The future of electricity bills in 2026: between spectacular increases and maintaining stability, the debate on the end of the Arenh intensifies

The End of the ARENH in 2026: A Decisive Turning Point for Electricity Bills

For nearly fifteen years, the ARENH (Regulated Access to Historic Nuclear Electricity) system has played a key role in the French energy landscape. By requiring EDF to resell a portion of its nuclear production at a fixed rate, approximately €42/MWh, this mechanism has helped maintain a degree of competitive equity while limiting sharp increases in electricity prices. But as of January 1, 2026, this arrangement will disappear, potentially disrupting the entire established price balance.

For EDF, the abolition of the ARENH is seen as a necessity. Current conditions underestimate the real costs of nuclear production, jeopardizing the company’s profitability and financial health. As the group embarks on the costly construction of new EPR reactors, this reform is intended to provide EDF with greater freedom and flexibility to sell its output at market prices or through long-term contracts better suited to the sector’s financial and technical constraints.

This transition is undoubtedly causing concern in various circles. Consumers fear a surge in prices, while industry professionals emphasize the need to readjust the rules to sustainably preserve investment in the nuclear fleet. This change therefore marks a turning point in regulation and raises the fundamental question of how costs should be shared between producers, distributors, and end users.

In this context, major energy players – EDF, Engie, TotalEnergies, as well as alternative suppliers such as Direct Energie, Cdiscount Energie, Ilek, and Ekwateur – are finding themselves having to rethink their business strategies. They will have to anticipate a more volatile market where prices will no longer be contained by strong government intervention, but will instead depend largely on supply and demand factors, wholesale market prices, and new regulatory mechanisms.

Public debates and expert reports are multiplying, including that of UFC-Que Choisir, which anticipates a surge in prices in the short term, and those of the Energy Regulatory Commission (CRE), which are more circumspect. This dual interpretation clearly illustrates the complexity of the process and the multiple economic, social, and industrial issues underlying the end of the ARENH (National Energy Regulatory Authority).

The Universal Nuclear Payment (UNV) mechanism: a balanced solution or a source of controversy?

In response to the abolition of the ARENH (National Energy Agency), the public authorities have introduced a new mechanism called the Universal Nuclear Payment (UNV). Starting next year, this system will replace regulated access with a revenue cap system for EDF, designed to prevent the company from making excessive profits when wholesale electricity prices rise.

The operation of the VNU is based on two thresholds based on the full cost of nuclear production. If the average price of nuclear electricity sales is below a first threshold, EDF receives all of its revenues without limitation. When this price exceeds this first threshold, a portion of the excess revenues is collected by the State: 50% between €78 and €110/MWh, then 90% above €110/MWh. This contribution is then supposed to be redistributed to consumers in the form of direct rebates on their electricity bills.

This design of the VNU therefore aims to establish a form of dynamic regulation, making EDF accountable for its profits in the face of market fluctuations while protecting consumers from excessive price increases. This framework could also encourage better management of the energy company’s costs and investments, while ensuring a balance between profitability and fair pricing.

However, this mechanism is far from unanimous. UFC-Que Choisir strongly criticizes this new system, which it considers essentially protective of EDF and insufficiently favorable to consumers. According to its analyses, the majority of household consumption would not truly benefit from the promised redistribution. Furthermore, the taxation of excess profits would not fully offset the increase generated by the abolition of the ARENH.

For example, the association estimates that if the VNU had been in effect this year, electricity bills would have increased by approximately 19%, or nearly €250 more annually for the average household. Beyond the financial implications, this opposition reflects concerns about the public authorities’ ability to effectively balance public interests, the profitability of key players like EDF, and the preservation of household purchasing power.

Alternative suppliers, such as Planète OUI, Happ-e, and Ilek, are also watching this reform closely. For them, these changes lead to a readjustment of market offerings, with a differentiated impact depending on the contracted tariffs, sometimes offering greater negotiating margins in the long term, but also greater volatility for customers committed to variable prices.

The outlook for consumers and electricity suppliers regarding tariff changes

Faced with the end of the ARENH and the new mechanisms, end consumers hope to understand the real impact of these changes on their bills. Today, bills are already highly sensitive to fluctuations in the wholesale market, especially since electricity represents a significant portion of household budgets, particularly in France, where a large proportion of generation comes from nuclear power, thus ensuring relatively stable rates.

For a typical residential consumer, we see that regulated tariffs based on average market prices could remain stable in 2026 if wholesale prices hover around €60/MWh, the current level. However, this stability will also depend on the specific taxes and contributions maintained or adjusted by the government, which adds a layer of uncertainty.

As for market offers, the situation is more mixed. Customers who have opted for variable price contracts with suppliers such as Direct Energie or Cdiscount Energie could experience fluctuations more directly, depending on the moment of signing the contract and real-time changes in market rates. This exposes these households to more volatility on their bills depending on consumption cycles and climatic conditions, for example.

Alternative suppliers also play a growing role in this dynamic. Players such as Ekwateur, Planète OUI or Happ-e offer offers often associated with renewable energies, with commercial strategies based on the diversification of supply sources and the integration of digital solutions to better manage consumption. This relative autonomy of suppliers can sometimes protect consumers from excessive variations, but it complicates the analysis when choosing a suitable offer.

In addition, the rise of local and community solutions, as well as the increased integration of intelligent technologies such as Enedis smart meters, embody a new promise of optimization of uses, giving hope for better control of electricity expenses despite the changing tariff context.

Impact on the competitiveness of the electricity market and the strategies of large energy groups

The end of the ARENH and the establishment of the VNU profoundly change the balance between historical players and new entrants on the French electricity market. EDF, despite the budgetary constraints linked to the modernization of its nuclear fleet, is finding greater room for commercial maneuver, which could strengthen its dominant position.

Faced with this new situation, Engie, which holds a significant share of thermal and renewable generation capacity, will have to adjust its pricing policy and commercial offerings to remain competitive with EDF, which enjoys greater freedom in setting its prices. TotalEnergies, with its strong presence in fossil and renewable energies, could also benefit from this increased flexibility by adapting its supply contracts and customer offerings.

However, this restructuring of the electricity landscape is not without its tensions. Alternative suppliers, often perceived as players in the energy transition and promoters of green offerings, risk suffering from increased price volatility, complicating their economic projections. For these players, such as Ilek and Planète OUI, the challenge is to offer competitive offers while managing sector-specific risks.

The role of distributors such as Enedis therefore becomes essential in ensuring the reliability and flexibility of the grid, facilitating the integration of intermittent renewable energies and responding to variable demand. Through these dynamics, public regulation will have to continue to play a role of arbiter to prevent increased liberalization from resulting in price destabilization to the detriment of consumers.

In short, major energy companies are adjusting their strategies in a now more liberalized market, with increased attention paid to risk management, technological innovation, and customer communication to retain a demanding consumer base that is vigilant in the face of price changes.

The ecological and economic challenges linked to the electricity market reform in 2026

Beyond the tariff debates, the end of the ARENH (National Energy Regulatory Authority) and the implementation of the VNU (United Nations Energy and Natural Resources) are part of a broader framework of ecological transition and modernization of the French electricity sector. The current energy mix is ​​predominantly based on nuclear power – a stable but controversial source – complemented by the accelerated development of renewables, notably driven by local initiatives promoted by suppliers such as Happ-e and Ekwateur.

This reform could influence consumer and business behaviors regarding energy efficiency and the adoption of green technologies. Indeed, if the prospect of price increases materializes, it could encourage investment in energy-efficient solutions such as heat pumps, home automation, or consumption monitoring systems offered by Enedis. The role of green electricity suppliers will therefore be crucial in supporting this transformation, combining ecological commitment with price competitiveness.

On the macroeconomic level, the government is banking on a more transparent and balanced market to boost the attractiveness of investments in nuclear power and grid infrastructure. The construction of new EPR reactors, essential to securing the long-term supply of low-carbon electricity, requires financial strength from EDF, facilitated by the lifting of ARENH constraints.

But the balance remains fragile. An excessive increase in bills could weaken household purchasing power, fuel social tensions, and slow the political acceptance of energy projects. Hence the importance of vigilantly managing pricing mechanisms, including taxation, as well as clear communication to support citizens through these transformations.

Current debates therefore shed light on the economic, industrial, and ecological challenges of reform. More than ever, integrating sustainable, social, and technological dimensions into public and private decision-making is essential to successfully implement this energy transition and secure a stable, accessible, and environmentally friendly electricity supply for years to come.