Core CCR: Cooperation of 16 European TSOs to further integrate European Energy Markets
Sixteen TSOs follow a decision of the Agency for the Cooperation of Energy Regulators (ACER) to combine the existing regional initiatives of former Central Eastern Europe and Central Western Europe to the enlarged European Core region (Decision 06/2016 of November 17, 2016). The countries within the Core region are located in the heart of Europe which is why the Core CCR Project has a substantial importance for the further European market integration.
Therefore, the TSOs have confirmed their commitment to realize all CCR-related obligations according to the respective European Commission Network Codes and Guidelines on electricity. The sixteen TSOs continue the development of a common day-ahead flow-based capacity calculation methodology in the Core CCR, project already started in March 2016. In accordance, the TSOs will also design and implement common capacity calculation methodologies for intraday and long-term time-frames. These methods will enable the TSOs to optimize the transmission capacity of the grid by maintaining high level of security of supply. Also, the Core Project will develop a common methodology for coordinated redispatching and countertrading to effectively relieve congestions within the interconnected transmission network.
For an effective cooperation, the TSOs are setting up the Governance structure of the Core CCR and are working on a Roadmap to perform the related tasks.
For reasons of transparency and information, the Core CCR TSOs plan to engage the concerned Market Parties of the Core CCR. These stakeholders are invited to get involved into the discussion and on the status of deliverables via periodic consultative groups. A first stakeholder workshop is planned to be scheduled in Q1 2017.
Please use the Project Webpage or the contact email address below for further information:
[https://www.entsoe.eu/major-projects/network-code-implementation/cacm/core-ccr/Pages/default.aspx Project Webpage]
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Transmission system operators publish first drafts of the Grid Development Plans 2030
* Four-week consultation period for the GDP and O-GDP starts
* Demand for expansion of the electricity transmission network continues to grow
* Grid expansion until 2030 – beyond the projects laid down in the Federal Requirements Plan – will primarily be required in existing routes and the three-phase AC network
On January 31 2017, the four German transmission system operators (TSOs) 50Hertz, Amprion, TenneT and TransnetBW submitted the first drafts of the Grid Development Plan (GDP) 2030 (version 2017) and the Offshore Grid Development Plan (O-GDP) 2030 (version 2017) to the German Federal Network Agency and published them on their website [http://www.netzentwicklungsplan.de www.netzentwicklungsplan.de]. This marks the start of the four-week public consultation period during which the general public is invited to submit its comments about the GDP and the O-GDP, either online, by e-mail or in writing until February 28, 2017. These responses will be taken into consideration for the second drafts of the GDP and the O-GDP.
The scenario framework, as approved by the Federal Network Agency (Bundesnetzagentur, BNetzA) on June 30 2016, is used as a starting point for both the GDP 2030 and the O-GDP 2030. The scenario framework contains a total of four different scenarios: three scenarios for the target year 2030 and one fairly long-term scenario for the target year 2035. The individual scenarios differ from one another by how quickly and how comprehensively the energy transformation to green energy is assumed to proceed, specifically with regards to the energy mix, energy consumption, the penetration of innovative technologies, energy storage technology, and options to improve flexibility.
A large difference in terms of power generation within Germany shows for both target years 2030 and 2035, with surplus generation in Northern Germany and a generation deficit in the south. In the southern German States, between a quarter and half of annual energy demand has to be covered by domestic and foreign imports. In contrast, energy generation in the northern and eastern Federal States exceeds the local demand by factor two. The importance of renewable energies continues to increase: in all scenarios, wind energy (on- and offshore) is the source with the largest share in the electricity mix. Key drivers behind the task of handling energy transmission within Germany are the continuing expansion of renewable energies as well as the strong and central integration of Germany in the European Single market.
'''Optimised combination of direct and alternating current'''
The combined use of direct current (DC) and alternating current (AC) technology as proposed in the GDP 2030 enables the collective optimisation of the transmission network to match the development of supply tasks over time as well as changing future transmission requirements with regard to network stability, economic efficiency and spatial demands.
Using the starting grid as a basis, along with the measures from the Federal Requirements Plan (FRP) 2015, an analysis is carried out in each of the scenarios A 2030, B 2030 and C 2030 looking at the extent to which the transmission requirements exceeding these measures can be represented by additional development of the AC grid in combination with point measures controlling the power flow. The network analyses show that, with regard to the target year 2030, the combination chosen by the TSOs proves to be a generally feasible alternative to constructing additional DC connections. It also represents a reasonable option, both from an economic point of view and with regard to the ‘NOVA principle’ of prioritising network optimisation over development and expansion.
The network analysis shows that the current path for the target year 2030 will begin to reach its limits when looking towards 2035. Within the context of a sustainable and efficient overall concept, additional DC connections amounting to 6 GW in volume, combined with further enhancements of the AC grid, are required in scenario B 2035, going beyond the measures identified in scenario B 2030. This is the result of growing long distance transmission demands from north to south.
The sustainability of the solution applied by the TSOs will be re-examined in the next GDP, which is anticipated to also cover the target years 2030 and 2035. For this reason, the TSOs have marked some of the measures identified for the first time in the GDP 2030 in addition to those in the FRP 2015 as so-called ‘measures not yet worthy of proposal’, as their sustainability is not yet sufficiently discernible. Unlike the other projects and measures of the GDP 2030, these are not enhanced by in-depth descriptions in the appendices and are represented with a different colour in the scenarios’ overview maps.
'''Demand to modify and expand the extra-high voltage network'''
The volume of network development measures required along existing routes (replacing cables or circuit requirements, construction of a more efficient power line along existing routes) and including the starting grid, ranges from between 7,600 km and 8,500 km of line routes depending on the scenario. In all scenarios for the target year 2030, the required level of new power line route expansion is calculated at around 3,800 km; of which approximately 2,600 km are HVDC connection lines and 1,200 km are AC connection lines. This also includes the German share in the direct current connection lines between Germany and Belgium, Denmark, Norway and Sweden with an overland length of approximately 330 km. In each of these scenarios, the transmission capacity of the DC connections within Germany totals 8 GW.
'''Investment costs GDP 2030'''
The investment costs for the network measures are calculated in the GDP on the basis of standardised costs and are of a provisional nature. For the scenarios looking at the target year 2030, the total volume of investments ranges from 34 to 36 billion euro, assuming that the HVDC connection lines DC1 and DC3-5 are to be completely constructed using underground cabling. This includes around six billion euro for the starting grid.
'''Current governmental expansion targets determine expansion of the offshore grid
The current O-GDP 2030 is the fourth and final O-GDP the transmission system operators have presented for public consultation. In the future, it will be replaced by a new instrument (in German: Flächenentwicklungsplan – FEP).
The starting offshore grid forms the basis for network planning in the O-GDP. This grid indicates all offshore connection systems that are assumed as pre-existing at the time of preparing the O-GDP and whose necessity is not subject to further investigation. In the O-GDP 2030, the expansion measures of the offshore starting grid have a total length of approximately 850 km. The amount of investments required totals around four billion euro.
In each of the scenarios A 2030, B 2030 and C 2030, the length of offshore grid expansions is 2,277 km and 3,702 km in scenario
B 2035. The total transmission capacity of these extensions to the offshore grid ranges from 7.4 GW for the target year 2030 to
11.4 GW for the target year 2035.
Overall, including the costs for the offshore starting grid, the total volume of investment is estimated at 16 billion euro until 2030 and
22 billion euro until 2035.
Further information can be found at www.netzentwicklungsplan.de
European transmission system operators to constantly strengthen their cooperation in the management of the interconnected power system
'''European transmission system operators – Amprion (Germany), Elia (Belgium), REE (Spain), RTE (France), Swissgrid (Switzerland), TenneT (Netherlands), Terna (Italy) and TransnetBW (Germany) – improve their cooperation with a view to optimising electricity exchange capacity.'''
To address increasing challenges in managing the security of power system while maximising the benefits for the European electricity market, transmission system operators (TSOs) and regional coordination centres (RSCs) further strengthen their collaboration, as well in their forecast studies as in the daily gestures, to optimize cross-border exchange capacity in each cross-border interconnection, according to system needs and conditions. These procedures are accelerated and coordinated by the RSCs (the main RSCs active in central Europe are currently CORESO and TSCNet).
Modelled on the process used in previous years to underpin security of electricity supply in Switzerland and Belgium, grid operators RTE, Elia, REE, Amprion, Swissgrid, Terna, TenneT and TransnetBW have established a joint action plan to ensure an efficient and harmonized usage of the power system resources. Cross border exchanges resulting from the optimisation of the interconnections, play a key role in ensuring the security supply in countries facing tension on their system. This strengthening cooperation will be particularly useful in case of tensions related to an insufficiency of production in a country.
The reinforced coordination will consist in the following main procedures:
- The European TSOs will be in constant contact through a newly-created catalogue of extraordinary measures: postponement of some maintenance works, end of some temporary safety margins in the new Flow Based process or the increase of the intraday capacity from Switzerland to France. The objective of this enhanced coordination is to optimise electricity exchange capacities between countries, so as to meet the needs of energy suppliers and limit the risk of power cuts when the supply-demand balance in different countries comes under strain at critical days.
- Maintenance works on the transmission lines most heavily impacting on cross-border exchanges have been rescheduled in an optimal way to boost electricity exchange capacity between countries and thus draw maximum benefit from the pooling of European generating facilities.
The deployment of these new measures comes in addition to the existing mutual assistance arrangements between TSOs. The speed with which these supplementary measures are being set up is a further demonstration of the already implemented Regional Security Initiatives effectiveness and the commitment of European TSOs to strengthening cooperation and solidarity mechanisms, particularly during periods marked by challenges to the electricity system.
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