According to International Energy Agency (IEA) website publication on Renewables 2022 Analysis and forecast to 2027 report, the financial statements of large European utilities indicate higher revenues resulting from steep fossil fuel and electricity prices in the first half of 2022 compared with the same period in 2021. However, unlike for oil and gas majors, higher revenues for European utilities have not always translated into profits in recent months because utility companies have diverse business profiles, allowing them to compensate losses in one business segment with profits from another. Plus, technological and geographical portfolios as well as business strategies have been important determinants for how companies are navigating the global energy crisis.
Our analysis cannot be generalised to cover the entire EU market, as it assesses just ten large utilities, or around one-quarter of total installed EU electricity generation capacity. The majority of installed renewable capacity is owned and operated by private companies that are not obligated to disclose their financial standing.
All the major utilities reported significantly higher revenues but also higher costs in H1 2022 than in H1 2021, with hikes ranging from 30% to 170%. Higher average electricity and gas prices since November 2021 have clearly boosted revenues. However, even though all large utilities reported higher revenues in H1 2022, their financial performance and profitability within Europe were quite different due to a myriad of variables, including generation mix diversity; the splitting of earnings before interest, taxes, depreciation and amortisation (EBITDA) into different operations involving regulated networks, contracted renewables and trading activities; and exposure to retail business.
An increase in costly fossil fuel-based generation is compensating for lower hydropower output in Europe. Indeed, extreme drought conditions in Italy, France, Spain and Portugal reduced EU hydropower output by more than 15% in the first half of 2022. Lower hydropower generation reduced the European EBIDTA of Enel, Iberdrola and EDP, although higher profits from increased fossil fuel-fired generation and trading activities made up for this loss. In addition, these utilities had to purchase energy from the market at higher prices to meet their retail customer obligations, putting further pressure on their profitability.
EDF’s nuclear power generation dropped more than 15% and hydropower production was 23% lower in the first half of 2022 compared with the same period in 2021, requiring the company to purchase electricity from the spot market at high prices and reducing its revenues significantly. In some cases, higher wind and solar PV generation and additional installed capacity have contributed to profitability. For example, EnBW registered an EBITDA rise of 43% related to its renewable energy business, and Orsted, a utility with major investments in renewable generation, increased its EBITDA (excluding new partnerships) by 48% relative to H1 2021.
Exposure to retail and customer business reduced utilities’ profitability. Most major European utilities have large retail customer businesses. While electricity generation and purchase costs have risen drastically, retail price increases remain limited in most parts of Europe due to regulated-price contracts and to additional government interventions to protect consumers in the current extraordinary situation.
For instance, Spain and Portugal capped the wholesale gas price for power plant use at EUR 40/MWh, leading to relatively lower wholesale electricity prices and shielding Iberian electricity consumers. In general, most utilities’ retail businesses recorded a lower EBIDTA in the first half of 2022 than in 2021. For instance, EDF’s EBITDA dropped sharply in France due to the government’s regulatory measures to limit sales price increases for consumers in 2022.
Hedging strategies and long-term contracts are key tools for utilities to navigate the current European energy crisis. The exposure of European utilities on wholesale markets can vary significantly, impacting their profits. For instance, only one-third of Statkraft’s total generation is hedged through 2030, resulting in higher revenues from the electricity spot market. At the same time, however, Orsted’s low 10% exposure to the wholesale market limits the company’s ability to profit from high market prices. For Verbund, the company’s hedging strategy has increased its profits, as it was able to obtain an average sale price of EUR 112.5/MWh in H1 2022, boosting its electricity revenue considerably and raising its EBITDA, 111% from the previous year.
Meanwhile, Spain introduced a clawback mechanism for forward electricity contracts of more than EUR 67/MWh, but Iberdrola contracted unregulated renewable generation with its retail business at EUR 66/MWh in January 2022, before Spain had introduced the clawback mechanism. The fixed-price policy partly sheltered the company from volatile wholesale market prices.
