Application of alkalis, polyelectrolytes, and nanoparticles for reducing adsorption loss of novel anionic surfactant in carbonate rocks at high salinity and temperature conditions

Scerbacova, Alexandra; Ivanova, Anastasia A.; Grishin, P. A.; Tokareva, Elena; Tkachev, Ivan; Sansiev, Georgy; Fedorchenko, Gennady; Afanasiev, Igor S.

doi:10.1016/j.colsurfa.2022.129996

Cited by 16 publications

(7 citation statements)

References 85 publications

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“…Similar adsorption profiles were obtained by Belhaj et al 38 for an AEC-based surfactant blend onto quartz samples at 106 °C and salinity of 32k ppm. In addition, a close pattern was demonstrated in previous work 51 that studied a novel AEC-based composition in contact with carbonate rock at brine salinity of 201 g/L and 70 °C.…”

Section: ζ-Potential Of Carbonate Rocksupporting

confidence: 76%

“…Then, the jars were sealed, manually shaken, and placed into an oven for 24 h at 70 °C. The solution was centrifuged for 30 min at 2500 rpm to separate the rock particles, and the supernatant was used for the analysis. , Knowing the surfactant concentrations in the solution before ( C 0 ) and after ( C eq ) contact with the rock, the adsorption value (Γ) was determined using the formula below, eq normalΓ = ( C 0 − C eq ) · m surf m rock …”

Section: Methodsmentioning

confidence: 99%

“…Finally, the oil-wet calcite slices were soaked in surfactant solutions for 48 h at 70 °C to assess the wetting ability of AEC surfactants in different brines; the volume of surfactant solution was 20 mL in each jar. After soaking in surfactant solutions, core plates were washed with deionized water and dried in the oven for 1 h. , It should be noted that polyoxyethylene units degrade in the presence of oxygen under high temperatures, and they was removed from each surfactant composition by purging with nitrogen and creating a “nitrogen cap” …”

Section: Methodsmentioning

confidence: 99%

“…After soaking in surfactant solutions, core plates were washed with deionized water and dried in the oven for 1 h. 47,63 It should be noted that polyoxyethylene units degrade in the presence of oxygen 64 under high temperatures, and they was removed from each surfactant composition by purging with nitrogen and creating a "nitrogen cap". 51 Thus, three series of contact angle measurements were performed: before aging (as-is), after aging in oil, and after treatment with surfactants. The measurements were conducted with Kruss Drop Shape Analyzer 30S at ambient pressure and temperature.…”

Section: Interfacial Tension Measurementsmentioning

confidence: 99%

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Rock–Fluid Interactions of Alkyl Ether Carboxylate Surfactants with Carbonates: Wettability Alteration, ζ-Potential, and Adsorption

et al. 2023

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This work evaluated the rock–fluid interactions of two linear alkyl ether carboxylate (AEC) surfactants C11E11A and C12E7A in carbonates: wetting ability, ζ-potential, and adsorption capacity. Contact angle measurements showed that the ability of AECs to hydrophilize the surface is strongly affected by the ethylene oxide (EO) chain length and the presence of electrolytes. An AEC with a shorter EO chain C12E7A demonstrated a better wetting ability and decreased the contact angle value on the limestone surface from 113 to 27 ± 11° in deionized (DI) water and until 17 ± 5° in 5 wt % NaCl. The mechanism of surfactant action was assessed through thermodesorbed hydrocarbon analysis and organic matter characterization with the help of the Rock-Eval (RE) pyrolysis technique for the first time. The analysis results revealed that all surfactant compositions partially removed free oil and heavy oil components from limestone samples. Also, the presence of C12E7A molecules was detected in the samples after surfactant treatment that indicates that a better wetting ability is achieved by the combination of washing hydrocarbons and adsorption of surfactants on clean sites. The combination of ζ-potential measurements and static adsorption test on crushed limestone demonstrated that the adsorption of AECs in deionized water is not governed by electrostatic interactions and mainly occurs due to hydrogen bonding. Salinity has a significant effect on the adsorption behavior of AECs and leads to the partial destruction of hydrogen bonds and the shift from monomolecular adsorption in DI water to polymolecular adsorption in brines. The adsorption of C11E11A achieved ∼9 mg/g-rock and was higher than that of C12E7A, showing a maximum value of ∼4 mg/g-rock. This work provides a set of experiments that characterize the behavior of AECs during interactions with carbonate rock and describes a novel approach of the wettability shift mechanism assessment through RE pyrolysis.

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Section: ζ-Potential Of Carbonate Rocksupporting

confidence: 76%

Section: Methodsmentioning

confidence: 99%

Section: Methodsmentioning

confidence: 99%

Section: Interfacial Tension Measurementsmentioning

confidence: 99%

See 2 more Smart Citations

Rock–Fluid Interactions of Alkyl Ether Carboxylate Surfactants with Carbonates: Wettability Alteration, ζ-Potential, and Adsorption

et al. 2023

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“…Each measurement was performed with 3 runs and 100 subruns. 39,40 2.2.2. Experimental Setup for the Test with a Mechanical Filter.…”

Section: Methodology 221 Size Determination Of Nanoparticle-augmented...mentioning

confidence: 99%

Water- and Surfactant-Based Huff-n-Puff Injection into Unconventional Liquid Hydrocarbon Reservoirs: Experimental and Modeling Study

et al. 2023

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The combination of horizontal well drilling and multistage hydraulic fracturing is currently the leading method for developing shale reservoirs. However, oil recovery from these techniques does not exceed 10%, and supporting technologies are being sought. The injection of water or surfactant solutions in huff-n-puff mode is often considered an enhanced oil recovery option for shales, which can be used alone or in combination with other technologies, such as CO2 injection. This study presents experimental and numerical investigations into the huff-n-puff treatment of low-permeability shale cores using water-based compositions. Additionally, an attempt was made to displace oil by applying a nanofluid booster. Computational tomography was used as one of the methods to determine the oil recovery factor. Two core flooding tests with different designs and injection fluids were conducted. The first experiment involved brine filtration in one direction, followed by nanofluid injection. Second core flooding/huff-n-puff test implied injection of a 0.5 wt % surfactant solution. The results showed that the oil recovery factor achieved using brine was approximately 50% and decreased after nanofluid injection until 31%. Besides that, there was no significant effect from the use of the surfactant. At the same time, critical issues were observed regarding a decrease in core permeability. A numerical simulation of the second experiment was performed to restore the relative phase permeability (RPP) in the surfactant–oil system and to study the dependency of the capillary number logarithm on the miscibility coefficient. The simulation showed a good convergence in terms of the recovery factor values, with an error of ∼1.5%.

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Adsorption characteristics, isotherm, kinetics, and diffusion of nanoemulsion in tight sandstone reservoir

Zhou

et al. 2023

Chemical Engineering Journal

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Application of alkalis, polyelectrolytes, and nanoparticles for reducing adsorption loss of novel anionic surfactant in carbonate rocks at high salinity and temperature conditions

Cited by 16 publications

References 85 publications

Rock–Fluid Interactions of Alkyl Ether Carboxylate Surfactants with Carbonates: Wettability Alteration, ζ-Potential, and Adsorption

Rock–Fluid Interactions of Alkyl Ether Carboxylate Surfactants with Carbonates: Wettability Alteration, ζ-Potential, and Adsorption

Water- and Surfactant-Based Huff-n-Puff Injection into Unconventional Liquid Hydrocarbon Reservoirs: Experimental and Modeling Study

Adsorption characteristics, isotherm, kinetics, and diffusion of nanoemulsion in tight sandstone reservoir

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