The landscape of wind energy financing in South-East Europe is experiencing significant changes, transitioning from a model heavily reliant on subsidies and feed-in tariffs to a more complex financial ecosystem. By the first quarter of 2026, this transformation is expected to be evident across key markets including Serbia, Romania, Greece, and the broader Western Balkans. Developers are shifting their focus from simply assessing project bankability under regulated frameworks to structuring revenue and capital in response to evolving market dynamics, pricing volatility, and cross-border influences.
Historically, early wind projects in the region utilized feed-in tariffs (FiTs) or quasi-contract for difference (CfD) frameworks that provided long-term price stability and allowed for high leverage with minimal equity risk. However, this model is being replaced by power purchase agreements (PPAs), which are now the primary mechanism for revenue stabilization, especially for newer projects lacking access to legacy support schemes. These PPAs can be categorized into three main types: utility-backed PPAs, corporate PPAs (cPPAs), and merchant-linked PPAs.
Utility-backed PPAs continue to serve as a viable alternative to traditional offtake structures. In Serbia and parts of the Western Balkans, state-affiliated utilities remain central to project financing by offering long-term contracts that ensure predictable cash flows. However, these agreements are increasingly being negotiated at market-reflective prices rather than fixed subsidy rates.
On the other hand, corporate PPAs are gaining traction, particularly in Romania and Greece, where industrial consumers seek long-term price hedging and sustainability credentials. These contracts introduce a more complex risk profile due to their reliance on private entities as counterparties. Additionally, merchant-linked PPAs represent an advanced form of offtake that combines fixed-price elements with exposure to wholesale markets, enabling developers to benefit from market fluctuations while maintaining some revenue stability.
All three PPA types share a common characteristic: price certainty is no longer guaranteed. Even long-term agreements now include mechanisms that tie revenue to market conditions, reflecting the increasing integration and volatility of electricity markets in South-East Europe.
Furthermore, developers are increasingly adopting take-off agreements as part of comprehensive portfolio strategies that extend beyond mere electricity sales. These arrangements often encompass multi-asset offtake approaches—integrating wind, solar, and storage resources—cross-border delivery structures, and bundled balancing services. This strategy aims to create more bankable revenue profiles by mitigating production variability and aligning generation with demand patterns.
The equity landscape in South-East Europe is also evolving. Initially dominated by strategic investors such as utilities focused on long-term operations, the sector is now welcoming a diverse range of financial investors. Institutional capital—including infrastructure funds and pension funds—is increasingly targeting operational assets and late-stage development projects due to attractive cash flows under PPA structures and relatively high returns compared to Western Europe.
At the same time, private equity firms are entering earlier stages of project development, taking on associated risks for potentially higher returns. This trend is particularly pronounced in Serbia and Romania where significant pipeline opportunities exist for portfolio aggregation.
This evolution has resulted in a two-tier equity market: one segment consists of long-term institutional investors focused on yield, while another comprises shorter-term investors concentrating on development and value creation. Consequently, developers must navigate the varying requirements of these investor classes while balancing risk allocation and return expectations.
Debt financing mechanisms are also undergoing changes. Early projects primarily relied on multilateral development banks and state-backed lending institutions for long-tenor financing. By 2026, commercial banks are expected to play a more prominent role in financing projects backed by robust PPAs and experienced sponsors. Debt terms are becoming increasingly market-driven with tenors typically ranging from 12 to 15 years while margins reflect project risk and PPA structures.
In this evolving context, lenders are now assessing projects not only based on contracted revenues but also considering market integration risks such as price volatility and balancing costs. This shift raises the bar for bankability; projects lacking solid offtake structures or flexibility components may encounter tougher financing conditions.
The broader market context reveals that electricity prices across South-East Europe have frequently fluctuated within the €90–120/MWh range during early 2026. This volatility stems from renewable generation variability and hydro conditions rather than fuel costs alone. High prices can enhance project economics but also introduce additional risks that necessitate careful contract structuring to balance downside protection with upside opportunities.
Looking forward, several trends are anticipated to shape the future of PPAs and funding in South-East Europe. In a base case scenario, PPAs will remain essential but will become increasingly sophisticated with hybrid contracts combining fixed and merchant elements becoming commonplace. In an upside scenario characterized by deeper market integration, more advanced financial structures such as portfolio-level PPAs and cross-border agreements may emerge, attracting greater volumes of institutional capital.
Conversely, in a downside scenario marked by regulatory uncertainties or grid constraints limiting PPA availability, reliance on merchant exposure could increase financing costs and hinder project development—particularly impacting smaller or less experienced developers.
This transformation underscores a broader shift within the energy sector where wind projects are no longer defined solely by their physical attributes but rather by their financial architecture. The ability to effectively design and implement financial structures will determine project viability moving forward. As such, stakeholders must enhance their capabilities in contract structuring, risk management, and investor relations while deepening their understanding of market dynamics and regulatory frameworks.
The trajectory of wind energy financing in South-East Europe indicates a rapid transition from subsidy-driven models towards a financially engineered ecosystem where success hinges on effective alignment of revenue streams with capital structures amidst growing complexity.
