Estimating slug liquid holdup in high viscosity oil-gas two-phase flow

A. Archibong-Eso, N. E. Okeke, Y. Baba, A. M. Aliyu, L. Lao, H. Yeung

Research output: Contribution to journalArticle

3 Citations (Scopus)

Abstract

Slug flow is one of the most critical and often encountered flow patterns in the oil and gas industry. It is characterised by intermittency which results in large fluctuations in liquid holdup and pressure gradient. A proper understanding of its parameters (such as slug holdup) is essential in the design of transport facilities (e.g. pipelines) and process equipment (slug catchers, separators etc.). In this paper, experimental investigation of slug liquid holdup (defined as the liquid volume fraction in the slug body of a slug unit) is performed. Mineral oil with viscosity, μ=−0.0043T3+0.0389T2−1.4174T+18.141 and air were used as test fluids. A 0.0254 m and 0.0762 m pipe internal diameters facilities with pipe lengths of 5.5 and 17 m respectively were used in the study. Electrical Capacitance Tomography was used for slug holdup measurements. Results obtained in the study shows that slug liquid holdup varied directly as the viscosity and inversely as the gas input fraction. Existing slug holdup correlations and models in literature did not sufficiently predict present experimental results. A new empirical predictive correlation for estimating slug liquid holdup was derived from present experimental databank and from data obtained in literature. The databank's liquid viscosity ranges from 0.189 to 8.0 Pa s. Statistical analysis of the new correlation vis-à-vis existing ones showed that the present correlation gave the best performance with an average percent error, E1; absolute average percent error, E2 and standard deviation, E3 of 0.001, 0.05 and 0.07 respectively, when tested on the high viscosity liquid–gas databank.

Original languageEnglish
Pages (from-to)22-32
Number of pages11
JournalFlow Measurement and Instrumentation
Volume65
Early online date29 Oct 2018
DOIs
Publication statusPublished - 1 Mar 2019
Externally publishedYes

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two phase flow
Two-phase Flow
Gas oils
Gas Flow
Two phase flow
Viscosity
estimating
oils
Liquid
viscosity
Liquids
liquids
gases
Percent
Pipe
Viscosity of liquids
Electrical Capacitance Tomography
catchers
Mineral oils
deviation

Cite this

Archibong-Eso, A. ; Okeke, N. E. ; Baba, Y. ; Aliyu, A. M. ; Lao, L. ; Yeung, H. / Estimating slug liquid holdup in high viscosity oil-gas two-phase flow. In: Flow Measurement and Instrumentation. 2019 ; Vol. 65. pp. 22-32.
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Estimating slug liquid holdup in high viscosity oil-gas two-phase flow. / Archibong-Eso, A.; Okeke, N. E.; Baba, Y.; Aliyu, A. M.; Lao, L.; Yeung, H.

In: Flow Measurement and Instrumentation, Vol. 65, 01.03.2019, p. 22-32.

Research output: Contribution to journalArticle

TY - JOUR

T1 - Estimating slug liquid holdup in high viscosity oil-gas two-phase flow

AU - Archibong-Eso, A.

AU - Okeke, N. E.

AU - Baba, Y.

AU - Aliyu, A. M.

AU - Lao, L.

AU - Yeung, H.

PY - 2019/3/1

Y1 - 2019/3/1

N2 - Slug flow is one of the most critical and often encountered flow patterns in the oil and gas industry. It is characterised by intermittency which results in large fluctuations in liquid holdup and pressure gradient. A proper understanding of its parameters (such as slug holdup) is essential in the design of transport facilities (e.g. pipelines) and process equipment (slug catchers, separators etc.). In this paper, experimental investigation of slug liquid holdup (defined as the liquid volume fraction in the slug body of a slug unit) is performed. Mineral oil with viscosity, μ=−0.0043T3+0.0389T2−1.4174T+18.141 and air were used as test fluids. A 0.0254 m and 0.0762 m pipe internal diameters facilities with pipe lengths of 5.5 and 17 m respectively were used in the study. Electrical Capacitance Tomography was used for slug holdup measurements. Results obtained in the study shows that slug liquid holdup varied directly as the viscosity and inversely as the gas input fraction. Existing slug holdup correlations and models in literature did not sufficiently predict present experimental results. A new empirical predictive correlation for estimating slug liquid holdup was derived from present experimental databank and from data obtained in literature. The databank's liquid viscosity ranges from 0.189 to 8.0 Pa s. Statistical analysis of the new correlation vis-à-vis existing ones showed that the present correlation gave the best performance with an average percent error, E1; absolute average percent error, E2 and standard deviation, E3 of 0.001, 0.05 and 0.07 respectively, when tested on the high viscosity liquid–gas databank.

AB - Slug flow is one of the most critical and often encountered flow patterns in the oil and gas industry. It is characterised by intermittency which results in large fluctuations in liquid holdup and pressure gradient. A proper understanding of its parameters (such as slug holdup) is essential in the design of transport facilities (e.g. pipelines) and process equipment (slug catchers, separators etc.). In this paper, experimental investigation of slug liquid holdup (defined as the liquid volume fraction in the slug body of a slug unit) is performed. Mineral oil with viscosity, μ=−0.0043T3+0.0389T2−1.4174T+18.141 and air were used as test fluids. A 0.0254 m and 0.0762 m pipe internal diameters facilities with pipe lengths of 5.5 and 17 m respectively were used in the study. Electrical Capacitance Tomography was used for slug holdup measurements. Results obtained in the study shows that slug liquid holdup varied directly as the viscosity and inversely as the gas input fraction. Existing slug holdup correlations and models in literature did not sufficiently predict present experimental results. A new empirical predictive correlation for estimating slug liquid holdup was derived from present experimental databank and from data obtained in literature. The databank's liquid viscosity ranges from 0.189 to 8.0 Pa s. Statistical analysis of the new correlation vis-à-vis existing ones showed that the present correlation gave the best performance with an average percent error, E1; absolute average percent error, E2 and standard deviation, E3 of 0.001, 0.05 and 0.07 respectively, when tested on the high viscosity liquid–gas databank.

KW - Air

KW - Dryers (equipment)

KW - Electric impedance tomography

KW - Gas industry

KW - Liquids

KW - Viscosity of liquids

KW - Two phase flow

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U2 - 10.1016/j.flowmeasinst.2018.10.027

DO - 10.1016/j.flowmeasinst.2018.10.027

M3 - Article

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VL - 65

SP - 22

EP - 32

JO - Flow Measurement and Instrumentation

JF - Flow Measurement and Instrumentation

SN - 0955-5986

ER -