Battery energy storage system for primary control reserve and energy arbitrage

Brivio, Claudio; Mandelli, Stefano; Merlo, Marco

doi:10.1016/j.segan.2016.03.004

Cited by 117 publications

(33 citation statements)

References 25 publications

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“…A second approach tries to overcome this by using more formal methods that can ensure optimality within the adopted framework. For instance, in [16], a fuzzy control logic is used for primary frequency control and energy arbitrage in the Italian energy market. Zhang et al [17] use dynamic programming to calculate an optimal recharging policy, recharging only when the frequency is in the deadband.…”

Section: B Related Workmentioning

confidence: 99%

Combined Stochastic Optimization of Frequency Control and Self-Consumption With a Battery

Engels

Claessens

Deconinck

2019

IEEE Trans. Smart Grid

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Optimally combining frequency control with selfconsumption can increase revenues from battery storage systems installed behind-the-meter. This work presents an optimized control strategy that allows a battery to be used simultaneously for self-consumption and primary frequency control. Therein, it addresses two stochastic problems: the delivery of primary frequency control with a battery and the use of the battery for self-consumption.We propose a linear recharging policy to regulate the state of charge of the battery while providing primary frequency control. Formulating this as a chance-constrained problem, we can ensure that the risk of battery constraint violations stays below a predefined probability. We use robust optimization as a safe approximation to the chance-constraints, which allows to make the risk of constraint violation arbitrarily low, while keeping the problem tractable and offering maximum reserve capacity. Simulations with real frequency measurements prove the effectiveness of the designed recharging strategy.We adopt a rule-based policy for self-consumption, which is optimized using stochastic programming. This policy allows to reserve more energy and power of the battery on moments when expected consumption or production is higher, while using other moments for recharging from primary frequency control. We show that optimally combining the two services increases value from batteries significantly.

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Section: B Related Workmentioning

confidence: 99%

Combined Stochastic Optimization of Frequency Control and Self-Consumption With a Battery

Engels

Claessens

Deconinck

2019

IEEE Trans. Smart Grid

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“…Different charging control strategies are proposed in [21], comparing the estimate of battery ageing [22] and maximizing both the service continuity and the BESS profitability [15]. A non-conventional droop-control law was proposed in [23]. Lifetime perspectives of Lithium Iron Phosphate batteries are discussed in [3], whereas [24] evaluates the investment revenue depending on different strategies for the SoC restoration.…”

Section: Bess Integration For Supplying Primary Control Reserve (Pcr)mentioning

confidence: 99%

“…In the Italian market, the PCR revenue is evaluated as a reimbursement depending on the effectively supplied regulating energy, with reference to the market price evolution [23]. The PCR availability forces the generation plants to reduce their effective output from the theoretical primary source availability, at least R times the overall rated power of operating units.…”

Section: Technical-economic Analysismentioning

confidence: 99%

Integration of Lithium-Ion Battery Storage Systems in Hydroelectric Plants for Supplying Primary Control Reserve

et al. 2017

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Abstract:The ever-growing diffusion of renewables as electrical generation sources is forcing the electrical power system to face new and challenging regulation problems to preserve grid stability. Among these, the primary control reserve is reckoned to be one of the most important issues, since the introduction of generators based on renewable energies and interconnected through static converters, if relieved from the primary reserve contribution, reduces both the system inertia and the available power reserve in case of network events involving frequency perturbations. In this scenario, renewable plants such as hydroelectric run-of-river generators could be required to provide the primary control reserve ancillary service. In this paper, the integration between a multi-unit run-of-river power plant and a lithium-ion based battery storage system is investigated, suitably accounting for the ancillary service characteristics as required by present grid codes. The storage system is studied in terms of maximum economic profitability, taking into account its operating constraints. Dynamic simulations are carried out within the DIgSILENT PowerFactory 2016 software environment in order to analyse the plant response in case of network frequency contingencies, comparing the pure hydroelectric plant with the hybrid one, in which the primary reserve is partially or completely supplied by the storage system. Results confirm that the battery storage system response to frequency perturbations is clearly faster and more accurate during the transient phase compared to a traditional plant, since time delays due to hydraulic and mechanical regulations are overpassed. A case study, based on data from an existing hydropower plant and referring to the Italian context in terms of operational constraints and ancillary service remuneration, is presented.

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“…Therefore, the participation in the provision of ancillary services has to be extended to the distributed generators as well. To do so, the adoption of Grid-connected Energy Storage Systems is one of the most suitable solutions to figure out those issues [18,19]. Moreover, providing a greater flexibility on the demand side by the use of the Demand Response (DR) strategy, it is necessary.…”

Section: Introductionmentioning

confidence: 99%

Analysis on the potential of an energy aggregator for domestic users in the Italian electricity system

Santoli

Mancini

Basso

2019

Second International Conference on Material Science, Smart Structures and Applications: Icmss-2019

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This study is focused on the definition of an energy aggregator model for domestic users, offering the Demand Response (DR) optimization and additional services. The research project is based on the Italian electricity system analysis pointing out the renewables high contribution, the poor domestic users' electrification and the need to figure out those issues by a demand flexibility system implementation. Moreover, the characterization of Italian domestic users' energy loads allowed to identify the suitable strategies to get higher flexibility degree. Thus, three case studies have been considered to assess the achievable economic savings due to the DR implementation, accounting for the revenue for dispatching services as well as the intraday energy price variations on the Italian market. It emerged that the demand side flexibility implementation offers benefits to the Italian electricity system but entails small economic benefits for the endusers. Additionally, the adoption of such a system is quite complicated due to the lack of suitable and reliable automation devices. For that reason, a potential energy aggregator for domestic users will have to search funds for its own operation providing customers with additional services, such as energy saving and assisted-living, by using of ICT along with automation within each dwelling.

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Battery energy storage system for primary control reserve and energy arbitrage

Cited by 117 publications

References 25 publications

Combined Stochastic Optimization of Frequency Control and Self-Consumption With a Battery

Combined Stochastic Optimization of Frequency Control and Self-Consumption With a Battery

Integration of Lithium-Ion Battery Storage Systems in Hydroelectric Plants for Supplying Primary Control Reserve

Analysis on the potential of an energy aggregator for domestic users in the Italian electricity system

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