Boralex and France: When Growth Meets a Saturated Power System
- Feb 13
- 8 min read
Introduction
This report examines whether Boralex’s growing concentration in France exposes the company to structurally weakening wind economics. While France continues to promote renewable energy at the policy level, the electricity system is increasingly constrained by nuclear baseload dominance, grid congestion, and synchronized renewable output.
The focus of this analysis is not on the operational viability of existing assets, but on marginal economics: whether incremental capacity additions and future contract repricing in France retain the same value profile as in prior years, or whether growth increasingly risks becoming value-dilutive rather than value-accretive.
To assess whether this risk is theoretical or already materializing, it is first necessary to examine how the French power system is evolving, and why renewable growth in France increasingly differs from renewable growth in less constrained markets.
France Overview
Policy backdrop and why the timeline feels messy
France’s energy policy over the last decade has been marked by repeated reversals between creating room for renewables by reducing nuclear and reaffirming nuclear as the backbone of the system for security and sovereignty. The 2015 Energy Transition for Green Growth Law set an objective to reduce nuclear’s share of electricity generation to 50% by 2025. That target was subsequently delayed and effectively abandoned, and by 2023 the political direction had clearly shifted toward maintaining a majority nuclear system rather than shrinking it.
This reversal became explicit in 2022 when President Macron announced a new nuclear build program, including at least six EPR2 reactors, with the possibility of additional units. Legislative discussions in 2023 further reinforced this shift by removing the objective of reducing nuclear to 50% by 2035 and replacing it with a “more than 50%” target toward 2050.
At the same time, France continues to publicly promote renewable energy growth. Under the France 2030 investment plan, the government earmarked €1 billion for renewable energy innovation, with ambitions to significantly expand installed renewable capacity by 2050, including 40 GW of offshore wind. The message is therefore not “no renewables,” but rather “renewables within a system that remains fundamentally nuclear.”
For investors, the core issue is not the existence of renewable targets, but the uncertainty surrounding execution. Delays to the PPE (Programmation Pluriannuelle de l’Énergie), the multi-year energy plan intended to lock in the roadmap and tender rhythm, have repeatedly reduced visibility. While policy uncertainty affects planning and investment timelines, it does not by itself explain weakening renewable economics. The more binding constraint is structural: the physical design of the French power system and the role nuclear plays within it.
Nuclear as both backbone and constraint
France’s electricity system remains structurally nuclear-centric. The country operates the largest nuclear reactor fleet in Europe, with 57 reactors, and nuclear generation surged back toward normal levels in 2024 following the maintenance-driven lows of 2022. Nuclear production reached approximately 361.7 TWh in 2024, materially increasing system supply even without meaningful new capacity additions.
While France’s reactors are technically capable of load-following, nuclear generation is still designed to operate as a stable backbone. As a result, nuclear output occupies a large share of system capacity during most hours, limiting flexibility precisely when wind and solar output spike.
As renewable capacity scales within this framework, the system increasingly resolves imbalances not through flexible dispatch, but through price signals and curtailment. This dynamic makes congestion the key transmission mechanism between system design and market outcomes.
Figure 1. Evolution of electricity production by generation type in France between 2019 and 2024. Source: RTE, 2024 Annual Electricity Report.
Grid congestion and curtailment: the bottleneck showing up now
The interaction between a nuclear-heavy system and rapidly scaling renewables is now visible in both physical and market outcomes. Grid congestion has emerged as a binding constraint.
In 2024, RTE reported record curtailment of wind and solar electricity, reaching approximately 1.7 TWh, up from 0.6 TWh in 2023 (Source: RTE, 2024). Curtailment events are strongly correlated with negative price hours and periods of system saturation.
Negative pricing has become a recurring feature rather than an exception. In the first half of 2025 alone, France recorded 363 hours of negative prices, compared with 235 hours in the same period in 2024 (Source: RTE, H1 2025). These conditions directly impair renewable economics by lowering capture prices and forcing production reductions during periods of high output.
Figure 2. Cumulative number of hourly negative electricity prices in France by year. Source: Bloomberg News, “France’s Tally of Negative Power Prices Just Beat the 2024 Total”, based on EPEX data.
While France has announced substantial grid investment plans, this does not resolve the bottleneck in the near term. RTE estimates grid upgrade needs of approximately €100 billion by 2040, while noting that less than 15% of projects are formally confirmed and initiated (Source: Reuters, 2025). The timeline for meaningful system-wide relief is therefore long, and execution risk remains significant.
Wind specifics: scale, variability, and synchronization risk
Wind is no longer marginal. By the end of 2024, installed wind capacity reached approximately 25 GW, generating around 47 TWh annually, with roughly 10,000 onshore turbines already installed. When wind conditions align across regions, production ramps quickly and concentrates output into the same hours that the system is already constrained by nuclear baseload and limited grid flexibility.
At the same time, recent periods have shown that realized wind volumes have been below long-term average (LTA) levels. This introduces a second layer of pressure. Lower-than-expected wind volumes under fixed or indexed contracts reduce delivered MWh, leading to revenue shortfalls versus guidance, which can erode market confidence even when pricing is contractually protected.
Figure 3. Evolution of wind and solar electricity production in France and their share in the electricity mix between 2000 and 2024. Source: RTE, 2024 Annual Electricity Report.
More importantly for the forward view, if weaker wind conditions persist or become more volatile, producers may face reduced bargaining power in future contract negotiations. Lower realized volumes and lower capacity factors weaken the ability to secure attractive terms for new PPAs or feed-in premiums, especially in a market already facing structural oversupply during peak generation hours. A substantial pipeline of wind projects remains in development, meaning additional capacity is likely to enter the system before grid and flexibility solutions materially expand. This creates a dual risk: volume risk in the near term and pricing risk at the margin over time.
Exports help, but they are not a structural escape valve
France is a major exporter of electricity, and exports reached record levels in 2024. However, exports only clear surplus when neighboring markets require power at the same moment. As European countries scale renewables in parallel, oversupply events increasingly occur simultaneously across borders. In such conditions, exports tend to clear at low or negative prices, limiting their ability to stabilize domestic pricing or absorb excess generation.
What does this mean for Boralex?
Boralex’s real exposure in France
As of November 6, 2025, Boralex reports 3,403 MW of installed capacity across 137 sites. While the company presents itself as a diversified renewable platform, the portfolio is heavily skewed toward wind, which accounts for approximately 2,952 MW, or 87% of installed capacity. Solar represents 268 MW (8%), hydro 178 MW (5%), and storage just 5 MW.
Geographically, France accounts for approximately 1,378 MW, or around 40% of total installed capacity. Europe totals 1,484 MW, meaning France represents roughly 93% of the European segment. The same concentration applies to wind capacity, with approximately 92% of European wind located in France.
Management highlights that approximately 92% of installed capacity operates under energy sales contracts or indexed pricing mechanisms. However, the weighted average remaining contract duration is shorter in Europe (≈8 years) than in North America (≈10 years), implying that France will face market repricing sooner.
Production vs revenue disconnect
In Q3 2025, consolidated production increased 7% year-over-year. Despite this, revenues declined, operating income turned negative, and EBITDA(A) decreased slightly. The regional split explains the divergence: European production increased 19%, while revenues, operating income, and EBITDA(A) declined. Management explicitly attributed this deterioration to lower prices observed in Europe.
Over nine months, Europe revenue fell $260M vs $325M (-20%), operating income fell $33M vs $119M (-72%), and EBITDA(A) fell $157M vs $213M (-27%). Wind revenue per MWh declined from roughly 171 CAD/MWh to 135 CAD/MWh (-21%), while North America remained relatively stable
Figure 4. Cash flow performance and final financial position of Boralex. Source: Boralex, Q3 2025 Interim Report.
This confirms that weaker European performance is not primarily a function of asset reliability. Instead, it reflects a decline in the value of each incremental megawatt-hour, driven by a combination of lower capture prices, congestion, and system saturation.
Importantly, Europe’s weaker performance is occurring in a context where wind volumes have been volatile and, at times, below long-term averages. Lower volumes under fixed pricing structures reduce delivered revenue, while periods of higher output increasingly coincide with low-value or negative-price hours. Together, these dynamics mean that both volume risk and pricing pressure are now working against European wind economics.
Growth strategy vs marginal economics
The more important question is not whether existing assets remain viable, but whether continued growth under these conditions creates or destroys incremental value.
Boralex’s strategy is explicitly expansionary, with management targeting growth from approximately 3.3–3.4 GW today to around 7 GW by 2030. The development portfolio totals approximately 7,005 MW, split between 4,462 MW in North America and 2,543 MW in Europe.
While North America represents the larger share, Europe remains a material growth engine. Given that approximately 93% of Europe’s capacity is France, the European pipeline effectively increases France exposure. Pipeline maturity indicates that French projects are embedded across the near- to mid-term development timeline.
In a market where marginal megawatt-hours increasingly clear at low or negative prices, scaling capacity does not automatically equate to value creation. Growth becomes increasingly sensitive to timing, grid constraints, wind variability, and contract repricing dynamics.
Figure 5. Development project portfolio of Boralex by technology and geography. Source: Boralex, Q3 2025 Interim Report.
Risks to the Bear Thesis (What Could Go Right)
While the above analysis suggests a structurally challenging backdrop, several developments could mitigate or reverse these dynamics over time.
The most direct upside risk would be an accelerated expansion of grid infrastructure. A material reduction in congestion could improve capture prices and restore value to marginal renewable output. However, the scale of required investment and France’s historical execution timelines suggest that system-wide relief is unlikely within the next five to seven years.
A second mitigating factor would be the rapid deployment of storage and other flexibility solutions. While additional flexibility could theoretically absorb excess generation during peak output periods, France starts from a low base, and near-term deployment is unlikely to reach sufficient scale to materially alter market dynamics.
Greater nuclear flexibility could also create additional space for renewables. While technically feasible, nuclear remains politically and economically positioned as the backbone of the system, limiting the likelihood of sustained structural change.
Finally, supportive market design reforms or a decisive reallocation of capital away from France could reduce downside risk. However, policy implementation has historically lagged announcements, and Boralex’s existing development pipeline and sunk costs constrain its ability to pivot rapidly.
Conclusion
France is not abandoning renewables, and Boralex is not a structurally flawed company. However, the French power system is entering a phase where infrastructure and market design lag renewable capacity additions, compressing the value of marginal output.
Given Boralex’s concentration in France, approaching contract repricing, wind volume variability, and continued expansion in a structurally constrained market, growth increasingly risks being value-dilutive rather than value-accretive.
In this context, the key investment question is no longer whether Boralex can grow, but whether growth in France still earns its cost of capital.
Disclosures
This document has been produced by Marchés Globaux HEC (“MGH”) strictly for academic and informational use. The views, forecasts, and assessments presented are derived from publicly accessible sources that are believed to be accurate at the time of preparation; however, MGH has not conducted any independent verification of such data. Nothing in this document should be interpreted as investment advice, a solicitation, or a recommendation to buy, sell, or hold securities, nor as a valuation or professional opinion under Canadian or other applicable regulations.
MGH operates as a student-led initiative. Its authors are not registered financial advisors, legal experts, or accounting professionals, and the content herein is provided solely to foster discussion and learning. This material is intended exclusively for educational purposes and may not be copied, quoted, or distributed in whole or in part without prior written approval from MGH.
Abdur Raoup Mohammed, Antoine Dussault, Harvey Jia, Thomas Boudreau
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