The Effect of Live Crude on Alkaline-Surfactant-Polymer Formulations; Implications for Final Formulation Design

Southwick, J. G.; Svec, Yi; Chilek, Greg; Shahin, Gordon T.

doi:10.2118/135357-ms

Cited by 25 publications

(16 citation statements)

References 7 publications

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“…Cottin et al (2012) reported a slight increase in the optimum salinity of their live oil compared with their dead oil. Puerto and Reed (1983), Roshanfekr et al (2012), and Southwick et al (2012) observed that the optimum salinity decreased when methane was added in oils. Sagi et al (2013) also observed a decrease in the optimum salinity when either methane, ethane or CO2 was added in a dead oil.…”

Section: Figure 1 -Types Of Microemulsions (Surfactant Systems)mentioning

confidence: 98%

Status of surfactant EOR technology

2015

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Section: Figure 1 -Types Of Microemulsions (Surfactant Systems)mentioning

confidence: 98%

Status of surfactant EOR technology

2015

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“…In recent years, surfactant flooding has become one of the most useful tools in enhanced oil recovery (EOR) methods (Elraies et al 2010;Flaaten et al 2010;Kumar and Mohanty 2010;Santanna et al 2009;Southwick et al 2010). Selection of proper surfactants for EOR is an important issue in surfactant flooding for better economic recovery.…”

Section: Introductionmentioning

confidence: 99%

Enhanced oil recovery by nonionic surfactants considering micellization, surface, and foaming properties

Bera¹,

Mandal

Belhaj³

et al. 2017

Pet. Sci.

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Surfactants for enhanced oil recovery are important to study due to their special characteristics like foam generation, lowering interfacial tension between oleic and aqueous phases, and wettability alteration of reservoir rock surfaces. Foam is a good mobility control agent in enhanced oil recovery for improving the mobility ratio. In the present work, the foaming behavior of three nonionic ethoxylated surfactants, namely Tergitol 15-S-7, Tergitol 15-S-9, and Tergitol 15-S-12, was studied experimentally. Among the surfactants, Tergitol 15-S-12 shows the highest foamability. The effect of NaCl concentration and synthetic seawater on foaming behavior of the surfactants was investigated by the test-tube shaking method. The critical micelle concentrations of aqueous solutions of the different nonionic surfactants were measured at 300 K. It was found that the critical micelle concentrations of all surfactants also increased with increasing ethylene oxide number. Dynamic light scattering experiments were performed to investigate the micelle sizes of the surfactants at their respective critical micelle concentrations. Core flooding experiments were carried out in sand packs using the surfactant solutions. It was found that 22% additional oil was recovered in the case of all the surfactants over secondary water flooding. Tergitol 15-S-12 exhibited the maximum additional oil recovery which is more than 26% after water injection.

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“…More recently, Southwick et al (2010) carried out experiments on live crude and observed that the optimum salinity is decreased and the optimum solubilization ratio increased compared to a dead crude-oil system at atmospheric pressure. Using regular solution theory, they predicted that optimum solubilization ratio will not always increase upon addition of methane to dead oil.…”

Section: Introductionmentioning

confidence: 99%

Simulation of the Effect of Pressure and Solution Gas on Oil Recovery From Surfactant/Polymer Floods

et al. 2012

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Surfactant/polymer (SP) and alkali/surfactant/polymer flooding is of current interest because of the need to recover residual oil after primary and secondary recovery. If designed properly, these enhanced-oil-recovery processes can give very high oil recoveries. Microemulsion phase behavior plays a central role in process performance and is typically measured by performing salinity scans in glass pipettes at atmospheric pressure and reservoir temperature using dead crude oil from the reservoir of interest. There have been only a few experiments reported in the literature on live oil at reservoir pressure and temperature, and the importance of those experimental results is conflicting.This paper investigates the effect of pressure and solution gas on microemulsion phase behavior and its impact on oil recovery. We examine previous data reported in the literature, and report new measurements with live oil to show that the optimum parameters can change significantly. The experiments show that while pressure induces a phase transition from upper microemulsion (Winsor Type IIþ) to lower microemulsion (Winsor Type II-), solution gas does the opposite. An increase in pressure decreases the optimum solubilization ratio and shifts the optimum salinity to a larger value. Adding methane to dead oil at constant pressure does the reverse. Thus, these effects are coupled and both must be taken into account. Using a numerical simulator, we show that these changes in the optimum conditions can significantly impact oil recovery if not accounted for in the SP design.

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The Effect of Live Crude on Alkaline-Surfactant-Polymer Formulations; Implications for Final Formulation Design

Cited by 25 publications

References 7 publications

Status of surfactant EOR technology

Status of surfactant EOR technology

Enhanced oil recovery by nonionic surfactants considering micellization, surface, and foaming properties

Simulation of the Effect of Pressure and Solution Gas on Oil Recovery From Surfactant/Polymer Floods

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