| Active network elements in Core flow-based market coupling during the evening peaks – July to September 2024 |
Figure 09 |
ACER calculation based on JAO Publication Tool data |
|
| Actual activation of curative remedial actions in Core capacity calculation per Core TSO – 2023 to 2025 |
Figure 28 |
ACER calculation based on JAO Publication Tool |
|
| Adoption of time-varying retail contracts among households across the EU and Norway – 2024 (% of total household consumers) |
Figure 33 |
ACER calculation based on NRA data |
|
| Average allowable temporary increase of Fmax and number of CNEs affected by curative remedial actions per Core TSO – 2025 (% over permanent thermal limit) |
Figure 29 |
ACER calculation based on JAO Publication Tool |
|
| Average day-ahead prices in selected bidding zones in Central and Southeast Europe at 19:00 CEST – July to September 2024 (EUR/MWh) |
Figure 01 |
ACER calculation based on ENTSO-E Transparency Platform data |
|
| Average hourly day-ahead price and solar generation for Member States in Southeast Europe during summer months – July to September 2020 to 2025 |
Figure 05 |
ACER calculation based on ENTSO-E Transparency Platform data |
|
| Average hourly day-ahead price in a selection of bidding zones in Central and Southeast Europe – July to September 2024 (EUR/MWh) |
Figure 02 |
ACER calculation based on ENTSO-E Transparency Platform data |
|
| Average level of implementation of the 70% requirement in the Core CCR per Member State, considering flows induced by third-country exchanges – 2022 to 2024 |
Figure 22 |
ACER calculation based on TSO data |
|
| Average load and generation pattern in Hungary during summer months of 2024 – July to September 2024 |
Figure 08 |
ACER calculation based on ENTSO-E Transparency Platform data |
|
| Average price spreads in the single day-ahead coupling during peak hours of the summer months of 2024 - July to September 2024 at 19:00 and 20:00 CEST |
Figure 11 |
ACER calculation based on ENTSO-E Transparency Platform |
|
| Comparison between number of distinct Fmax values (logarithmic scale) and relative difference between the lowest and highest Fmax value, per Core CNE - 2025 (%) |
Figure 17 |
ACER calculation based on JAO Publication Tool data |
|
| Comparison of average daily load profile in Southeast Europe during the summer months of 2023, 2024 and 2025 |
Figure 07 |
ACER calculation based on ENTSO-E Transparency Platform data |
|
| Count of instances of day-ahead prices above 400 EUR/MWh in select EU bidding zones, compared with the counterfactual analysis – July to September 2024 |
Figure 24 |
ACER calculation based on Simulation Facility |
|
| Day-ahead net cross-zonal exchanges between the EU and UA, WB6, TR and MD during summer months - July to September 2021 to 2025 (TWh) |
Figure 12 |
ACER calculation based on ENTSO-E Transparency Platform data |
|
| Evolution of installed capacity of selected technologies in Southeast Europe – 2020 to 2025 (GW) |
Figure 04 |
ACER calculation based on ENTSO-E Transparency Platform data |
|
| Example of implementation of dynamic line rating in capacity calculation on network element ‘Hradec - Mirovka’ |
Figure 14 |
ACER calculation based on JAO Publication Tool data |
|
| Impact of ATC extraction from flow-based domains in the Nordic CCR, compared to ATC leftovers prior to the implementation of flow-based market coupling in day-ahead – 2023 to 2024 |
Figure 37 |
ACER calculation based on ENTSO-E Transparency Platform data |
|
| Impact on average Fmax of upgrading the conductor of cross-border line between Belgium and France ‘Avelgem - Avelin’ – 2022 (MW) |
Figure 20 |
ACER calculation based on JAO Publication Tool data |
|
| Minimum requirements for cross-zonal trade in the Core CCR per Member State – 2024 |
Figure 23 |
ACER calculation based on TSO data |
|
| Overview of available non-costly remedial actions in Core capacity calculation per Core TSO based on Core Static Grid Model |
Figure 27 |
ACER calculation based on Core Static Grid Model |
|
| Overview of dynamic line rating use in capacity calculation per Core TSO - 2024 (% of CNEs) |
Figure 16 |
ACER calculation based on JAO Publication Tool data |
|
| Smart meter roll-out across Southeast Europe – 2024 (% of household and non-household consumers) |
Figure 35 |
ACER calculation based on NRA data |
|
| Two-week rolling average of the maximum possible bilateral exchange and price spread on the Austria-Hungary bidding zone border at 19:00 – 2024 |
Figure 10 |
ACER calculation based on JAO Publication Tool and ENSTO-E TP data |
|
| Unavailability of cross-border lines reducing cross-border capacity in the bidding zone border between Austria and Hungary during the summer of 2024 – July to September 2024 |
Figure 32 |
ACER elaboration based on ENTSO-E Transparency Platform |
|
| Uptake of time-of-use network tariffs for the transmission and distribution networks across the EU and Norway in 2024 |
Figure 34 |
ACER calculation based on NRA data |
|
| Usage of dynamic line rating in Core capacity calculation on network elements limiting crosszonal trade - 2024 (EUR/MW) |
Figure 15 |
ACER calculation based on JAO Publication Tool data |
|
| Year-on-year changes in electricity generation in Southeast Europe between the summer of 2023 and 2024, categorised by generation technology |
Figure 06 |
ACER calculation based on ENTSO-E Transparency Platform data |
|
| Yearly changes in installed capacity of selected technologies in Southeast Europe – 2020 to 2025 (GW) |
Figure 03 |
ACER calculation based on ENTSO-E Transparency Platform data |
|