Effect of the surface charge of silica nanoparticles on oil recovery: wettability alteration of sandstone cores and imbibition experiments

Alvarez-Berríos, Merlis P.; Aponte-Reyes, Lisa M.; Aponte-Cruz, Lissette M.; Loman-Cortes, Paula; Vivero‐Escoto, Juan L.

doi:10.1007/s40089-018-0243-5

Cited by 31 publications

(12 citation statements)

References 32 publications

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“…This confirms the premise proposed by Omurlu et al [ 67 ] that the more negatively charged, diol-modified nanomaterials tend to adhere better to the pore walls that are coated by ferric oxide, which promotes more positive surface charge. The observation is also in agreement with Alvarez-Berrios et al [ 30 ], who proposed that due to this adhesion (NPs adhering to the rock surface), the mineral surface will be tuned towards more favorable wettability state. One reason to explain this effect is the exchange of the nanofluid forms a wedge-shaped thin film due to the existence of disjoining pressure.…”

Section: Resultssupporting

confidence: 91%

“…Hydrophilicity promotes a water-wet surface [ 28 ], while hydrophobic NPs have almost no impact on the wettability [ 29 ]. Alvarez-Berrios et al [ 30 ] investigated the effect of surface charge of silica NPs on the wettability alteration using Berea sandstone outcrops. The authors found through contact angle measurements that slightly negatively charged SiNPs reduced the contact angle from oil-wet to water-wet (106.3° to 74°).…”

Section: Introductionmentioning

confidence: 99%

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Wettability Changes Due to Nanomaterials and Alkali—A Proposed Formulation for EOR

et al. 2021

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We investigated the usage of two silica nanomaterials (surface-modified) and alkali in enhanced oil recovery through Amott spontaneous imbibition tests, interfacial tension (IFT) measurements, and phase behavior. We evaluated the wettability alteration induced by the synergy between nanomaterials and alkali. Moreover, numerical analysis of the results was carried out using inverse Bond number and capillary diffusion coefficient. Evaluations included the use of Berea and Keuper outcrop material, crude oil with different total acid numbers (TAN), and Na2CO3 as alkaline agent. Data showed that nanomaterials can reduce the IFT, with surface charge playing an important role in this process. In synergy with alkali, the use of nanomaterials led to low-stable IFT values. This effect was also seen in the phase behavior tests, where brine/oil systems with lower IFT exhibited better emulsification. Nanomaterials’ contribution to the phase behavior was mainly the stabilization of the emulsion middle phase. The influence of TAN number on the IFT and phase behavior was prominent especially when combined with alkali. Amott spontaneous imbibition resulted in additional oil recovery ranging from 4% to 50% above the baseline, which was confirmed by inverse Bond number analysis. High recoveries were achieved using alkali and nanomaterials; these values were attributed to wettability alteration that accelerated the imbibition kinetics as seen in capillary diffusion coefficient analysis.

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Section: Resultssupporting

confidence: 91%

Section: Introductionmentioning

confidence: 99%

Wettability Changes Due to Nanomaterials and Alkali—A Proposed Formulation for EOR

et al. 2021

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“…Similarly, the prominent role of zirconia NFs on the wettability alteration at 70 °C and 20 MPa and at low concentration was observed on the quartz surface. 47 Alvarez-Berrios et al 48 stated that the surface-modified silica NPs have a good impact on wettability alteration of a sandstone surface at higher concentrations of NPs. Similarly, Wang et al 49 disclosed that surface-modified TiO 2 NPs perform better than bare TiO 2 NPs in altering the wettability of the rock surface.…”

Section: Introductionmentioning

confidence: 99%

Nanofluids of Kaolinite and Silica in Low Saline Seawater (LowSal) with and without Surfactant: Interfacial Tension and Wettability Alteration of Oil–Water–Rock System for Low Salinity-Enhanced Oil Recovery

Behera

Sangwai

2020

Ind. Eng. Chem. Res.

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Low salinity water injection (LSWI) has gained popularity recently as a potential enhanced oil recovery (EOR) method. The efficiency of LSWI can be improved with the advent of nanotechnology. Nanofluids can alter the wettability of the solid surface from intermediate-wet to water-wet, a condition most favorable to enhance the oil displacement efficiency. Studies have been reported in the literature on the use of nanoparticles and surfactants with LSWI mainly for carbonate rock and synthesized saline water containing mainly sodium salt; however, not much information is available for sandstone rock and the use of low saline seawater (LowSal). Also, a comparative study on the use of silica and kaolinite nanofluids in LowSal has not yet been explored in detail to understand their impact on the wettability alteration and interfacial tension (IFT) of the oil−nanofluid−rock system. Thus, in this work, silica and kaolinite nanofluids have been prepared in LowSal with varying concentrations (0−2000 ppm) without and with an anionic surfactant, dioctyl sodium sulfosuccinate (AOT), to assess their impact on the IFT and wettability alternation (through contact angle measurements) of the oil−nanofluid−rock system. Three different oil samples, viz., model oil A, model oil B, and light crude oil to represent acidic, basic, and weakly basic oil systems, respectively, have been considered. An intermediate-wet quartz plate is used to mimic the properties of the sandstone rock. A detailed mechanism has been highlighted to ascertain the impact of nanofluids on the IFT and wettability alteration of the representative rock sample from an intermediate-wet to water-wet condition based on the Gibbs adsorption isotherm, scanning electron microscopy (SEM), and energy-dispersive X-ray (EDXA/EDS/EDX) studies. The results are outlined to understand the possible future applications of silica and kaolinite nanofluids for enhanced oil recovery processes.

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“…However, instead of the mean diameter decreasing as the number of aqueous silica nanoparticles raises, the mean particle diameter increased initially then was reduced in the present study. Generally, silica nanoparticles have negatively charged surfaces due to the presence of siloxane and silanol groups on their surfaces [25].…”

Section: Results and Discussion Effect Of Silica Nanoparticles On The...mentioning

confidence: 99%

Influence of silica nanoparticles on the stability of paraffin wax emulsion

GÖNEN

2022

Sigma J Eng Nat Sci - Sigma Müh Fen Bil Derg

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Paraffin wax emulsions have been used widely in various areas. However, the basic problem faced in all areas is instability of emulsion. Different methods and emulsifiers have been proposed to overcome this problem. This study focuses on using a commercial emulsifier, (IK-8000) and aqueous silica nanoparticles to formulate paraffin wax emulsions and investigate their effects on the stability and mean diameter of paraffin wax emulsions. For comparison purpose, different emulsifier, PEG-7 Glyceryl Cocoate was used to stabilize one of 20 % (wt./wt.) paraffin wax emulsions. The PEG-7-Glyceryl Cocoate stabilized emulsion phase-separated after 3 days while the IK-8000 stabilized remained stable for more than a month. The effect of the silica nanoparticles on the emulsion's stability was studied by observing samples stored for over 2 months. It was seen that aqueous silica nanoparticles helped to increase the stability of the paraffin wax emulsions. Emulsions prepared without silica nanoparticles (only IK-8000) were stable for just a month (1 month) whereas those which were formulated with silica nanoparticles and IK-8000 remained stable for more than 2 months (> 2 months). However, the addition of aqueous silica nanoparticles did not have a significant effect on the mean particle size of the emulsion.It was observed that the addition of 0.5 mL aqueous silica nanoparticles to the paraffin wax emulsion first increased the mean particle size from 1.142 µm to 2.680 µm. Nonetheless, further increasing the amount of the aqueous silica nanoparticles from 1.0-5.0 mL decreased the mean particles size of the paraffin wax emulsion from 2.680 µm to 0.942 µm. The contact angle formed by water drop on the surfaces coated with different emulsion samples of 30%wt. PWE, 40%wt. PWE, 50%wt. PWE and 60 2 %wt. PWE were measured. The higher the degree of solid content in emulsion, the greater the contact angle measured thus higher hydrophobicity.

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Effect of the surface charge of silica nanoparticles on oil recovery: wettability alteration of sandstone cores and imbibition experiments

Cited by 31 publications

References 32 publications

Wettability Changes Due to Nanomaterials and Alkali—A Proposed Formulation for EOR

Wettability Changes Due to Nanomaterials and Alkali—A Proposed Formulation for EOR

Nanofluids of Kaolinite and Silica in Low Saline Seawater (LowSal) with and without Surfactant: Interfacial Tension and Wettability Alteration of Oil–Water–Rock System for Low Salinity-Enhanced Oil Recovery

Influence of silica nanoparticles on the stability of paraffin wax emulsion

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