Influence of carbonate impurities on smartwater effect: Evaluation of wettability alteration process by geochemical simulation

Hao, Xingjuan; Abu-Al-Saud, Moataz O.; Ayirala, Subhash C.; Elakneswaran, Yogarajah

doi:10.1016/j.molliq.2021.117165

Cited by 17 publications

(8 citation statements)

References 44 publications

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“…The impact of the temperature on emulsion formation and stability remains unclear, and the investigation of the emulsion formation process, which significantly influences emulsion stability, has often been overlooked. Some studies have attributed shifts in emulsion stability to changes in viscosity or interfacial tension. ,,,, However, changes in interfacial tension with the temperature have been inconsistent across different publications, likely as a result of variations in crude oil properties. − Asphaltenes and resins, with their functional group content, are considered the natural surface-active agents in crude oils. ,− Liu et al reported that emulsion stability increased initially as a result of the synergistic effect between asphaltenes and resins with the increasing resin concentration and then decreased, which aligns with previous studies. , In contrast, Pu et al demonstrated the effect of resin/asphaltene on the stability of emulsions formed by simulated oils, showing variations with aging time . A deeper understanding of the impact of crude oil properties on emulsion stability is still needed.…”

Section: Introductionsupporting

confidence: 61%

Impact of the Temperature, Homogenization Condition, and Oil Property on the Formation and Stability of Crude Oil Emulsion

Hao,

Elakneswaran,

Shimokawara

et al. 2024

Energy Fuels

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Water-in-oil (W/O) emulsions have garnered significant attention in the petroleum industry as a result of their adverse effects, such as reduced oil recovery, increased pressure drop, and equipment corrosion. This study investigated the influences of the temperature, homogenization conditions, and crude oil properties on emulsion formation and stability. We focused on nine crude oils with varying viscosities, observing the emulsion formation process and analyzing functional groups, percentage of resolved water, and emulsion particle sizes. Under all conditions, W/O emulsions for most oils underwent a transformation from multiple emulsions, including water-in-oil-inwater (W/O/W) and water-in-oil-in-water-in-oil-in-water (W/O/ W/O/W) emulsions. As the temperature increased, the variation in the W/O emulsion amount at the end of the transformation differed on the basis of oil viscosity, while emulsion stability showed no significant differences. However, W/O emulsion stability increased after 24 h of aging at high temperatures. Additionally, four hypotheses regarding the final changes in the W/O emulsion amount with the temperature were consistent with the emulsion formation process. With regard to the effect of homogenization conditions, increasing shear intensity resulted in a larger amount of W/O emulsion with high stability. This was attributed to changes in the activity of different natural surfactants with increasing shear intensity. Furthermore, the final amount of W/O emulsion was primarily influenced by hydrogen-bonded O−H, followed by hydrogen-bonded N−H. The mechanisms underlying the influence of different factors on emulsion formation and stability are described.

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Section: Introductionsupporting

confidence: 61%

Impact of the Temperature, Homogenization Condition, and Oil Property on the Formation and Stability of Crude Oil Emulsion

Hao,

Elakneswaran,

Shimokawara

et al. 2024

Energy Fuels

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“…Ca 2+ and Mg 2+ ions, which are known to strongly interact at the COBR interface, were assumed at the inner layer, with a net charge transfer to the outer layer (1-plane or Δ Z 1 ). The values used for the Δ Z i in Table were sourced from the work by Hao et al, which were based on the understanding of the calcite–brine lattice. ,,− The calcite–brine interface was equilibrated with calcite mineral and atmospheric CO 2 , i.e., partial pressure of 10 –3.4 atm. However, the oil–brine interface was only equilibrated with atmospheric CO 2 .…”

Section: Methodsmentioning

confidence: 99%

“…Sorption Reaction, Constants (log K), and Charge Distribution Used for the TLM-Based SCM at 25 °Careaction ΔZ o * ΔZ 1 * ΔZ 2 * Log(K)calcite−brine interface67,80,86,87 ( site density = 4.95 sites/nm 2 ,11,21,26,34 specific surface area = 1 m 2 /g11,34 ) >CaOH + H + ↔>CaOH 2…”

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confidence: 99%

Ionic Interactions at the Crude Oil–Brine–Rock Interfaces Using Different Surface Complexation Models and DLVO Theory: Application to Carbonate Wettability

2022

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The impact of ionic association with the carbonate surface and its influence toward carbonate wettability remains unclear and is an important topic of interest in the current literature. In this work, a triple layer model (TLM) approach was used to capture the electrokinetic interactions at both calcite–brine and oil–brine interfaces. The developed TLM was assembled against measured ζ-potential values from the literature, successfully capturing the trends and closely matching the ζ-potential magnitudes. The developed TLM was compared to a diffused layer model (DLM) presented in previous works, with the DLM showing a better match to the ζ-potential values for seawater brine solutions. The ζ-potential values predicted from both surface complexation models (SCMs) were used to calculate the total interaction energy (or potential) based on the Derjaguin, Landau, Verwey, and Overbeek (DLVO) theory. It was observed that low Mg 2+ and high SO 4 2– concentrations in modified composition brine (MCB) made the calcite–brine interface more negative. However, at the oil–brine interface, low Mg 2+ made the oil–brine interface more negative but high SO 4 2– concentrations slightly shifted the oil–brine ζ-potential toward negative. At the crude oil–brine–rock (COBR) interfaces, low Mg 2+ and high SO 4 2– concentrations in the MCB were observed to generate a greater repulsive interaction energy, which could trigger carbonate wettability alteration toward water wetness. The absolute sum of the ζ-potential at both interfaces was observed to be correlated to the total interaction potential at a 0.25 nm separating distance. Thus, an increase in the absolute sum of the ζ-potentials would generate a greater repulsive interaction potential and trigger wettability alteration. Therefore, these SCMs can be applied to design modified composition brine capable of triggering a repulsive interaction energy to alter carbonate wettability toward water wetness.

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“…Globally, zeta potentials obtained for EST2 are less negative for SWd40 and SW-SO4 and more positive for FMB than those obtained for EST1. This variation can be related to differences in rock texture or the presence of impurities [49,55,56], as the calculated zeta potential represents a macroscopic weighted average that accounts for the magnitude and distribution of microscopic zeta potentials arising at each mineral surfaces (Figure 7). It can also be related to the difference in the composition of the solutions after interaction with the intact sample, as some variations in pH, conductivity and viscosity were observed ( Table 4).…”

Section: Zeta Potentialmentioning

confidence: 99%

Relevance of zeta potential as a tool for predicting the response of controlled salinity waterflooding in oil–water-carbonate systems

Rodrigues

Levant

Klimenko

2022

Fuel

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Influence of carbonate impurities on smartwater effect: Evaluation of wettability alteration process by geochemical simulation

Cited by 17 publications

References 44 publications

Impact of the Temperature, Homogenization Condition, and Oil Property on the Formation and Stability of Crude Oil Emulsion

Impact of the Temperature, Homogenization Condition, and Oil Property on the Formation and Stability of Crude Oil Emulsion

Ionic Interactions at the Crude Oil–Brine–Rock Interfaces Using Different Surface Complexation Models and DLVO Theory: Application to Carbonate Wettability

Relevance of zeta potential as a tool for predicting the response of controlled salinity waterflooding in oil–water-carbonate systems

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