Effect of brine salinity on the rheological properties of hydrate-in-oil slurries

Liu, Zaixing; Wang, Ji‐Guang; Liu, Weiguo; Li, Yanghui; Chen, Lang; Zhang, Mengmeng; Song, Yongchen

doi:10.1016/j.petrol.2021.109756

Cited by 10 publications

(7 citation statements)

References 70 publications

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“…Although the early hydrate interparticle adhesion force increases due to the enhanced liquid bridge force, the thermodynamic inhibitors are more suitable for long-term anti-hydrate adhesion. This is consistent with the experimental results of the rheological behavior of hydrate that the viscosity of the hydrate slurry first increased, then decreased, and finally tended to be flat in the presence of thermodynamic inhibitors . The effect of different thermodynamic inhibitors on the rheological behavior of the hydrate slurry needs to be studied and compared in the future.…”

Section: Resultssupporting

confidence: 88%

Interfacial Adhesion Forces of Hydrate Particles in the Presence of Hydrate Inhibitors

et al. 2022

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Hydrate inhibitors are traditionally utilized to prevent hydrate plugging. In this study, the adhesion forces of cyclopentane (CP) hydrates with thermodynamic inhibitors (ethanol, urea, and NaCl) and anti-agglomerant inhibitors [sorbitan monooleate (Span 80) and lecithin] were measured to understand the effects of hydrate inhibitors on the adhesion forces of hydrates. It was found that the thermodynamic inhibitors increased the early hydrate interparticle adhesion force due to the enhanced liquid bridge force. However, the liquid bridge acted as a lubricant layer to prevent the irreversible agglomeration of hydrate after long-term contact. The hydrate adhesion forces decreased by 90.5−93.0% and 76.6−92.7% with an increase in the concentration of Span 80 and lecithin, respectively, from 0.1 to 1 wt %. Both rough morphology and low interfacial tension contributed to the adhesion force decrease of hydrate after the addition of anti-agglomerant inhibitors. The results may be helpful for understanding the mechanism of influence and quantifying the impact of hydrate inhibitors on hydrate interparticle adhesion force.

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Section: Resultssupporting

confidence: 88%

Interfacial Adhesion Forces of Hydrate Particles in the Presence of Hydrate Inhibitors

et al. 2022

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“…The hydrate blockage in pipelines has led to an urgent demand for an enhanced understanding of the gas hydrate formation and flow characteristics in multiphase flow conditions. − Traditionally, laboratory-scale studies on hydrate formation and deposition are facilitated by the employment of a stirred cell system. − The stirred cell with a small size partially enable the measurement of viscosity, particle size, and distribution of hydrate under mechanically stirred conditions . However, it is unable to reproduce the real flow conditions corresponding to the pipeline flow.…”

Section: Introductionmentioning

confidence: 99%

Characterization of Hydrate Formation and Flow Influenced by Hydrophilic–Hydrophobic Components within a Fully Visual Rocking Cell

Lang,

Han,

Zou

et al. 2024

Energy Fuels

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The intricate interplay of crude oil composition and additives critically affects hydrate formation and flow behavior, which is significant for flow assurance particularly in deepwater. To investigate, we varied the hydrophilic and hydrophobic properties by proportioning two nonionic surfactants (Span 80 and Tween 80) and conducting hydrate formation experiments in a visual rocking cell. The results show that the increasing hydrophilic−lipophilic balance (HLB) value shifted emulsions from water-in-oil to multiple and oil-in-water phases and significantly affected the hydrate formation among different emulsion types, with a marked increase in the hydrate formation rate in the HLB range of 9 to 11. Slurries maintained flowability due to low hydrate conversion, yet higher HLB (>11) led to slight agglomeration and deposition. In addition, the impacts of water conversion were investigated by multiple pressurization, showing that the hydrate formation amount affected slurry flowability but was primarily dependent on the hydrophilicity and hydrophobicity of the surfactants. When the HLB was below 11, the final water conversion was about 80%, but the formed hydrate still exhibited good dispersion and flowability. In contrast, HLB exceeding 13 resulted in extensive adhesion and deposition on the cell walls. When the water conversion reached about 40%, flowability was completely lost and hydrate blockage occurred.

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“…10 Calorimetric studies of gas hydrate formation in water-in-crude oil emulsions containing various brine concentrations have revealed that both emulsion and gas hydrate slurry stability increased with higher NaCl concentrations. 11,12 It is noteworthy to remember that salts are gas hydrate thermodynamic inhibitors, promoting a shift in the hydrate equilibrium curve. 13 The inhibition is proportional to the inhibitor concentration, and the system is said to be "underinhibited" when a thermodynamic inhibitor is used in insufficient concentration to completely inhibit the formation of gas hydrates.…”

Section: Introductionmentioning

confidence: 99%

“…Bassani et al showed that the wettability of gas hydrate particles will vary according to the interfacial characteristic, altering the gas hydrate agglomeration process . Calorimetric studies of gas hydrate formation in water-in-crude oil emulsions containing various brine concentrations have revealed that both emulsion and gas hydrate slurry stability increased with higher NaCl concentrations. , …”

Section: Introductionmentioning

confidence: 99%

Gas Hydrate Formation in Water-in-Crude Oil Emulsions: The Role of NaCl in Slurry Stability and Transportability

Teixeira,

Valim,

Sum

et al. 2024

Energy Fuels

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Gas hydrates are solid compounds that can be formed during oil and gas production, causing interruptions in the flow of the produced fluids. Certain crude oil antiagglomerants promote the formation of stable hydrate slurries that do not block the production lines. In these cases, if hydrates are formed, they do not agglomerate, and the resulting slurry is flowable. As produced water composition may influence the stability and characteristics of water/oil emulsions, assessing the impact of water composition on the antiagglomerant properties of crude oils becomes crucial. This study aimed to evaluate the influence of brines containing 10 and 20 wt % of NaCl in the presence of three different crude oils on hydrate slurry formation and their flowability. Water-incrude oil emulsions with 40% water cut were prepared for a high-pressure rheometer study. To visualize the hydrate formation process, emulsions with 30% WC were studied by using a rock-flow cell. The key findings revealed that under the same pressure and temperature conditions, with different subcooling, the apparent viscosity of slurries decreased as salinity increased. The differences in the apparent viscosity of the hydrate slurry were minimized for experiments at the same subcooling. The results suggest that the composition of the crude oil, subcooling levels, and morphology of hydrate particles may explain the effects of NaCl and possibly other salts on the agglomeration process of hydrates when crude oil phases are present. The practical implications of these findings relate directly to the management of hydrate-related risks during transient operations in offshore oil production.

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Effect of brine salinity on the rheological properties of hydrate-in-oil slurries

Cited by 10 publications

References 70 publications

Interfacial Adhesion Forces of Hydrate Particles in the Presence of Hydrate Inhibitors

Interfacial Adhesion Forces of Hydrate Particles in the Presence of Hydrate Inhibitors

Characterization of Hydrate Formation and Flow Influenced by Hydrophilic–Hydrophobic Components within a Fully Visual Rocking Cell

Gas Hydrate Formation in Water-in-Crude Oil Emulsions: The Role of NaCl in Slurry Stability and Transportability

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