Generation and Demand data from the Trading Operations Report

Glossary

The page below details highlighted Generation and Demand data from the previous month. This data is acquired from BSC Agents and inputted to the Trading Operation Monitoring Analysis System (TOMAS) database.

To expand the graphs featured on the page, tap the double-headed arrow in the bottom right corner of the graph.

Generation 

Sum of CVA Generation by fuel type per settlement date

BM Units that are registered in the Central Volume Allocation arrangements rather than through the Supplier Volume Allocation Arrangements have their metered data collected centrally by the Central Data Collection Agent. A single fuel type is assigned to each BM Unit and the sum of metered volume by fuel type is displayed by Settlement Day.

Highlights

CVA generation in January 2021:

  • Gas: 44%
  • Wind: 18%
  • Nuclear: 17%
  • Interconnectors: 9% 

The highest daily total generation for all fuel types was 912GWh on 7 December 2020.

Sum of CVA wind generation per settlement date

The graph below displays the wind generation that is registered in CVA only. The sum of metered volume is displayed by Settlement Day. GB wind generation can be registered in the Central Volume Allocation (CVA) arrangements, the Supplier Volume Allocation Arrangements or may not register at all. 

Highlights

On 21 January 2021, CVA Wind generation was 266GWh – accounting for 34% of all CVA generation on that day.

Minimum GSP Group Take based on SF run

The aim of the charts is to provide timely notification of any GSP Group that could become a net exporting GSP Group. The concern is that the underlying rules in the BSC implicitly assume that GSP Groups will import energy. Any deviation from this assumption results in the rules becoming unstable.

This chart provides a plot of the minimum value of GSP Group Take, (i.e. consumption) at the (Initial Settlement) SF run for each of the GSP Groups in each Settlement Day over the last 3 months. A negative GSP Group Take means the GSP Group is a net exporter.  

Highlights

In February 2021, North Scotland GSP Group continued to be the only net exporter; of the 24 days of data available, North Scotland GSP Group was a net exporter for 17 of those days.

Maximum GSP Group metered volume supplied by SVA registered embedded generation for each GSP Group

The aim of this graph is to show the total volume of embedded generation. This chart shows the daily sum of the SVA Registered Embedded Generation volume for each GSP Group.

Highlights

Maximum embedded generation dropped in 7 out of 14 GSP regions in February 2021. The largest drop was in the North Scotland GSP Group, where maximum embedded generation metered volumes dropped from 34GWh in January 2021 to 28GWh in February 2021. This is was lowest figure in the region since July 2020 (25GWh). The largest increase in Maximum embedded generation was in the Merseyside and Northern Wales GSP Group, where maximum embedded generation metered volumes increased from 15GWh in January 2021 to 17GWh in February 2021.

Demand

Annual Demand Ratio Values based on Settlement Run Type R2 or later

The chart below shows the ADR values for each GSP Group on a daily basis. ADR values have been calculated for the year ending on the dates indicated. To achieve the best trade-off between up to date information and accuracy the chart is based on Second Reconciliation (R2) Settlement Run data or from later Settlement Runs if these are available. Trends in the pattern of ADR may indicate issues with metering data within the GSP Groups.

Highlights

The ADR graph shows three regions beyond the threshold variation of +/- 1.5%: Eastern (_A), South Wales (_K), and Yorkshire (_M).  

Regarding the ADR for Eastern, Elexon can confirm that the GSP metering fault that we feel accounts for the continued ADR drop has been fixed. We therefore expect that the ADR will gradually rise to normal levels, as the data enters into Settlement through the Settlement Runs.  

On the upward trend for the ADR in both South Wales and Yorkshire, investigation is still ongoing.  Elexon will continue to update industry, and the relevant Elexon committees, on a regular basis, with feedback from committees taken into account in our investigations.  

About Annual Demand Ratio

Annual Demand Ratio provides a high-level understanding of the overall performance of the Non Half Hourly (NHH) Supplier Volume Allocation (SVA) market and identifies any significant under-/over-accounting of energy. Whilst the theoretical ‘ideal’ value of ADR is 1, variations of +/- 1.5% are to be expected due to inaccuracies in line loss estimates and a small usage of estimates at Final Reconciliation (RF) run. Values of less than 1 may result from the over-accounting of import energy in SVA, the under-accounting of export energy in SVA or under-accounting of Grid Supply Point (GSP) metering. Values of greater than 1 may result from the under-accounting of import energy in SVA, the over-accounting of export energy in SVA or over-accounting of GSP metering.

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