Asphaltene deposition during various stages of oil recovery from hydrocarbon reservoirs, including at the wellhead, in the wellbore, and in surface equipment, can create numerous challenges. These challenges may include the deposition of solids in pores, clogging of the porous media, reduction of permeability and porosity, blockage of tubing, and disruption of pipeline and other surface equipment operations. Additionally, during the application of water-based enhanced oil recovery (EOR) methods, asphaltene deposition at the oil-water interface can negatively impact the efficiency of the recovery process by affecting interfacial tension (IFT). Therefore, studying the properties of the oil-water interface through IFT measurements can lead to a better understanding of this phenomenon.
The main objective of this study is to quantitatively and qualitatively examine the behavior of asphaltenes at the oil-water interface. In this context, the effects of crude oil composition (various polar and nonpolar components) and the composition of the injected fluid (presence of different ions and chemical agents) will be investigated. One of the key approaches to characterizing these phenomena is the use of IFT measurements. In general, the presence of asphaltene particles at the oil-water interface during flooding processes with various solutions (including low or high salinity water and different chemicals) can affect interfacial properties and lead to phenomena such as emulsion formation.
This research is designed based on laboratory tests and the understanding of governing mechanisms. In this regard, measuring the IFT between oil and water serves as the core focus of this study. The tests are conducted under ambient temperature and pressure conditions, and the main goal is to investigate the effect of various components in the oil phase (asphaltene content and other polar materials) and the aqueous phase (salts, nanoparticles, and chemicals) on interfacial properties.
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