scholarly journals Effect of the fluid viscosity on three phase flow (oil, water and gas) through Multiphase Flow Meter

2006 ◽  
Vol 71 (6) ◽  
pp. 599-606
Author(s):  
Tomoko Watanabe ◽  
Kiyoshi Minemura
Keyword(s):  
Multiphase Flow ◽  
Fluid Viscosity ◽  
Phase Flow ◽  
Flow Meter ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Water

An Improved Three-Phase Relative Permeability and Hysteresis Model for the Simulation of a Water-Alternating-Gas Injection

SPE Journal ◽  
2013 ◽  
Vol 18 (05) ◽  
pp. 841-850 ◽  
Author(s):  
H.. Shahverdi ◽  
M.. Sohrabi
Keyword(s):  
Relative Permeability ◽  
Oil Recovery ◽  
Gas Injection ◽  
Phase Flow ◽  
Relative Permeabilities ◽  
Water Alternating Gas ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Water ◽  
Wag Injection

Summary Water-alternating-gas (WAG) injection in waterflooded reservoirs can increase oil recovery and extend the life of these reservoirs. Reliable reservoir simulations are needed to predict the performance of WAG injection before field implementation. This requires accurate sets of relative permeability (kr) and capillary pressure (Pc) functions for each fluid phase, in a three-phase-flow regime. The WAG process also involves another major complication, hysteresis, which is caused by flow reversal happening during WAG injection. Hysteresis is one of the most important phenomena manipulating the performance of WAG injection, and hence, it has to be carefully accounted for. In this study, we have benefited from the results of a series of coreflood experiments that we have been performing since 1997 as a part of the Characterization of Three-Phase Flow and WAG Injection JIP (joint industry project) at Heriot-Watt University. In particular, we focus on a WAG experiment carried out on a water-wet core to obtain three-phase relative permeability values for oil, water, and gas. The relative permeabilities exhibit significant and irreversible hysteresis for oil, water, and gas. The observed hysteresis, which is a result of the cyclic injection of water and gas during WAG injection, is not predicted by the existing hysteresis models. We present a new three-phase relative permeability model coupled with hysteresis effects for the modeling of the observed cycle-dependent relative permeabilities taking place during WAG injection. The approach has been successfully tested and verified with measured three-phase relative permeability values obtained from a WAG experiment. In line with our laboratory observations, the new model predicts the reduction of the gas relative permeability during consecutive water-and-gas-injection cycles as well as the increase in oil relative permeability happening in consecutive water-injection cycles.

Analysis of Oil-Water-Gas Three-Phase Flow in a Curved Leaking Pipe

2016 ◽  
Vol 366 ◽  
pp. 144-150
Author(s):  
Boniek Evangelista Leite ◽  
Severino Rodrigues de Farias Neto ◽  
Antonio Gilson Barbosa de Lima ◽  
Lígia Rafaely Barbosa Sarmento
Keyword(s):  
Continuous Phase ◽  
Environmental Damage ◽  
Particle Model ◽  
Phase Flow ◽  
Curved Pipe ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Water ◽  
Object Of Study ◽  
Water Gas

The onshore and offshore production of oil and natural gas is characterized by the multiphase flow in ducts and pipes, which are interconnected by various equipments such as wellhead, pumps, compressors, processing platforms, among others. The transport of oil and oil products is essential to the viability of the sector, but is susceptible to failures, that can cause great environmental damage. Considering this necessity of the transportation sector of oil and derivatives, leakage in pipelines with curved connections, are the object of study for various researchers. In this sense, this work contributes to the study of three-phase flow (oil-water-gas) in a curved pipe (90°) using Computational Fluid Dynamics. The physical domain is constituted by two tubes of 4 meters trenched by a 90° curve, with the poring whole in the curvated accessory. The mathematical model is based on a particle model, where the oil is considered as a continuous phase and the water and gas as a particulate phase. The SST (Shear Stress Transport) turbulence model was adopted. All simulations were carried out using the Ansys CFX® 12.1 commercial code. Results of the pressure, velocity and volumetric fraction of the phases are presented and discussed.

Hydrodynamic Modeling of Three-Phase Flow in Production and Gathering Pipelines

2007 ◽  
Author(s):  
Jose Zaghloul ◽  
Michael Adewumi ◽  
M. Thaddeus Ityokumbul
Keyword(s):  
Water Flow ◽  
Fluid Model ◽  
Hydrate Formation ◽  
Phase Flow ◽  
Gas Oil ◽  
Two Phase ◽  
Flow Reduction ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Water

The transport of unprocessed gas streams in production and gathering pipelines is becoming more attractive for new developments, particularly those is less friendly enviroments such as deep offshore locations. Transporting gas, oil, and water together from wells in satellite fields to existing processing facilities reduces the investments required for expanding production. However, engineers often face several problems when designing these systems. These problems include reduced flow capacity, corrosion, emulsion, asphaltene or wax deposition, and hydrate formation. Engineers need a tool to understand how the fluids travel together, quantify the flow reduction in the pipe, and determine where, how much, and the type of liquid that would from in a pipe. The present work provides a fundamental understanding of the thermodynamics and hydrodynamic mechanisms of this type of flow. We present a model that couples complex hydrodynamic and thermodynamic models for describing the behavior of fluids traveling in near-horizontal pipes. The model incorporates: • A hydrodynamic formulation for three-phase flow in pipes. • A thermodynamic model capable of performing two-phase and three-phase flow calculations in an accurate, fast and reliable manner. • A new theoretical approach for determining flow pattern transitions in three-phase (gas-oil-water) flow, and closure models that effectively handle different three-phase flow patterns and their transitions. The unified two-fluid model developed herein is demonstrated to be capable of handling systems exhibiting two-phase (gas-water and gas-oil) and three-phase (gas-oil-water) flow. Model predictions were compared against field and experimental data with excellent matches. The hydrodynamic model allows: 1) the determination of flow reduction due to the condensation of liquid(s) in the pipe, 2) assessment of the potential for forming substances that might affect the integrity of the pipe, and 3) evaluation of the possible measures for improving the deliverability of the pipeline.

Research on the Oil-Gas-Water Three-Phase Flow Experimental Apparatus

2011 ◽  
Vol 328-330 ◽  
pp. 2023-2026
Author(s):  
Ying Xu ◽  
Tao Li
Keyword(s):  
Control System ◽  
Multiphase Flow ◽  
System Control ◽  
Phase Flow ◽  
Monitoring And Control ◽  
Three Phase ◽  
Experimental Apparatus ◽  
Three Phase Flow ◽  
And Control ◽  
Oil Gas

The oil-gas-water three-phase flow experimental apparatus in key laboratory of process monitoring and control in Tianjin University is a set of indoor small experimental device, which can simulate oil wells, simulate the pipeline transport of multiphase flow and study the experiment of multiphase flow. The device includes energy power dynamic systems, measurement pipelines systems, multiphase flow test pipelines system, control valves, sampling and control system platform. The software of the control system is mixed programming between the configuration software MCGS and the Visual Basic.

Development of Transient Mechanistic Three-Phase Flow Model for Wellbores

SPE Journal ◽  
2016 ◽  
Vol 22 (01) ◽  
pp. 374-388 ◽  
Author(s):  
Mahdy Shirdel ◽  
Kamy Sepehrnoori
Keyword(s):  
Multiphase Flow ◽  
Flow Model ◽  
Fluid Model ◽  
Phase Flow ◽  
Complex Flow ◽  
Flow Models ◽  
Drift Flux Model ◽  
Three Phase ◽  
Three Phase Flow ◽  
Two Fluid

Summary Multiphase flow models have been widely used for downhole-gauging and production logging analysis in the wellbores. Coexistence of hydrocarbon fluids with water in production wells yields a complex flow system that requires a three-phase flow model for better characterizing the flow and analyzing measured downhole data. In the past few decades, many researchers and commercial developers in the petroleum industry have aggressively expanded development of robust multiphase flow models for the wellbore. However, many of the developed models apply homogeneous-flow models with limited assumptions for slippage between gas and liquid bulks or use purely two-fluid models. In this paper, we propose a new three-phase flow model that consists of a two-fluid model between liquid and gas and a drift-flux model between water and oil in the liquid phase. With our new method, we improve the simplifying assumptions for modeling oil, water, and gas multiphase flow in wells, which can be advantageous for better downhole flow characterization and phase separations in gravity-dominated systems. Furthermore, we developed semi-implicit and nearly implicit numerical algorithms to solve the system of equations. We discuss the stepwise-development procedures for these methods along with the assumptions in our flow model. We verify our model results against analytical solutions for the water faucet problem and phase redistribution, field data, and a commercial simulator. Our model results show very good agreement with benchmarks in the data.

Experimental Investigation of Liquid Carry-Over in GLCC© Separators for 3-Phase Flow

2016 ◽  
Author(s):  
Srinivas Swaroop Kolla ◽  
Ram S. Mohan ◽  
Ovadia Shoham
Keyword(s):  
Heavy Oil ◽  
Phase Flow ◽  
Level Control ◽  
Three Phase ◽  
Three Phase Flow ◽  
Light Oil ◽  
Series Of Experiments ◽  
Oil Water ◽  
Carry Over ◽  
Operational Envelope

Prediction of the Operational Envelope (OPEN) for liquid carry-over is essential for optimized performance of Gas-Liquid Cylindrical Cyclone (GLCC©1) compact separators. This study extends the previous GLCC liquid carry-over studies from 2-phase flow to 3-phase gas-oil-water flow incorporating pressure and level control configurations. A series of experiments were conducted to evaluate the performance of a 3″ diameter GLCC in terms of OPEN for liquid carry-over. Both light oil and heavy oil were utilized, with watercuts ranging from 0 to 100%. The liquid level was controlled at 6″ below the GLCC inlet. A significant effect of watercut on the OPEN for liquid carry-over for three-phase flow was observed. As the watercut reduces, the OPEN for liquid carry-over reduces too. Also, the OPEN for heavy oil reduces as compared to light oil, which could be primary due to the effect of viscosity. Finally, the annular mist velocity increases with the increment of watercut and viscosity.

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