Abstract
Currently, the power transmission system of the Baltic states is synchronized with the Integrated/Unified Power System (IPS/UPS), which includes the Russian grid, and the IPS/UPS provides frequency regulation and system security within the Baltic states. Since joining the European Union (EU) in 2004, the Baltic states have been following the EU’s energy policy targets. The Baltics are presently participating in a European electricity market, i.e., the NordPool market, while they are expected to join the pan-European electricity market—the European target model for power market integration. Moreover, from a power grid perspective, EU energy policies intend to desynchronize the power grid of the Baltic states from the IPS/UPS over the coming years. This paper evaluates these policy trends through market impacts, and it complements existing studies on Baltic-IPS/UPS desynchronization in terms of wholesale electricity prices, generation surpluses, primary reserve adequacy, and redispatch costs. Participation of the Baltic states in the integrated pan-European day-ahead electricity market with zonal pricing was modeled for 2030, followed by a national redispatch, with detailed power grid modeling of Baltic states to solve potential intrazonal congestion. The simulation results imply the superiority of the Baltics’ synchronization to continental Europe, compared to the other schemes.
Highlights
The power system in the Baltic states is currently synchronized with the Integrated/UnifiedPower System (IPS/UPS), including the power grids of Russia and Belarus, through 330 kV high voltage alternating current (HVAC) transmission lines [1]
To preserve the consistency of the FCR in Nordic countries with the primary reserve in CEN countries, this paper focuses on the frequency containment reserve under disturbance (FCR-D).The FCR-D capacity inside the Nordic synchronous area is based on the concept of a dimensioning fault/incident in each control region that is “the fault which entails the loss of individual major components and entails the greatest impact upon the power system from all fault events that have taken into account” [13,17]
Over the summer-peak snapshot in all three desynchronization schemes, the day-ahead market schedules satisfy internal network constraints inside Estonia, Latvia, and Lithuania, and there is no need to redispatch the generation units
Summary
The power system in the Baltic states is currently synchronized with the Integrated/Unified. Regional transmission system operators (TSOs) need to ensure a sound operation of an integrated European market, with respect to internal network constraints, providing that a proper congestion management approach is required to solve potential intrazonal congestions. For the full integration of Baltics’ electricity system into the EU power market, desynchronization from the IPS/UPS and synchronization with the power systems of the Union is required by EU energy policy [9]. The three scenarios were analyzed under the pan-European electricity market (including the Baltics) following the desynchronization from the IPS/UPS and under possible alternative schemes for the interconnections with the EU network. Along with the other 31 European countries, are modeled in the day-ahead integrated electricity market through the zonal pricing approach.
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