A three-phase solid-liquid-gas slug flow mechanistic model coupling hydrate dispersion formation with heat and mass transfer

Bassani, Carlos L.; Barbuto, Fausto Arinos; Sum, Amadeu K.; Morales, Rigoberto E. M.

doi:10.1016/j.ces.2017.12.034

Cited by 22 publications

(18 citation statements)

References 38 publications

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“…Figure 17I presents the mean gas fraction of the elongated bubble (R GB ). From Taitel and Barnea's 9 theory, the shape of the elongated bubble profile is equal for the same conditions of mixture superficial velocity 44,45 nevertheless the case of j L /J (also shown in Figure 18a). However, (i) the bubble length is inversely proportional to the nonslip liquid fraction (j L /J) ( Figure 16III), and (ii) the gas fraction is higher at the end part of the film region.…”

Section: Intermittence Factormentioning

confidence: 72%

“…From (a), it can be seen that the intermittence factor is inversely proportional to the nonslip liquid fraction, L B =L U / ðj L =JÞ 21 , which is in agreement with the literature for two-phase liquid-gas slug flow. 43,44 From (b), the mean value of the intermittence factor reduces due to the introduction of the solid particles. Since the elongated bubble length reduces with the particles concentration, the slug length does not presents a defined behavior, then the intermittence factor has a general trend of reduction.…”

Section: Intermittence Factormentioning

confidence: 98%

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Measurements of horizontal three‐phase solid‐liquid‐gas slug flow: Influence of hydrate‐like particles on hydrodynamics

et al. 2018

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Gas hydrate formation is a main flow assurance concern in oil and gas production. Understanding the effects of the introduction of solid particles in the slug flow is essential to improve the efficiency and safety of multiphase production. The purpose of the present work is the experimental characterization of solid‐liquid‐gas slug flow with the presence of dispersed hydrate‐like particles. Experimental tests were carried out with inert polyethylene particles of 0.5‐mm diameter with density similar to gas hydrates (938 kg/m3). The test section comprised a 26‐mm ID, 9‐m length horizontal duct of transparent Plexiglas. High Speed Imaging and resistivity sensors was used to analyze the slug flow unit cell behavior due to the introduction of the solid particles and to measure the unit cell translational velocity, the slug flow frequency, the bubble and slug lengths, and the phase fractions. Two distinct concentrations of solid particles were tested (6 and 8 g/dm3). © 2018 American Institute of Chemical Engineers AIChE J, 64: 2864–2880, 2018

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Section: Intermittence Factormentioning

confidence: 72%

Section: Intermittence Factormentioning

confidence: 98%

Measurements of horizontal three‐phase solid‐liquid‐gas slug flow: Influence of hydrate‐like particles on hydrodynamics

et al. 2018

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“… Comprehension of the limiting step of outer growth (permeation vs. crystal integration) is key to understand if particle is wet or dry, with consequences on agglomeration and plugging. 22,80,81,84 and in the micro-scale of interaction between particle and mixture bulk 14,21 . In this appendix, we show that the micro-scale heat transfer is not important in flowing systems, that is, the shear is always enough to equilibrate the temperature of the growing surface to the bulk one (in coherence with the observed by Sampaio et al 21 that the particle-to-bulk temperature gradient is never higher than 0.2 K).…”

Section: Discussionmentioning

confidence: 99%

“…This simplifies considerably the equations developed in section 2 of the article. Further consideration of heat transfer from the mixture to the outer medium/ocean (pipeline-scale) is dependent on multiphase flow convection and the pipeline material and thickness 22 . That is, the temperature of the growing surface is considered equal to the bulk temperature in means that the heat released by crystallization in one capillary or in one particle is instantly transferred to the bulk.…”

Section: Discussionmentioning

confidence: 99%

A Multiscale Approach for Gas Hydrates Considering Structure, Agglomeration, and Transportability under Multiphase Flow Conditions: II. Growth Kinetic Model

Bassani

Sum

Herri

et al. 2020

Ind. Eng. Chem. Res.

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In the second part of this series, we introduce the mathematical model for the growth kinetics of gas hydrates in oil continuous flow. Mathematical description of the capillary filling-up process is given (porosity evolution), coupled with growth phenomena already described in the literature (gas absorption by the oil bulk, mass transfer particle/bulk, outer growth due to permeation). The range of closure parameters reported in the literature for CH 4 hydrates is used to understand the limiting steps of crystallization, the evolution of porosity being the controlling factor in the asymptotic trend of the gas consumed over time. Furthermore, gas absorption by the bulk and mass transfer particle/bulk is shown to be negligible for oil-continuous flow when considering a gas that is much more soluble in oil than in water. The model is simplified for engineering purposes, giving rise to an explicit semi-empirical equation for the gas consumption rate because of hydrate formation based on two independent parameters that are experimentally regressed. A criterion for the existence of wet or dry particles (the water layer covering the particles in oilcontinuous flow) is proposed in means of the competition of crystal integration in the outer surface versus water permeation through the porous hydrate.

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“…Bassani et al [10] proposed a three-phase solid-liquid-gas slug flow mechanistic model coupling hydrate dispersion formation with heat and mass transfer. The model couples mass, momentum and energy balances for the slug flow unit cell and provides analytic expressions for temperature and pressure distributions along the pipeline.…”

Section: Introductionmentioning

confidence: 99%

Experimental study on gas-liquid-coal fines three-phase flow in undulating pipeline

Wang¹,

Wu²,

Han³

et al. 2018

THERM SCI

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Original scientific paper https://doi.org/10.2298/TSCI171218162WThe aggregation of coal fines particles at the bottom of the coal-bed methane well is a common occurrence during production, which could inhibit the flow in the bottom of wells and have adverse effect on the downhole equipment. In this work, gas-liquid-solid three-phase flow experiments were carried out to investigate the migration and discharge of coal fines particles in undulating pipeline. The experiments were conducted in downbent V-shaped pipes with different inclination angles. Based on the conductivity method, the real-time liquid holdup at three positions of the elbow was measured by the developed software. The slugs were identified on the time series curves of liquid holdup, and the characteristics of each slug were calculated, such as length and translational velocity. Meanwhile, the moving of particles with different size and concentration can be observed through visualized flow channel. The dyed coal fines particles are injected into the multiphase flow loop. By observing whether they can be discharged from the V-shaped pipe, the lower limits of superficial gas and liquid velocities to avoid particle retention at the elbow were determined. A correlation to predict the critical gas and liquid velocity was presented, and the accuracy of the calculation model was verified in comparison with the experimental results.

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A three-phase solid-liquid-gas slug flow mechanistic model coupling hydrate dispersion formation with heat and mass transfer

Cited by 22 publications

References 38 publications

Measurements of horizontal three‐phase solid‐liquid‐gas slug flow: Influence of hydrate‐like particles on hydrodynamics

Measurements of horizontal three‐phase solid‐liquid‐gas slug flow: Influence of hydrate‐like particles on hydrodynamics

A Multiscale Approach for Gas Hydrates Considering Structure, Agglomeration, and Transportability under Multiphase Flow Conditions: II. Growth Kinetic Model

Experimental study on gas-liquid-coal fines three-phase flow in undulating pipeline

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