Experimental study on adsorption of a new surfactant onto carbonate reservoir samples—application to EOR

Zendehboudi, Sohrab; Ahmadi, Mohammad Ali; Rajabzadeh, Amin Reza; Mahinpey, Nader; Chatzis, Ioannis

doi:10.1002/cjce.21806

Cited by 90 publications

(76 citation statements)

References 45 publications

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“…To evaluate adsorption of the ionic surfactant in the presence of different silica nanoparticles, two core samples were crushed using a jaw crusher and then passed through specific sieves (50-70 mesh size) for repeatability of the experiments and to double check our adsorption experiments (Salari et al 2011;Ahmadi and Shadizadeh 2012, 2013a, b, c, 2015Ahmadi et al 2014;Zendehboudi et al 2013). X-ray diffraction (XRD) was conducted to analyze the phase composition of the core samples, and the results are shown in Fig.…”

Section: Core and Crushed Core Samplesmentioning

confidence: 99%

“…was used in experiments (Salari et al 2011; Specific gravity of C 6? 0.8325 , 2013c, 2015Zendehboudi et al 2013). The electrical conductivity trend of surfactant solutions at various concentrations without nanoparticles is illustrated in Fig.…”

Section: Determination Of Critical Micelle Concentration (Cmc)mentioning

confidence: 99%

“…According to the procedure of adsorption experiments reported by Ahmadi and his colleagues (Ahmadi and Shadizadeh 2012, 2013c, 2015Zendehboudi et al 2013) and Salari et al (2011), the depletion solution or batch tests were conducted to indicate adsorption behavior of the ionic surfactant on the carbonate surface in the presence of silica nanoparticles. Two crucial points of the proposed adsorption experiments are the adsorption equilibrium time and the ratio of the solid and aqueous phases.…”

Section: Adsorption Experimentsmentioning

confidence: 99%

“…For more details about the procedure of conductivity measurement for adsorption experiments, the authors referred to Ahmadi and Shadizadeh (2012, 2013a, c, 2015. Finally, the magnitude of the surfactant loss onto the rock surface (in terms of mg surfactant/g of rock) was calculated from the following formulation (Salari et al 2011;Ahmadi and Shadizadeh 2012, 2013c, 2015Zendehboudi et al 2013):…”

Section: Adsorption Experimentsmentioning

confidence: 99%

“…The CMC of SDS was determined by measuring the electrical conductivity of the solution, which was also used by Ahmadi and his coworkers (Salari et al 2011;Ahmadi and Shadizadeh 2012, 2013c, 2015Zendehboudi et al 2013). The CMC of SDS was 2485 ppm.…”

Section: Adsorption Experimentsmentioning

confidence: 99%

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Performance improvement of ionic surfactant flooding in carbonate rock samples by use of nanoparticles

Ahmadi

Sheng

2016

Pet. Sci.

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Various surfactants have been used in upstream petroleum processes like chemical flooding. Ultimately, the performance of these surfactants depends on their ability to reduce the interfacial tension between oil and water. The surfactant concentration in the aqueous solution decreases owing to the loss of the surfactant on the rock surface in the injection process. The main objective of this paper is to inhibit the surfactant loss by means of adding nanoparticles. Sodium dodecyl sulfate and silica nanoparticles were used as ionic surfactant and nanoparticles in our experiments, respectively. AEROSIL Ò 816 and AEROSIL Ò 200 are hydrophobic and hydrophilic nanoparticles. To determine the adsorption loss of the surfactant onto rock samples, a conductivity approach was used. Real carbonate rock samples were used as the solid phase in adsorption experiments. It should be noted that the rock samples were water wet. This paper describes how equilibrium adsorption was investigated by examining adsorption behavior in a system of carbonate sample (solid phase) and surfactant solution (aqueous phase). The initial surfactant and nanoparticle concentrations were 500-5000 and 500-2000 ppm, respectively. The rate of surfactant losses was extremely dependent on the concentration of the surfactant in the system, and the adsorption of the surfactant decreased with an increase in the nanoparticle concentration. Also, the hydrophilic nanoparticles are more effective than the hydrophobic nanoparticles.

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Section: Core and Crushed Core Samplesmentioning

confidence: 99%

Section: Determination Of Critical Micelle Concentration (Cmc)mentioning

confidence: 99%

Section: Adsorption Experimentsmentioning

confidence: 99%

Section: Adsorption Experimentsmentioning

confidence: 99%

Section: Adsorption Experimentsmentioning

confidence: 99%

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Performance improvement of ionic surfactant flooding in carbonate rock samples by use of nanoparticles

Ahmadi

Sheng

2016

Pet. Sci.

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Simulation of kinetic behavior of natural surfactants adsorption using a new robust approach

Daryasafar

Borazjani

Daryasafar

2018

Journal of Chemometrics

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Surfactant-based enhanced oil recovery techniques are known as promising methods for mobilizing the trapped oil in porous media. Surfactants can improve oil recovery by modifying the wettability of rock minerals and also by reducing the interfacial tension between injected water and the trapped oil. Natural surfactants have been introduced as good candidates for enhanced oil recovery applications. In addition, they are less expensive and also have less detrimental environmental effects in comparison with the industrial surfactants. Various empirical models have been proposed for simulating the kinetic behavior of surfactants adsorption, but these models suffer from overestimation and underestimation and they cannot be generalized for even a type of surfactant. Therefore, it is crucial to develop a new model that can overcome these issues. In this study, a new simple, rapid, and accurate model based on least square support vector machines (LSSVMs) was developed for predicting the kinetic adsorption density of natural surfactants on both sandstone and carbonate minerals. Coupled simulated annealing algorithm (CSA) is used for tuning the parameters of the model. Predicted values by this model were in an excellent agreement with experimental values with a coefficient of determination of 0.990. The results demonstrated that the proposed LSSVM-CSA model has the best performance in comparison with the other well-established kinetic models. Furthermore, the model reliability was investigated over input parameters changes and showed the acceptable efficiency of the proposed model.

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On the evaluation of Alkaline‐Surfactant‐Polymer flooding in a field scale: Screening, modelling, and optimization

et al. 2017

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Chemical enhanced oil recovery methods, including alkaline surfactant polymer (ASP) flooding, have found special significance for oil reservoirs. ASP flooding provides different situations based on ratio of injection of three ASP components. This study identifies the behaviour of injection components and their interaction, investigating the synergy between them. To this end, an Iranian oil reservoir is studied. The factors influencing the injection process are identified and then a combination of these factors and the concentration of ASP components are modelled. All modelling results are fitted with R‐squared and adjusted R‐squared values above 0.96. Finally, the optimization is conducted to determine the best injection scenario. The most important aspect of this study is to investigate simultaneously the effect of different parameters of ASP in a real case. The screening results show that the effect of polymer on viscosity is the most influential factor in ASP flooding. The modelling results show that water cut in the case of simultaneous injection of three components is less than other cases of injection. This represents the synergy of components in the injection process during ASP flooding. The miscibility between water and polymer solution also leads to less produced water and more produced oil. In the final stage, the optimization results show that the optimal scenario is injection of surfactant and polymer with the greatest amount of miscibility between water and polymer solution. It can be concluded that with this approach, ASP injection can efficiently be analyzed and optimized from a technical point of view.

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Experimental study on adsorption of a new surfactant onto carbonate reservoir samples—application to EOR

Cited by 90 publications

References 45 publications

Performance improvement of ionic surfactant flooding in carbonate rock samples by use of nanoparticles

Performance improvement of ionic surfactant flooding in carbonate rock samples by use of nanoparticles

Simulation of kinetic behavior of natural surfactants adsorption using a new robust approach

On the evaluation of Alkaline‐Surfactant‐Polymer flooding in a field scale: Screening, modelling, and optimization

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