April 2026 showed lower spot pricing across Southeast Europe while investment signals shifted toward a finance model tied to capture price, dispatch flexibility, cross-border spreads, balancing revenues, and carbon-adjusted industrial demand. The market backdrop was described as volatile, with solar-heavy conditions and gas exposure alongside CBAM sensitivity. In this setting, the cost of capital for each technology class was linked to how it performs rather than to generation growth alone.
Spot price softness across SEE markets
Solar finance became more selective as weaker demand and stronger renewable output pushed prices down in April. Hungary, Croatia, Bulgaria, Romania, Greece and Serbia all saw softening. Hungary recorded an hourly price collapse to -€19.90/MWh, while Croatia’s low reached €4.83/MWh. The shift was framed as a move into a capture-price risk environment for standalone solar.
For lenders, the focus moved from installed MW or EPC cost alone to whether projects can withstand lower midday prices. Financing conditions were also linked to curtailment risk, negative-price clauses and weaker merchant DSCR. Solar projects without storage or industrial offtake were described as facing higher equity return requirements and tighter debt sizing.
Wind revenue profile compared with solar
Wind finance was described as structurally stronger than solar under the April market pattern. Wind output was said to be less concentrated in the lowest-priced solar hours, allowing it to capture evening, night and winter pricing more effectively. The financing view emphasized better revenue diversification and lower cannibalisation exposure. It also highlighted stronger PPA value for industrial buyers seeking stable low-carbon supply.
In Serbia, renewables accounted for only 6.47% of the April mix while coal/lignite remained at 52.49%. Against that backdrop, wind projects were described as having a larger market-entry window before saturation risk becomes severe.
Hydro variability and dispatchable value
Hydro was presented as premium flexibility infrastructure after April showed large hydrological divergence across countries. Greece’s hydro output fell by 57.38%, while Serbia rose by 7.22%. Romania increased by 7.14%, Türkiye by 9.96%, and Italy by 21.75%. The volatility was tied to higher value for dispatchable water in monetizing peak spreads and supporting balancing scarcity.
The same month’s pattern was also linked to cross-border arbitrage opportunities for dispatchable resources. Hydro-backed portfolios were described as expected to command stronger valuation multiples than intermittent-only portfolios. The rationale given was DSCR stability and reduced imbalance exposure.
Nuclear baseload in Bulgaria and Romania
Nuclear finance was described as benefiting from April’s market structure through stable low-carbon baseload characteristics. Bulgaria’s generation mix was anchored by 43.59% nuclear, while Romania had 23.55%. This placement occurred during a month marked by renewable volatility and gas-market uncertainty.
Nuclear-linked assets were characterized as offering long-duration cashflow visibility and lower fuel-price exposure than gas. They were also noted as having strategic value for industrial PPAs. The main constraints were stated as CAPEX, construction risk and political complexity, alongside an increase in the market value of firm low-carbon generation.
Gas marginal risk and TTF price movement
Gas-fired generation was described as the marginal-risk anchor in April’s pricing environment. TTF prices moved from above €48/MWh early in April to a low of €38.78/MWh. Despite that decline, gas exposure remained linked to LNG flows, storage strategy and geopolitical risk.
The premium pricing for gas-linked systems was illustrated with Italy’s average power price of €119.47/MWh. For financing purposes, flexible gas was described as valuable for capacity and balancing roles while also becoming increasingly risky for long-term merchant exposure under carbon, fuel and geopolitical volatility.
Coal utilisation pressure under ETS and CBAM
Coal finance was described as deteriorating fastest among the technology classes discussed. Serbia’s coal share of 52.49% was said to still support dispatchability, but its value was framed as transitional. Coal could provide system security in the near term while future financing constraints were tied to ETS alignment, CBAM pressure, lender exclusion policies and refinancing risk.
Bulgaria’s coal/lignite output fell by 31.64% month-on-month in April, reflecting how quickly coal utilisation can weaken when demand falls and renewables improve.
Toward hybrid portfolios combining multiple revenue streams
The best-financed SEE portfolios were described as hybrid rather than single-technology builds. The bankable structure was stated as combining wind + solar + BESS + hydro flexibility, along with an industrial PPA and GO/MRV documentation. This approach was described as protecting capture prices while improving debt capacity and reducing merchant volatility.
The same structure was also linked to creating CBAM-compliant electricity products for exporters through portfolio design rather than relying on one generation type alone.
Regional hierarchy across stability, new-build renewables and transition assets
An investment hierarchy for Serbia and the wider Balkans was outlined based on asset roles in the April market context. Hydro and nuclear were listed as stability assets, wind as the strongest new-build renewable class, and solar with storage as bankable but more conditional.
The hierarchy also placed gas as flexible but exposed, while coal was described as increasingly stranded without transition financing. The finance premium was attributed to assets that can control timing rather than merely produce electricity.