Absolute aggregate sum of UFs |
Figure 32 |
ACER calculations based on ENTSO-E and Vulcanus data |

Average annual DA electricity prices and relative change compared to the previous year in European bidding zones |
Figure 01 |
ACER calculations based on the ENTSO-E’s TP data |

Average oriented UFs, UAFs and LFs in Continental Europe |
Figure 33, 34, 35 |
ACER calculations based on ENTSO-E and Vulcanus data |

Average relative MACZT and percentage of time when 70% is reached for all CNECs in the Core (CWE) region |
Figure 12 |
ACER calculations based on ENTSO-E/TSOs and Nordpool data |

Average relative MACZT and percentage of time when the minimum 70% target is achieved on DC bidding-zone borders |
Figure 11 |
ACER calculations based on ENTSO-E/TSOs and Nordpool data |

Average relative MACZT in the Italy North region, when including or excluding consideration of the Swiss-Italian border |
Figure 14 |
ACER calculations based on ENTSO-E/TSOs and Nordpool data |

Average relative MACZT on selected AC bidding-zone borders in Europe |
Figure 10 |
ACER calculations based on ENTSO-E/TSOs and Nordpool data |

Average size of the FB domain in the economic direction in the Core (CWE) region |
Figure 09 |
ACER calculations based on Core (CWE) TSOs data |

Changes in tradable capacity (NTC) in Europe |
Figure 08 |
ACER calculations based on ENTSO-E, NRAs and NordPool data |

Costs incurred or forecast to finance CMs per unit demand and expressed as a percentage of the yearly average DA price in Europe |
Figure 28 |
ACER calculations based on NRAs data |

DA price convergence in Europe |
Figure 05 |
ACER calculations based on the ENTSO-E’s TP data |

EENS relative to total annual demand, for MSs with approved or operational CMs according to ENTSOE’s MAF |
Figure 30 |
ACER calculations based on ENTSO-E’s MAF 2018 results and dataset |

Estimated social welfare gains still to be obtained from further extending DA market coupling per border |
Figure 25 |
ACER calculations based on ENTSO-E, NRAs and Vulcanus data |

Evolution of annual DA electricity prices in a selection of European markets |
Figure 02 |
ACER calculations based on the ENTSO-E’s TP data |

Evolution of the number of occurrences of negative DA prices and the distribution of these occurrences per bidding zone |
Figure 04 |
ACER calculations based on the ENTSO-E’s TP data |

LOLE for MSs with approved or operational CMs according to ENTSO-E’s MAF |
Figure 29 |
ACER calculations based on ENTSO-E’s MAF 2018 results |

Level of detail and harmonisation of the main features of the approved CCMs |
Figure 20 |
ACER calculations |

Level of detail and harmonisation of the processes for the calculation of DA capacity and ID capacity in the CCMs |
Figure 21 |
ACER calculations |

Monthly DA prices and frequency of full price convergence in the Core (CWE) region |
Figure 06 |
ACER calculations based on the ENTSO-E’s TP data |

NTC averages of both directions on cross-zonal borders, aggregated per CCR |
Figure 07 |
ACER calculations based on ENTSO-E, NRAs and NordPool data |

Occurrence of DA price spikes |
Figure 03 |
ACER calculations based on the ENTSO-E’s TP and PLATTS data |

Share of assessment criteria met by approved CCMs per category |
Figure 18 |
ACER calculations |

Share of total ID-traded volumes according to intra-zonal vs cross-zonal nature of trades in Europe and monthly evolution of the cross-zonal ID-traded volumes for all continuous trading markets |
Figure 26 |
ACER calculations based on Nominated Electricity Market Operators (NEMOs) data |