Quantifying the Aggregate Frequency Response from Wind Generation with Synthetic Inertial Response Capability

Modern variable-speed wind turbines, although decoupled from the system frequency, can respond to significant power imbalances through power electronic controls as synthetic inertial or governor-like droop responses. However, frequency response capabilities from wind power plant cannot be considered a direct replacement for traditional frequency responsive services. Before such capabilities should be incorporated into systems, their most effective implementation should be considered and a methodology for system operation under high synthetic inertia technology penetration should be identified. This paper considers a possible system frequency response requirement from wind generation and investigates issues surrounding quantification and scheduling of the future system resource, taking the combined Ireland and Northern Ireland system as an example. The distribution of local wind speeds, the variation in the response provided by different control structures, as well as the uncertainty associated with the aggregated capability at any one time, and the implications for the development of ancillary service market incentives or grid code requirements are considered. The impact of uncertainty over the aggregate wind response available is assessed and a strategy for the forecasting, management and coordination of such a resource on future power systems is proposed.