The paper presents the description of an integrated approach, which is implemented in a program module and allows predicting scale deposition in well based on distributions of specific multiphase flow parameters (temperature, pressure, and gas content). Parameters are obtained from calculated pump operation regimes. The method's apparent advantages are presented, namely: -automatic input of reservoir water/gas chemical content data, -numerical estimation of scale deposition risk in different well sections by means of the saturation index, -built-in tips on selecting the optimal scale prevention technology specifying the inhibitor type and amount, -prediction of pump life cycle buildup, -estimation of the expected economic benefit caused by scale prevention. The prediction method of scale deposition and the algorithm of selection of the scale prevention technology can be successfully used during analysis of scale deposition risk and planning the activities for scale prevention for a group of oil wells or oilfield. The proposed algorithmic module has been tested in a number of active oil fields of Western Siberia, and has already garnered positive references from production professionals. This module is planned to serve as a basis for similar modules for forecasting risks of mechanical dashes, corrosion and paraffin buildup.
Monitoring and testing of subsurface equipment is crucial when stepping up artificial lift efficiency. Oil production using electrical submersible pumps (ESP) in RN-Purneftegas was initially complicated by a strong gas influence. The main method to increase ESP performance in wells with a high GOR is using rotary gas separators. Subsurface equipment adjustment for high GOR conditions, including gas separator calibration, is of primary importance, due to a strong influence of the ESP design on well performance. To perform the corresponding calculations, appropriate data is necessary. Currently, there are many tools and measurement devices for oil production monitoring and controlling, however, it is impossible to use its data without a good understanding of all the parts of the "reservoir-well-pump" production chain. The artificial lift team formed under Rosneft's New Technology System program conducted a wide range of field tests. The main goal of such tests was gathering information for parameter analysis and proper timing of ESPs with malfunctions in rotary gas separators. The collected information about real field performance was then used for validation of the accuracy of the lab data for gas separator performance, acquired by Russian State Oil&Gas University. It was concluded that the gas separator performance data obtained in laboratory if combined with correlation for natural separation prediction can be used for total separation efficiency estimation. The test results allowed us to estimate the potential for oil production increase at over 700 tons per day in Purneftegas. Importance of separation efficiency for well performance A number of geological and technical factors such as pump performance acquired in lab tests with a single phase fluid (typically water), or well operation history are used in ESP calibration. However, gas separator performance had not been adequately modeled during previous ESP sizing. The separator was treated as an intake module with constant separation efficiency in most cases.
High oil price indeed creates conditions for successful life extension of mature assets. Even old suspended wells could be successfully revived as the watercut threshold for economic production is being changed due to new price situation. Normally, it is uneconomical to build new surface facilities for mature assets, therefore the most critical point for oil production level maximization of such fields is existing infrastructure constrains. The most common constraints are total liquid production and power capacities. These constraints are especially important in case of high watercut wells with medium to high well productivity. The Electrical Submersible Pump is the most widely used artificial lift method for the wells in late development stage. High liquid volume with high watercut leads to considerable power consumption and it turns out pumping equipment as the most significant power consumer. Obviously artificial lift optimization and appropriate management of available power are key enablers for life extension of mature assets. All power consumers in an asset are interconnected; therefore one cannot significantly optimize a field production doing artificial lift system performance optimization for a single well. Valuable optimization only could be achieved using an integrated performance optimization strategy on the whole asset production system and the strategy development is considered in this paper.The paper presents the value maximization methodology for ESPs driven assets, which consists of optimal well production targets identification and equipment selection & sizing strategy. The key idea of the methodology is to break-down field production system into "capacity" consuming components, understand components behavior and efficiency of power consumption by each component redistribute available capacity between components, targeting maximization of oil production under existing constraints. The paper describes in detail the methodology and provides an example of application.
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