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Statistics

Updated: . Based on 30 seconds aggregation (PRC activation)

15 Minutes

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1 Hour

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Primary Control Reserve

Grid-Time corrections may cause base frequency to be lifted by +/- 10 Mhz

Last Action
On Frequency
Base Frequency

Recovery Momentum

Grid ability to recover from a low/high frequency. Peaks indicate an incident that got balanced by regulation energy.

Open Investigations

DateOffgrid CapacityTypeRoot Cause
07/22 22:00 283MW Steinkohle NA03
05/03 16:00 475MW Erdgas Array
05/02 03:37 200MW Steinkohle Array
05/02 03:30 875MW Steinkohle Array
05/02 03:30 445MW Steinkohle Array
05/02 02:30 757MW Steinkohle Array
05/02 01:15 607.5MW Erdgas Array
05/01 22:00 377.8MW Erdgas Array
04/30 23:15 622MW Steinkohle Array
04/30 23:15 846MW Erdgas Array

Frequency Moving Average

Use zoom buttons for a more detailed view. Regular updates every hour. Sampling Rate: n=1 Minute.

Operators Handbook Notes (ENTSOe)

Observation Incident Size for System Response Analysis. Large incidents, such as the sudden loss of generation or load, that exceed 600 MW (first level) respectively 1000 MW (second level) in the SYNCHRONOUS AREA, trigger a response analysis procedure. .

For FREQUENCY CONTROL, the quasi steady-state security margin is defined to be 20 mHz

The maximum dynamic FREQUENCY DEVIATION of ±800 mHz includes a safety margin. This margin of 200 mHz in total is intended to cover the following influences and elements of uncertainty:

  • Possible stationary FREQUENCY DEVIATION before an incident (50 mHz)
  • Insensitivity of turbine controller (20 mHz)
  • Other elements of uncertainty in the model (approximately 10 %, 80 mHz)