A mechanistic model for vertical and inclined two-phase slug flow

Abdul-Majeed, Ghassan H.; Al-Mashat, Ali M.

doi:10.1016/s0920-4105(00)00047-4

Cited by 28 publications

(13 citation statements)

References 16 publications

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“…Gomez et al [21] concluded that H LS is maximum at horizontal flow conditions, decreasing as the upward inclination increases, and it is minimum for upward vertical flow. The mechanistic models of Abdul-Majeed and Al-Mashat [3] and Brauner and Ullmann [14] confirmed the decreasing of H LS with increasing of θ from horizontal. Al-Ruhaimani et al [5] compared their vertical data with Kora et al [23] horizontal data and observed a decrease in H LS with increasing of θ and a decreasing effect of θ on H LS with increasing of V m .…”

Section: Introductionmentioning

confidence: 68%

“…Regarding the effect of pipe diameter, the observations of Wen et al [32] and Andreussi and Bendksen [9] and the mechanistic models of Barnea and Brauner [12] and Abdul-Majeed and Al-Mashat [3] indicated a slight increase of H LS with increasing of pipe diameter. Godbole et al [19] stated that the reason, for this effect, is due to higher bubble rise velocity in larger pipe diameter.…”

Section: Introductionmentioning

confidence: 98%

“…The correlations included are those of Gomez et al [21], Abdul-Majeed [2], Kora et al [23], Al-Safran et al [8] and Al-Ruhaimani et al [5]. Other correlations, namely, Abdul-Majeed and Al-Mashat [3], Brauner and Ullmann [14], Al-Safran [7] and Wang et al [31] are not included due to their complexity. An experimental study is then conducted to provide a new data set of slug liquid holdup data for viscous two-phase flow covered liquid viscosity ranging from 200 to 800 mPa s. A new unified semi-empirical correlation is proposed to predict H LS for viscous two-phase flow in horizontal, vertical and inclined pipes.…”

Section: Introductionmentioning

confidence: 99%

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A unified correlation for predicting slug liquid holdup in viscous two-phase flow for pipe inclination from horizontal to vertical

Abdul-Majeed

Al-Mashat²

2018

SN Appl. Sci.

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This study presents new measured slug liquid holdup data for liquid viscosity ranging from 200 to 800 mPa s. The experiments were conducted using two different large pipe diameters (0.08 and 0.1 m) and pipe inclination angles of 0°, 30°, 60° and 90° from horizontal. To our best knowledge, most of the existing experimental data were limited to either vertical or horizontal flow and mostly performed using small pipe diameters. Based on the measured data, a new unified empirical correlation is developed to predict slug liquid holdup for viscous two-phase flow in horizontal, vertical and inclined pipes. The proposed correlation is simple and fully consistent with the trends of published experimental data. This study also investigates in details the performance of the existing liquid holdup correlations using different flow conditions. The investigation reveals several discrepancies associated with these correlations. Based on statistical analysis, the proposed correlation performs best as compared to the existing correlations using both the present measured data and data from three independent sources. Keywords Slug liquid holdup • Two-phase flow • High liquid viscosity • Inclined flow List of symbols A, C Constants d Pipe diameter (m) g Acceleration gravity (m/s 2) N Dimensionless number H Slug liquid holdup N f Inverse viscosity number N Re Reynolds number T Temperature (°C) V Velocity (m/s) Greek letters ɛ Residual error ɸ Correlation independent parameter σ Surface tension (N/m) µ Viscosity (kg/m s) (Pa s) ρ Density (kg/m 3) Δρ Density difference (kg/m 3) θ Inclination angle from horizontal (°)

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Section: Introductionmentioning

confidence: 68%

Section: Introductionmentioning

confidence: 98%

Section: Introductionmentioning

confidence: 99%

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A unified correlation for predicting slug liquid holdup in viscous two-phase flow for pipe inclination from horizontal to vertical

Abdul-Majeed

Al-Mashat²

2018

SN Appl. Sci.

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“…In the last twenty years the slug flow has been studied and mechanistic models have been proposed (Orell, Rembrand, 1986;Kaya, 1998;Gomez et al, 2000;Abdul-Majeed, Al-Mashat, 2000;etc). Since the Ig-Bo flow pattern is similar to the slug two-phase flow, the methodology of Abdul-Majeed, Al-Mashat (2000) model, for calculation of ratio between the liquidslug length and the slug-unit length ( ), was used only for comparative purposes.…”

Section: Comparision With Other Modelsmentioning

confidence: 99%

Simulation of Intermittent Gas-Bubbly Oil Three Phase Flow in Upward Vertical Pipe Using the Two-Fluid Model

Cazarez-Candia

Montoya-Hernández

Bannwart

2012

SPE Latin America and Caribbean Petroleum Engineering Conference

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In the petroleum industry the heavy oil-gas-water three phase flow is present in both, on-shore and offshore pipelines. The adequate predictions of three-phase flow characteristics, such as flow patterns, pressure drop and holdup, can have significant impact on the proper design and operation of pipelines and on many flow assurance issues. To achieve this, experimental work and a rigorous modeling of three-phase flow must be carried out.When water, heavy oil and gas flow simultaneously through experimental vertical pipes, in such a way that water is the continuous phase, the Intermittent gas-Bubbly oil (Ig-Bo) flow pattern may appear. In this work a one-dimensional, thermal, transient, two-fluid, mathematical model for Ig-Bo flow is presented. The model was developed under the hypothesis that the Ig-Bo flow pattern can be approached by two different flow patterns, each one in neighboring regions: heavy oil-water bubbly flow in an annular region and heavy oil-gas-water bubbly flow in a slug region. The model consists of mass, momentum and energy conservation equations for every phase whose numerical solution is based on the finite difference technique in implicit scheme. The model is able to predict pressure, temperature, volumetric fraction and velocity profiles for each phase. The ratio between the liquid-slug length and the slug-unit length ( 2 Λ ), commonly used in two-phase flow, was modified to take into account the presence of heavy oil. It was observed that ( 2 Λ ) is larger than the two-phase flow and the correlation allow having the best predictions. The predictions are in agreement with experimental data reported in literature.

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“…Some authors who have reported, in literature, their studies on Taylor bubble behavior are [1][2][3][4] and [7][8][9][10][11][12][13][14].…”

Section: Introductionmentioning

confidence: 99%

Unsteady Fluidynamic Behavior of Gas Bubbles Flowing in Curved Pipes: A Numerical Study

Marinho¹,

Swarnakar²,

Neto³

et al. 2012

ACES

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Petroleum is considered as one of the factors for the development of a nation as well as a cause of economic and political conflicts around the world because of the diversity of products obtained with their derivatives such as fuel for automotives and aviation, and manufacturing plastic parts, among others. The crude petroleum (usually oil, water and gas) found in an underground reservoir is transported to the surface by pipes, and has drawn the attention of researchers because of the problems generated in the pipeline with particular attention to the loss of pressure, friction and bubbles. For a fluid flow in plug regime, where many of the bubbles formed coalesce and produce bigger ones of sizes almost equal to the pipe diameter (Taylor bubble), severe instability in the flow is caused. In this context, the objective of this research has been to study the Taylor bubble flow in curved ducts using the software CFX. Results of the transient effects of the air concentration on the bubble air volumetric fraction, of the viscosity on bubble format, and pipe angle of 90˚ on bubble symmetry are presented and interpreted.

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A mechanistic model for vertical and inclined two-phase slug flow

Cited by 28 publications

References 16 publications

A unified correlation for predicting slug liquid holdup in viscous two-phase flow for pipe inclination from horizontal to vertical

A unified correlation for predicting slug liquid holdup in viscous two-phase flow for pipe inclination from horizontal to vertical

Simulation of Intermittent Gas-Bubbly Oil Three Phase Flow in Upward Vertical Pipe Using the Two-Fluid Model

Unsteady Fluidynamic Behavior of Gas Bubbles Flowing in Curved Pipes: A Numerical Study

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