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%.

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.

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.

scholarly journals Pore-Scale Imaging and Analysis of Wettability Order, Trapping and Displacement in Three-Phase Flow in Porous Media with Various Wettabilities

2021 ◽  
Author(s):  
Abdulla Alhosani ◽  
Branko Bijeljic ◽  
Martin J. Blunt
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Pore Space ◽  
Flow In Porous Media ◽  
Phase Flow ◽  
Pore Scale ◽  
Gas Oil ◽  
Capillary Trapping ◽  
Three Phase ◽  
Three Phase Flow

AbstractThree-phase flow in porous media is encountered in many applications including subsurface carbon dioxide storage, enhanced oil recovery, groundwater remediation and the design of microfluidic devices. However, the pore-scale physics that controls three-phase flow under capillary dominated conditions is still not fully understood. Recent advances in three-dimensional pore-scale imaging have provided new insights into three-phase flow. Based on these findings, this paper describes the key pore-scale processes that control flow and trapping in a three-phase system, namely wettability order, spreading and wetting layers, and double/multiple displacement events. We show that in a porous medium containing water, oil and gas, the behaviour is controlled by wettability, which can either be water-wet, weakly oil-wet or strongly oil-wet, and by gas–oil miscibility. We provide evidence that, for the same wettability state, the three-phase pore-scale events are different under near-miscible conditions—where the gas–oil interfacial tension is ≤ 1 mN/m—compared to immiscible conditions. In a water-wet system, at immiscible conditions, water is the most-wetting phase residing in the corners of the pore space, gas is the most non-wetting phase occupying the centres, while oil is the intermediate-wet phase spreading in layers sandwiched between water and gas. This fluid configuration allows for double capillary trapping, which can result in more gas trapping than for two-phase flow. At near-miscible conditions, oil and gas appear to become neutrally wetting to each other, preventing oil from spreading in layers; instead, gas and oil compete to occupy the centre of the larger pores, while water remains connected in wetting layers in the corners. This allows for the rapid production of oil since it is no longer confined to movement in thin layers. In a weakly oil-wet system, at immiscible conditions, the wettability order is oil–water–gas, from most to least wetting, promoting capillary trapping of gas in the pore centres by oil and water during water-alternating-gas injection. This wettability order is altered under near-miscible conditions as gas becomes the intermediate-wet phase, spreading in layers between water in the centres and oil in the corners. This fluid configuration allows for a high oil recovery factor while restricting gas flow in the reservoir. Moreover, we show evidence of the predicted, but hitherto not reported, wettability order in strongly oil-wet systems at immiscible conditions, oil–gas–water, from most to least wetting. At these conditions, gas progresses through the pore space in disconnected clusters by double and multiple displacements; therefore, the injection of large amounts of water to disconnect the gas phase is unnecessary. We place the analysis in a practical context by discussing implications for carbon dioxide storage combined with enhanced oil recovery before suggesting topics for future work.

scholarly journals Proposing an Intelligent Dual-Energy Radiation-Based System for Metering Scale Layer Thickness in Oil Pipelines Containing an Annular Regime of Three-Phase Flow

Mathematics ◽  
2021 ◽  
Vol 9 (19) ◽  
pp. 2391
Author(s):  
Osman Taylan ◽  
Mona Abusurrah ◽  
Saba Amiri ◽  
Ehsan Nazemi ◽  
Ehsan Eftekhari-Zadeh ◽  
...  
Keyword(s):  
Layer Thickness ◽  
Radiation Detection ◽  
Dual Energy ◽  
Internal Diameter ◽  
Phase Flow ◽  
Invasive Approach ◽  
Energy Radiation ◽  
Scale Layer ◽  
Three Phase ◽  
Three Phase Flow

Deposition of scale layers inside pipelines leads to many problems, e.g., reducing the internal diameter of pipelines, damage to drilling equipment because of corrosion, increasing energy consumption because of decreased efficiency of equipment, and shortened life, etc., in the petroleum industry. Gamma attenuation could be implemented as a non-invasive approach suitable for determining the mineral scale layer. In this paper, an intelligent system for metering the scale layer thickness independently of each phase’s volume fraction in an annular three-phase flow is presented. The approach is based on the use of a combination of an RBF neural network and a dual-energy radiation detection system. Photo peaks of 241Am and 133Ba registered in the two transmitted detectors, and scale-layer thickness of the pipe were considered as the network’s input and output, respectively. The architecture of the presented network was optimized using a trial-and-error method. The regression diagrams for the testing set were plotted, which demonstrate the precision of the system as well as correction. The MAE and RMSE of the presented system were 0.07 and 0.09, respectively. This novel metering system in three-phase flows could be a promising and practical tool in the oil, chemical, and petrochemical industries.

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.

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