Abstract:The availability of accurate data is fundamental for several monitoring and control applications of modern power grids. Nevertheless, the knowledge of critical data such as transmission line and transformer parameters is often affected by uncertainty. This can lead to important problems in the correct management of the power systems. In spite of a monitoring infrastructure that is being renewed thanks to new generation devices providing synchronized measurements, the actual values of line parameters and tap ch… Show more
“…Thus, the DSSE used in this paper runs with measurements of node voltage and current injection. Branch currents, together with node voltage measurements, are instead used for the line parameters estimation method as presented in [40], [41]. Operators can apply such a method, in quasi-steady-state conditions, both online or offline depending on the needs, to periodically update the estimates of line parameters and systematic errors of the measurement chain.…”
Grid management undoubtedly benefits from an accurate monitoring of actual network operating conditions. Such monitoring can be obtained starting from a widespread presence of measurement points and different types of estimation techniques. To exploit all the possible measurements present on the network, data coming from the protection systems can be considered in addition to those from the measurement systems. In this scenario, however, accuracy should not be underestimated, because in the presence of dynamic signals it can be dramatically reduced. In this context, this paper presents an improved fault detection and location method based on synchronized measurements, estimation techniques and an appropriate accuracy modeling aimed at reducing the uncertainty in the fault analysis. The proposed approach is validated by simulations carried out by means of a Digital Real Time Simulator (DRTS) on the threephase CIGRE European Medium Voltage distribution network.
“…Thus, the DSSE used in this paper runs with measurements of node voltage and current injection. Branch currents, together with node voltage measurements, are instead used for the line parameters estimation method as presented in [40], [41]. Operators can apply such a method, in quasi-steady-state conditions, both online or offline depending on the needs, to periodically update the estimates of line parameters and systematic errors of the measurement chain.…”
Grid management undoubtedly benefits from an accurate monitoring of actual network operating conditions. Such monitoring can be obtained starting from a widespread presence of measurement points and different types of estimation techniques. To exploit all the possible measurements present on the network, data coming from the protection systems can be considered in addition to those from the measurement systems. In this scenario, however, accuracy should not be underestimated, because in the presence of dynamic signals it can be dramatically reduced. In this context, this paper presents an improved fault detection and location method based on synchronized measurements, estimation techniques and an appropriate accuracy modeling aimed at reducing the uncertainty in the fault analysis. The proposed approach is validated by simulations carried out by means of a Digital Real Time Simulator (DRTS) on the threephase CIGRE European Medium Voltage distribution network.
“…These synchrophasor measurements are referred to the same time instant t, i.e an UTC (Coordinated Universal Time) timestamp. The π-models of transmission lines and transformers, like in [16], allow the definition of a measurement model that links synchrophasor measurements to the magnitude and phase-angle measurement errors and to line parameters deviations from their nominal (or available) values. Thanks to this model, it is possible to express each synchrophasor measurement as function of its reference value (indicated in this paper with superscript R ) and all associated measurement errors as follows:…”
Section: A Tap-changing Transformer and Measurement Uncertainty Modelsmentioning
confidence: 99%
“…where β sr and τ sr are the unknowns relative deviations from the nominal transformer reactance and tap ratio, while X 0 sr and a 0 sr are the associated nominal (or available) values. Like in [16], tap changer ratios are here considered uncertain because they cannot be known exactly.…”
Section: A Tap-changing Transformer and Measurement Uncertainty Modelsmentioning
confidence: 99%
“…The proposed methodology is inspired by the outcomes of [15] and [16], where a traditional model of the tap-changing transformer was applied, and therefore the simultaneous estimation of systematic measurement errors along with the parameters associated with π-models of transmission lines and tap-changing transformers is conducted: both the systematic and random errors of the measurement chain affecting synchronized measurements in modern power systems are appropriately modelled and taken into account. With respect to [15] and [16], the more general model of tap-changing transformer is now introduced in the estimation framework, which is therefore completely redesigned relying on new constraints among the measurements and the quantities to estimate.…”
A primary requirement for the transmission system operator is an accurate knowledge of grid parameters. Moreover, the availability of effective and accurate monitoring tools allows the proper operation of power transmission grids. However, in spite of the now widespread possibility of having monitoring systems based on synchronized measurements, the monitoring applications can be affected not only by the inevitable uncertainty sources but also by the simplified or incomplete modelling of the network components. For this reason, the impact on power system monitoring and control applications of tap-changing transformer models is a key point. In this scenario, this paper presents a method to estimate simultaneously line parameters, tap changer ratios and systematic measurement errors associated with the instrument transformers. The method exploits a flexible model of the tap-changing transformer based on a parameter representing the ratio between the two winding impedances of the transformer. The proposal is based also on the suitable modelling of the measurement chain and on the constraints introduced by the equations of involved transmissions lines and transformers. The validation has been carried out by means of tests performed on the IEEE 14 Bus Test Case.INDEX TERMS phasor measurement units (PMUs), power transmission lines, tap changers, instrument transformers, parameter estimation, voltage measurement, current measurement, measurement errors.
“…Reference [9] mentioned the problem of data loss caused by PMUs and reference [10] showed a method of using PMUs' synchronous measurement data to determine the uncertainty bounds of transmission lines. Reference [11] designed a PMU-based robust state estimation method for real-time monitoring of a power system under different operational conditions, and reference [12] constructed a Kalman filter approach to power system state estimation based on PMUs. The real-time assessment of STVS is based on the dynamic information collected by PMUs after the power system experiences disturbances, and the power system will trigger emergency control in a timely manner when an unstable state is predicted.…”
To fully learn the latent temporal dependencies from post-disturbance system dynamic trajectories, deep learning is utilized for short-term voltage stability (STVS) assessment of power systems in this paper. First of all, a semi-supervised cluster algorithm is performed to obtain class labels of STVS instances due to the unavailability of reliable quantitative criteria. Secondly, a long short-term memory (LSTM) based assessment model is built through learning the time dependencies from the post-disturbance system dynamics. Finally, the trained assessment model is employed to determine the systems stability status in real time. The test results on the IEEE 39-bus system suggest that the proposed approach manages to assess the stability status of the system accurately and timely. Furthermore, the superiority of the proposed method over traditional shallow learning-based assessment methods has also been proved.
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