An intelligent integrated approach of Jaya optimization algorithm and neuro-fuzzy network to model the stratified three-phase flow of gas–oil–water

2019 ◽  
Vol 38 (1) ◽  
Author(s):  
Gholam Hossein Roshani ◽  
Ali Karami ◽  
Ehsan Nazemi
Keyword(s):  
Optimization Algorithm ◽  
Integrated Approach ◽  
Phase Flow ◽  
Gas Oil ◽  
Neuro Fuzzy ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Water ◽  
Fuzzy Network

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.

Characteristics of the Interfacial Wave Velocity on the Liquid Film of Annular Flow for Gas-Oil-Water Three-Phase Flow in a Horizontal Pipe

2011 ◽  
Vol 402 ◽  
pp. 816-819
Author(s):  
Hai Qin Wang ◽  
Yong Wang ◽  
Lei Zhang ◽  
Jin Hai Gong ◽  
Zhen Yu Wang
Keyword(s):  
Flow Pattern ◽  
Wave Velocity ◽  
Annular Flow ◽  
Superficial Velocity ◽  
Phase Flow ◽  
Gas Oil ◽  
Interfacial Wave ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Water

The experiments were conducted in a horizontal multiphase flow test loop (50mm inner diameter, 40m long) and the cross-correlation technology was used for the study of the characteristics of the interfacial wave velocity about two types of annular flow regimes (AN║DO/W and AN║DW/O) for gas-oil-water three-phase flow. The results show that the interfacial wave velocity on the liquid film of AN║DO/W flow pattern and AN║DW/O flow pattern all increases with the increase of gas superficial velocity and liquid superficial velocity on the condition of fixed ratio of oil and water flow rates, but the difference is that the increase is a linear monotonic increase for AN║DO/W flow pattern and a non-linear increase for AN║DW/O flow pattern, and the liquid superficial velocity makes a larger contribution than the gas superficial velocity. The interfacial wave velocity also increases with the increase of input water cut in liquid at different gas superficial velocities under the conditions of liquid superficial velocity fixed.

Oil-Water Phase Inversion in the Horizontal Section of Upstream 90° Bend during Gas-Oil-Water Three-Phase Flow

2019 ◽  
Vol 796 ◽  
pp. 137-144 ◽  
Author(s):  
Muhammad Waqas Yaqub ◽  
Rajashekhar Pendyala ◽  
Risza Rusli
Keyword(s):  
Phase Inversion ◽  
Volume Fraction ◽  
Liquid Mixtures ◽  
Liquid Volume ◽  
Internal Diameter ◽  
Phase Flow ◽  
Gas Oil ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Water

The gas, oil and water co-current flow in pipes either flow in separate layers or in the form of a mixture. Other than gas, the liquid mixtures are common during the transportation of oil. In liquid mixtures, one liquid acts as a continuous phase and the other liquid dispersed in it. The phase inversion in three-phase flow majorly depends on the superficial velocity of individual phases, the volume fraction of liquid phases in total liquid and the internal diameter of the pipe. Pipe bends and fittings are commonly used in pipe networks for the diversion and distribution of flow. The 90° elbow bends are commonly used in such systems, where they change the flow direction from horizontal to vertical and vice versa. For the case of horizontal to upward vertical flow, the bend offers restriction to the flow compared to the straight pipe. Therefore, the process of phase inversion gets effected upstream 90° bend. In the current work, the phase inversion process during three-phase horizontal flow upstream 90° bend has been studied. The internal diameter of the pipe was 0.1524 m and the bend radius to diameter ratio (r/d) was 1. The range of superficial velocities are 0.5-5, 0.08-0.4, and 0.08-0.4 for oil-gas and water respectively. The continuous liquid phase and its effect on pressure drop have been studied at various oil to liquid volume ratios (fo). The results show the different oil-water relationships and the liquid holdup occurred due to the bend.

scholarly journals Application of Artificial Intelligence and Gamma Attenuation Techniques for Predicting Gas–Oil–Water Volume Fraction in Annular Regime of Three-Phase Flow Independent of Oil Pipeline’s Scale Layer

Mathematics ◽  
2021 ◽  
Vol 9 (13) ◽  
pp. 1460
Author(s):  
Abdulaziz S. Alkabaa ◽  
Ehsan Nazemi ◽  
Osman Taylan ◽  
El Mostafa Kalmoun
Keyword(s):  
Gamma Radiation ◽  
Volume Fraction ◽  
Phase Flow ◽  
Gas Oil ◽  
Oil Pipeline ◽  
Intelligent Technique ◽  
Scale Layer ◽  
Three Phase ◽  
Three Phase Flow ◽  
Annular Regime

To the best knowledge of the authors, in former studies in the field of measuring volume fraction of gas, oil, and water components in a three-phase flow using gamma radiation technique, the existence of a scale layer has not been considered. The formed scale layer usually has a higher density in comparison to the fluid flow inside the oil pipeline, which can lead to high photon attenuation and, consequently, reduce the measuring precision of three-phase flow meter. The purpose of this study is to present an intelligent gamma radiation-based, nondestructive technique with the ability to measure volume fraction of gas, oil, and water components in the annular regime of a three-phase flow independent of the scale layer. Since, in this problem, there are several unknown parameters, such as gas, oil, and water components with different amounts and densities and scale layers with different thicknesses, it is not possible to measure the volume fraction using a conventional gamma radiation system. In this study, a system including a 241Am-133Ba dual energy source and two transmission detectors was used. The first detector was located diametrically in front of the source. For the second detector, at first, a sensitivity investigation was conducted in order to find the optimum position. The four extracted signals in both detectors (counts under photo peaks of both detectors) were used as inputs of neural network, and volume fractions of gas and oil components were utilized as the outputs. Using the proposed intelligent technique, volume fraction of each component was predicted independent of the barium sulfate scale layer, with a maximum MAE error of 3.66%.

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.

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