System Operation Guideline (SOGL)
Principal objectives and contents
Commission Regulation (EU) 2017/1485 establishing a guideline on electricity transmission system operation (System Operation Guideline, SOGL) entered into force on 14 September 2017.
The SOGL aims to establish harmonised rules on system operation for transmission system operators (TSOs), distribution system operators (DSOs) and significant grid users (SGUs). This is to:
provide a clear legal framework for system operation;
ensure system security;
ensure the availability and exchange of necessary data and information between TSOs and between TSOs and all other stakeholders;
facilitate the integration of renewable energy sources;
facilitate Union-wide trade in electricity; and thus increase competition, for the benefit of consumers
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Submission of master data and metered values of significant grid users in accordance with the SOGL Data Exchange Regulation (SOGL Datenaustausch-V) from 1 December 2021
Link to the SOGL Data Exchange Regulation: https://www.ris.bka.gv.at/Dokumente/BgblAuth/BGBLA_2021_II_316/BGBLA_2021_II_316.html
Significant electricity generation facilities (or significant grid users, SGUs) are required to submit the relevant data to the transmission system operator (TSO), the connecting grid operator and the grid operator (GO) upstream of the connecting grid operator from 1 December 2021 in accordance with the paragraphs cited below from the SOGL Data Exchange Regulation. The SGU operator can make use of third parties to fulfil this obligation. Provided that the connecting GO receives this data to the necessary extent, this arrangement should also ease the burden on the affected SGUs. This is because the relevant connecting GO has to submit the affected data directly to the upstream GO, which in turn has to submit the data to its upstream GO and so on, until it reaches the TSO. The data is thus passed on in a cascade (step by step in a chain) to each GO that is a legitimate recipient in accordance with the SOGL Data Exchange Regulation. The operator of the relevant SGU has a duty to cooperate in ensuring that the connecting GO receives the data listed below from the facility:
- Master data in accordance with Section 5 SOGL Data Exchange Regulation
Master data is transmitted by the GO as described above. The template to be used has been supplied by the TSO to the GOs and can be requested again by the TSO at any time. The data must be transmitted by e-mail in CSV format (values separated by a semicolon, one row per metering point).
- Metered values in accordance with Section 10 SOGL Data Exchange Regulation
Contrary to expectations, some ongoing technical and regulatory work still needs to be completed before the planned transmission of metered values in a secure, encrypted and automatically processable form can proceed via the energy industry data exchange system (EDA platform).
A temporary solution is therefore required until the aforementioned work is completed. Consequently, grid operators are asked to transmit metered values (as described above) in MSCONS format by e-mail to email@example.com.
If historical generation data in accordance with Section 10(2) SOGL Data Exchange Regulation cannot be sent by e-mail (for instance due to size restrictions) or if an alternative method of transmission is preferred, you can inform APG by e-mailing firstname.lastname@example.org. You will then be contacted regarding a secure means of transmission.
This procedure will be reproduced in the Electricity Market Code in cooperation with E-Control.
Implementation of SOGL Data Exchange Regulation from 1 July 2022
In accordance with Sections 6, 7 and 9 SOGL Data Exchange Regulation, SGU schedules/periods of unavailability and SGU real-time data must be submitted to grid operators from 1 July 2022. The detailed provisions needed for this to happen are complex and have been discussed in depth over recent months. Due to the number of elements and the scope involved, these rules are still being finalised and will be consulted upon and published by E-Control in the near future. Following their publication, it will then be possible for the entire industry to implement the rules in an orderly and legally compliant manner.
From 1 July 2022 onwards, the existing data exchange obligations (in accordance with the Schedules chapter version 6.4 in the Electricity Market Code) will still be applicable and will then be extended gradually after the updated rules have been published. The staged plan needed to implement the entire scope of data in accordance with the SOGL Data Exchange Regulation will be further coordinated among all relevant parties and updates on its implementation will be submitted to E-Control as evidence in the form of regular reports.
Due to the large amount of implementation work incumbent on market participants, arising primarily from the requirement to produce detailed generation schedules at a metering point level for numerous SGUs from 1 July 2022, the burden on the industry is due to be temporarily eased over an appropriate transitional period. APG agrees that, until the requirements to supply data in the case of market partners under Section 7(1) SOGL Data Exchange Regulation have been fully implemented, it will produce generation schedules for run-of-river power plants with Pmax up to 25 MW and for photovoltaic plants with Pmax up to 5 MW – even if these do not correspond to the SGUs excluded under Section 7(2) SOGL Data Exchange Regulation – and will prepare such schedules internally at APG based on the supply and the estimated impact of altered feed-in behaviour on market price changes. Existing data supply arrangements will remain unchanged. For smaller SGUs (Pmax up to 5 MW), periods of unavailability can only be notified in accordance with Section 6(1) SOGL Data Exchange Regulation by indicating “connected” or “not connected”. However, these notifications must be submitted in ESS format in accordance with the Schedules chapter in the Electricity Market Code. Therefore, when the plant is “not connected”, the value “99999” must be entered for the affected hours in the separate time series for the availability status; when the plant is (once again) “connected”, the value is “0”.
Until the requirements for schedule submission are fully implemented, particularly in the case of wind power plants where there is market price-induced curtailment, APG must receive information via a brief telephone call to APG/the main control room on +43 50320 53251 no later than 15 minutes before action is taken if the resulting deviation from the planned or supplied feed-in is more than 50 MW. During the call, the supplier will report the maximum curtailment in MW of its wind portfolio in the affected time span. APG must be notified again by telephone if the maximum curtailment subsequently increases. Furthermore, APG must be informed immediately by telephone if the supplier has wind turbines amounting to 25 MW of installed capacity in its portfolio that will be unavailable to feed in electricity for more than three hours (e.g. in the event of a shutdown due to icing). The supplier will also immediately provide APG with a list of the affected metering points if requested.