Communication Breakdown

It is well known that EDF has a majority presence in the electricity generation in France. More specifically, EDF is the only player which produces nuclear-based electricity, which accounts for more than 70% of the French power mix. The production fluctuations of the French nuclear fleet immediately translate into price variations on the electricity futures market, which ultimately have a significant impact on end-customers’ bills.

Under the European REMIT regulation on the integrity and transparency of wholesale energy markets, market participants must publish all information relating to the capacity and use of their production facilities, including planned or unplanned unavailability of these facilities. EDF does so with the necessary frequency. However, the interpretation of such announced unavailability incidents is not necessarily obvious.

For its part, RTE, in its role as guarantor of the stability of the French electricity system, regularly issues supply/demand balance studies or even warnings and recommendations when it considers that there are risks to the system. RTE and EDF do not always seem to agree on their vision of the future availability of the nuclear fleet. EDF tends to be much more optimistic than what the facts show, while RTE takes a more conservative position.

It is for this reason that, at HES, we closely follow the different announcements made regarding unavailability and system balance studies to be able to assess their real impact on electricity futures prices. In this article we shall focus on the various events and discrepancies between the declarations and announcements made around the French nuclear fleet and their effects on the markets, with special attention of the very peculiar COVID 2020 year. Enjoy your reading!

As was the case with everyone else, the health crisis took EDF completely by surprise in early 2020. The restrictive measures taken in March 2020 to avoid the collapse of the sanitary system and ensure the safety of workers slowed down the planned maintenance activities of EDF´s nuclear fleet, delaying those that were already underway and forcing the utility to readapt its maintenance plan so as to adjust production capacity as much as possible. As a result, in April 2020, EDF forecasted a production of 300 TWh for 2020, compared to the 375 – 390 TWh initially estimated. This was a consequence of the rescheduling of its maintenance plan with the aim of securing electricity supply during the winter season. To this end, among other measures, the operation of power plants during the summer period was reduced to save fuel for the winter. At the same time, RTE published a report forecasting the impact of the health crisis on the electricity system, without issuing any warnings of any specific danger.

The impact of EDF’s announcement was significant, with an increase of +15% in the price of the French Q4 2020 baseload contract (from 45.25 €/MWh to 53.63 €/MWh) and +10% for its equivalent Q1 2021 contract (from 47.74 €/MWh to 52.52 €/MWh)[1]. At that point, the capacity market did not seem to echo these disturbances: the certified nuclear capacity for AL-2020 was over 50 GW at the beginning of April, aligned with the certified AL-2020 capacity in 2019 and, for the April auction for AL-2021, prices remained in line with the recent trend.

HES team observed a reduction in the average nuclear availability if compared to the beginning of the year view of -17.5 GW (-33%) for the months of July to October 2020, and of -7.5 MW (-13%) for the months of November 2020 to February 2021[2]. This was in line with the announcements made both by EDF and RTE, although not with the certified capacity for 2020.

It was not until after the ‘first wave’, in June 2020, that RTE published a forecast of electricity supply risk for the 2020/2021 winter period, placing supply under ‘special surveillance’. In this report, a delay in the return to operation of nuclear reactors undergoing maintenance is mentioned as one of the main risk factors. In addition, in another report published around that time, RTE points to a shortfall of capacity certifications in the range of 4.6 and 7.9 GW – which greatly impacted the price of certification imbalances for the AL2020 product.

This time, the impact on electricity futures markets was minor, with just a slight increase in prices. However, it was in the capacity auctions where RTE’s pessimistic forecasts were clearly reflected: 2020 capacity certificates, which had traded up until then at an average price of 19.5 k€/MW, reached 45 k€/MW, and their equivalent 2021 certificates have reached 47 k€/MW compared to 19.2 k€/MW of the previous auction. As a reminder, certifications are normally made on the basis of operating forecasts for specific periods: for AL-2020, at that time, specifically in November and December.

At that point in time, the observed availability of the nuclear fleet was considerably higher than that observed in April. For example, the availability forecasted for December 2020 was more than 57 GW in June compared to 46.7 GW forecasted in April. However, this increase of +24% was not mentioned in the report published by RTE, which forecasted an average nuclear availability for December 2020 in the range of 43 and 50 GW.

What was the reason for this disparity in numbers? It seems that RTE did not share EDF’s optimistic view on the availability of its nuclear fleet and that it expected significant delays beyond those officially declared.

As winter approached, RTE updated its report on the supply risk by slightly increasing the availability forecast for the nuclear fleet, though keeping it under a ‘special surveillance’. Once again, RTE highlighted as the main risk the return to operation of the numerous nuclear power plants under maintenance, a return which was expected in the following weeks, highlighting the ‘atypical shutdowns’ of 5 reactors whose risk of delay was greater than that of the rest.

It seems that EDF left its optimism aside at the time and announced a lower availability (-9 GW) for November, -3.5 GW for December 2020 and January 2021, leaving its vision unchanged for February 2021. By contrast, EDF did not think it appropriate to align its nuclear capacity certification forecast, which remained at 42.7 GW, well below the average availability expected by EDF itself. Here we must point out an inconsistency with significant consequences for the certification market. Whenever EDF announces its maintenance programmes, and implicitly an available capacity, the certification estimates for this capacity should be reflected in the certification records, which does not seem to be the case. Although EDF and RTE’s forecasts were gradually coming closer together, mainly due to a less optimism on EDF’s side, they were still far from each other: RTE was forecasting around 48 GW by December 2020 compared to the 54 GW forecast by EDF.

Finally, EDF gradually accepted the reality and reduced its availability forecasts: from an average of 54 GW for November and December 2020 in November, to 50 GW in December, and finally 47 GW – within the range forecast by RTE. On the nuclear certification side, the process was slower and followed the opposite direction. Thus, certification went from 42.7 GW in November to 44.2 in January. In the end, there was no shortfall in certification in 2020 and production was sufficient to ensure the electricity supply without any major problems.

In view of the events of 2020, we understand that the system needs to improve in terms of transparency. Undoubtedly, this should be one of the conclusions of the “retour d’expérience” that the CRE has recently launched on the capacity mechanism. And, if we want to be optimistic, we can assume that the information made available will become more reliable in the medium terms. Until we achieve this higher degree of transparency, the recommendation to our readers is to dive deeper into the available sources and trace the inconsistencies in order to be able to fine-tune the forecasts. Good luck!

Manuel Domínguez León

[1] Price variation between 15/04/2020 and 22/04/2020.

[2] Difference in availability forecast between 01/01/2020 and 23/04/2020.

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Céline graduated in Spanish and English Language, Literature and Civilisation at La Sorbonne IV (2018). She also holds a master’s degree II in cultural projects and establishments management, with a special focus on international tourism. She also studied abroad at the University of London (England) and Universidad de Morón (Argentina).

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Marketing Responsible

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“Decarbonization of the Energy and Transport sectors is arguably today’s main economic driver for the industry.”

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His career started in civil engineering as a Project Manager in France, Martinique and Australia. Afterwards, he became the General Manager of a subsidiary in Venezuela. In 1992, he established Dalkia in Germany (district heating, cogeneration, and partnerships) and represented Véolia in Thailand. In 2000, he opened the commercial office of Endesa in France to take advantage of the liberalized retail market. From 2006, as a development Manager at Endesa France, he led Endesa’s plan for Combined Cycle generation in France and developed the wind and PV portfolio of Snet at the same time. Philippe Boulanger worked for 3 years at E.ON’s headquarters coordinating the company´s activities in France. He was strongly involved in the French hydro concession renewal project. As a Senior Vice President – Project Director at Solvay Energy Services from April 2012 to February 2014 he was in charge of the H2/Power to gas and European direct market access deployment projects. Philippe has been an HES expert since 2014.

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Philippe Boulanger holds engineering degrees both from the Ecole Polytechnique and the Ecole Nationale des Ponts & Chaussées (France) and has a combined experience of more than 25 years in energy and infrastructure. In addition to English, Mr. Boulanger is fluent in French, German & Spanish.

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Electricity Expert

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“The world is changing. New investors pay particular attention to the energy sector while historical actors adapt their position to the market.”

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Antonio started his career in the electricity sector in 1991 working as a member of staff for the General Manager of Sevillana de Electricidad (Spain). In 1997, he was in charge of the commercial regulation at Endesa Distribution. In 2000, he joined Endesa’s European M&A department. He was appointed CEO of Endesa Power Trading Ltd in 2003. He became Head of Energy Management for SNET, France, in 2004 and was appointed CEO of this company in 2008. In 2009, he held the position of Head of Corporate Development for E.ON France. In 2011, he founded Haya Energy Solutions (HES), a consulting firm which assists companies in optimizing their value chain: from strategy definition to day-to-day operations, based on a strong experience and understanding of the energy industry. From 2015 to 2018, Antonio was Chairman and CEO of 2 French CCGTs (2x410MW), owned by KKR. At the end of 2018, he joined Asterion Industrial Partners, a dedicated infrastructure investment fund, as an Operating Partner.

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