Impact of aqueous phase in emulsified form on distribution and instability of asphaltene molecules

Shahsavani, Behnam; Malayeri, M.R.; Riazi, Masoud

doi:10.1016/j.molliq.2019.111688

Cited by 7 publications

(9 citation statements)

References 47 publications

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“…As Figure reveals, the amount of asphaltene precipitation increases in all emulsified synthetic brines up to a certain salt concentration and then decreases. It should be noted that precipitation in this study refers to asphaltene adsorbed in the interface of water/oil and precipitated by emulsion drops . The change in the trend of absorbance values, which occurs at concentrations ranging from 25 000 and 40 000 ppm, can be explained via two competitions: (a) increasing the surface excess concentration and (b) decreasing the zeta potential of asphaltene.…”

Section: Resultsmentioning

confidence: 95%

“…Titration with normal heptane showed that asphaltene of oil 3 was more likely to be present at the interface. They also showed that higher valence ions increase the tendency of asphaltene to participate at the interface . Since water injection is one of the most effective methods for enhanced oil recovery (EOR), this paper studies the effect of asphaltene behavior during the process experimentally.…”

Section: Introductionmentioning

confidence: 99%

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Experimental Investigation of the Brine Effect on Asphaltene Precipitation and Deposition during Water Injection in Porous Media Using Static and Dynamic Systems

Alizadeh

Soulgani

2021

Energy Fuels

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Asphaltene precipitation and deposition in porous media damages formation by reducing permeability and altering wettability, resulting in a significant reduction in reservoir oil production. Although the effects of some factors such as temperature, pressure, and composition have been studied over time, the effects of others, such as emulsified brine, remain uncertain and the available data in this area is limited. Most importantly, the effect of brine injection on deposition has never been studied in previous research. In this study, a number of systematic experiments were designed and conducted to investigate the effect of the aqueous phase. Several variables, including the water content, salt type, and salt concentration were studied in both the static and dynamic systems, and the evidence of consistent changes in asphaltene precipitation and deposition has been obtained. The results revealed that when the water amount reaches 50 wt %, asphaltene precipitation increases close to 10 wt %. However, as the amount of water increased, the intensity of asphaltene precipitation decreased. Furthermore, various salts have shown different behaviors in the static system and dual effects have been observed with increasing concentration. The optimum concentration of different salts was found to be between 25 000 and 40 000 ppm, MgCl2 producing the most asphaltene precipitation and KCl producing the least. MgCl2 at a concentration of about 40 000 ppm resulted in the precipitation of 7.8 wt % asphaltene and while this was 6.4 wt % for KCl 25 000 ppm. Also, for these salt concentrations, the interfacial tension reached 20.5 and 22.5 mN/m, respectively. Although the presence of water in the flooding system reduced the permeability up to 60% by depositing the asphaltene, unlike the static test, the presence of salt had no significant effect on the permeability reduction.

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Section: Resultsmentioning

confidence: 95%

Section: Introductionmentioning

confidence: 99%

Experimental Investigation of the Brine Effect on Asphaltene Precipitation and Deposition during Water Injection in Porous Media Using Static and Dynamic Systems

Alizadeh

Soulgani

2021

Energy Fuels

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“…We have learned that it is essential to thoroughly study the interactions between the injected phase (brine) and oil at different salinity conditions. The emulsion stability depends on pressure, , temperature, , salinity, type of salt, ,, pH, , resin to asphaltene ratio, , and the presence of solids particles. , All the factors mentioned above are different from atmospheric conditions. Asphaltene’s behavior and interactions may significantly differ in reservoir conditions.…”

Section: Challenges and Perspectivesmentioning

confidence: 99%

“…Shahsavani et al 154 investigated the stability and deposition in water and synthetic oil (toluene + asphaltene) systems. They distinguished the difference between the precipitated asphaltenes in the bulk phase and those attached to the water− oil interface.…”

Section: Underlying Mechanismsmentioning

confidence: 99%

Critical Review of Underlying Mechanisms of Interactions of Asphaltenes with Oil and Aqueous Phases in the Presence of Ions

Mahdavi

Moghadam

2021

Energy Fuels

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Asphaltene studies have been a prime focus topic for many decades. However, the underlying interaction mechanisms between water, oil, and asphaltenes requires more attention. Water is involved in all production parts (reservoir, tubing, surface facilities, and refinery), posing comprehensive research about the issues and operating conditions. According to the available literature, there are contradictory opinions regarding the effect of salinity on the aqueous phase and the oil phase interfacial characteristics. This review provides a critical summary of asphaltene’s role in the stability of the aqueous phase emulsions in an oil phase. We reviewed the effect of temperature, pressure, asphaltene concentration, bulk phase components, different salinity, types of ions, and pH on emulsion stability regarding the low salinity water injection aspects. Moreover, the studied cases investigating emulsion stability in the presence of asphaltenes and other species were collected, compared, and categorized. Furthermore, the interfacial and rheological characteristics of the brine–oil interface composed of asphaltenes and other species were compared. We found that the effect of some parameters requires an in-depth study as there are not many related works. For example, the effect of pressure on the rheological characteristics of emulsions and, at the same time, on the aggregation, precipitation, and deposition using visual devices (high pressure–high temperature microfluidic) is missing from the literature. Therefore, we recommend a specific study of each crude oil’s combined effects of temperature, pressure, and salinity. Low salinity water injection is a newly developed enhanced oil recovery method that employs the results of emulsion studies in the presence of different ions and reservoir conditions (high pressure and high temperature).

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“…Various effects contribute to the emulsion stability including the presence of heavy polar particles in the crude oil like asphaltene, solid particles, pressure, temperature, the size distribution of the droplets, pH of the brine and its composition (Akizuki et al, 2014). Ions of higher valence react with asphaltene and as a consequence, asphaltene molecule would go to the interface of water/oil (Shahsavani et al, 2019). Also, the adsorption of asphaltene at the interface of water/oil increases with pressure.…”

Section: Introductionmentioning

confidence: 99%

Experimental study ofin-situW/O emulsification during the injection of MgSO₄and Na₂CO₃solutions in a glass micromodel

Palizdan

Doryani

Riazi

et al. 2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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In-situ emulsification of injected brines of various types is gaining increased attention for the purpose of enhanced oil recovery. The present experimental study aims at evaluating the impact of injecting various solutions of Na2CO3 and MgSO4 at different flow rates resembling those in the reservoir and near wellbore using a glass micromodel with different permeability regions. Emulsification process was visualized through the injection of deionized water and different brines at different flow rates. The experimental results showed that the extent of emulsions produced in the vicinity of the micromodel exit was profoundly higher than those at the entrance of the micromodel. The injection of Na2CO3 brine after deionized water caused the impact of emulsification process more efficiently for attaining higher oil recovery than that for the MgSO4 brine. For instance, the injection of MgSO4 solution after water flooding increased oil recovery only up to 1%, while the equivalent figure for Na2CO3 was 28%. It was also found that lower flow rate of injection would cause the displacement front to be broadened since the injected fluid had more time to interact with the oil phase. Finally, lower injection flow rate reduced the viscous force of the displacing fluid which led to lesser occurrence of viscous fingering phenomenon.

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Impact of aqueous phase in emulsified form on distribution and instability of asphaltene molecules

Cited by 7 publications

References 47 publications

Experimental Investigation of the Brine Effect on Asphaltene Precipitation and Deposition during Water Injection in Porous Media Using Static and Dynamic Systems

Experimental Investigation of the Brine Effect on Asphaltene Precipitation and Deposition during Water Injection in Porous Media Using Static and Dynamic Systems

Critical Review of Underlying Mechanisms of Interactions of Asphaltenes with Oil and Aqueous Phases in the Presence of Ions

Experimental study ofin-situW/O emulsification during the injection of MgSO₄and Na₂CO₃solutions in a glass micromodel

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Impact of aqueous phase in emulsified form on distribution and instability of asphaltene molecules

Cited by 7 publications

References 47 publications

Experimental Investigation of the Brine Effect on Asphaltene Precipitation and Deposition during Water Injection in Porous Media Using Static and Dynamic Systems

Experimental Investigation of the Brine Effect on Asphaltene Precipitation and Deposition during Water Injection in Porous Media Using Static and Dynamic Systems

Critical Review of Underlying Mechanisms of Interactions of Asphaltenes with Oil and Aqueous Phases in the Presence of Ions

Experimental study ofin-situW/O emulsification during the injection of MgSO4and Na2CO3solutions in a glass micromodel

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Product

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Experimental study ofin-situW/O emulsification during the injection of MgSO₄and Na₂CO₃solutions in a glass micromodel