Summary One of the main problems regarding the use of the artificial-lift method of electrical-submersible-pump (ESP) systems is the presence of gas in the pump. This paper presents and describes an analysis of ESP systems with a stage-by-stage calculation to determine intake and discharge pressures to adjust total dynamic head (TDH) for each stage of the pump. The modeling was designed to acknowledge free gas in the pump, and iterative calculations are applied to recalculate, for each stage, fluid characteristics and physical properties, such as viscosity, density, formation volume factor (FVF), surface tension, solubility ratio, gas/oil ratio (GOR), and other flow characteristics along the tubing, such as temperature and pressure. Developed modeling validation was achieved by comparisons in two scenarios. In the first one, fixed values of intake pressure and changeable values of GOR were used to assess gas effect. In the tests for the second scenario, fixed values of GOR and changeable values of intake pressure were used. Necessary research was conducted through a developed computational tool used to size ESP components. The results were different from those obtained with the usual calculations, and it may be implied that the developed modeling is more accurate to determine parameters related to this artificial-lift method. Also, the results were more consistent and closer to the actual behavior of multiphase-flow phenomena within the tubing because each stage has its characteristics individually evaluated. These observations may have an effect on the number of pump stages and influence in choosing the adequate equipment of the system.
Estimation of temperature effects on wells with artificial lift by Electric Submersible Pump (ESP) is necessary because heat transfer may interfere with fluid characteristics, motor behavior, cables and pump, affecting the whole system. This work presents and describes a computational model of heat transfer in ESP systems for multiphase flow in deviated wells. The methodology adopted in this work considered geothermal gradient and the heat transfer between motor and production fluids. The geothermal gradient represents how temperature increases inside the well as the true vertical depth increases. For deviated wells, the well is divided by sections and temperature increase at each section is calculated as a function of its true vertical depth and the geothermal gradient. In the transfer of heat between motor and production fluids, calculated changes in motor and fluid temperature occur mostly by forced convection on account of high flow rates available in this artificial lift method. The computational model was implemented in a program developed to simulate ESP system behavior. To validate developed modeling, results obtained through simulation of vertical wells were compared with field data obtained from wells equipped with bottom-hole sensors. These comparisons showed that calculated temperature values were similar to those obtained from a field data, implying satisfactory results. Deviated wells with ESP system were simulated and the results were also evaluated. Therefore, through analysis of the obtained results for thermal calculation in ESP systems, it is possible to verify if the equipment are working according to their specification, especially those related to the electrical system such as cable and motor. In order to increase the ESP system efficiency, the results obtained through this work are useful for the development of studies focused on reducing harmful effects caused by the high temperatures present in this artificial lift method.
One of the main problems regarding the use of artificial lift method by Electric Submersible Pump (ESP) systems is the presence of gas in the pump. This paper presents and describes an analysis of ESP systems using a stage by stage calculation to determine intake and discharge pressures to adjust total dynamic head (TDH) for each stage of the pump.The modeling was designed acknowledging free gas in the pump and iterative calculations are applied to recalculate, for each stage, fluid characteristics and physical properties, such as viscosity, density, formation volume factor, surface tension, solubility ratio, oil-gas ratio (OGR), and other flow characteristics along the tubing, like temperature and pressure. Developed modeling validation was achieved by comparisons in two scenarios. In the first one, fixed values of intake pressure and changeable values of GOR were used to assess gas effect. In the tests for the second scenario, fixed values of OGR and changeable values of intake pressure were used.Necessary research was done through a developed computational tool used to size ESP components. The results were different from those obtained with usual calculations and it may be implied that the developed modeling is more accurate to determine parameters related to this artificial method. Also, the results were more consistent and closer to the actual behavior of multiphase flow phenomena within the tubing because each stage has its characteristics individually evaluated. These observations may have effect on the number of pump stages and influence in choosing the adequate equipment of the system.
This paper presents a computational sizing tool for artificial lift by Electric Submersible Pump (ESP), considering well mechanical scheme, reservoir, fluid properties, and production data as input. This tool provides data to the user about pump types, motor, seal, cables, and auxiliary equipment for proper performance. The developed program exhibits graphs and alarms, which may help the user, while sizing the system. Also, it contains an extensive database with information about equipment used in the petroleum industry. Results from this developed tool were compared with those from a commercial program used in the industry, obtaining coherent and satisfactory results.
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