Experience of Application of Different Multiphase Metering Technologies for Cold Production and High Viscosity Oil Systems

2021 ◽  
Author(s):  
Mikhail Igorevich Tonkonog ◽  
Yermek Talgatovich Kaipov ◽  
Dmitry Sergeevich Pruglo
Keyword(s):  
Volume Fraction ◽  
High Viscosity ◽  
Production Optimization ◽  
Gas Content ◽  
Two Phase ◽  
Production Monitoring ◽  
Oil Rim ◽  
Phase Separator ◽  
High Viscosity Oil ◽  
Gas Volume

Abstract Production monitoring is essential not only for fiscal applications, but also for production optimization and efficient reservoir management. So, production measurements must be both accurate and frequent enough, revealing a consistent trend of well operating parameters. This is especially important for reservoirs of complex geology, like oil rim reservoirs in poorly consolidated sandstone formations with presence of aquifer and gas cap drive. Production monitoring can be implemented with different technologies, accuracy of monitoring is however affected by different factors like gas content, viscosity and temperature of produced fluids. Paper presents pragmatic approach and analysis of applicability of different measurement technologies: compact two-phase separator and two different multiphase metering technologies applied at oil wells of Tazovskoye field operated by LLC "Meretoyakhaneftegaz", which production conditions are very challenging due to high gas volume fraction of the produced fluid, high viscosities and low temperatures.

BC10 Field Mudline Pump Operation Case Study: A Deepwater, Long Tie Back, High GVF and High Viscosity Application

2021 ◽  
Author(s):  
Igor Vieira Debacker ◽  
David Liney ◽  
Mariana Ferreira Palacios ◽  
Nicholas Fletcher
Keyword(s):  
Volume Fraction ◽  
Flow Instability ◽  
High Viscosity ◽  
Gas Content ◽  
Oil Emulsion ◽  
Pump Operation ◽  
Field Development ◽  
Artificial Lift ◽  
Electrical Submersible Pumps ◽  
Gas Volume

Abstract The Parque das Conchas (BC10) block offshore southern Brazil's Campos Basin has fields with challenging subsea well conditions (high viscosity and high gas content). The fields require subsea boosting to lift the production to the FPSO facility. The field development was conceived with ten Electrical Submersible Pumps (ESP) installed in dummy wells in three different subsea artificial lift manifolds (ALM) in water depths around 2000m. In 2018, the first Mudline Pump (MLP) was installed in the BC10 field. The MLP was conceived to be fully compatible with the existing infrastructure and replaced one of the existing seabed Module of Boost (MOBOs) in the Argonauta O-North field. Argonauta O-North has heavy crude oil and forms tight water-in-oil emulsion. Another challenge in this field is frequent flow instability causing abrupt variations of the Gas Volume Fraction (GVF) at the ALM inlet. The MLP was commissioned and started up in November of 2018. The initial weeks of operation were marked by frequent trips caused mainly by a non-optimized controller combined with excessive flow transients generated in the flowlines and risers, and lack of understanding of the interaction between the pump and the seafloor flowline, manifold system and production riser. The main results of the work performed in the first year of MLP operation were to significantly reduce the number of trips, and to optimize MLP oil production.

scholarly journals Effect of Diversion Cavity Geometry on the Performance of Gas-Liquid Two-Phase Mixed Transport Pump

Energies ◽  
2020 ◽  
Vol 13 (8) ◽  
pp. 1882
Author(s):  
Chenhao Li ◽  
Xingqi Luo ◽  
Jianjun Feng ◽  
Guojun Zhu ◽  
Sina Yan
Keyword(s):  
Volume Fraction ◽  
Internal Flow ◽  
Gas Content ◽  
Two Phase ◽  
Flow Energy ◽  
Model Liquid ◽  
Abnormal Pressure ◽  
Object Based ◽  
Before And After ◽  
Gas Volume

For the purpose of improving the transport capability of the mixed transport pump, a new self-made three-stage deep-sea multiphase pump was taken as the research object. Based on the Euler-Euler heterogeneous flow model, liquid (water) and gas (air) are used as the mixed media to study the external characteristics and internal flow identities of the mixed pump under different gas volume fraction (GVF) conditions. According to the simulation results, a local optimal design scheme of the diversion cavity in the dynamic and static connection section is proposed. The numerical results before and after the optimization are compared and analyzed to explore the effect of the diversion cavity optimization on the performance, blade load and internal flow identities of the pump. The results show that the head and efficiency are obviously improved when the inner wall of the diversion cavity is reduced by 4 mm along the radial direction. After optimization, under the condition of 10% gas content, the head and efficiency is increased by 3.73% and 2.91% respectively. Meanwhile, the hydraulic losses of the diversion cavity and diffuser are reduced by 9.11% and 4.32% respectively. The gas distribution in the impeller is improved obviously and the phenomenon of a large amount of gas phase accumulation is eliminated in the channel. In addition, the abnormal pressure load on the blade surface is eliminated and the turbulent flow energy intensity is reduced. The average turbulent kinetic energy ( T K ) at i = 0.51 of the first stage impeller passage is reduced by 35%. Finally, the reliability of the numerical method is verified by the experimental results. To sum up, the performance and internal flow identities of the optimized mixed transport pump are improved, which verifies the availability and applicability of the optimization results. This provides a reference for the research and design of a multiphase mixed transport pump in the future.

Two-Phase Filtration Model for Nonlinear Viscoplastic Oil and Hard Water Drive

2014 ◽  
Vol 698 ◽  
pp. 679-682
Author(s):  
Anastasia Markelova ◽  
Artem Trifonov ◽  
Valeria Olkhovskaya
Keyword(s):  
Hard Water ◽  
Component Composition ◽  
High Viscosity ◽  
Oil Fields ◽  
Nonlinear Dependence ◽  
Fractional Flow ◽  
Two Phase ◽  
Oil Flow ◽  
High Viscosity Oil

The article offers a method to solve Buckley-Leverett’s problem, taking into account the nonlinear dependence of the filtration rate of viscoplastic oil on the pressure gradient. This method is based on the transformation of the fractional flow function by introducing in the theory of water drive the equations reflecting the rheological features of the oil flow. The resulting model allows us to quantify the influence of rheological factors on the completeness of the water-oil displacement and to calculate the performance, taking into account the component composition of the hydrocarbon phases. Taking the Samara Region oil fields as an example, the article shows that the quality of design is unsatisfactory when the bundled software being used does not take into account specific non-Newtonian properties of the high-viscosity oil.

Visual Criteria for Measuring Two-phase Flow Rate in Venturi with Flow Homogenizer

2015 ◽  
Vol 137 (8) ◽  
Author(s):  
Sangho Sohn ◽  
Jaebum Park ◽  
Dong-Wook Oh
Keyword(s):  
Flow Rate ◽  
High Speed ◽  
Two Phase Flow ◽  
Volume Fraction ◽  
Differential Pressure ◽  
Phase Flow ◽  
Two Phase ◽  
3 Dimensional ◽  
Lower Amplitude ◽  
Gas Volume

A simple use of Venturi might be used to measure two-phase flow rate within relatively low GVF(gas volume fraction). Upstream flow entering Venturi can be improved with installed flow homogenizer which is easily fabricated by 3-dimensional printer with multiple holes. Simultaneous measurement between high-speed flow visualization and dynamic differential pressure measurement was made to find visual criteria for two-phase flow rate measurement with different GVF ranged from 0% to 30%. It was observed that the two-phase flow rate can be reliably measured up to 15% of GVF using flow homogenizer. FFT(Fast-Fourier Transform) results proved that the long flow homogenizers (type 2 and 4) showed a lower amplitude of differential pressure (Δp) than the short flow homogenizers (type 1 and 3) respectively. So the optimized flow homogenizer can be useful to measure two-phase flow rate at low GVF.

Flow Characterization in an ESP Pump Using Conductivity Measurements

2014 ◽  
Author(s):  
Sahand Pirouzpanah ◽  
Sujan Reddy Gudigopuram ◽  
Gerald L. Morrison
Keyword(s):  
Volume Fraction ◽  
Petroleum Industry ◽  
Pure Liquid ◽  
Two Phase ◽  
Fluid Mixture ◽  
Air Inlet ◽  
Flow Characterization ◽  
Electrical Submersible Pumps ◽  
Flow Medium ◽  
Gas Volume

Electrical Submersible Pumps (ESPs) are used in upstream petroleum industry for pumping liquid-gas mixtures. The presence of gas in the flow reduces the efficiency of ESPs. To investigate the effect of gas in the flow medium, Electrical Resistance Tomography (ERT) is performed on the two diffuser stages in a three-stage ESP which was manufactured by Baker Hughes Company. In an ERT system, the relative conductivity of the two-phase fluid mixture in comparison with the conductivity of pure liquid is measured which is used to obtain the Gas Volume Fraction (GVF) and mixture concentration. The measured GVF and concentration is used to characterize the flow for different flow rates of water and air, inlet pressures and rotating speeds.

Direct numerical simulation of a turbulent core-annular flow with water-lubricated high viscosity oil in a vertical pipe

2018 ◽  
Vol 849 ◽  
pp. 419-447 ◽  
Author(s):  
Kiyoung Kim ◽  
Haecheon Choi
Keyword(s):  
Numerical Simulation ◽  
Direct Numerical Simulation ◽  
Pipe Flow ◽  
Annular Flow ◽  
Volume Fraction ◽  
Phase Interface ◽  
High Viscosity ◽  
Vertical Pipe ◽  
The Core ◽  
High Viscosity Oil

The characteristics of a turbulent core-annular flow with water-lubricated high viscosity oil in a vertical pipe are investigated using direct numerical simulation, in conjunction with a level-set method to track the phase interface between oil and water. At a given mean wall friction ($Re_{\unicode[STIX]{x1D70F}}=u_{\unicode[STIX]{x1D70F}}R/\unicode[STIX]{x1D708}_{w}=720$, where $u_{\unicode[STIX]{x1D70F}}$ is the friction velocity, $R$ is the pipe radius and $\unicode[STIX]{x1D708}_{w}$ is the kinematic viscosity of water), the total volume flow rate of a core-annular flow is similar to that of a turbulent single-phase pipe flow of water, indicating that water lubrication is an effective tool to transport high viscosity oil in a pipe. The high viscosity oil flow in the core region is almost a plug flow due to its high viscosity, and the water flow in the annular region is turbulent except for the case of large oil volume fraction (e.g. 0.91 in the present study). With decreasing oil volume fraction, the mean velocity profile in the annulus becomes more like that of turbulent pipe flow, but the streamwise evolution of vortical structures is obstructed by the phase interface wave. In a reference frame moving with the core velocity, water is observed to be trapped inside the wave valley in the annulus, and only a small amount of water runs through the wave crest. The phase interface of the core-annular flow consists of different streamwise and azimuthal wavenumber components for different oil holdups. The azimuthal wavenumber spectra of the phase interface amplitude have largest power at the smallest wavenumber whose corresponding wavelength is the pipe circumference, while the streamwise wavenumber having the largest power decreases with decreasing oil volume fraction. The overall convection velocity of the phase interface is slightly lower than the core velocity. Finally, we suggest a predictive oil holdup model by defining the displacement thickness in the annulus and considering the boundary layer characteristics of water flow. This model predicts the variation of the oil holdup with the superficial velocity ratio very well.

A combined 2-D/1-D magma ascent model of explosive volcanic eruptions

2019 ◽  
Vol 219 (3) ◽  
pp. 1818-1835
Author(s):  
Hélène Massol
Keyword(s):  
Volume Fraction ◽  
Experimental Studies ◽  
Volcanic Eruptions ◽  
Gas Content ◽  
Magma Ascent ◽  
Explosive Eruptions ◽  
Shear Stresses ◽  
Order Of Magnitude ◽  
Gas Volume Fraction ◽  
Gas Volume

SUMMARY Explosive eruptions involve the fragmentation of magma that changes the flow regime from laminar to turbulent within the volcanic conduit during ascent. If the gas volume fraction is high, magma fragments and the eruption style is explosive, but if not, the magma flows effusively out of the vent. Gas escape processes depend on how the magma can rupture, and recent experimental studies measured rupture stress thresholds of the order of a few megapascals. It is thus critical to model the gas content and state of stress evolution in the flowing magma within the conduit. We present a new self-consistent model of an explosive eruption from the magma chamber to the surface, based on a critical gas volume fraction. Our model allows to explore irregular geometries below the fragmentation level (2-D). We first compare our model with classical 1-D models of explosive eruptions and find that in the case of straight conduits and fragmented flows, 1-D models are accurate enough to model the gas pressure and vertical velocity distribution in the conduit. However, in the case of an irregular conduit shape at depth, 2-D models are necessary. Despite a certain conduit radius visible at the surface, very different stress fields within the flow could be present depending upon the position and shape of any conduit irregularities. Stresses of the order of more than 1 MPa can be attained in some locations. High tensile stresses are located at the centre of the conduit, while high shear stresses are located at the conduit walls leading to several potential rupture locations. Due to the interplay between the velocity field and decompression rate, similar conduit radius visible at the surface might also lead to very different fragmentation depths with a difference of more than 1500 m between an enlarged conduit shape at some depth and a straight conduit. At depth, different conduit sizes might lead to the same order of magnitude for the mass flux, depending on the conduit geometry.

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