Abstract:In this work, we
prepared nonionic surfactants from waste cooking
oil materials. Hydrolysis was carried out for palm and palm kernel
waste cooking oils to get a mixture of free fatty acids. The mixture
of free acids was esterified with sorbitan and then ethoxylated at
different ethylene oxide units. Two surfactants exhibited promising
surface-active properties among the six prepared surfactants based
on the results of surface tension. The interfacial tension (IFT) around
the critical micelle concentration was … Show more
“…By lowering IFT of the interface of O/W and stabilizing emulsions, capillary trapped oil in the rock pores will be mobilized toward the production well. As depicted in Table 5 , the oil displacement efficiency of SBNS performs comparatively well to oil recovery reported for viscoelastic surfactants and biosurfactants in previous studies (Alsabagh et al 2021 ; Hu et al 2021 ). Fig.…”
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.
“…By lowering IFT of the interface of O/W and stabilizing emulsions, capillary trapped oil in the rock pores will be mobilized toward the production well. As depicted in Table 5 , the oil displacement efficiency of SBNS performs comparatively well to oil recovery reported for viscoelastic surfactants and biosurfactants in previous studies (Alsabagh et al 2021 ; Hu et al 2021 ). Fig.…”
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.
“…After that, 150 ppm of surfactant AOT [at the critical micelle concentration (CMC)] was added to 1 L of LSSW and homogenized using a magnetic stirrer (Big Squid, IKA, Germany) at 500 rpm for 12 h. The CMC of the surfactant AOT was evaluated from a plot of the surface tension (SFT) versus the concentration of AOT in LSSW, where SFT is perpetual after the CMC (see Figure S3, Supporting Information). The concentration of the AOT surfactant was optimized at the CMC because at the CMC the optimum efficiency of the surfactant is reported and the nanoemulsion due to Gibbs monolayer adsorption at the CMC helps in oil recovery . Afterward, PVP-K30 polymer (1000 ppm) was added to the LSSW–surfactant solution and homogenized for 6 h. The concentration (1000 ppm) of PVP-K30 polymer was optimized from the stability test carried out by varying the concentration of the polymer in the NFs solution .…”
Section: Methodsmentioning
confidence: 99%
“…Oil recovery due to injection of surfactant in a sand-pack reactor is reported to be identical (e.g., 53.87% oil recovery with a porosity of 29.7% and 52.07% oil recovery from a sand-pack reactor with a porosity of 31%) . On the contrary, a significant difference in oil recovery percentage due to chemical flooding (surfactant + alcohol) is also reported (e.g., 57% oil recovery from a sand-pack reactor with a porosity of 25.19% and 25.9% oil recovery from a sand-pack reactor with a porosity of 26.41%) . In such cases, the oil recovery experiment can be tested with an alternative method for proper justification of the efficacy and optimum composition of the injection fluids.…”
Section: Introductionmentioning
confidence: 98%
“…11 On the contrary, a significant difference in oil recovery percentage due to chemical flooding (surfactant + alcohol) is also reported (e.g., 57% oil recovery from a sand-pack reactor with a porosity of 25.19% and 25.9% oil recovery from a sand-pack reactor with a porosity of 26.41%). 20 In such cases, the oil recovery experiment can be tested with an alternative method for proper justification of the efficacy and optimum composition of the injection fluids. Moreover, the efficacy of the nanofluid in oil recovery is reported to be higher than that of chemical flooding, i.e., an additional 4% oil recovery is reported due to the nanofluid after chemical flooding.…”
Oil recovery from a matured oilfield is challenging due to the low recovery factor. These challenges became opportunities for existing low-salinity water (LSW)-based enhanced oil recovery (EOR) methods. The performance of the LSW in recovering the residual oil from a matured oilfield is improved with the help of additives, viz., surfactant, water-soluble polymer, and silica nanoparticles (NPs). In the present study, series of experiments have been carried out to understand the pore-scale oil displacement phenomena of the novel nanofluids (SMART LowSal) using a microfluidic chip (lab-on-a-chip) integrated with an inverted microscope. The microfluidic chip is saturated with oil and is flooded with different nanofluids (NFs) to recover oil. The efficacy of oil displacement is evaluated using two unique methods (series and parallel). The oil displacement efficacy from the chip matrix, the interaction between rock−oil−nanofluid, and wettability alteration of the rock representative surface have been visually investigated. The oil displacement results are compared with the oil recovery results from the sand-pack reactor and Amott cell. Oil displacement was found to increase with increasing concentration of nanoparticles in NFs and slightly decreases beyond 1000 ppm of NPs. Visual observation clarified the complex interaction of rock− oil−nanofluid systems. A significant reduction in the interfacial tension of the fluid−fluid phase in the presence of surfactant leads to elongation of the oil globules and higher oil recovery. A thin layer of a film of water is noticed between the grain and the fluid phase, which could be the reason for the wettability alteration and improved oil recovery. The lab-on-a-chip method adopted for evaluating the efficacy of oil recovery due to the various nanofluids could help better understand the displacement phenomena and screening of additives for the best formulation of injection fluid for EOR application.
“…Many ways have been tried to alter reservoir wettability, including surfactant flooding, low-salinity water flooding, nanoparticles, alkaline flooding. − These methods transform an oil-wet reservoir to a weak water-wet reservoir to improve oil recovery, still there is no better way for the strongly water-wet reservoir to change to a weakly water-wet reservoir. To neutralize low-permeability reservoir wettability, using physical methods like ultrasonic treatment and microwaves and plasma pulse shock has attracted increasing attention .…”
Understanding
and manipulating wettability alterations has tremendous
implications in theoretical research and industrial applications.
This study proposes a novel idea of applying ultrasonic for wettability
alterations and also provides its quantitative characterizations and
in-depth analyses. More specifically, with pretreatment of ultrasonic,
mechanisms of wettability alteration were characterized from the contact
angle measurements, as well as the in-depth analyses from atomic force
microscopy (AFM), X-ray diffraction (XRD), and Fourier-transform infrared
spectroscopy (FTIR). After ultrasonic treatments, the wettability
of mineral with low permeability is determined to altered from strong
hydrophilic to intermediate wettability. The mechanism interpretations
are conducted by means of the AFM, XRD, and FTIR. Basically, as the
time of ultrasonic treatment increases, the AFM results indicate that
the roughness of rock surface and oil/rock interface (contact area)
with surroundings of brine is enhanced. Meanwhile, the XRD results
show the diffusions of clays from the rock surface to the aqueous
phase, and FTIR indicates that the number of functional groups of
Si–O–Si, C–O–C, C–O, CO,
and OH decreases while the number of COOH and CCO
groups increases. This study clearly reveals the surface chemistry
of oil-rock wettability alteration in the subsurface conditions, which
would provide technical support for subsurface usage of geo-energy
productions and carbon sequestrations.
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