Thermodynamic modeling of the temperature impact on low-salinity waterflooding performance in sandstones

Mansi, Mohamed; Mehana, Mohamed; Fahes, Mashhad; Viswanathan, Hari

doi:10.1016/j.colsurfa.2019.124207

Cited by 5 publications

(2 citation statements)

References 43 publications

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“…The low salinity effect on rock wettability improves at higher temperatures by triggering the increased activity of PDIs. ,,,, Thus, it would be very important to carefully consider the effect of temperature in SCM. Tetteh et al and Mansi et al modeled the effect of temperature on the electrostatic interactions at the sandstone and carbonate surfaces, respectively, using the van’t Hoff equation and proposed reaction enthalpies. However, a limiting component of the van’t Hoff equation is the unavailability of reliable data on the heat of reactions and enthalpies for the surface complexation reactions reported in the literature.…”

Section: Predicting Ionic Adsorption On Calcite Surfaces Using Dlm-ba...mentioning

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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Section: Predicting Ionic Adsorption On Calcite Surfaces Using Dlm-ba...mentioning

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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“…It is possible that the higher amount of basic components in crude oil A and stronger interactions between basic components and the glass surface can justify more oil-wet conditions for crude oil A than for C at room temperature. This is supported by the thermodynamic modeling performed by Mansi et al, who showed that the adsorption of basic species at the oil/water interface is significantly reduced at higher temperatures, while it has less effect on acids 28 . Crude oil A, containing more basic components, could have been more susceptible to lower adsorption or desorption of basic species at the surface at higher temperatures, thereby explaining the larger wettability change towards water-wet networks.…”

Section: Resultsmentioning

confidence: 64%

A microfluidic study of oil displacement in porous media at elevated temperature and pressure

Saadat

Vikse

Øye

et al. 2021

Sci Rep

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Microfluidics methods offer possibilities for visual observations of oil recovery processes. Good control over test parameters also provides the opportunity to conduct tests that simulate representative reservoir conditions. This paper presents a setup and procedure development for microfluidic oil recovery tests at elevated temperature and pressure. Oil recovery factors and displacement patterns were determined in single- or two-step recovery tests using two crude oils, high salinity salt solutions and low salinity surfactant solutions. Neither the displacement pattern nor the recovery factor was significantly affected by the pressure range tested here. Increasing temperature affected the recovery factor significantly, but with opposite trends for the two tested crude oils. The difference was justified by changes in wettability alteration, due to variations in the amounts and structure of the acidic and basic oil fractions. Low salinity surfactant solutions enhanced the oil recovery for both oils.

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Impact of temperature and SO42- on electrostatic controls over carbonate wettability

Tetteh

Brady

Ghahfarokhi

2021

Colloids and Surfaces A: Physicochemical and Engineering Aspect

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Thermodynamic modeling of the temperature impact on low-salinity waterflooding performance in sandstones

Cited by 5 publications

References 43 publications

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

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

A microfluidic study of oil displacement in porous media at elevated temperature and pressure

Impact of temperature and SO42- on electrostatic controls over carbonate wettability

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