Effect of Hydrocarbon Parts of the Polar Headgroup on Surfactant Aggregates in Gemini and Bola Surfactant Solutions

Langmuir ◽  
2007 ◽  
Vol 23 (6) ◽  
pp. 2932-2936 ◽  
Author(s):  
Ting Lu ◽  
Feng Han ◽  
Guangru Mao ◽  
Guofeng Lin ◽  
Jianbin Huang ◽  
...  
Keyword(s):  
Surfactant Aggregates ◽  
Surfactant Solutions ◽  
Bola Surfactant

NUMERICAL SIMULATION OF PULSATING HEAT PIPE WITH SURFACTANT SOLUTIONS

2018 ◽  
Author(s):  
Durga Bastakoti ◽  
Hongna Zhang ◽  
Wei-Hua Cai ◽  
Feng-Chen Li
Keyword(s):  
Numerical Simulation ◽  
Heat Pipe ◽  
Pulsating Heat Pipe ◽  
Surfactant Solutions

PRESSURE LOSSES AND HEAT TRANSFER FOR FLOW OF DRAG REDUCING SURFACTANT SOLUTIONS IN PIPES AND FITTINGS

Equipment ◽  
2006 ◽  
Author(s):  
J. Sestak ◽  
V. Mik ◽  
J. Myska ◽  
M. Dostal ◽  
L. Mihalka
Keyword(s):  
Heat Transfer ◽  
Pressure Losses ◽  
Surfactant Solutions

Effect of Microbubble Mixtures on the Washing Rate of Surfactant Solutions in a Swirling Flow and an Alternating Flow

2013 ◽  
Vol 50 (5) ◽  
pp. 332-338 ◽  
Author(s):  
Akiomi Ushida ◽  
Tomiichi Hasegawa ◽  
Keiko Amaki ◽  
Takatsune Narumi
Keyword(s):  
Swirling Flow ◽  
Surfactant Solutions

In vitro and in vivo evaluation of Bola-surfactant containing niosomes for transdermal delivery

2007 ◽  
Vol 9 (4) ◽  
pp. 421-433 ◽  
Author(s):  
Donatella Paolino ◽  
Rita Muzzalupo ◽  
Antonio Ricciardi ◽  
Christian Celia ◽  
Nevio Picci ◽  
...  
Keyword(s):  
Transdermal Delivery ◽  
In Vivo Evaluation ◽  
Bola Surfactant

A New Dynamic Wettability-Alteration Model for Oil-Wet Cores During Surfactant-Solution Imbibition

SPE Journal ◽  
2013 ◽  
Vol 18 (05) ◽  
pp. 818-828 ◽  
Author(s):  
M. Hosein Kalaei ◽  
Don W. Green ◽  
G. Paul Willhite
Keyword(s):  
Experimental Data ◽  
Oil Recovery ◽  
History Matching ◽  
Mechanistic Model ◽  
Surfactant Solution ◽  
Experimental Tests ◽  
Quantitative Agreement ◽  
Wettability Alteration ◽  
Porous Rock ◽  
Surfactant Solutions

Summary Wettability modification of solid rocks with surfactants is an important process and has the potential to recover oil from reservoirs. When wettability is altered by use of surfactant solutions, capillary pressure, relative permeabilities, and residual oil saturations change wherever the porous rock is contacted by the surfactant. In this study, a mechanistic model is described in which wettability alteration is simulated by a new empirical correlation of the contact angle with surfactant concentration developed from experimental data. This model was tested against results from experimental tests in which oil was displaced from oil-wet cores by imbibition of surfactant solutions. Quantitative agreement between the simulation results of oil displacement and experimental data from the literature was obtained. Simulation of the imbibition of surfactant solution in laboratory-scale cores with the new model demonstrated that wettability alteration is a dynamic process, which plays a significant role in history matching and prediction of oil recovery from oil-wet porous media. In these simulations, the gravity force was the primary cause of the surfactant-solution invasion of the core that changed the rock wettability toward a less oil-wet state.

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