Experimental flowloop investigations of gas hydrate formation in high water cut systems

Joshi, Sanjeev; Grasso, Giovanny; Lafond, Patrick G.; Rao, Ishan; Webb, Eric B.; Zerpa, Luis E.; Sloan, E. Dendy; Koh, Carolyn A.; Sum, Amadeu K.

doi:10.1016/j.ces.2013.04.019

Cited by 191 publications

(178 citation statements)

References 21 publications

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“…After 190 min, the temperature and pressure became steady, and ∆P achieved the maximum value. This tendency of ∆P with elapsed time is consistent with the results reported by Joshi et al [10] at low velocities. The up-and-down fluctuation in ∆P may be caused by the piston pump, which was designed to minimize shear on hydrate slurries and influence of the operation mode.…”

Section: Typical Experimental Runsupporting

confidence: 82%

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Investigation of the Flow Characteristics of Methane Hydrate Slurries with Low Flow Rates

Tang

Zhao

et al. 2017

Energies

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Gas hydrate blockage in pipelines during offshore production becomes a major problem with increasing water depth. In this work, a series of experiments on gas hydrate formation in a flow loop was performed with low flow rates of 0.33, 0.66, and 0.88 m/s; the effects of the initial subcooling, flow rate, pressure, and morphology were investigated for methane hydrate formation in the flow loop. The results indicate that the differential pressure drop (∆P) across two ends of the horizontal straight pipe increases with increasing hydrate concentration at the early stage of gas hydrate formation. When the flow rates of hydrate fluid are low, the higher the subcooling is, the faster the transition of the hydrates macrostructures. Gas hydrates can agglomerate, and sludge hydrates appear at subcoolings of 6.5 and 8.5 • C. The difference between the ∆P values at different flow rates is small, and there is no obvious influence of the flow rates on ∆P. Three hydrate macrostructures were observed: slurry-like, sludge-like, and their transition. When the initial pressure is 8.0 MPa, large methane hydrate blockages appear at the gas hydrate concentration of approximately 7%. Based on the gas-liquid two-phase flow model, a correlation between the gas hydrate concentration and the value of ∆P is also presented. These results can enrich the kinetic data of gas hydrate formation and agglomeration and provide guidance for oil and gas transportation in pipelines.

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Section: Typical Experimental Runsupporting

confidence: 82%

“…Methane content in the gas phase was calculated by the SoaveRedlich-Kwong equation of state using the P/T data. The hydration number of 6 is chosen and the gas hydrate formula is considered as CH4·6H2O [10]. The densities of the gas hydrate and water here are considered as 9.…”

Section: Typical Experimental Runmentioning

confidence: 99%

Investigation of the Flow Characteristics of Methane Hydrate Slurries with Low Flow Rates

Tang

Zhao

et al. 2017

Energies

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“…Because of the lower density of hydrate particles compared to water, they may rise to the top of the water phase and below the gas phase. Joshi et al (2013) revealed that hydrates are dispersed in the liquid phase unless a high volume fraction of the hydrate phase restricts the flow in the system.…”

Section: Hydrate Formation and Growthmentioning

confidence: 99%

“…Hydrate particles grow in the flow direction in a pipeline both near the wall (Nicholas, 2008;Rao et al, 2013), and at the interface of liquid and gas. Hydrate formation on pipe walls is normally relatively slow (Lachance et al, 2012), and thus will not be considered in this thesis.…”

Section: Hydrate Formation and Growth Modelsmentioning

confidence: 99%

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Volume Averaging of Multiphase Flows With Hydrate Formation in Subsea Pipelines

Torbati

Naterer

Odukoya

2015

Volume 5B: Pipeline and Riser Technology

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In oil and gas pipeline operations, the gas, oil, and water phases simultaneously move through pipe systems. The mixture cools as it flows through subsea pipelines, and forms a hydrate formation region, where the hydrate crystals start to grow and may eventually block the pipeline. The potential of pipe blockage due to hydrate formation is one of the most significant flow-assurance problems in deep-water subsea operations. Due to the catastrophic safety and economic implications of hydrate blockage, it is important to accurately predict the simultaneous flow of gas, water, and hydrate particles in flowlines. Currently, there are few or no studies that account for the simultaneous effects of hydrate growth and heat transfer on flow characteristics within pipelines.This thesis presents new and more accurate predictive models of multiphase flows in undersea pipelines to describe the simultaneous flow of gas, water, and hydrate particles

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