Abstract
The generation management concept for non-interconnected island (NII) systems is traditionally based on simple, semi-empirical operating rules dating back to the era before the massive deployment of renewable energy sources (RES), which do not achieve maximum RES penetration, optimal dispatch of thermal units and satisfaction of system security criteria. Nowadays, more advanced unit commitment (UC) and economic-dispatch (ED) approaches based on optimization techniques are gradually introduced to safeguard system operation against severe disturbances, to prioritize RES participation and to optimize dispatch of the thermal generation fleet. The main objective of this paper is to comparatively assess the traditionally applied priority listing (PL) UC method and a more sophisticated mixed integer linear programming (MILP) UC optimization approach, dedicated to NII power systems. Additionally, to facilitate the comparison of the UC approaches and quantify their impact on systems security, a first attempt is made to relate the primary reserves capability of each unit to the maximum acceptable frequency deviation at steady state conditions after a severe disturbance and the droop characteristic of the unit’s speed governor. The fundamental differences between the two approaches are presented and discussed, while daily and annual simulations are performed and the results obtained are further analyzed.
Highlights
Isolated island grids are power systems present particular characteristics compared to larger, robust continental power systems
Results obtained from the application of priority listing (PL)- and mixed integer linear programming (MILP)-unit commitment (UC) methods to the medium-sized island
UC is performed without wind forecasting, to avoid changes in commitment patterns due to the substitution performed without wind forecasting, to avoid changes in commitment patterns due to the of thermal by wind production
Summary
Isolated island grids are power systems present particular characteristics compared to larger, robust continental power systems They are generally systems of limited size (with peak demand typically not exceeding some hundreds of MWs for the largest of them [1,2]) and low inertia, lacking interconnections to large mainland grids, being vulnerable to disturbances, such as the unexpected loss of generation, be it thermal or RES units [3,4]. The generation management practices currently applied in many NII systems are based predominantly on traditional dispatch methods that come from the era before the massive development of renewables [11,12].
Sign-in/Register to view highlights & summary Sign-in/Register to access full text options 
Free) 
Talk to us
Join us for a 30 min session where you can share your feedback and ask us any queries you have
Schedule a call
