Nanotechnology Application in Chemical Enhanced Oil Recovery: Current Opinion and Recent Advances

Gbadamosi, Afeez; Junin, Radzuan; Manan, Muhammad A.; Agi, Augustine; Oseh, Jeffrey

doi:10.5772/intechopen.88140

Cited by 13 publications

(9 citation statements)

References 93 publications

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“…This was shaken for 2 min on an orbital shaker (Protech Model 720) after which the beaker was positioned in an ultrasonic water bath (40 kHz, 500 W). The characteristics of the ultrasonic power and measurement of the water bath can be found somewhere else (Agi et al 2018b(Agi et al , 2019a. The extraction was done for 2 h during which the bath temperature was between 27 and 35 °C.…”

Section: Experimental Testmentioning

confidence: 99%

“…Hence, alternative ways to increase oil production economically are prodigiously being investigated (Agi et al 2020a, b). Hitherto, various EOR processes, such as chemical, thermal and gas, have been used to boost the recovery of oil (Guo et al 2016;Adil et al 2018;Gbadamosi et al 2019a; Responsible Editor: Santanu Banerjee * Afeez Gbadamosi gbadamosiafeezo@gmail.com; r-radzuan@utm.my 2021a, b). Chemical EOR (CEOR) technology is believed to be potentially beneficial due to the increasing expertise, rational cost of capital, functional and financial capabilities (Wang et al 2021a, b;Zhong et al 2020;Gbadamosi et al 2019b;Agi et al, 2020a).…”

Section: Introductionmentioning

confidence: 99%

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Extraction, characterization and evaluation of saponin-based natural surfactant for enhanced oil recovery

et al. 2022

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To minimize environmental impact and costs, natural surfactants are suggested as an ecologically sustainable replacement for synthetic surfactants. The aim of this work is to evaluate the efficiency of low-cost saponin-based natural surfactant (SBNS) from Vernonia amygdalina ( VA ) leaves for enhanced oil recovery (EOR). Furthermore, the study investigated the IFT behaviour of SBNS at oil-water interface and the emulsion behaviour and oil displacement efficiency of SBNS. The SBNS was obtained via ultrasonic extraction of dried VA leaves in a water bath, centrifuging the obtained liquid mixture and freeze drying to evaporate to dryness. Thereafter, Fourier-transform infrared spectroscopy (FTIR) and high-performance liquid chromatography were used to characterize the extracted SBNS. Moreover, tensiometer (Easy-Dyne KRUSS) was used to study the interfacial tension (IFT) behaviour of the SBNS at oil-water interface. Also, the SBNS ability to form stable emulsion in the presence of crude oil was determined. Finally, oil displacement by SBNS solution was investigated under simulated reservoir conditions (3000 psi and 100 °C) with high-pressure high-temperature (Fars EOR) core flooding equipment. The performance of SBNS was compared to commercial non-ionic surfactant 4-octylphenol polyethoxylated (TX-100). Experimental result indicated that the SBNS reduced the IFT at oil-water interface. The natural surfactant lowered the IFT of the oil-water interface from 18.0 to 0.97 mN/m. Moreover, emulsions formed with SBNS showed good stability characterized by a decrease in the median drop diameter with an increase in SBNS concentration. Finally, oil displacement test shows that oil recovery of TX-100 and SBNS increased by 9% and 15% original-oil-in-place (OOIP), respectively. Hence, SBNS is recommended as an appropriate substitute for conventional surfactant due to its inexpensive raw material, lower toxicity, and higher efficiency.

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Section: Experimental Testmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Extraction, characterization and evaluation of saponin-based natural surfactant for enhanced oil recovery

et al. 2022

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“…To alter the rock's wettability [34], improve rheological properties [35], and lessen interfacial tension [36][37][38], NPs can be injected to EOR displacement fluids. The amount of polymer or surfactant that adheres to reservoir rock can also be decreased by using NPs [39][40][41]. In a similar vein, additional research has shown that introducing NPs into PAM can increase its thermal stability [42][43][44].…”

Section: Introductionmentioning

confidence: 98%

Experimental and modeling study of hydrophobic associative polyacrylamide for enhanced oil recovery in carbonate reservoir

Mohmmed¹,

Hadi²

2022

PEN

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In this study, hydrophobic associative polyacrylamide (HAPAM) was used in conjunction with the chemical flooding technique in a low-permeability carbonates reservoir. To test the efficacy of the proposed method, both a model and an experiment were created. Experiments were run to compare the relative permeability (Kr) curves, oil recovery rates, and rheological, physical, aging time, and petrophysical features of brine water and polymer flooding in a core. The purpose of these tests was to show how HAPAM can be used to boost oil recovery. Computer Modelling Group (CMG), a simulator, was then used. An oil-and-brine (or HAPAM solution) grid in three dimensions (3D) was developed. The validity of the suggested simulator was established by comparing its results to those obtained from commercial software and from most of the brine or polymer flooding experiments. The developed simulator was used to undertake additional research into the non-Newtonian flow of brine or polymer solution in porous media. The experimental consequences indicated that the polymer solution has a shear thinning viscosity curve and flow behavior index. Shear thinning, viscosity, shear resistance, aging time, density, surface tension, and interfacial tension, and the water wet relative permeability curve are all improved by the adding 1500 ppm HAPAM to brine water. Moreover, oil recovery was about 80%. There was a strong agreement between the results of the modeling study and the experiments.

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“…To extract the remaining hydrocarbon, a tertiary recovery technique, i.e., enhanced oil recovery (EOR) technique, is applied. Among various EOR methods (thermal, microbial, gas injection), chemical EOR is attractive for specific reservoirs [ 4 ].…”

Section: Introductionmentioning

confidence: 99%

Adsorption Study of Novel Gemini Cationic Surfactant in Carbonate Reservoir Cores—Influence of Critical Parameters

et al. 2022

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Surfactant flooding is an enhanced oil recovery method that recovers residual and capillary trapped oil by improving pore-scale displacement efficiency. Low retention of injected chemicals is desired to ensure an economic and cost-effective recovery process. This paper examines the adsorption behavior of a novel gemini cationic surfactant on carbonate cores. The rock cores were characterized using an X-ray diffraction (XRD) spectroscope. In addition, the influence of critical parameters on the dynamic adsorption of the cationic gemini surfactant was studied by injecting the surfactant solution through carbonate cores in a core flooding apparatus until an equilibrium state was achieved. The concentration of surfactant was observed using high performance liquid chromatography. Experimental results showed that an increasing surfactant concentration causes higher retention of the surfactant. Moreover, increasing the flow rate to 0.2 mL/min results in lowering the surfactant retention percentage to 17%. At typical high salinity and high temperature conditions, the cationic gemini surfactant demonstrated low retention (0.42 mg/g-rock) on an Indiana limestone core. This study extends the frontier of knowledge in gemini surfactant applications for enhanced oil recovery.

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Nanotechnology Application in Chemical Enhanced Oil Recovery: Current Opinion and Recent Advances

Cited by 13 publications

References 93 publications

Extraction, characterization and evaluation of saponin-based natural surfactant for enhanced oil recovery

Extraction, characterization and evaluation of saponin-based natural surfactant for enhanced oil recovery

Experimental and modeling study of hydrophobic associative polyacrylamide for enhanced oil recovery in carbonate reservoir

Adsorption Study of Novel Gemini Cationic Surfactant in Carbonate Reservoir Cores—Influence of Critical Parameters

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