A review on applications of nanotechnology in the enhanced oil recovery part A: effects of nanoparticles on interfacial tension

Cheraghian, Goshtasp; Hendraningrat, Luky

doi:10.1007/s40089-015-0173-4

Cited by 185 publications

(109 citation statements)

References 89 publications

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“…The purpose of surfactant flooding is to increase the capillary number by reducing IFT between the oil and water [1,47]. Nanofluids of 70-150 nm dissolved in aqueous solution of surfactants can result in effective oil displacement of 35% compared to using only surfactants in a homogeneous reservoir, and 17% in a heterogeneous reservoir at a temperature of 25 °C.…”

Section: Interfacial Tension (Ift) Reductionmentioning

confidence: 99%

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Mechanism governing nanoparticle flow behaviour in porous media: insight for enhanced oil recovery applications

Agi

Gbadamosi

2018

Int Nano Lett

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Nanotechnology has found its way to petroleum engineering, it is well-accepted path in the oil and gas industry to recover more oil trapped in the reservoir. But the addition of nanoparticles to a liquid can result in the simplest flow becoming complex. To understand the working mechanism, there is a need to study the flow behaviour of these particles. This review highlights the mechanism affecting the flow of nanoparticles in porous media as it relates to enhanced oil recovery. The discussion focuses on chemical-enhanced oil recovery, a review on laboratory experiment on wettability alteration, effect of interfacial tension and the stability of emulsion and foam is discussed. The flow behaviour of nanoparticles in porous media was discussed laying emphasis on the physical aspect of the flow, the microscopic rheological behaviour and the adsorption of the nanoparticles. It was observed that nanofluids exhibit Newtonian behaviour at low shear rate and non-Newtonian behaviour at high shear rate. Gravitational and capillary forces are responsible for the shift in wettability from oil-wet to water-wet. The dominant mechanisms of foam flow process were lamellae division and bubble to multiple bubble lamellae division. In a water-wet system, the dominant mechanism of flow process and residual oil mobilization are lamellae division and emulsification, respectively. Whereas in an oil-wet system, the generation of pre-spinning continuous gas foam was the dominant mechanism. The literature review on oil displacement test and field trials indicates that nanoparticles can recover additional oil. The challenges encountered have opened new frontier for research and are highlighted herein.

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Section: Interfacial Tension (Ift) Reductionmentioning

confidence: 99%

“…Effect of reservoir temperature Surfactant also precipitate at high temperature, the median temperature for the surveyed surfactant project is 25.3 °C [47]. Ranka et al [64] stabilized nanoparticles at high-temperature reservoir condition.…”

Section: Effect Of Formationmentioning

confidence: 99%

Mechanism governing nanoparticle flow behaviour in porous media: insight for enhanced oil recovery applications

Agi

Gbadamosi

2018

Int Nano Lett

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“…The nanofluids usually exhibit high thermal conductivities, which are significant to the development of energy, and have been widely used in drug delivery solar cells, lipase immobilization, soil remediation, lubrication, and hydraulic fracturing of gas and oil. In addition, nanofluids have been introduced to the enhanced oil recovery (EOR) area due to their unique thermal properties and large surface area [4][5][6][7][8]. Many works have been done to study the EOR performance of nanofluids composed of different nanoparticles.…”

Section: Nanofluid Floodingmentioning

confidence: 99%

Lessons Learned from Our Recent Research in Chemical Enhanced Oil Recovery (C-EOR) Methods

Wei¹,

Wei²,

Zhao³

et al. 2018

Recent Insights in Petroleum Science and Engineering

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As a result of the ever-increasing global energy demand coupled with the rapid decline of the oil production, the games of enhanced oil recovery (EOR) are played in many oilfields worldwide especially in China. It was reported that EOR jobs produced 45.1 × 10 4 m 3 /d of oil production rate in 2014 all over the world, proving the significance of these jobs.Due to the complex geology, chemical enhanced oil recovery (C-EOR) methods are considered the predominant technology in China and takes nearly 86% of the total EOR projects currently. This fact motivates us to develop novel and more advanced C-EOR methods for different geological types of Chinese reservoirs such as high temperature and pressure, ultralow permeability, heavy oil reservoirs, etc. Through 20 years' efforts, many advantageous C-EOR methods have been successfully developed in our group and tested in oilfields such as stabilized foam injection, nanofluid flooding, functional polymer flooding, etc. Herein, this chapter summarized the latest experimental results of three representative C-EOR methods. More attentions were given to the relationship between bulk properties and flow behaviors in porous media. The lessons learned from our research in C-EOR were also discussed in this chapter.Keywords: enhanced oil recovery, chemical flooding, innovative EOR, nanofluid, polymer microsphere, enhanced foam Nanofluid floodingTo date, hydrolyzed polyacrylamide (HPAM) is still the most widely used polymer due to its availability in large quantities with customizable properties (molecular weight, hydrolysis degree, etc.) and low manufacturing cost. However, acrylamide-based polymers are susceptible to chemical, mechanical, thermal, and microbial degradations [1]. In addition, the acrylamide monomers place © 2018 The Author(s). Licensee InTech. This chapter is distributed under the terms of the Creative Commons Attribution License (http://creativecommons.org/licenses/by/3.0), which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited.detriment to the environment due to its toxicity [2,3]. Nanofluids, which are obtained through dispersing nanoparticles in the base fluids, are attracting research attentions. The nanofluids usually exhibit high thermal conductivities, which are significant to the development of energy, and have been widely used in drug delivery solar cells, lipase immobilization, soil remediation, lubrication, and hydraulic fracturing of gas and oil. In addition, nanofluids have been introduced to the enhanced oil recovery (EOR) area due to their unique thermal properties and large surface area [4][5][6][7][8]. Many works have been done to study the EOR performance of nanofluids composed of different nanoparticles. Hendraningrat et al. evaluated the displacement efficiency of the nanofluid. They claimed that the nanofluid increased the oil recovery by 7-14.3% and the optimum concentration was 0.05 wt% for water-wet core [9,10]. The stability of nanofluids was considered as an imp...

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“…Recently, it was shown that the inclusion of nanoparticles into surfactant solutions affected their properties (Cheraghian and Hendraningrat, ; Khalafi et al, ; Ogolo et al, ), including viscosity (Rudyak and Krasnolutskii, ), wettability alteration effectiveness (Jha et al, , b; Nwidee et al, ), and interfacial and surface tension reduction (Dong and Johnson, ; Zargartalebi et al, ). Due to this, nanoparticles–surfactant solutions (surfactant nanofluids) have been regarded as potential formulations for improving the surfactant flooding EOR (Jha et al, , b; Joonaki and Ghanaatian, ).…”

Section: Introductionmentioning

confidence: 99%

Effect of Nanoparticles on Viscosity and Interfacial Tension of Aqueous Surfactant Solutions at High Salinity and High Temperature

Ivanova

Phan

Barifcani

et al. 2019

J Surfact & Detergents

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Surfactant flooding has widely been used as one of the chemically enhanced oil recovery (EOR) techniques. Surfactants majorly influence the interfacial tension, γ, between oil and brine phase and control capillary number and relative permeability behavior and, thus, influence ultimate recovery. Additives, such as nanoparticles, are known to affect surfactant properties and are regarded as promising EOR agents. However, their detailed interactions with surfactants are not well understood. Thus, in this work, we examined the influence of silica nanoparticles on the ability of surfactants to lower γ and to increase viscosity at various temperatures and salinities. Results show that the presence of nanoparticles decreased γ between n‐decane and various surfactant formulations by up to 20%. It was found that γ of nanoparticles–surfactant solutions passed through a minimum at 35 °C when salt was added. Furthermore, the viscosity of cationic surfactant solutions increased at specific salt (1.5 wt.%) and nanoparticle (0.05 wt.%) concentrations. Results illustrate that selected nanoparticles–surfactant formulations appear very promising for EOR as they can lower brine/n‐decane interfacial tension and act as viscosity modifiers of the injected fluids.

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A review on applications of nanotechnology in the enhanced oil recovery part A: effects of nanoparticles on interfacial tension

Cited by 185 publications

References 89 publications

Mechanism governing nanoparticle flow behaviour in porous media: insight for enhanced oil recovery applications

Mechanism governing nanoparticle flow behaviour in porous media: insight for enhanced oil recovery applications

Lessons Learned from Our Recent Research in Chemical Enhanced Oil Recovery (C-EOR) Methods

Effect of Nanoparticles on Viscosity and Interfacial Tension of Aqueous Surfactant Solutions at High Salinity and High Temperature

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