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![Effect of nanoparticle size, temperature on the contact angle of water. Reprinted with permission from ref. [133], copyright 2017, Elsevier.](profile/Jinjian-Hou/publication/357892948/figure/fig4/AS:1119448169754628@1643908650331/Effect-of-nanoparticle-size-temperature-on-the-contact-angle-of-water-Reprinted-with.png)
Effect of nanoparticle size, temperature on the contact angle of water. Reprinted with permission from ref. [133], copyright 2017, Elsevier.
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Enhanced oil recovery (EOR) has been widely used to recover residual oil after the primary or secondary oil recovery processes. Compared to conventional methods, chemical EOR has demonstrated high oil recovery and low operational costs. Nanofluids have received extensive attention owing to their advantages of low cost, high oil recovery, and wide a...
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... et al. indicated that the size of nanoparticles has no effect on mineral wettability, but temperature influences the wettability, as shown in Fig. 6 [133]. The contact angle decreased with increasing immersion ...
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... tension decreased with increasing temperature at a constant concentration of nanoparticles and SDS. Ivanova et al. studied the effect of temperature on oil/ water interfacial tension in a nanoparticle-surfactant system [92]; however, their results were different from the results presented by Yekeen et al. [214] and Saien et al. [198]. As shown in Fig. 16, the oil/water interface showed a 'V' pattern with increasing temperature for different salinities. Specifically, the oil/water interfacial tension decreased from 25 °C to 35 °C at different salinities owing to the closely packed surfactant layer formed at the interface due to the counterion screening effect. The interfacial tension ...
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Low salinity/engineered water injection is an effective enhanced oil recovery method, confirmed by many laboratory investigations. The success of this approach depends on different criteria such as oil, formation brine, injected fluid, and rock properties. The performance of this method in heavy oil formations has not been addressed yet. In this pa...
Citations
... Nanoparticles, characterized by their small particle size and a large surface-area-to-volume ratio, exhibit exceptional interfacial adsorption properties. 4,5 They demonstrate remarkable stability under high-temperature and high-salinity conditions, making them particularly useful in the pursuit of increased petroleum recovery. Bila and Torsaeter have demonstrated through oil displacement experiments that polymer-encapsulated nano silica particles can improve oil recovery by up to 6% of the original oil in place. ...
Unfavorable mobility ratios in heterogeneous reservoirs have resulted in progressively poor waterflood sweep efficiency and diminishing production. In order to address this issue, our study has developed amphiphilic-structured nanoparticles aimed at enhancing the microscopic displacement capability and oil displacement efficiency. First, the transport process of Janus nanoparticles in porous media was investigated. During the water flooding, Janus nanoparticle injection, and subsequent water flooding stages, the injection pressure increased in a “stepped” pattern, reaching 0.023, 0.029, and 0.038 MPa, respectively. Second, emulsification effects and emulsion viscosity experiments demonstrated that the amphiphilic structure improved the interaction at the oil–water interface, reducing the seepage resistance of the oil phase through emulsification. In porous media, Janus nanoparticles transported with water exhibit ‘self-seeking oil’ behavior and interact with the oil phase, reducing the viscosity of the oil phase from 19 to 5 mPa·s at 80 °C. Finally, the core model displacement experiment verified the characteristics of Janus nanoparticles in improving the oil–water mobility ratio. Compared with the water flooding stage, the recovery percent increased by 20.8%, of which 13.7% was attributed to the subsequent water flooding stage. Utilizing the asymmetry of the Janus particle structure can provide an effective path to enhanced oil recovery in inhomogeneous reservoirs.
... The unique physicochemical characteristics of nanoparticles at the nanoscale compared to their bulk size have led to their development in EOR operations (Tohidi et al., 2022). Due to their small size, nanoparticles have an exceptionally large surface-to-volume ratio and can easily enter pores without getting stuck (Hou et al., 2022;Gharibshahi et al., 2024). Additionally, nanoparticles are more environmentally friendly and require more energy to deform compared to chemicals used in chemical processes. ...
... For example, NPs can be used to reduce the viscosity of the oil, making it easier to extract. They can also be used to increase the mobility of the oil, allowing it to flow more easily through the reservoir [44]. Another merit of EOR using NPs is that it can be used in combination with other EOR methods, such as waterflooding or gas injection. ...
In recent decades, nanotechnology has emerged as a rapidly growing field with diverse applications in industries such as pharmaceuticals, energy, and engineering. One of the key areas of interest is the use of nanoparticles (NPs) and nanofluids (NFs) in Enhanced Oil Recovery (EOR) to improve oil recovery efficiency. NPs offer several benefits in the hydrocarbon industry and have been shown to enhance oil and gas production. In EOR, NPs play a crucial role by interacting with the rock/oil system, optimizing conditions for oil retrieval. They offer a cost-effective and eco-friendly alternative compared to conventional methods. This comprehensive study delves into the diverse range of NPs and nanomaterials utilized in the petroleum industry, detailing their classification, characterization, and inherent properties. It explores multiple applications of NPs in chemical, thermal, and microbial flooding, elucidating the involved mechanisms like wettability modification and mobility control. Moreover, the research examines the utilization of NPs in EOR through image-based modeling, a groundbreaking approach in enhancing EOR techniques. It highlights the considerable progress achieved in EOR through the application of NPs and nanofluids (NFs). Additionally, the study assesses the potential of NPs in image-based modeling and their implications for future EOR applications, indicating a promising trajectory for integrating NPs into the petroleum industry.
... Injection of NFs also improves the oil recovery factor by reduction of IFT, wettability alteration, pore channel plugging, preventing asphaltene precipitation and decreasing the mobility ratio [30][31][32][33][34]. Nanoparticles such as SiO 2 , TiO 2 , Al 2 O 3, nano clay, and carbon-based nanoparticles are commonly used in EOR and typically range in size from 1 to 100 nm, which is relatively smaller compared to the sizes of pores and throats [35]. In the research conducted by Youssif et al. [36], it was observed that the utilization of SiO 2 NF resulted in improved oil recovery in sandstone formations. ...
... Микро и нанофлюиды активно применяются в различных областях промышленности [1][2][3][4][5][6][7]. Применение нанофлюидов в нефтяной промышленности в последнее время также приобрело широкий масштаб [8][9][10][11]. Увеличение добычи нефти при использовании нанофлюидов связано со снижением межфазного натяжения [11,12], изменением смачиваемости из-за адсорбции наночастиц на поверхности пор [13], образованием стабильной водонефтяной эмульсии [14], изменением расклинивающего давления [15] и т.д. ...
The results of thermophysical properties studies and stabilization of nano- and microfluids prepared on the basis of glycerol aqueous
solutions are presented. The results of determination of thermal conductivity, rheology, interfacial tension and stability of the studied
solutions are presented. Cu, Ni and Al nanoparticles were used for the preparation of nanofluids, and microparticles of the metal-string
complex [Ni5(μ5-pppmda)4Cl2] synthesized in laboratory conditions were used for the preparation of microfluids. It was shown
that the Ni5 microfluid has a higher stability than the studied nanofluids due to the formation of hydrogen bonds, lower density of
microparticles and the formation of ensembles of particles whose sizes are determined by the buoyancy conditions. The rheology of Ni5
microfluids exhibiting thixotropic behavior is also significantly different. The investigated Ni5 microfluids exhibited almost the same
increase in thermal conductivity compared to the base fluid as the nanofluids. It is shown that the increase in thermal conductivity of
the microfluids is related to the single-crystal structure of the used microparticles. An equation predicting a 10-fold increase in thermal
conductivity for Ni5 nanofluid solutions as compared to microfluids is proposed.
... As a result, Choi and Eastman [1] suggested using 100-nmsized nanoparticles in ordinary fuids and came up with the term "nanofuid" to refer to them. Nanofuids are frequently employed in contemporary industries and technologies, including modern drug delivery systems [2], engineering devices in power [3], automotive industry [4], biotechnology cooling [5], oil recovery [6], nanotechnology [7], and others. Tese nanofuid applications led Alotaibi and Rafque [8] to explore the heat relocation aspects of nanofuid fow across two parallel disks. ...
... Te compact version of (17) is obtained through rearrangement, as in (18). 6 Mathematical Problems in Engineering Prδ t y 1 + y 6 y 2 + y 7 y 12 − PrNby 12 y 14 − PrNty 2 12 − Pr y 1 + y 6 y 12 1 − δ t P r y 1 + y 6 2 y 14 − N t /N b y 12 ′ − Sc y 1 + y 6 y 14 + δ c Sc y 1 + y 6 y 2 + y 7 y 14 ...
The overall goal of this paper is to look at how non-Fick’s and non-Fourier’s concepts affect the quadratic convection flow of a couple stress nanofluid across an extending surface under Wu’s slip, convective heating, and convective mass transfer conditions. The governing equations in the investigation are also initially stated as higher-order partial differential equations and thereafter rehabilitated into ordinary differential equations via similarity conversions. Finally, the numerical approach of the bvp5c solver in MATLAB R2019a is engaged to solve the resultant equations. It has been researched and shown using graphs and tables how physical characteristics affect the velocity, temperature, and concentration fields. The results show that the velocity profile along the x-direction grows with intensifying values of the couple stress, quadratic convection, buoyancy, and third-order slip constraints, whereas it declines with intensifying values of the fourth-order slip and magnetic field constraints. Also, the results show that as the velocity ratio constraint is increased, the velocity field along the y-axis increases. Furthermore, an augment in the values of the quadratic convection constraint and Schmidt number, respectively, causes a diminution in temperature and concentration distributions. The results of the current study can be used to increase lubricant production and reduce machinery deterioration. Furthermore, this theoretical and numerical deliberation has the potential to be beneficial in the field of bio-fluid dynamics and biomedicine.
... Structural disjoining pressure is the force at a section responsible for a very important mechanism of wettability transformation. An excessive amount of pressure is created in the film by the nanoparticles' layering and structuring arrangement (Eltoum et al., 2021;Hou et al., 2022;Li et al., 2018). The oil drops are released from the mineral surface because of the effective disjoining pressure, which encourages the nanofluid to migrate toward the boundary layer (Hou et al., 2022). ...
... An excessive amount of pressure is created in the film by the nanoparticles' layering and structuring arrangement (Eltoum et al., 2021;Hou et al., 2022;Li et al., 2018). The oil drops are released from the mineral surface because of the effective disjoining pressure, which encourages the nanofluid to migrate toward the boundary layer (Hou et al., 2022). Zhang et al. (2018) calculated the effect of the structural disjoining pressure of nanofluid in EOR using a model of fractured porous media (Fig. 4.20). ...
... A special characteristic of nanofluids is the inner contact line. At larger concentrations, the nanoparticles get smaller, which aids in raising the inner contact line rate (Hou et al., 2022) (Fig. 4.21). ...
... To date, multiple papers reviewing NT roles in EOR have been published: [4,24,25,26,27,28,29,30,31,32,33,34,35,36,37,32,38,39,40], and [41]. The main topic gaps not covered by the aforementioned reviews are identified as: The addition of copper oxide NP at concentrations of 0.5, 0.8, and 1 w.t % resulted in a drop in plastic viscosity of 24 percent for a concentration of 0.8 w.t % and a maximum decrease of filtration for copper oxide of 24 %. ...
... 24. Summary of NP influences on rock / mineral surface wettability [33,169,170]. ...
Oil reservoir formation damage is a challenging issue associated with water and/or gas reservoir flooding in secondary and tertiary oil recovery operations. Some enhanced oil recovery (EOR) techniques offer the potential to overcome the multiple problems associated with formation damage and improve production rates and resource recovery. Regrettably, EOR techniques have their own problems to overcome, such as degradation of chemicals (polymers and surfactants) used under reservoir conditions, the large amount of chemicals required, and their high cost. Thus, the applications of nanotechnologies for oil-recovery enhancement offers huge potential benefits. Nanotechnologies can have positive impacts on the properties of subsurface porous media and the pore fluids present. They can assist in the separation of fluid phases, particularly oil and water, and introduce influential coatings to reservoir components. Moreover, nanomaterials can improve the performance of various sensors and control devices used as part of the production system. This study reviews NT laboratory- and field-scale tests to EOR and the ways in which NT can be applied to EOR to cause a reduction in capillary forces thereby enhancing oil displacement by reducing the wettability of the rock matrix and its interfacial tension. It considers the potential of Janus nanoparticles (JNP) for certain EOR applications, contrasting the characteristics of JNP with nanoparticles (NP), and establishing that JNP tend to display higher stability. NP-enhanced carbon dioxide (CO2) reservoir flooding is of particular interest because of its capacity for carbon capture and storage (CCS). NPs act a stabilizer in nano-emulsions, CO2 nanofoams, and liquids containing surfactants and/or polymers. NP are also able to improve the quality of hydraulic fracturing, alter reservoir wettability, reduce interfacial tension, avoid formation damage and inhibit the precipitation of asphaltenes. This review describes the economic hurdles and potential environmental impacts confronting nano-EOR, and makes recommendations regarding future required research and likely EOR-related NP developments. The review’s findings indicate substantial technical and commercial scope for expanded use of nanotechnology for EOR, in particular to enhance reservoir wettability and interfacial tension conditions.
... In the process of AFM measurement, when the probe closes to the solid surface, the interaction force is repulsive and the repulsive force increases gradually with the shortening of the distance between probe and solid; when the probe leaves the solid surface, the interaction force changes to the attraction force and the attraction force increases with the increase of the distance. Previous studies have used this oil-solid interaction force to evaluate the difficulty level of separation of heavy oil and solid (Hou et al., 2022a, Hou et al., 2022b. The less attractive the oil-solid interaction force is, the easier it is to release heavy oil from the solid surface. ...
The oily sludge would cause environment pollution, and would cause the heavy oil waste. Therefore, it was vital for us to find novel methods to obtain heavy oil from the oily sludges. In this study, the [C12mim][PF6] and [C12mim][Br] ionic liquids(ILs) were used to enhance the oil recovery. The toluene could obtain the highest oil recovery, and both the two ILs could increase the oil recovery. Toluene could obtain the highest oil recovery (89.4 wt%), and n-octane could obtain the lowest oil recovery (76.8 wt%). [C12mim] [PF6] could efficiently increase the heavy oil recovery to 91.2 wt%(by toluene). The [C12mim][Br] could increase the heavy oil recovery further. Both the [C12mim] [PF6] and the [C12mim][Br] ionic liquids could increase the heavy ois C/H ratio, decrease heavy oil viscosity and increase the sands hydrophilicity. The [C12mim][Br] ionic liquids showed better effect. In addition, the ionic liquids could increase the solvents recovery, and the ionic liquids recovery were high. Therefore, the ionic liquids enhanced oil recovery could be recycled to ten times. The two ionic liquids could effectively decrease the heavy oil interaction force, and when the ionic liquids increased to 200 ppm, the force remained stable. In the end, the ionic liquids enhancing solvent extraction mechanism was put forward.
... Several papers have recently been published in which nanofluid flooding is proposed as an agent for EOR [27][28][29][30][31]. The effect of nanofluid flooding on enhancing oil extraction from porous media has also been reported. ...
It is necessary to sustain energy from an external reservoir or employ advanced technologies to enhance oil recovery. A greater volume of oil may be recovered by employing nanofluid flooding. In this study, we investigated oil extraction in a two-phase incompressible fluid in a two-dimensional rectangular porous homogenous area filled with oil and having no capillary pressure. The governing equations that were derived from Darcy's law and the mass conservation law were solved using the finite element method. Compared to earlier research, a more efficient numerical model is proposed here. The proposed model allows for the cost-effective study of heating-based inlet fluid in enhanced oil recovery (EOR) and uses the empirical correlations of the nanofluid thermophysical properties on the relative permeability equations of the nanofluid and oil, so it is more accurate than other models to determine the higher recovery factor of one nanoparticle compared to other nanoparticles. Next, the effect of nanoparticle volume fraction on flooding was evaluated. EOR via nanofluid flooding processes and the effect of the intake temperatures (300 and 350 K) were also simulated by comparing three nanoparticles: SiO2, Al2O3, and CuO. The results show that adding nanoparticles (<5 v%) to a base fluid enhanced the oil recovery by more than 20%. Increasing the inlet temperature enhanced the oil recovery due to changes in viscosity and density of oil. Increasing the relative permeability of nanofluid while simultaneously reducing the relative permeability of oil due to the presence of nanoparticles was the primary reason for EOR.
