ArticleACS omega2025
Experimental Study on Water-in-Oil Emulsion Stability Induced by Asphaltene Colloids in Heavy Oil.
Article in ACS omega, 2025. The graph could read no effect estimate from its abstract, so it casts no vote on the map. Cited by 4 papers.
What it found
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Who cites it
4 citing papers in PubMed.
- Gelatin-Based Microspheres for Sustained Ketoprofen Delivery in Difficult-to-Heal Wounds.Polymers · 2026Article
- Synergistic effects of CTAB and low salinity brines on asphaltene behavior and emulsion stability in clay rich sandstone reservoirs.Scientific reports · 2025Article
- Experimental investigation of CTAB modified clay on oil recovery and emulsion behavior in low salinity water flooding.Scientific reports · 2025Article
- Effect of the Free Radical Initiator on the Production of Castor Oil Maleate Oligomers.ACS omega · 2025Article
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Authors and funding
2 authors.
Funding
No grant is acknowledged in the PubMed record.
Abstract
Emulsion stability in water-oil systems is critical for numerous industrial applications, particularly in oil recovery and transportation. However, predicting and controlling the stability of these emulsions under varying conditions remains a challenge. In this study, we investigated the formation and stability of water-oil emulsions under both atmospheric and high-pressure, high-temperature (HPHT) conditions, with a focus on the role of asphaltenes and interfacial tension (IFT). Emulsion stability tests revealed that emulsions exhibit consistent long-term stability at atmospheric conditions, irrespective of the oil-water ratio. Under HPHT conditions, stability varied significantly, with the 75:25 oil-water ratio exhibiting temporary stability, while 50:50 and 25:75 ratios consistently produced unstable emulsions. IFT measurements showed that at atmospheric conditions, crude oil-formation water had an IFT of 21.8 dyn/cm, while crude oil-distilled water had an IFT of 19.8 dyn/cm. Under HPHT conditions (225 °F, 4500 psi), the IFT of live oil-formation water was 18.8 dyn/cm, while live oil-distilled water was 8.0 dyn/cm. At atmospheric conditions, the average IFT was 20.8 dyn/cm, while under HPHT conditions (225 °F, 4500 psi), the average IFT decreased to 13.4 dyn/cm, indicating significant thermodynamic effects on interfacial behavior. Formation water was found to reduce asphaltene precipitation and enhance emulsion stability, emphasizing its role in mitigating asphaltene-related challenges. These findings highlight the importance of tailoring EOR strategies to specific reservoir conditions, including pressure, temperature, oil composition, and water content/chemistry, to optimize emulsion stability, oil displacement, and recovery rates. Future research should explore extended-duration emulsion stability and diverse environmental conditions to better understand their long-term behavior in petroleum applications.
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Registered trials
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