Where the returns sit depends on the sector and the route to market. Utility-scale and rooftop solar still drive new build, but solar’s own success now works against it: midday oversupply depresses capture prices, so a merchant park earns least precisely when it generates most. The economic response is flexibility and contracting. Hungary’s policy framework targets around 1 GW of battery storage by 2030, supported by Recovery-funded schemes and the HUF 50 billion Jedlik Ányos program; corporate PPAs and self-consumption (materially easier since the Jan. 1, 2024, amendments to the Electricity Act introduced private-line arrangements, closed distribution systems and electricity sharing) convert volatile spot exposure into the predictable cash flow lenders price. Wind, effectively frozen for a decade, reopened in 2024 when the minimum setback distance was cut from 12 km to 700 m, while biomass, biogas and geothermal diversify the base.

None of this is investable without the regulatory architecture. Generation is regulated under Act LXXXVI of 2007 on Electricity and supervised by MEKH, with Mavir playing a central role on the transmission-system side. The licensing burden scales with project size: installations below 0.5 MW are outside the full MEKH generation licensing regime; projects between 0.5 MW and 50 MW are subject to a simplified small power plant licensing procedure; and projects of 50 MW or more require separate establishment and operating licenses. Support has historically been available through the legacy KÁT feed-in tariff and the Metár premium regime. However, the practical relevance of new Metár support has diminished as tenders have slowed or paused, and recent solar development has increasingly relied on merchant exposure, corporate PPAs or self-consumption structures.

The harder questions concern execution. Grid capacity is finite, and a firm connection right now is often as valuable as the site itself. Under the Land Transfer Act, companies cannot freely acquire arable land, pushing renewable projects towards long-term leases, use rights or reclassified industrial plots. Acquisitions may also fall within Hungary’s foreign-investment screening framework, including the special screening regime now placed on a more permanent legislative footing by Act L of 2025. In sensitive sectors such as energy, prior ministerial clearance may be required, and the regime may capture certain EU and EEA investors as well as third-country investors. Separately, changes of control in regulated or supported energy assets may require MEKH consent. There is a strong case for narrowing and streamlining this, particularly for intra-EU and EEA transactions, where mandatory review may add cost and delay without an obvious security justification.

The timing adds a tailwind. Hungary faces a tight end-August 2026 deadline to access its EUR 10.4 billion Recovery and Resilience Facility allocation, comprising EUR 6.5 billion in grants and EUR 3.9 billion in loans. The REPowerEU chapter and related recovery measures are closely linked to reducing fossil-fuel dependence, improving energy efficiency, expanding renewable capacity and reinforcing the grid. If the funding is unlocked and channeled into bankable projects, it could become the largest near-term driver of Hungarian energy investment.

But EU funding arrives wrapped in EU conditionality. These projects will have to be delivered against binding milestones, state aid and public procurement rules and environmental compliance requirements, on top of the domestic licensing, grid, land and FDI requirements already described. The opportunity is, therefore, inseparable from the regulatory groundwork needed to capture it: clean title, a firm connection, a bankable offtake, EU-compliant structuring and consents that survive due diligence. For developers, funds and investors alike, success will turn less on the megawatts than on that groundwork.

This article was first published in the Budapest Business Journal print issue of June 5, 2026.