Abstract
Battery energy storage systems (BESSs) offer many desirable services from peak demand lopping/valley filling too fast power response services. These services can be scheduled so they enhance each other; in this manner, the inverter size is effectively leveraged with battery capacity. A variable cost for under-frequency service provision will be required to incentivise this type of operation, and various options are explored in this study. It is demonstrated that BESSs may struggle for profitability under certain service payments; however, returns can be maximised through revenue stacking. In this study, enhanced service provision results in increased power system service provision and returns from energy arbitrage. A 10 and 2 years datasets, containing information on the Irish power system, are used to investigate potential per MW revenue from a BESS with a 1.5 and 2.5 h batteries. Three statistically derived, engineering-based, power system service scalar multipliers are investigated and compared with the scalar being introduced on the Irish system. It is demonstrated that flexible service payments can be increased by more than 10% while receiving arbitrage payments. The seasonal variation in BESS revenue is investigated and observed to be mitigated or exacerbated by service scalars.
Highlights
Many governments have set ambitious renewable energy targets that will stress national and international power systems, forcing them to work in unanticipated ways [1]
If a transmission system operators (TSOs) wanted to encourage a Battery energy storage systems (BESSs) to actively participate in daily system dynamics, a temporal scarcity scalar based on this method could be employed
This paper demonstrated that BESS in Great Britain might struggle for financial viability
Summary
Many governments have set ambitious renewable energy targets that will stress national and international power systems, forcing them to work in unanticipated ways [1]. The same method is being employed for power system services in Great Britain [3] and Ireland [4]; these services should allow the power system to operate securely during times of low inertia, due to high renewable infeed or low demand. If the frequency response time is reduced, potentially BESS could be eligible for a rate of change of frequency (RoCoF) or inertia service [13]; similar to the synchronous inertia service (SIR) described in [4] These types of services should allow significant expansions of renewable energy resources and prevent incidents such as the 2016 blackout in South Australia. It is argued in this paper that SNSP is not the best metric to reflect power system inertia or service availability
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