Interfacial tension of double-chain cationic surfactants

2007 ◽  
pp. 131-134 ◽  
Author(s):  
S. Haas ◽  
H. Hoffmann
Keyword(s):  
Interfacial Tension ◽  
Cationic Surfactants ◽  
Double Chain

scholarly journals Micelle and Surface Tension of Double-Chain Cationic Surfactants

ACS Omega ◽  
2018 ◽  
Vol 3 (9) ◽  
pp. 10907-10911 ◽  
Author(s):  
Chi Minh Phan ◽  
Shin-ichi Yusa ◽  
Tomoko Honda ◽  
Komol Kanta Sharker ◽  
Anita Evelyn Hyde ◽  
...  
Keyword(s):  
Surface Tension ◽  
Cationic Surfactants ◽  
Double Chain

scholarly journals The Role of Chain Length and Structure in Surfactant Adsorption at Na-Kaolinite

1998 ◽  
Vol 16 (7) ◽  
pp. 565-575 ◽  
Author(s):  
Jinben Wang ◽  
Buxing Han ◽  
Ming Dai ◽  
Haike Yan ◽  
Zhixin Li ◽  
...  
Keyword(s):  
Chain Length ◽  
Cationic Surfactants ◽  
Adsorption Mechanism ◽  
Alkyl Chain ◽  
Quantitative Description ◽  
Single Chain ◽  
Double Chain ◽  
Intramolecular Association ◽  
Chain Lengths

The adsorption of a series of cationic surfactants with different chain lengths and structures on a non-swelling clay surface (sodium kaolinite) has been studied by microelectrophoresis and adsorption isotherms. It was found that an increase in the number of CH2 groups in the shorter alkyl chain of the double-chain surfactant has much less effect on the adsorption behaviour than changing the length of the alkyl chain in the single-chain surfactants. It is inferred that the effective hydrophobicity of the shorter chains in these double-chain surfactants is reduced by their intramolecular association with the longer chain. A comparison of adsorption and micellization leads to an empirical, quantitative description of the effects of alkyl chain length and structure on adsorption. The adsorption mechanism of cationic surfactants on to Na-kaolinite was discussed.

scholarly journals The use of laurylamine hydrocholoride CH3(CH2)11 NH3 –Cl for secondary oil recovery

2012 ◽  
Vol 9 (1) ◽  
pp. 120-123
Author(s):  
Baghdad Science Journal
Keyword(s):  
Interfacial Tension ◽  
Oil Recovery ◽  
Cationic Surfactants ◽  
Water Injection ◽  
Solution Concentration ◽  
Oil Field ◽  
Residual Oil ◽  
Secondary Oil Recovery ◽  
Total Oil ◽  
The Relationship

Laurylamine hydrochloride CH3(CH2)11 NH3 – Cl has been chosen from cationic surfactants to produce secondary oil using lab. model shown in fig. (1). The relationship between interfacial tension and (temperature, salinity and solution concentration) have been studied as shown in fig. (2, 3, 4) respectively. The optimum values of these three variables are taken (those values that give the lowest interfacial tension). Saturation, permeability and porosity are measured in the lab. The primary oil recovery was displaced by water injection until no more oil can be obtained, then laurylamine chloride is injected as a secondary oil recovery. The total oil recovery is 96.6% or 88.8% of the residual oil has been recovered by this technique as shown in fig. (5). This method was applied in an oil field and it gave approximate values close to that obtained in the lab.

Synthesis and Physicochemical Properties of Double-Chain Cationic Surfactants

2015 ◽  
Vol 61 (1) ◽  
pp. 142-150 ◽  
Author(s):  
Sinem Engin Özdil ◽  
Halide Akbaş ◽  
Mesut Boz
Keyword(s):  
Physicochemical Properties ◽  
Cationic Surfactants ◽  
Double Chain

Laboratory Monitoring of Surfactant Imbibition With Computerized Tomography

2001 ◽  
Vol 4 (01) ◽  
pp. 16-25 ◽  
Author(s):  
H.L. Chen ◽  
L.R. Lucas ◽  
L.A.D. Nogaret ◽  
H.D. Yang ◽  
D.E. Kenyon
Keyword(s):  
Interfacial Tension ◽  
Oil Recovery ◽  
Cationic Surfactants ◽  
Marangoni Effect ◽  
Fractured Reservoir ◽  
Improved Oil Recovery ◽  
The Matrix ◽  
Ethoxylated Surfactants ◽  
Oil Water ◽  
Pilot Tests

Summary Oil production from fractured reservoirs can occur by spontaneous water imbibition and oil expulsion from the matrix into the fracture network. Injection of dilute surfactant can recover additional oil by lowering oil/water interfacial tension (IFT) or altering rock wettability, thereby enhancing countercurrent movement and accelerating gravity segregation. Modeling of such recovery mechanisms requires knowledge of temporal and spatial fluid distribution within porous media. In this study, dilute surfactant imbibition tests performed for vertically oriented carbonate cores of the Yates field were found to produce additional oil over brine imbibition. Computerized tomography (CT) scans were acquired at times during the imbibition process to quantify spatial fluid movement and saturation distribution, and CT results were in reasonable agreement with material-balance information. Imbibition and CT-scan results suggest that capillary force and IFT gradient (Marangoni effect) expedited countercurrent movement in the radial direction within a short period, whereas vertical gravity segregation was responsible for a late-time ultimate recovery. Wettability indices, determined by the U.S. Bureau of Mines (USBM) centrifuge method, show that dilute surfactants have shifted the wetting characteristic of the Yates rocks toward less oil-wet. A numerical model was developed to simulate the surfactant imbibition experiments. A reasonable agreement between simulated and experimental results was achieved with surfactant diffusion and transitioning of relative permeability and capillary pressure data as a function of IFT and surfactant adsorption. Introduction The Yates field, discovered in 1926, is a massive naturally fractured carbonate reservoir located at the southern tip of the Central Basin Platform in the Permian Basin of west Texas. The main production comes from a 400-ft-thick San Andres formation with average matrix porosity and permeability of 15% and 100 md, respectively, and a fracture permeability of greater than 1,000 md. The primary oil recovery mechanism at the Yates field is a gravity-dominated double displacement process in which the gas cap is inflated through nitrogen injection. Dilute surfactant pilot tests have been conducted at the Yates field since early 1990. The surfactant, Shell 91-8 nonionic ethoxy alcohol, was diluted with produced water to a concentration (3,100-3,880 ppm) much higher than the critical micelle concentration (CMC) and was injected into the oil/water transition zone below the oil/water contact (OWC) for both single-and multiwell tests. Single- and multiwell pilot tests demonstrated improved oil recovery (IOR) and a reduced water/oil ratio in response to dilute surfactant treatments. Previous viscous flooding experiments with Yates reservoir cores indicated that the injection of dilute surfactants resulted in improved oil recovery when compared to the injection of brine.1 However, in a fractured reservoir such as Yates, the success of surfactant flooding depends on how effectively the surfactant residing in the fracture spaces can penetrate the matrix. Thus, static sponta neous imbibition was believed to better represent the fluid exchange between the rock matrix and fracture network. Spontaneous imbibition can be driven by either capillary or gravity forces and is a function of interfacial tension, wettability, density difference, and characteristic pore radius. Austad et al. investigated spontaneous surfactant imbibition into oil-saturated and low-permeability (less than 10 md) chalk cores.2–4 They concluded that, for water- and mixed-wet cores using an anionic surfactant, the early-time recovery mechanism was countercurrent movement, followed by gravity displacement at late time. For oil-wet cores using a cationic surfactant, the primary displacement mechanism was countercurrent movement. Countercurrent movement was believed to be a function not only of capillary forces, but also of the Marangoni effect that describes spontaneous interfacial flows induced by an IFT gradient.3,5,6 It was believed that the Marangoni effect created a hydrodynamic shear stress at the oil/water interface that provided additional force to mobilize the displaced oil phase in the direction opposite to the imbibed aqueous phase. For the oil-wet cores, Austad et al. hypothesized that the cationic surfactant improved oil recovery by altering rock wettability.4 In particular, the increased water wettability resulted in a decreased contact angle and increased capillary forces, thus maximizing countercurrent movement. The Yates reservoir is similarly believed to be oil- to mixed-wet. Cationic surfactants, although effective in altering wettability for oil-wet rocks, are too expensive to be implemented in a field treatment. Nonionic and anionic ethoxylated surfactants were selected for the Yates field pilot tests and laboratory studies because they were less expensive than cationic surfactants and they improved oil recovery without forming emulsions. The IOR mechanism for the ethoxylated surfactants used at Yates is different from the mechanism for the cationic surfactants used by Austad et al. The different IOR mechanism at Yates is largely owing to the nature of the highly fractured reservoir with a high-permeability matrix (average 100 md). Gravity is the dominant force in oil recovery for a fractured reservoir (mixed dolomite/sandstone formation).7 For such a gravity-dominated process, oil is displaced from the matrix blocks by cocurrent movement vertically through the top surface. The ethoxylated surfactants used at Yates are believed to quickly distribute monomers along the oil/water interface. These monomers lower the IFT and, while the surfactant is present in the aqueous phase, they may alter the wettability from oil-wet to less oil-wet. Thus, although the wettability alteration may occur, enhancing gravity forces owing to IFT-lowering may be the primary IOR mechanism for the Yates field. The objective of this work is to quantify the relative significance of radial countercurrent movement caused by capillary forces and vertical cocurrent movement caused by gravity during surfactant static imbibition into Yates cores. The importance of IOR mechanisms such as adsorption-dependent wettability alteration, interfacial tension reduction, and surfactant diffusion are illustrated through a comparison of laboratory data and numerical simulation results.

scholarly journals Vesicles Formation of Double-Chain Cationic Surfactants with Different Chain-Lengths in Deep Sea Water.

2002 ◽  
Vol 51 (1) ◽  
pp. 43-50 ◽  
Author(s):  
Chihiro KAISE ◽  
Hideki SAKAI ◽  
Aritomo YAMAGUCHI ◽  
Shoko YOKOYAMA ◽  
Teruhisa KANEKO ◽  
...  
Keyword(s):  
Deep Sea ◽  
Cationic Surfactants ◽  
Sea Water ◽  
Double Chain ◽  
Deep Sea Water ◽  
Chain Lengths

scholarly journals Impact of anionic and cationic surfactants interfacial tension on the oil recovery enhancement

2020 ◽  
Vol 373 ◽  
pp. 93-98 ◽  
Author(s):  
Fei Pan ◽  
Zaixu Zhang ◽  
Xiaoxuan Zhang ◽  
Afshin Davarpanah
Keyword(s):  
Interfacial Tension ◽  
Oil Recovery ◽  
Cationic Surfactants ◽  
Anionic And Cationic Surfactants
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