi.org/10.3390/pr8080965.

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As-synthesized oleic amido propyl betaine surfactant mixture was developed through a slight modification of a conventional two-step betaine synthesis process of amidation and quaternization reactions. This method is a “direct formulating through synthesis” to achieve a targeted interfacial property (interfacial tension or IFT) of the as-synthesized surfactant. Oil–water IFT was measured in the crude oil–seawater system at 96 °C. The result showed that the as-synthesized surfactant was able to reduce crude oil–seawater IFT to the ultra-low level (<0.01 mN/m). As the finding emerged, the investigation was conducted to identify the elements that would bring the characteristic of ultra-low IFT. The characterization of the surfactant using FTIR, TG-IR, and HPLC suggested that unreacted materials associated with the surfactant remained, such as the carryover of a fatty amide from the intermediate process, residues of N, N trimethylene dimethylamine and sodium chloride as a by-product, and the important newly formed sodium oleate compound that was inadvertently generated via the reaction. The performance of the as-synthesized in seawater condition has been verified and the surface tension plot shows the lowest surface tension point at 0.05 wt.% concentration before developing a plateau region at higher surfactant concentration, indicating that the formation of surfactant micelles has been interrupted by the presence of other components in the solution. The dynamic IFT test performed on the as-synthesized product revealed that it was still able to reduce the crude oil–seawater IFT to an ultra-low level, despite the multiple undesirable components in the surfactant. IFT as low as 3.4 × 10−4 mN/m for the specific seawater and crude oil composition was obtained at a temperature of 96 °C.
28

Niu, Li Wei, Xiang Guo Lu, Hai Hong Zhang, and Li Xin Zhong. "Performance Evaluation of S/P System and its Mechanism Analysis." Advanced Materials Research 791-793 (September 2013): 294–98. http://dx.doi.org/10.4028/www.scientific.net/amr.791-793.294.

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Xinbei Oilfield in Jilin is a tectonic lithology reservoir with high porosity, high permeability, thin oil layers and severe heterogeneity, which has entered a period of high water-cut development. Aiming at actual demand of field development, making use of indoor apparatus monitoring and theoretical analysis method, the author evaluated the viscosity, interfacial tension, absorption characteristics, rheological property, viscoelasticity and displacement efficiency of 5 different binary composite systems composed of surfactants and polymer to optimize the binary flooding system. The results show that Daqing Lianhua/Polymer system can achieve ultra-low interfacial tension with crude oil with small absorption, well stability and little effect on viscoelasticity of polymer solution. The system has higher displacement efficiency and stronger mobility control ability, which is recommend as flooding system for oilfield.
29

Wang, Guo Feng, Lian Zhen Song, Zhi Li Wei, and Xue Wu Wang. "A Laboratory Study of Polymer and Surfactant Binary Combination Flooding in Reservoirs with Low to Medium Permeability." Advanced Materials Research 718-720 (July 2013): 233–38. http://dx.doi.org/10.4028/www.scientific.net/amr.718-720.233.

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Based on the viscosity of 10mPa.s after high speed shearing and the limit surfactants up to ultra-low interfacial tension, polymers and surfactant systems suitable for Longhupao oilfield were optimized by means of mixing formation simulation water with different polymers and surfactants. The relationship between the interfacial tension of the compound system and the component concentration, the effect of surfactants on viscosity, the injectivity of the compound system, etc. were studied on the basis of the research on the binary compound system. The results indicate that the viscosity of the compound system is lower than that of a single polymer solution to a certain degree and the compound system has good migration character in cores. In addition, core flooding experiments on slug combination optimization were made. The experiment results show that the compounded system with pre-pad polymers and surfactants has good oil displacement efficiency and in terms of enhancing the recovery efficiency, chemical flooding should be implemented as soon as possible.
30

Hai-Na, ZHAO, CHENG Xin-Hao, ZHAO Ou-Di, HUANG Jian-Bin, LIU Chen-Jiang, and ZHAO Bo. "Mixed Cationic and Anionic Surfactant Systems Achieve Ultra-Low Interfacial Tension in the Karamay Oil Field." Acta Physico-Chimica Sinica 30, no. 4 (2014): 693–98. http://dx.doi.org/10.3866/pku.whxb201402121.

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31

Shi, Chang Xin, Wei Dong Liu, Bin Cui, and Ji Liu. "Use of petroleum sulfonates to obtain an alkali-free flooding system ensuring ultra-low interfacial tension." Chemistry and Technology of Fuels and Oils 48, no. 2 (May 2012): 109–11. http://dx.doi.org/10.1007/s10553-012-0345-0.

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32

Bai, Yu, Shangqi Liu, Guangyue Liang, Yang Liu, Yuxin Chen, Yu Bao, and Yang Shen. "Wormlike micelles properties and oil displacement efficiency of a salt-tolerant C22-tailed amidosulfobetaine surfactant." Energy Exploration & Exploitation 39, no. 4 (March 2, 2021): 1057–75. http://dx.doi.org/10.1177/0144598721996549.

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Wormlike micelles formed by amidosulfobetaine surfactants present advantage in increasing viscosity, salt-tolerance, thermal-stability and shear-resistance. In the past few years, much attention has been paid on rheology behaviours of amidosulfobetaine surfactants that normally bear C18 or shorter tails. Properties and oil displacement performances of the wormlike micelles formed by counterparts bearing the long carbon chain have not been well documented. In this paper, the various properties of C22-tailed amidosulfobetaine surfactant EHSB under high salinity (TDS = 40g/L) are investigated systematically, including solubility, rheology and interfacial activity. Moreover, its oil displacement performance is studied for the first time. These properties are first compared with those of C16-tailed counterpart HDPS. Results show that the Krafft temperature( TK) of EHSB decreases from above 100°C to 53°C with the increase of TDS to 40 g/L. Increasing concentration of EHSB in the semidilute region induces micelle growth from rod-like micelles to wormlike micelles, and then the worms become entangled or branched to form viscoelastic micelle solution, which will increase the viscosity by several orders of magnitude. The interfacial tension with oil can be reduced to ultra-low level by EHSB solution with concentration below 4.5 mM. Possessing dual functions of mobility control and reducing interfacial tension, wormlike micelles formed by EHSB present a good displacement effect as a flooding system, which is more than 10% higher than HPAM with the same viscosity. Compared with the shorter tailed surfactant, the ultra-long tailed surfactant is more efficient in enhancing viscosity and reducing interfacial tension, so as to enhance more oil recovery. Our work provides a helpful insight for comprehending surfactant-based viscoelastic fluid and provides a new viscoelastic surfactant flooding agent which is quite efficient in chemical flooding of offshore oilfield.
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Xian-Zhong, WANG, KANG Wan-Li, MENG Xiang-Can, FAN Hai-Ming, XU Hai, HUANG Jing-Wei, FU Jian-Bin, and ZHANG Yi-Nuo. "Ultra-Low Interfacial Tension in High Salinity Reservoir Driven by Synergistic Interaction of Zwitterionic and Anionic Surfactants." Acta Physico-Chimica Sinica 28, no. 10 (2012): 2285–90. http://dx.doi.org/10.3866/pku.whxb201206291.

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34

Das, Alolika, Nhut Nguyen, and Quoc P. Nguyen. "Low-tension gas process in high-salinity and low-permeability reservoirs." Petroleum Science 17, no. 5 (May 6, 2020): 1329–44. http://dx.doi.org/10.1007/s12182-020-00455-9.

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Abstract Polymer-based EOR methods in low-permeability reservoirs face injectivity issues and increased fracturing due to near wellbore plugging, as well as high-pressure gradients in these reservoirs. Polymer may cause pore blockage and undergo shear degradation and even oxidative degradation at high temperatures in the presence of very hard brine. Low-tension gas (LTG) flooding has the potential to be applied successfully for low-permeability carbonate reservoirs even in the presence of high formation brine salinity. In LTG flooding, the interfacial tension between oil and water is reduced to ultra-low values (10−3 dyne/cm) by injecting an optimized surfactant formulation to maximize mobilization of residual oil post-waterflood. Gas (nitrogen, hydrocarbon gases or CO2) is co-injected along with the surfactant slug to generate in situ foam which reduces the mobility ratio between the displaced (oil) and displacing phases, thus improving the displacement efficiency of the oil. In this work, the mechanism governing LTG flooding in low-permeability, high-salinity reservoirs was studied at a microscopic level using microemulsion properties and on a macroscopic scale by laboratory-scale coreflooding experiments. The main injection parameters studied were injected slug salinity and the interrelation between surfactant concentration and injected foam quality, and how they influence oil mobilization and displacement efficiency. Qualitative assessment of the results was performed by studying oil recovery, oil fractional flow, oil bank breakthrough and effluent salinity and pressure drop characteristics.
35

Sottmann, T., and R. Strey. "Shape Similarities of Ultra-Low Interfacial Tension Curves in Ternary Microemulsion Systems of the Water-Alkane-CiEj Type." Berichte der Bunsengesellschaft für physikalische Chemie 100, no. 3 (March 1996): 237–41. http://dx.doi.org/10.1002/bbpc.19961000309.

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36

Feng, Haishun, Jirui Hou, Tao Ma, Ziyu Meng, Hairong Wu, Hongbin Yang, and Wanli Kang. "The ultra-low interfacial tension behavior of the combined cationic/anionic-nonionic gemini surfactants system for chemical flooding." Colloids and Surfaces A: Physicochemical and Engineering Aspects 554 (October 2018): 74–80. http://dx.doi.org/10.1016/j.colsurfa.2018.06.028.

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37

Canevari, Gerard P., Jan Bock, and Max Robbins. "IMPROVED DISPERSANT BASED ON MICROEMULSION TECHNOLOGY." International Oil Spill Conference Proceedings 1989, no. 1 (February 1, 1989): 317–20. http://dx.doi.org/10.7901/2169-3358-1989-1-317.

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ABSTRACT An initial basic study focused on the interaction between dispersant surfactants and the oil-water interface. In essence, the study identified criteria to explain why a good dispersant is effective and why a poor dispersant is ineffective. The dynamic behavior of the oil-water interface, after the addition of the dispersant, was continuously monitored by a modified Wilhelmy plate device. This procedure provided much insight on the impact of the dispersant at the oil-water interface. One key finding of this study concerned the conditions for achieving very low interfacial tensions. It is known in microemulsion technology that a microemulsion formed by specific surfactants exhibits ultra-low interfacial tension against either oil or water. Microemulsion phase behavior studies then established that some specific surfactants, which form a certain type of microemulsion, are also highly effective dispersants, more effective than current state-of-the-art products. This improvement results in the formation of much finer dispersed oil droplets generated by a very minimum and lower level of energy. This paper will review the results of the basic study and the subsequent formulation of an improved dispersant. Laboratory and field data evaluating and supporting the improved overall performance will be presented.
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Fan, Jiacheng, Zhanqing Qu, Tiankui Guo, Ning Qi, Ming Chen, Xiaoqiang Liu, and Jiwei Wand. "Evaluation on the Basis and Application Performance of a Modified Surface Active Oil-displacing Agent." Revista de Chimie 73, no. 2 (May 2, 2022): 50–61. http://dx.doi.org/10.37358/rc.22.2.8519.

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The oil development has entered the water flooding stage in Changqing Oilfield. Due to the low reservoir permeability and the high oil viscosity, the water-flooding does not achieved the desired effect. A large amount of oil is retained in the reservoir due to the high water surface tension and oil-water interfacial tension. Currently, the performance of an oil-displacing agent is suitable for Changqing oilfield to mitigate this situation, but with high application cost due to its synthesis in an organic solution. In this study the oil-displacing agent is modified, and an amphiphilic oil-displacing agent is synthesized through aqueous polymerization. With addition of the oil-displacing agent, the surface/interface activity of water and oil changed significantly. The surface tension of water and oil reduces from 69mN/m to 25mN/m and from 21mN/m to 7.8mN/m respectively in the 1500mg/L oil-displacing agent at 60℃, and the oil-water interfacial tension reaches the ultra-low level. In addition, the oil-displacing agent has the good oil emulsification ability, and the emulsion shows stable performance. The core flooding experiment shows that the 2000mg/L oil-displacing agent can increase the oil recovery by 20% compared with the water flooding, and this meets the production needs in the oilfield. Since the oil-displacing agent contains a large number of chelating functional groups, so it can also chelate the heavy metal ions in the reservoir to prevent precipitation with incompatible anions in the injected water.
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Esanullah, Yosamin, Japan Trivedi, Benedicta Nwani, and Madison Barth. "Optimal Zwitterionic Surfactant Slug for an Improved Oil Recovery in Oil Wet Carbonate Rocks - Silurian Dolomite." Alberta Academic Review 2, no. 2 (September 10, 2019): 27–28. http://dx.doi.org/10.29173/aar40.

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The increase in energy demand has led to extensive research and development on economically, environmentally and technically feasible ways of improving the ever-growing energy demand. A common derivative of energy is from hydrocarbons, specifically oil. The process of oil recovery can be divided into primary, secondary, and tertiary recovery (also known as enhanced oil recovery). Once the internal pressure of a reservoir has depleted enough during primary and secondary recovery, more advanced techniques in enhanced oil recovery mechanisms are used to recover 50-80% of oil in the reservoir. Tertiary recovery includes the use of surfactants to reduce interfacial tension (IFT) or alter wettability. In this work, a zwitter ionic surfactant at two different concentrations is evaluated for its ability to reduce the interfacial tension between oil and water, as well as altering wettability in silurian dolomite. To achieve this, fluid-fluid analysis was done by a compatibility test, phase behavior test and interfacial tension measurements. Rock-fluid analysis was also completed by means of floatation test, carried out with carbonate rock particles to analyze the surfactant’s ability to alter wettability. Solution pH measurements were taken to validate the qualitative floatation test results. Results show that the surfactant, chembetaine C surfactant, is compatible with all ranges of salinities investigated, though was not able to produce a winsor type III micro-emulsion. The results of the interfacial tension measurements are in line with the phase behavior test, as none of the measurements were at ultra-low values. Surfactant retention is likely to occur with the analyzed zwitterionic surfactant based on the fluid-fluid analysis. Qualitative results from the floatation test show that the wettability of the carbonate rock particles cannot be significantly altered to more water-wet conditions. The pH of the solution remains at alkaline values, which can be beneficial in enhanced oil recovery in producing soap in situ, also known as saponification. Overall, tests conclude that this zwitterionic surfactant at 1% concentration would be most effective at 10,000 ppm salinity brine, though overall is not suitable for chemically enhanced oil recovery.
40

Shreve, Gina S., and Ronald Makula. "Characterization of a New Rhamnolipid Biosurfactant Complex from Pseudomonas Isolate DYNA270." Biomolecules 9, no. 12 (December 17, 2019): 885. http://dx.doi.org/10.3390/biom9120885.

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The chemical and physical properties of extracellular rhamnolipid synthesized by a nonfluorescent Pseudomonas species soil isolate, identified as DYNA270, is described, along with characteristics of rhamnolipid production under varying growth conditions and substrates. The biosurfactant is determined to be an anionic, extracellular glycolipid consisting of two major components, the rhamnopyranoside β-1-3-hydroxydecanoyl-3-hydroxydecanoic acid (GU-6) and rhamnopyranosyl β→β2-rhamnopyranoside-β1-3-hydroxydecanoyl-3-hydroxydecanoic acid (GL-2), of molecular weight 504 and 649 daltons, respectively. These glycolipids are produced in a stoichiometric ratio of 1:3, respectively. The purified rhamnolipid mixture exhibits a critical micelle concentration of 20 mg/L, minimum surface (air/water interface) tension of 22 mN/m, and minimum interfacial tension values of 0.005 mN/m (against hexane). The pH optimum, critical micelle concentration, and effective alkane carbon number were established for Pseudomonas species DYNA270 and compared to those of rhamnolipid produced by Pseudomonas aeruginosa PG201. Significant differences are documented in the physical properties of extracellular rhamnolipids derived from these two microorganisms. The surface properties of this rhamnolipid are unique in that ultra-low surface and interfacial tension values are present in both purified rhamnolipid and culture broth containing the rhamnolipid complex (GU6 and GL2). We are not aware of prior studies reporting surface activity values this low for rhamnolipids. An exception is noted for an extracellular trehalose glycolipid produced by Rhodococcus species H13-A, which measured 0.00005 mN/m in the presence of the co-agent pentanol (Singer et al. 1990). Similar CMC values of 20 mg/L have been reported for rhamnolipids, a few being recorded as 5–10 mg/L for Pseudomonas species DSM2874 (Lang et al. 1984).
41

Xu, Derong, Wanli Kang, Liming Zhang, Jiatong Jiang, Zhe Li, Yao Lu, Pengyi Zhang, and Hairong Wu. "Ultra-Low Interfacial Tension of a Surfactant under a Wide Range of Temperature and Salinity Conditions for Chemical Enhanced Oil Recovery." Tenside Surfactants Detergents 55, no. 3 (May 14, 2018): 252–57. http://dx.doi.org/10.3139/113.110562.

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42

Cao, Renyi, Huaijun Yang, Wei Sun, and Y. Zee Ma. "A new laboratory study on alternate injection of high strength foam and ultra-low interfacial tension foam to enhance oil recovery." Journal of Petroleum Science and Engineering 125 (January 2015): 75–89. http://dx.doi.org/10.1016/j.petrol.2014.11.018.

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43

Betancur, Stefania, Lady J. Giraldo, Francisco Carrasco-Marín, Masoud Riazi, Eduardo J. Manrique, Henderson Quintero, Hugo A. García, Camilo A. Franco-Ariza, and Farid B. Cortés. "Importance of the Nanofluid Preparation for Ultra-Low Interfacial Tension in Enhanced Oil Recovery Based on Surfactant–Nanoparticle–Brine System Interaction." ACS Omega 4, no. 14 (September 17, 2019): 16171–80. http://dx.doi.org/10.1021/acsomega.9b02372.

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44

Yue, Pu, Fan Zhang, and Hui Li Fan. "Study of Oil Displacement Performance of Hydroxyl Sulfobetaine Surfactant." Advanced Materials Research 853 (December 2013): 223–28. http://dx.doi.org/10.4028/www.scientific.net/amr.853.223.

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In this paper, new alkali-free hydroxyl sulfobetaine surfactant designed for the target oil reservoir in our laboratory was used. The interfacial tension property, emulsifying capability, peeling the oil film between surfactant/polymer binary oil-displacing system and the target crude oil and the viscosity of the system were investigated systematically. Finally, oil-displacement capacity of the binary oil-displacing system on the target reservoirs natural cores was discussed. The experimental results indicated under the actual condition of the target oil reservoir with total salinity ranging from 4694mg/L to 24270mg/L and temperature being 50°C, the surfactant/polymer binary oil-displacing system with surfactant mass fraction ranging from 0.025% to 0.2% and polymer mass fraction of 0.15% could reach ultra-low interfacial tension with the target crude oil rapidly. The surfactant/polymer binary system above mentioned could emulsified crude oil easily and the volume fraction of WinsorIII middle phase microemulsion could be up to 53.06%. It also could peel the oil film adhered to oil-wet quartz plate quickly and increase the viscoelastic of surfactant/polymer binary oil-displacing system slightly. The displacement experiments made by using natural core in the target oil field indicated that oil recovery was improved by 15% after water flooding. All these results showed that hydroxyl sulfobetaine surfactant had a good potential for flooding in EOR.
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Barth, Madison, Japan Trivedi, Benedicta Nwani, and Yosamin Esanullah. "Optimal Zwitterionic Surfactant Slug for an Improved Oil Recovery in Oil Wet Carbonate Rocks." Alberta Academic Review 2, no. 2 (September 10, 2019): 7–8. http://dx.doi.org/10.29173/aar45.

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Of recent, there has been research and development in the technologies/techniques required to meet the ever-growing energy demand in the world. Oil is a major source of energy which is contained in over 50% of carbonate reservoirs. The oil/mixed wettability of carbonate rocks makes it technically challenging to recover the needed oil. The process of crude oil recovery has three different stages primary, secondary and tertiary recovery. Tertiary recovery is also known as enhanced oil recovery or EOR. EOR includes the use of surfactants to reduce the interfacial tension between a hydrocarbon and brine, thus suspending them both in a microemulsion. Surfactant performance can be affected by multiple variables, including brine salinity, surfactant concentration, and type of hydrocarbon. A petroleum engineer must take all variables into consideration when selecting a surfactant to make sure that its efficiency is as high as possible, especially because the use of surfactants is costly. In this work, a chembetaine zwitter ionic surfactant of two different concentrations are evaluated at various synthetic formation brine salinities for their favourable wettability alteration and interfacial tension reduction in oil-wet carbonate- Silurian Dolomite. For the evaluation, fluid-fluid and rock-fluid analysis are carried out to select the optimal surfactant concentration and brine salinity with the greatest improved oil recovery potential. Results are indicative that the surfactant at the two concentrations studied is compatible at the ranges of salinities evaluated. However, from the fluid-fluid analysis, there was no ultra-low interfacial tension that is needed for oil mobilization. More so, the rock-fluid analysis shows that the surfactant is not able to alter the wettability of oil-wet rocks favourably. The optimal surfactant slug for the greatest oil recovery, in this case, would be expected at 0.5% surfactant concentration in 10,000 ppm synthetic formation brine salinity. This study, therefore, serves as a guide for the design of optimal surfactant slug in oil-wet carbonate cores requires to reduce non-productive time, prevent reservoir damage and therefore improve recovery.
46

Haq, Bashirul, Jishan Liu, and Keyu Liu. "Evaluation of ionic effect of green surfactants on interfacial tension reduction under reservoir conditions for enhanced oil recovery." APPEA Journal 51, no. 2 (2011): 727. http://dx.doi.org/10.1071/aj10107.

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Ions play a vital role in surfactant chemistry of EOR. The ionic effects of green surfactants are not yet well characterised, but they are biodegradable and environmental friendly, and have great potential for EOR. This study characterises some green anionic and non-ionic surfactants through the determination of the interfacial tension (IFT) of each group and the combined effect of the green surfactants with alcohols on IFT and micro emulsions; and the oil recovery factor through laboratory experiments. Alky Polyglucosides (APG) was selected from the non-ionic group, which can produce ultra low IFT. APG surfactants are produced from coconut/palm oil, corn, potato or wheat residues. Bio-surfactants produced by a microbe called Bacillus mojavensis was taken from the anionic group. This study has found that the APG surfactants are completely and quickly biodegradable and environmentally friendly. APG surfactants show low long-term aquatic toxicity for bacteria, favourable for fish and acceptable effects are on Daphnia and Algae. Our laboratory tests have confirmed that APG PG 8166 can reduce IFT from 12–3.16 dyne/cm at 40 ppm under laboratory ambient condition and from 12–4.32 dyne/cm at a reservoir condition of 50oC and 1000psi. In contrast, the bio-surfactant at 40 ppm decreased IFT from 12–4.14 dyne/cm at the same reservoir condition. Temperature appears to have little effect on the IFT of APG surfactants. There is no significant reduction in the IFT values when APG at 10 ppm combined with the pentanol at concentrations of 15–120 ppm.
47

Gao, Cheng‐Long, Hong‐Ze Gang, Jin‐Feng Liu, Bo‐Zhong Mu, and Shi‐Zhong Yang. "A New Benzylated Fatty Acid Amide Amphoteric Surfactant Derived from Hydrogenated Castor Oil with Ultra‐Low Interfacial Tension between Crude Oil and Brine." Journal of Surfactants and Detergents 24, no. 3 (February 27, 2021): 511–15. http://dx.doi.org/10.1002/jsde.12483.

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48

Bao, Xin-Ning, Wei-Dong Zhang, Jun Jin, Hui Zhang, Hong-Ze Gang, Shi-Zhong Yang, Ying-Cheng Li, and Bo-Zhong Mu. "Binary system of alkyl polyether carboxylate and quaternary ammonium with ultra-low interfacial tension at high temperature and a wide range of salinity." Journal of Petroleum Science and Engineering 208 (January 2022): 109541. http://dx.doi.org/10.1016/j.petrol.2021.109541.

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49

Song, Qiang, Jian Kang, Min Tang, and Yun Liang. "Separation of Water in Diesel Using Filter Media Containing Kapok Fibers." Materials 13, no. 11 (June 11, 2020): 2667. http://dx.doi.org/10.3390/ma13112667.

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Traditional water-repellent filter media for water separation in diesel fail to meet requirements due to the high content of surfactants in low sulfur diesel and ULSD (ultra low sulfur diesel). To improve the water separation performance of filter media, a novel dual-layer filter medium was prepared by hydrophilic fibers (glass microfibers) and hydrophobic fibers (kapok fibers and bi-component PET fibers). The results showed that the separation efficiency of a filter medium (sample #2) with the upstream layer containing 20 wt% kapok fibers was 89.5%, which was higher than that of filter samples with the upstream layer containing 0 wt%, 40 wt%, 60 wt% and 80 wt% kapok fibers. When the interfacial tension (IFT) of water in diesel was 21 mN/m, 17 mN/m and 13 mN/m, the separation efficiency of filter sample #2 was 99.5%, 89.5% and 30.5%, respectively, which was 23.9%, 57.4% and 17.8% higher than that of the commercial water-repellent filter samples composed of a polybutylene terephthalate (PBT) fiber layer and cellulose fiber layer.
50

WANG, Xin, Hongze GANG, Jinfeng LIU, Shizhong YANG, and Bozhong MU. "Consideration of Application Possibility of Biosurfactant and Alkaline-surfactant-polymer (B-ASP) with Ultra-low Crude Oil/Brine Interfacial Tension for Enhancement of Oil Recovery." Journal of the Japan Petroleum Institute 64, no. 2 (March 1, 2021): 84–91. http://dx.doi.org/10.1627/jpi.64.84.

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