The evaluation of the necessary operating reserve margins in an electric power system has been traditionally carried out by the System Operator (SO) on a deterministic basis, using the so called “first contingency security criterion”. According this approach, only few generating units and/or power lines are considered in order to determine the worst operation conditions. As an alternative, this paper presents a simulation method, based on a probabilistic approach using a sequential Montecarlo technique, which takes into account all the generating units and the transmission power lines of the electric system considered. Starting from the production and consumption profiles scheduled by the energy markets, the real time operation is simulated in normal, contingency and emergency conditions, taking into account the availability of generating units and power lines; the redispatching procedures activated after a contingency are carried out minimizing the expenses for the auxiliary services purchase under line power flow limits constraints. A daily case study, calibrated on an IEEE test grid, is carried out and discussed, focusing how such a technique can be suitably used to evaluate system reliability as a function of reserve margins, load shedding amounts, dispatching rules and emergency procedures.

MonteCarlo procedures for simulating real time contingencies and setting optimal redispatching strategies in multi-area systems

PELACCHI, PAOLO;POLI, DAVIDE
2007

Abstract

The evaluation of the necessary operating reserve margins in an electric power system has been traditionally carried out by the System Operator (SO) on a deterministic basis, using the so called “first contingency security criterion”. According this approach, only few generating units and/or power lines are considered in order to determine the worst operation conditions. As an alternative, this paper presents a simulation method, based on a probabilistic approach using a sequential Montecarlo technique, which takes into account all the generating units and the transmission power lines of the electric system considered. Starting from the production and consumption profiles scheduled by the energy markets, the real time operation is simulated in normal, contingency and emergency conditions, taking into account the availability of generating units and power lines; the redispatching procedures activated after a contingency are carried out minimizing the expenses for the auxiliary services purchase under line power flow limits constraints. A daily case study, calibrated on an IEEE test grid, is carried out and discussed, focusing how such a technique can be suitably used to evaluate system reliability as a function of reserve margins, load shedding amounts, dispatching rules and emergency procedures.
9789944578912
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Utilizza questo identificativo per citare o creare un link a questo documento: https://hdl.handle.net/11568/206266
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