Particle-Transport Mechanism in Liquid/Liquid/Solid Multiphase Pipeline Flow of High-Viscosity Oil/Water/Sand

SPE Journal ◽  
2021 ◽  
pp. 1-16
Author(s):  
Archibong Archibong-Eso ◽  
Yahaya Baba ◽  
Aliyu Aliyu ◽  
Joseph Ribeiro ◽  
Fidelis Abam ◽  
...  
Keyword(s):  
Pressure Gradient ◽  
Heavy Oil ◽  
Test Section ◽  
Transport Mechanism ◽  
Plug Flow ◽  
Flow Patterns ◽  
Sand Transport ◽  
Oil Viscosity ◽  
Oil Water ◽  
Water Cut

Summary In this study, an investigation of sand transport in heavy-oil/water multiphase flow is performed. The study is conducted in three multiphase-flowpipeline-test facilities with internal diameters (IDs) of 1, 1, and 3 in. The pipeline orientations relative to the horizontal in the facilities are 0, +30, and 0°, respectively. Oil viscosity of 3.5 and 10.0 Pa·s with sand volume fractions from 0.010 to 0.100 vol% were used in the study. The effects of oil viscosity, upward inclination, sand volume fraction, pipe ID, and water cut on the sand-transport mechanism in pipelines are investigated. In the horizontal test section, flow patterns—namely, dispersed flow (DF), plug flow (PF), plug flow with moving sand bed (PFM), and plug flow with stationary sand bed (PFS)—were identified through flow visualization. In addition to the aforementioned, two flow patterns—stratified wavy flow with moving sand bed (SWM) and stratified wavy flow with dunes (SWD)—were observed in the inclined pipeline orientation. The pressure gradient measured decreased with a decrease in water cut until a minimum value was reached. Beyond the minimum pressure gradient, further reduction in water cut led to an increase in pressure gradient. The sand minimum transport condition (MTC) in the oil/water/sand test was largely the same for the 1-in. 30° upward inclined and the 1-in. horizontal test section. In contrast, that of the 3-in. horizontal test section was considerably higher. An improved MTC predictive correlation is proposed for multiphase heavy-oil/water/sand flow. The proposed correlation outperforms the existing models when tested on the heavy-oil/water/sand data set.

Effect of oil viscosity on the flow structure and pressure gradient in horizontal oil–water flow

2012 ◽  
Vol 90 (8) ◽  
pp. 1019-1030 ◽  
Author(s):  
N. Yusuf ◽  
Y. Al-Wahaibi ◽  
T. Al-Wahaibi ◽  
A. Al-Ajmi ◽  
A.S. Olawale ◽  
...  
Keyword(s):  
Pressure Gradient ◽  
Water Flow ◽  
Flow Structure ◽  
Oil Viscosity ◽  
Oil Water

Indoor Study of Viscosity Reducer for Thickened Oil of Huancai

2012 ◽  
Vol 268-270 ◽  
pp. 547-550
Author(s):  
Qing Wang Liu ◽  
Xin Wang ◽  
Zhen Zhong Fan ◽  
Jiao Wang ◽  
Rui Gao ◽  
...  
Keyword(s):  
Interfacial Tension ◽  
Oil Recovery ◽  
Heavy Oil ◽  
High Viscosity ◽  
Oil Field ◽  
Viscosity Reduction ◽  
Oil Viscosity ◽  
Low Viscosity ◽  
Viscosity Reducer ◽  
Oil Water

Liaohe oil field block 58 for Huancai, the efficiency of production of thickened oil is low, and the efficiency of displacement is worse, likely to cause other issues. Researching and developing an type of Heavy Oil Viscosity Reducer for exploiting. The high viscosity of W/O emulsion changed into low viscosity O/W emulsion to facilitate recovery, enhanced oil recovery. Through the experiment determine the viscosity properties of Heavy Oil Viscosity Reducer. The oil/water interfacial tension is lower than 0.0031mN•m-1, salt-resisting is good. The efficiency of viscosity reduction is higher than 90%, and also good at 180°C.

Flow Patterns in Heavy Crude Oil-Water Flow

2001 ◽  
Author(s):  
Antonio C. Bannwart ◽  
Oscar M. H. Rodriguez ◽  
Carlos H. M. de Carvalho ◽  
Isabela S. Wang ◽  
Rosa M. O. Vara
Keyword(s):  
Crude Oil ◽  
Flow Pattern ◽  
Heavy Oil ◽  
Annular Flow ◽  
Effective Means ◽  
Practical Importance ◽  
Flow Patterns ◽  
Heavy Crude Oil ◽  
Oil Water ◽  
Heavy Crude

Abstract This paper is aimed to an experimental study on the flow patterns formed by heavy crude oil (488 mPa.s, 925.5 kg/m3 at 20 °C) and water inside vertical and horizontal 1 in. pipes. The interfacial tension was 29 dynes/cm. Effort is concentrated into flow pattern characterization, which was visually defined. The similarities with gas-liquid flow patterns are explored and the results are expressed in flow maps of the superficial velocities. In contrast with other studies, the annular flow pattern (‘core annular flow’) was observed in both horizontal and vertical test sections. In fact this flow pattern typically occurs in heavy oil-water flows at low water input fractions. Because of the practical importance of core flow in providing an effective means for heavy oil production and transportation, this paper discusses two criteria that favor its occurrence in pipes.

A Machine Learning Approach to Predict the Pressure Gradient of Different Oil-Water Flow Patterns in a Horizontal Wellbore

2021 ◽  
Author(s):  
MD Ferdous Wahid ◽  
Reza Tafreshi ◽  
Zurwa Khan ◽  
Albertus Retnanto
Keyword(s):  
Machine Learning ◽  
Surface Tension ◽  
Surface Roughness ◽  
Pressure Gradient ◽  
Water Flow ◽  
Flow Patterns ◽  
Data Driven ◽  
Pressure Gradients ◽  
Horizontal Wellbore ◽  
Oil Water

Abstract Fluid pressure gradient in a wellbore plays a significant role to efficiently transport between source and separator facilities. The mixture of two immiscible fluids manifests in various flow patterns such as stratified, dispersed, intermittent, and annular flow, which can significantly influence the fluid’s pressure gradient. However, previous studies have only used limited flow patterns when developing their data-driven model. The aim of this study is to develop a uniform data-driven model using machine-learning (ML) algorithms that can accurately predict the pressure gradient for the oil-water flow with two stratified and seven dispersed flow patterns in a horizontal wellbore. Two different machine-learning algorithms, Artificial Neural Network (ANN) and Random Forest (RF), were employed to predict the pressure gradients. A total of 662 experimental points from nine different flow patterns were extracted from five sources that include twelve variables for different physical properties of oil-water, wellbore’s surface roughness, and input diameter. The variables are entrance length to diameter ratio, oil and water viscosity, density, velocity, and surface tension, between oil and water surface tension, surface roughness, input diameter, and flow pattern. The algorithms’ performance was evaluated using median absolute percentage error (MdAPE) and root mean squared error (RMSE). A repeated train-test split strategy was used where the final MdAPE and RMSE were computed from the average of all repetitions. The MdAPE and RMSE for the prediction of pressure gradients are 13.89% and 0.138 kPa/m using RF and 12.17% and 0.088 kPa/m using ANN, respectively. The ML algorithms’ ability to model the pressure gradient is demonstrated using measured vs. predicted analysis where the experimental data points are mostly located in close proximity of the diagonal line, indicating a suitable generalization of the models. Comparing the performance between RF and ANN shows that the latter algorithm’s prediction accuracy is significantly better (p<0.01).

Flow Patterns in Heavy Crude Oil-Water Flow

2004 ◽  
Vol 126 (3) ◽  
pp. 184-189 ◽  
Author(s):  
Antonio C. Bannwart ◽  
Oscar M. H. Rodriguez ◽  
Carlos H. M. de Carvalho ◽  
Isabela S. Wang ◽  
Rosa M. O. Vara
Keyword(s):  
Crude Oil ◽  
Flow Pattern ◽  
Heavy Oil ◽  
Annular Flow ◽  
Effective Means ◽  
Practical Importance ◽  
Flow Patterns ◽  
Heavy Crude Oil ◽  
Oil Water ◽  
Heavy Crude

This paper is aimed to an experimental study on the flow patterns formed by heavy crude oil (initial viscosity and density 488 mPa s, 925.5kg/m3 at 20°C) and water inside vertical and horizontal 2.84-cm-i.d. pipes. The oil-water interfacial tension was 29 dyn/cm. Effort is concentrated into flow pattern characterization, which was visually defined. The similarities with gas-liquid flow patterns are explored and the results are expressed in flow maps. In contrast with other studies, the annular flow pattern (“core annular flow”) was observed in both horizontal and vertical test sections. These flow pattern tends to occur in heavy oil-water flows at low water input fractions. Because of the practical importance of core flow in providing an effective means for heavy oil production and transportation, this paper discusses criteria that favor its occurrence in pipes.

scholarly journals Experimental Study on the Flow Regimes and Pressure Gradients of Air-Oil-Water Three-Phase Flow in Horizontal Pipes

2014 ◽  
Vol 2014 ◽  
pp. 1-11 ◽  
Author(s):  
Luai M. Al-Hadhrami ◽  
S. M. Shaahid ◽  
Lukman O. Tunde ◽  
A. Al-Sarkhi
Keyword(s):  
Tap Water ◽  
Strong Dependence ◽  
Flow Regimes ◽  
Flow Patterns ◽  
Pressure Gradients ◽  
Horizontal Pipe ◽  
Three Phase ◽  
Wide Range ◽  
Oil Water ◽  
Water Cut

An experimental investigation has been carried out to study the flow regimes and pressure gradients of air-oil-water three-phase flows in 2.25 ID horizontal pipe at different flow conditions. The effects of water cuts, liquid and gas velocities on flow patterns and pressure gradients have been studied. The experiments have been conducted at 20°C using low viscosity Safrasol D80 oil, tap water and air. Superficial water and oil velocities were varied from 0.3 m/s to 3 m/s and air velocity varied from 0.29 m/s to 52.5 m/s to cover wide range of flow patterns. The experiments were performed for 10% to 90% water cuts. The flow patterns were observed and recorded using high speed video camera while the pressure drops were measured using pressure transducers and U-tube manometers. The flow patterns show strong dependence on water fraction, gas velocities, and liquid velocities. The observed flow patterns are stratified (smooth and wavy), elongated bubble, slug, dispersed bubble, and annular flow patterns. The pressure gradients have been found to increase with the increase in gas flow rates. Also, for a given superficial gas velocity, the pressure gradients increased with the increase in the superficial liquid velocity. The pressure gradient first increases and then decreases with increasing water cut. In general, phase inversion was observed with increase in the water cut. The experimental results have been compared with the existing unified Model and a good agreement has been noticed.

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