Existing grid links could become a shortcut for new clean power
Europe’s power transition increasingly has a queue problem. Governments are setting higher renewable targets, developers are proposing more projects, and grid operators are struggling to connect them quickly enough. An analysis released by energy think tank Ember argues that one of the fastest ways to ease that bottleneck is not to wait for entirely new transmission capacity, but to use infrastructure that already exists.
According to Ember, hydropower sites across Austria, Bulgaria, France, Italy, Portugal, Romania and Spain could accommodate 25 gigawatts of additional wind and solar generation by sharing their existing grid connections. The premise is straightforward: many hydropower facilities do not use their full export capacity all day, especially during daylight hours. If new renewable generation is added behind the same connection point, developers may be able to bring projects online faster while staying within the site’s grid limits.
That matters because connection delays have become one of the most stubborn constraints on clean-energy growth. In practical terms, the proposal is less about inventing a new class of technology than about reorganizing how existing assets are used. Hydropower stations already occupy strategic points in the network, and Ember’s case is that they can serve as anchors for hybrid renewable sites instead of functioning as stand-alone assets.
What hybridisation means in practice
Ember frames the opportunity around hybridisation, the practice of combining multiple technologies behind a single grid connection. In this case, the pairing is typically hydropower with solar or wind, and potentially storage as well. The goal is to increase the productivity of a limited connection by sending more useful clean electricity through it over the course of a day, not by raising the maximum export ceiling.
The argument rests on complementary generation profiles. Hydropower output does not always occupy all available grid capacity, and solar production tends to peak during daytime periods when some hydropower-linked infrastructure can absorb extra generation. By co-locating technologies and sharing a connection, operators can increase overall utilization of grid assets that would otherwise sit underused for part of the day.
Ember says this approach could on average double utilization of those connections while remaining inside existing export limits. That makes hybrid projects attractive in a region where grid buildouts often move far more slowly than clean-energy procurement goals. Instead of treating interconnection as a hard stop, hybridisation turns it into a design constraint that can still support new capacity.
The report’s most striking number is not just the 25 GW estimate itself, but the implication that this could cover 18% of the new renewables expected by 2030 in the seven hydropower-heavy EU markets examined. If that estimate holds up in project development and national permitting, it would make hybridisation a meaningful contributor to near-term decarbonization rather than a niche engineering workaround.
Why this matters now
The timing is central to Ember’s pitch. European countries are under pressure to cut reliance on imported fossil fuels, meet climate commitments and keep electricity systems reliable while demand patterns change. Yet new grid infrastructure is capital-intensive, politically sensitive and slow to permit. That creates a mismatch between clean-energy ambition and physical deployment capacity.
In that context, hybridisation offers something policymakers rarely get: a measure that can potentially accelerate renewable additions without depending on entirely new network corridors. It does not remove the need for future grid expansion, but it may help bridge the gap between long-term infrastructure plans and short-term decarbonization targets.
Ember’s infrastructure lead, Elisabeth Cremona, described hybridisation as an immediate solution for countries facing gridlock. The think tank’s argument is that clean power should not remain stranded in interconnection queues when there are existing nodes capable of hosting more generation. That framing is likely to resonate in national capitals that want visible progress before the end of the decade.
For developers, the appeal is equally practical. Faster access to a connection point can reduce project risk, improve financing timelines and lower exposure to regulatory delays. For operators, shared infrastructure can raise the value of assets already tied into the grid. For governments, it is a way to show momentum on renewable deployment even where transmission upgrades remain bogged down.
The policy obstacle is not physics but regulation
Ember’s analysis also points to a familiar European problem: uneven rules across national markets. Among the seven countries in the study, only Portugal and Spain are described as having specific frameworks for hybrid projects. The others, Ember says, still lack clear regulatory pathways.
That gap could prove more important than the engineering. Many energy transitions stall not because the equipment is unavailable, but because permitting rules, interconnection procedures and market design have not caught up with technically workable models. Hybrid projects can end up trapped between categories, treated neither as straightforward upgrades nor as conventional greenfield developments.
Ember is calling for targeted legislative reforms and faster priority processing for hybrid applications. In effect, the organization is arguing that policymakers should treat shared-connection projects as a special class of renewable deployment worthy of streamlined handling. If governments accept that logic, the 25 GW estimate becomes less of a theoretical ceiling and more of a deployable pipeline.
The broader significance is that grid efficiency is becoming as important as generation technology in the next phase of Europe’s energy buildout. Solar panels and wind turbines are no longer the only scarce resource. Connection rights, queue management and regulatory clarity increasingly determine how much clean power reaches the system in time to matter.
A narrow fix with potentially broad impact
Hybridisation will not solve every structural problem in Europe’s electricity networks. It cannot replace major transmission expansion, and it depends on site-specific technical and commercial conditions. Some hydropower facilities will be much better suited than others, and the path from analytical potential to commissioned capacity is rarely smooth.
Even so, the concept is compelling because it targets a bottleneck that is immediate and expensive to ignore. If countries can unlock meaningful renewable additions by making better use of existing grid links, they gain time while bigger infrastructure projects move through slower planning cycles.
That makes Ember’s report less a claim of effortless abundance than a reminder that the energy transition is partly an optimization challenge. Europe may not need to wait for every new wire to be built before adding more clean power. In some places, the next tranche of renewables could arrive by sharing the grid assets already in service.
If regulators move quickly, hydropower sites could become staging grounds for a faster renewable rollout. The scale outlined by Ember suggests this is no marginal tweak. It is a potentially material piece of Europe’s 2030 clean-power puzzle, built not on speculative technology, but on better use of infrastructure already standing.
This article is based on reporting by CleanTechnica. Read the original article.
Originally published on cleantechnica.com
