Relative Viscosity Model for Oil/Water Stable Emulsion Flow within Electrical Submersible Pumps

2021 ◽  
pp. 116827
Author(s):  
Natan Augusto Vieira Bulgarelli ◽  
Jorge Luiz Biazussi ◽  
William Monte Verde ◽  
Carlos Eduardo Perles ◽  
Marcelo Souza de Castro ◽  
...  
Keyword(s):  
Relative Viscosity ◽  
Viscosity Model ◽  
Stable Emulsion ◽  
Electrical Submersible Pumps ◽  
Emulsion Flow ◽  
Oil Water

A New Mechanistic Model for Emulsion Rheology and Boosting Pressure Prediction in Electrical Submersible Pumps (ESPs) under Oil-Water Two-Phase Flow

SPE Journal ◽  
2021 ◽  
pp. 1-18
Author(s):  
Jianjun Zhu ◽  
Hanjun Zhao ◽  
Guangqiang Cao ◽  
Hattan Banjar ◽  
Haiwen Zhu ◽  
...  
Keyword(s):  
Flow Rate ◽  
Mechanistic Model ◽  
Hydraulic Pressure ◽  
Water Emulsion ◽  
Flow Rates ◽  
Electrical Submersible Pumps ◽  
Pressure Increment ◽  
Emulsion Flow ◽  
Oil Water ◽  
Rheology Model

Summary As the second most widely used artificial lift method in the petroleum industry, electrical submersible pumps (ESPs) maintain or increase flow rates by converting the kinetic energy to hydraulic pressure. As oilfields age, water is invariably produced with crude oil. The increase of water cut generates oil-water emulsions due to the high-shearing effects inside a rotating ESP. Emulsions can be stabilized by natural surfactants or fine solids existing in the reservoir fluids. The formation of emulsions during oil production creates a high viscous mixture, resulting in costly problems and flow assurance issues, such as increasing pressure drop and reducing production rates. This paper, for the first time, proposes a new rheology model to predict the oil-water emulsion effective viscosities and establishes a link of fluid rheology and its effect with the stage pressure increment of ESPs. Based on Brinkman's (1952) correlation, a new rheology model, accounting for ESP rotational speed, stage number, fluid properties, and so on, is developed, which can also predict the phase inversion in oil-water emulsions. For the new mechanistic model to calculate ESP boosting pressure, a conceptual best-match flow rate (QBM) is introduced. QBM corresponds to the flow rate whose direction at the ESP impeller outlet matches the designed flow direction. Induced by the liquid flow rates changing, various pressure losses can be derived from QBM, including recirculation losses, and losses due to friction, leakage, sudden change of flow directions, and so on. Incorporating the new rheology model into the mechanistic model, the ESP boosting pressure under oil-water emulsion flow can be calculated. To validate the proposed model, the experimental data from two different types of ESPs were compared with the model predictions in terms of ESP boosting pressure. Under both high-viscositysingle-phase fluid flow and oil-water emulsion flow, the model predicted ESP pressure increment matches the experimental measurements well. From medium to high flow rates with varying oil viscosities and water cuts, the prediction error is less than 15%.

scholarly journals Study of Influences of Fracture Additives on Stability of Crude Oil Emulsion

2018 ◽  
Vol 11 (1) ◽  
pp. 118-128
Author(s):  
Hongbo Fang ◽  
Mingxia Wang ◽  
Xiaoyun Liu ◽  
Weinan Jin ◽  
Xiangyang Ma ◽  
...  
Keyword(s):  
Interfacial Tension ◽  
Crude Oil ◽  
Oil Recovery ◽  
Oil Field ◽  
Stable Emulsion ◽  
Water Emulsion ◽  
High Efficient ◽  
Fracture Fluid ◽  
Oil Water ◽  
The Stability

Background: A hydraulic fracture is a key technology to increase production of the low permeability oil fields. Fracture additives such as gels, friction reducers, pH adjusters and clay stabilizers were injected into the underground. While more than 50% of the fracture fluid remains underground. The residue of fracture fluid comes out with the produced liquid (a mixture of crude oil and water) in the subsequent oil recovery process, which results in a highly stable crude oil-water emulsion. Objective: The stability and stable mechanism of the emulsion with fracture fluid have been experimentally investigated. Materials and Methods: The influences of fracture additives and components of crude oil on the stability of emulsion were investigated by bottle test and microscopic examination. The interfacial tension and modulus of dilation were explored by a spinning drop interfacial tension meter and an interface expansion rheometer, respectively. Results: The fracture additives played the key role on the emulsion stability. On one hand, the interface energy of oil-water was reduced by friction reducer (IFT was decreased from 24.0 mN/m to 1.9 mN/m), which was a favor for the formation of an emulsion. On the other hand, the dilational modulus of crude oil-water film was increased by hydroxypropyl guar and pH adjuster (Na2CO3) to form a viscoelastic film, which resulted in a highly stable emulsion. Conclusion: The residual fracture fluid accompanied by produced liquid resulted in a highly stable emulsion. The emulsion with fracture additives was difficult to be broken, which may affect the normal production of the oil field. A positive strategy such as developing demulsifier with high efficient should be put onto the schedule.

Effect of Nano-Clay Cloisite 20A on water-in-oil stable emulsion flow at different temperatures

2020 ◽  
Vol 184 ◽  
pp. 106595
Author(s):  
Mozamil Khalid ◽  
Abdullah Sultan ◽  
Mohamed Nabil Noui-Mehidi ◽  
Abdelsalam Al-Sarkhi ◽  
Omer Salim
Keyword(s):  
Stable Emulsion ◽  
Nano Clay ◽  
Different Temperatures ◽  
Emulsion Flow ◽  
Cloisite 20A

Oil, Water, and Climate

2001 ◽  
Author(s):  
Catherine Gautier
Keyword(s):  
Oil Water
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