Flexible transmission expansion planning associated with large-scale wind farms integration considering demand response


With increasing large-scale wind farms being integrated into the power grids, transmission enlargement coming up with (TEP) increasingly needs additional flexibility to account for the intermittency as well as alternative uncertainty factors concerned in the method. In this study, a probabilistic TEP model is proposed for planners to tackle the variability and uncertainty factors related to grid connected wind farms. Both load forecast and wind power output uncertainties are thought-about in the proposed model. Alternative factors thought of in the model embrace the forced outage rates of transmission lines and generators, and the wind speed correlation between wind farms. Moreover, the incentive-based mostly demand response (IBDR) program is introduced as a non-network answer instead of the conventional network enlargement approaches. The utilities can pay IBDR providers for his or her contributions to peak demand reduction. The proposed TEP model can notice the optimal trade-off between transmission investment and demand response expenses. The hierarchical Bender's decomposition algorithm integrated with Monte Carlo simulation is utilized to unravel the proposed model. Case studies are given using the Garver's six-bus system and therefore the IEEE-reliability test system to point out the effectiveness of the tactic.

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