A methodology and database to quantify the confidence level of methods for gas–liquid two-phase flow pattern prediction

Pereyra, Eduardo; Torres, Carlos F.; Mohan, Ram S.; Gómez, Luis E.; Kouba, Gene; Shoham, Ovadia

doi:10.1016/j.cherd.2011.08.009

Cited by 34 publications

(24 citation statements)

References 9 publications

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“…In these cases, the annular flow represents specific types of segregated phases. For horizontal cases, OLGA does not recognize an annular flow pattern, and this pattern is grouped with the segregated flow pattern (0 or SG) [76,77].…”

Section: Experimental Data Processingmentioning

confidence: 99%

Probabilistic approach of a flow pattern map for horizontal, vertical, and inclined pipes

Amaya-Gómez

López

Pineda

et al. 2019

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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A way to predict two-phase liquid-gas flow patterns is presented for horizontal, vertical and inclined pipes. A set of experimental data (7702 points, distributed among 22 authors) and a set of synthetic data generated using OLGA Multiphase Toolkit v.7.3.3 (59 674 points) were gathered. A filtering process based on the experimental void fraction was proposed. Moreover, a classification of the pattern flows based on a supervised classification and a probabilistic flow pattern map is proposed based on a Bayesian approach using four pattern flows: Segregated Flow, Annular Flow, Intermittent Flow, and Bubble Flow. A new visualization technique for flow pattern maps is proposed to understand the transition zones among flow patterns and provide further information than the flow pattern map boundaries reported in the literature. Following the methodology proposed in this approach, probabilistic flow pattern maps are obtained for oil–water pipes. These maps were determined using an experimental dataset of 11 071 records distributed among 53 authors and a numerical filter with the water cut reported by OLGA Multiphase Toolkit v7.3.3.

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Section: Experimental Data Processingmentioning

confidence: 99%

Probabilistic approach of a flow pattern map for horizontal, vertical, and inclined pipes

Amaya-Gómez

López

Pineda

et al. 2019

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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“…One of the main properties in the study of two-phase flows is the flow regime, which makes reference to the spatial distribution of the gas and liquid phases during the flow in pipes. The correct estimation of the regimes is fundamental in two-phase analysis, taking into account that design variables such as pressure drop, phase holdup, rate of chemical reaction and others, are strongly related to the registered flow pattern (Pereyra et al, 2012). There are two main approaches to predict the flow regime in a particular configuration.…”

Section: Introductionmentioning

confidence: 99%

“…When gases and liquids flow simultaneously in a pipe, depending on a wide number of variables, the phases can distribute themselves in a variety of configurations. The configuration is determined by the interface distribution, which results in different flow characteristics (Pereyra et al, 2012). The overlapping between flow regimes, especially at the transition zones makes the identification a difficult work and introduces metering errors (Bratland, 2008).…”

Section: Introductionmentioning

confidence: 99%

“…On the other side, Weber and Eotvos number explain the bubble agglomeration that carries to the differentiation between bubble flow and non-bubble flow (Pereyra et al, 2012). In the case of Weber number, if the surface tension of the fluid decreases (we are greater) bubbles will tend to decrease because of higher momentum transfer between the phases.…”

Section: Introductionmentioning

confidence: 99%

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Data driven methodology for model selection in flow pattern prediction

Hernandez

Valencia

Ratkovich

et al. 2019

Heliyon

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The determination of multiphase flow parameters such as flow pattern, pressure drop and liquid holdup, is a very challenging and valuable problem in chemical, oil and gas industries, especially during transportation. There are two main approaches to solve this problem in literature: data based algorithms and mechanistic models. Although data based methods may achieve better prediction accuracy, they fail to explain the two-phase characteristics (i.e. pressure gradient, holdup, gas and liquid local velocities, etc.). Recently, many approaches have been made for establishing a unified mechanistic model for steady-state two-phase flow to predict accurately the mentioned properties. This paper proposes a novel data-driven methodology for selecting closure relationships from the models included in the unified model. A decision tree based model is built based on a data driven methodology developed from a 27670 points data set and later tested for flow pattern prediction in a set made of 9224 observations. The closure relationship selection model achieved high accuracy in classifying flow regimes for a wide range of two-phase flow conditions. Intermittent flow registering the highest accuracy (86.32%) and annular flow the lowest (49.11%). The results show that less than 10% of global accuracy is lost compared to direct data based algorithms, which is explained by the worse performance presented for atypical values and zones close to boundaries between flow patterns.

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“…Pereyra et al (2012) compiled all the available gas-liquid flow pattern experimental data for different oil viscosity ranging from lower viscosity (1 cP -7 cP) to high viscosity (140 cP -700 cP). Accurate prediction of the flow pattern, pressure drop and liquid holdup is imperative for the design of production and transport systems.…”

Section: Introductionmentioning

confidence: 99%

Effect of Medium Oil Viscosity on Two Phase Oil Gas Flow Behavior in Horizontal Pipes

2013

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There are significant amount of fields operating with medium viscosity oils(10 cP<µ O < 180 cP) Moreover, some of the oils produced from offshore fields can have medium range viscosities when they are exposed to cold sea temperatures. Current two-phase flow models are based on experimental data with low (10 cP<µ O ) and high (µ O >180 cP) viscosity liquids. Therefore, existing mechanistic models need to be verified or improved with medium liquid viscosity experimental results. Effect of liquid viscosity on gas-liquid two phase flow is still not well understood. In the past, most of the studies focused on low (10 cP<µ O ) viscosity liquids. Significant changes has been observed for high viscosity conditions (µ O >180 cP) but no experimental studies for medium oil viscosities has been reported. Thus, there is a need for experimental investigation of medium viscosities in order to characterize the two-phase flow behavior for the entire range of possible viscosities.A systematic experimental program on medium oil viscosities (39 cP<µ O <166 cP) is presented in this study. The experiments are performed using a flow loop with a test section of 50.8-mm ID and 18.9-m-long horizontal pipe. The range of superficial liquid and gas velocity are 0.01 m/s to 3.0 m/s and 0 to 7.0 m/s, respectively. Two-wire capacitance sensors are used to measure the liquid holdup. Visual observation and high speed video recordings are used for flow pattern identification. Effect of viscosity on pressure gradient, liquid holdup and flow pattern is reported. It is observed that the stratified smooth region shrinks when the oil viscosity increases. Dispersed bubble flow presents larger bubble concentration at the top of the pipe as compared with low viscosity case. Acquired experimental data are used to evaluate existing mechanistic models and discrepancies are reported as function of oil viscosity.

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A methodology and database to quantify the confidence level of methods for gas–liquid two-phase flow pattern prediction

Cited by 34 publications

References 9 publications

Probabilistic approach of a flow pattern map for horizontal, vertical, and inclined pipes

Probabilistic approach of a flow pattern map for horizontal, vertical, and inclined pipes

Data driven methodology for model selection in flow pattern prediction

Effect of Medium Oil Viscosity on Two Phase Oil Gas Flow Behavior in Horizontal Pipes

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