Oilfield solids and water-in-oil emulsion stability

Sztukowski, Danuta M.; Yarranton, Harvey W.

doi:10.1016/j.jcis.2004.12.029

Cited by 140 publications

(117 citation statements)

References 53 publications

(102 reference statements)

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“…It must be noticed that the emulsion stabilization properties of particles depend on their wettability and therefore the extent of asphaltene-like compounds adsorbed on their surface 95,[128][129][130] .…”

Section: Asphaltenes As Stabilizersmentioning

confidence: 99%

Model molecules mimicking asphaltenes

Sjöblom

Simon

2015

Advances in Colloid and Interface Science

153

127

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Section: Asphaltenes As Stabilizersmentioning

confidence: 99%

Model molecules mimicking asphaltenes

Sjöblom

Simon

2015

Advances in Colloid and Interface Science

153

127

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“…The asphaltenic material from the oil adsorbs slowly and irreversibly and forms rigid skins of water-in-oil emulsions in competition with surfactant-like species, which is fast and reversible [55]. Sztukowski et al indicate that asphaltene properties have a significant impact on emulsion stability even for emulsions partially stabilized by solids, and asphaltenes with a larger molar mass make more stable emulsion [36]. Emulsions with particles and asphaltenes combined can be much more stable than those stabilized by asphaltenes alone, provided that all the adsorption sites on the particle surface are saturated with asphaltene [32,33].…”

Section: Asphaltenesmentioning

confidence: 99%

“…Generally speaking, the crude oil with higher asphaltene concentration can make more stable emulsions [16,56]. However, Sztukowski et al [36] observed that for emulsions prepared with asphaltenes and no solids, the stability decreases as the asphaltene concentration increases. They explained this result by arguing that the asphaltenes may contain a small amount of a component that reduces emulsion stability and at low concentrations, there may be too little of this component to affect emulsion behavior [43].…”

Section: Asphaltenesmentioning

confidence: 99%

Stability Proxies for Water-in-Oil Emulsions and Implications in Aqueous-based Enhanced Oil Recovery

2011

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Several researchers have proposed that mobility control mechanisms can positively contribute to oil recovery in the case of emulsions generated in Enhanced-Oil Recovery (EOR) operations. Chemical EOR techniques that use alkaline components or/and surfactants are known to produce undesirable emulsions that create operational problems and are difficult to break. Other water-based methods have been less studied in this sense. EOR processes such as polymer flooding and LoSal TM injection require adjustments of water chemistry, mainly by lowering the ionic strength of the solution or by decreasing hardness. The decreased ionic strength of EOR solutions can give rise to more stable water-in-oil emulsions, which are speculated to improve mobility ratio between the injectant and the displaced oil. The first step toward understanding the connection between the emulsions and EOR mechanisms is to show that EOR conditions, such as salinity and hardness requirements, among others, are conducive to stabilizing emulsions. In order to do this, adequate stability proxies are required. This paper reviews commonly used emulsion stability proxies and explains the advantages and disadvantage of methods reviewed. This paper also reviews aqueous-based EOR processes with focus on heavy oil to contextualize in-situ emulsion stabilization conditions. This context sets the basis for comparison of emulsion stability proxies.

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“…Sztukowski and Yarraton [6] studied W/O emulsion stability with clays. They used heptane, toluene, asphaltenes as model fluids and native solids extracted from oilfield operations.…”

mentioning

confidence: 99%

Kaolinite and Silica Dispersions in Low-Salinity Environments: Impact on a Water-in-Crude Oil Emulsion Stability

Wang

Alvarado

2011

Energies

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Abstract:This research aims at providing evidence of particle suspension contributions to emulsion stability, which has been cited as a contributing factor in crude oil recovery by low-salinity waterflooding. Kaolinite and silica particle dispersions were characterized as functions of brine salinity. A reference aqueous phase, representing reservoir brine, was used and then diluted with distilled water to obtain brines at 10 and 100 times lower Total Dissolved Solid (TDS). Scanning Electron Microscope (SEM) and X-ray Diffraction (XRD) were used to examine at the morphology and composition of clays. The zeta potential and particle size distribution were also measured. Emulsions were prepared by mixing a crude oil with brine, with and without dispersed particles to investigate emulsion stability. The clay zeta potential as a function of pH was used to investigate the effect of particle charge on emulsion stability. The stability was determined through bottle tests and optical microscopy. Results show that both kaolinite and silica promote emulsion stability. Also, kaolinite, roughly 1 μm in size, stabilizes emulsions better than larger clay particles. Silica particles of larger size (5 µm) yielded more stable emulsions than smaller silica particles do. Test results show that clay particles with zero point of charge (ZPC) at low pH become less effective at stabilizing emulsions, while silica stabilizes emulsions better at ZPC. These result shed light on emulsion stabilization in low-salinity waterflooding. OPEN ACCESSEnergies 2011, 4 1764

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Oilfield solids and water-in-oil emulsion stability

Cited by 140 publications

References 53 publications

Model molecules mimicking asphaltenes

Model molecules mimicking asphaltenes

Stability Proxies for Water-in-Oil Emulsions and Implications in Aqueous-based Enhanced Oil Recovery

Kaolinite and Silica Dispersions in Low-Salinity Environments: Impact on a Water-in-Crude Oil Emulsion Stability

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