Hydropower spent the last decade keeping the lights on quietly while wind and solar grabbed headlines. In 2025, that changed. The sector put up tangible milestones – from large scale inaugurations in Africa to long-awaited pumped storage plants entering service in Europe – while regulators and financiers finally began to price hydropower’s unique ability to balance renewable grids. It wasn’t an unqualified boom: climate volatility pressed river basins from the Amazon to the Alps, and uncomfortable debates flared over river protections, dam safety, and who pays for long-duration water storage. But the year’s arc was unmistakable: hydro is moving from “legacy baseload” to “flex centerpiece,” and policy is starting, at last, to catch up.
The tone for 2025 was set mid-year when the International Hydropower Association (IHA) published its flagship World Hydropower Outlook. The report put hard numbers to what system operators already felt in their bones: hydro remains the world’s largest source of renewable electricity and is increasingly the glue holding variable renewables together. The 2025 Outlook highlighted global momentum, particularly the sharp rise of pumped storage hydropower (PSH), even as it warned that investment and regulatory models must evolve to recognise water power’s multi-service benefits.
GERD switches from symbol to system asset
A headline event of 2025 was Ethiopia’s formal inauguration of the 5150MW Grand Ethiopian Renaissance Dam (GERD) on September 9. Built by Webuild in collaboration with Ethiopian partners, the project represents one of the most ambitious hydropower undertakings in Africa’s modern history. Its vast infrastructure includes a 1800m long and 1170m high main dam, extensive spillways, and a powerhouse complex housing 13 turbines to harness the full potential of the water of the Blue Nile. After 14 years of construction, the continent’s largest hydropower project crossed its ceremonial finish line and immediately reshaped conversations about East African power trade. Government dignitaries, regional leaders, and millions of Ethiopians marked the moment while grid planners focused on the practicalities: how fast the new capacity can be integrated, and how much of it will flow into neighbouring countries.
If the inauguration was celebratory at home, it remained sensitive abroad. Egypt’s longstanding concerns over Nile flows did not vanish with the ribbon-cutting; water diplomacy will continue to track reservoir operations, seasonal releases, and drought protocols. But the inauguration consolidated GERD’s role as a regional anchor.
Europe’s “water battery” moment
If 2025 gave Africa a new baseload giant, Europe flexed its storage muscle. Austria’s 480MW Limberg III pumped storage plant – tucked above Kaprun in the Hohe Tauern – entered service in September after a demanding high-alpine build and a 9m raise of the Wasserfallboden dam. The project was officially inaugurated on September 12 and immediately became a case study in modern PSH: compact, fast-ramping, and integrated into a complex of existing reservoirs to deliver system flexibility at scale.
This was more than a local triumph. Across interconnected European markets, short-term price volatility is rising with the shift to 15-minute bidding intervals and denser cross-border flows. Storage that can respond in seconds is increasingly valuable, and PSH’s technical strengths are starting to be reflected in market reforms. Analysts noted that Central-Nordic market design changes and ongoing grid reinforcements will amplify the need for flexible assets; Limberg III arrived right on cue.
The UK, long an outlier on PSH investment, showed policy movement of its own. In capacity market and revenue-stabilisation steps that would have been unthinkable just a few years ago, authorities moved to underpin existing pumped storage and hydro portfolios, while laying groundwork for a “cap-and-floor” style approach for new long-duration storage. In parallel, Cruachan and other legacy assets secured fresh contracts, and public debate sharpened around SSE’s proposed 1.5GW Coire Glas scheme in the Highlands. The latter scored a world-first: Gold certification under the Hydropower Sustainability Standard (HSS), a notable proof that large-scale pumped storage can meet stringent social and environmental benchmarks at the planning stage.
Recognition wasn’t only from standards bodies. At the sector’s own World Hydropower Congress awards, Coire Glas shared the limelight as a project that could unlock a step change in the UK’s system adequacy – if revenue frameworks line up. That “if” is shrinking: political consensus is forming that long-duration flexibility is a grid necessity, not a luxury.
Also in September 2025, IHA and Eurelectric launched the Paris Pledge – a collective commitment from the European hydropower value chain to scale up PSH capacity and urge both EU-level and national policymakers to restructure markets, incentives and permitting frameworks accordingly.
The Pledge states that PSH remains the “most important, scalable and cost-effective long-duration electricity storage solution” and notes that the European pipeline exceeds 32GW of PSH projects (plus ~3 GW in Switzerland, Norway & Turkey) which together would provide more than 700 GWh of storage capacity – enough to power two major European economies for over 10 hours.
Key policy asks include:
- A dedicated EU initiative to accelerate electricity-storage deployment.
- Recognition, in legislation, of long-duration storage as distinct from short-duration solutions.
- Ensuring remuneration for system-services and security of supply across all time-frames, with PSH able to participate in revenue-stabilisation schemes.
- Elimination of double grid-fees for storage technologies and fast-tracked permitting for PSH development.
By issuing the Paris Pledge, the industry signalled: building pumped storage is no longer a niche option, it is central to Europe’s clean-energy transformation. The pledge complements the commissioning of assets like Limberg III not only from a technical standpoint, but by embedding regulatory and market reform as intrinsic to deployment success.
China’s surge on water storage
While Europe made headline inaugurations and the UK debated frameworks, China kept doing what China does: build at unprecedented scale. By mid-2025, the country was on track to exceed its 2030 pumped storage target by more than 8%, potentially reaching ~130 GW by decade’s end. The sheer pipeline (over 200GW of PSH under construction) dwarfs activity elsewhere and highlights how policy signals (notably pricing mechanisms that reward peak-shifting and ancillary services) can turn storage from “pilot” to industrial program. For global OEMs, consultants, and EPCs, China’s PSH surge remains both a competitive challenge and a market barometer for costs, timelines, and staffing models.
Australia: pumped storage moves from concept to cornerstone
Australia’s energy transition gave pumped storage renewed urgency in 2025, as coal exits accelerated and the limits of short-duration batteries became clearer during extended low-renewable events. Snowy 2.0 remained the sector’s most visible (and controversial) flagship: its scale (2GW/350GWh) continued to anchor national debate about cost overruns, construction risk and delivery timelines, but it also underscored a hard truth for system planners – there are few alternatives that can provide multi-day firming at continental scale. Beyond Snowy, momentum broadened. State governments and private developers advanced a pipeline of smaller, faster-to-build pumped storage projects in Queensland, Tasmania and New South Wales, many leveraging existing reservoirs, mine pits or transmission corridors to reduce permitting friction. Market reform kept pace: the National Electricity Market’s evolving capacity and reliability mechanisms increasingly modelled long-duration storage explicitly, rather than assuming batteries could do the job alone.
The Americas: diversification, divestments, and drought lessons
Brazil, historically the world’s hydropower bellwether, spent 2025 extending a trend that would have sounded like heresy a decade ago: leaning more on wind and solar to hedge hydro’s hydrology risk. In August, wind and solar together supplied a record one-third of the country’s electricity, while hydro’s share fell to a four-year low. The good news: fossil backup stayed muted. The takeaway: climate variability is now baked into dispatch planning, and market rules need to reward both flexibility and firming.
Policy and procurement followed suit. In August, energy auctions focused on modernising and optimising existing hydro fleets rather than adding new mega-dams, which is consistent with Brasília’s post-Belo Monte stance that large Amazonian projects carry political and environmental costs out of step with today’s climate and biodiversity priorities. Meanwhile, researchers quantified the economic drag deforestation imposes on hydropower output, putting real money on the table for forest protection as energy infrastructure risk mitigation.
To the north, the US saw fewer ribbon cuttings and more paperwork. 2025 was a permitting year for PSH, with the Federal Energy Regulatory Commission (FERC) advancing major environmental reviews such as the draft EIS for the Seminoe PSH project in Wyoming. Faster, clearer federal permitting is the difference between decade-long limbo and bankable timelines. Industry data roundups this autumn underscored the same message: the project pipeline is large, but only regulatory throughput (and a revenue model for long-duration services) will convert “paper GW” to shovels and steel.
Across the Andes, Peru surfaced repeatedly this year for both grid modernisation and the politics of new dams. UNOPS announced upgrades to core hydropower components on the Mantaro system while debate reignited over the long-stalled Pakitzapango project and its social footprint. The pattern echoed across the region: rehabilitation and uprating of existing plants moved faster than greenfield mega-hydro, which faces stiffer scrutiny over displacement, biodiversity, and river ecosystem impacts.
South and Central Asia: from “build” to “bankable”
Central Asia’s hydro potential returned to the front burner with the EU, EIB, and EBRD sketching a financing pathway for Kyrgyzstan’s 1,860MW Kambar-Ata-1. An indicative package discussed in October – up to $1.5 billion in EBRD sovereign loans among a wider funding stack – signalled that IFIs are willing to underwrite complex transboundary projects when governance and benefits are credibly shared. Meanwhile, the EU’s “Global Gateway” stitched hydropower deeper into its development diplomacy, with new investments across the region.
In Tajikistan, the Sebzor plant was inaugurated under the Global Gateway umbrella, a more modest project by megawatt count, but transformative locally, with reliability gains for more than 430,000 people in underserved areas and spillover benefits for cross-border power links. These are the kinds of projects that don’t trend on social media but change daily life: lights that stay on, clinics that refrigerate vaccines, small enterprises that finally buy machinery etc.
India offered a study in contrasts. On paper, the country extended a crucial inter-state transmission charge waiver for storage – including pumped storage – through June 2028, a clear policy nudge to get long-duration capacity built. In practice, the near-term storage buildout skewed toward batteries, and even that slowed sharply in 1H 2025, with analysts flagging only 48–49MWh of new energy storage commissioned in the half and a modest 490 =MWh cumulative base by June. Hydropower’s installed PSH base remained about 5GW, respectable, but far shy of what planners say is required by 2030 to firm 500GW of non-fossil generation. The good news: India’s policy levers are now calibrated to favour storage, and record-setting renewable output in May showed why those levers matter.
The Nordics: wrestling with rivers, markets, and money
Norway – Europe’s hydropower heart – lived out hydropower’s political complexity in public this year. Parliament greenlit a law allowing new hydropower on previously protected rivers (over 1MW) in cases of “significant societal benefit” and acceptable environmental impact, pitting flood protection and electrification goals against biodiversity and conservation priorities. Later in the year, MPs looked set to block a proposed tax increase on small hydro, reflecting the delicate equilibrium between extracting more value from resources and keeping investment attractive. Meanwhile, utilities pressed ahead with high-value uprates and refurbishments, and the government rolled out a new household price-stability scheme to buffer consumers from volatility tied to continental market coupling.
Behind the politics, the project work continued. Aker Solutions secured a major rehabilitation package at Blåfalli Fjellhaugen, one of the country’s largest new hydro builds in two decades, underscoring the scale of Norway’s modernisation wave. This year, Norway also attracted attention as a power-rich location for energy-intensive computing projects – proof that hydropower’s role in “new electrification” reaches well beyond heating and EVs.
Standards, sustainability, and social license
The sector’s social and environmental ledger was busy. Coire Glas’s Gold rating under the Hydropower Sustainability Standard marked a turning point: it showed a developer can embed best practice before shovels hit ground, not just certify after commissioning. For regulators and financiers, this provides a process blueprint; for communities, it offers a clearer way to judge whether promises on labour, biodiversity, and cultural heritage have teeth. Expect more lenders to require HSS or equivalent frameworks in 2026 financings.
But the year also reminded us that social license is earned, not inherited. In Brazil’s Xingu basin, legal fights over Belo Monte’s flow regime intensified, with Indigenous communities and fishers arguing that reduced natural flows along the Volta Grande are incompatible with both livelihoods and biodiversity. Research released this year put dollar signs on deforestation’s drag on generation at marquee plants like Itaipu and Belo Monte – aligning conservation and energy security in ways that could reshape basin management and compensation schemes.
Technology and asset management: uprate, digitise, de-risk
Away from large headlines, 2025 was rich with the kind of incremental improvements that compound over time. In Peru, modernisation of turbines, generators, and fire systems on the Mantaro complex exemplified a global wave of reliability-driven upgrades – with procurement standards now tying equipment replacement to water quality and greenhouse-gas co-benefits. In the Alps and Scandinavia, uprates and cavern retrofits pushed more megawatts through existing penstocks. And across all regions, digital twins and condition-based maintenance crept from pilot to practice, supported by lenders who now see O&M analytics as a bankable efficiency lever.
Hydro manufacturers also had a showcase year. The Limberg III build demonstrated the tight choreography now common in PSH – massive component lifts (a 355-ton rotor in May), high-precision civil works, and formwork innovations that make nine-meter dam raises feasible on short alpine construction windows. Suppliers leaned into modularisation and pre-assembly to keep schedules on track despite labour shortages.
Markets and money: finally paying for flexibility
Hydropower’s economic case has always been strongest when grid operators value what only hydro can do: inertia, black-start, seasonal storage, minute-to-minute regulation, and long-duration shifting measured in days, not minutes. 2025 saw real movement toward that valuation. In Britain, the conversation around cap-and-floor-style support for long-duration storage migrated from think-tank papers to policy scaffolding; the capacity market rewarded PSH portfolios, and investors started to price a lower revenue-risk profile into models. On the continent, the shift to 15-minute markets and the spread of scarcity pricing increased the upside capture for flexible assets. In the US, while the patchwork remains, federal process on PSH permitting sharpened and state IRPs increasingly modelled long-duration storage explicitly rather than treating it as an add-on to batteries.
International finance also tilted green in ways that matter for hydro. The EBRD, EU, and partners put hydropower upgrades and greenfield anchors onto priority lists in the Western Balkans and Central Asia, packaging grants with sovereign loans to crowd in private capital. Where older fleets dominate, blended finance for rehabilitation, paired with environmental remediation, looks set to be 2026’s biggest hydropower investment theme.
Water and climate volatility
Climate remained the wildcard. Europe’s hydropower generation rebounded in 2024 after a bruising 2022–2023, and that recovery rolled into 2025 in many basins. But South America’s El Niño-intensified droughts stressed systems and tested dispatch strategies; in Brazil, the diversification to wind and solar proved its worth, but policy now has to catch up with multi-year hydro variability. Globally, the IHA Outlook emphasised that hydropower’s value grows as climate makes grids spikier, provided dams and reservoirs are operated with water, biodiversity, and downstream communities front of mind.
The research linking forest cover to hydropower output sharpened that point. If deforestation can erase tens to hundreds of millions of dollars a year from flagship plants, then watershed management is not a social program, it’s risk management and revenue protection. Expect more PPAs and concession agreements to incorporate basin-level conservation covenants, and more utilities to join jurisdictional deforestation-free compacts.
Key points from 2025
1) Scale returned, but with new guardrails. GERD’s inauguration showed large hydro is not dead; Limberg III proved PSH can still be built on time in Europe. But both were accompanied by tighter standards, stronger social expectations, and a recognition that basin health equals project health.
2) Pumped storage moved from “should” to “shall.” China’s buildout dwarfs the field, Europe is modernising the rules, and the UK is inching toward durable revenue models. The US is looking to clear permitting pathways. Could 2026 see more financial closes on PSH than any year since the 1980s?
3) Rehabilitation is the fastest decarbonisation dollar. From the Balkans to Peru and Norway, uprates and rehab packages are stretching MWs and MWhs within existing footprints. Lenders like EBRD are leaning in with blended capital.
4) Markets started to pay for flexibility. Cap-and-floor concepts, scarcity pricing, shorter market intervals, and adequacy products are turning PSH economics from a hand-wave to a spreadsheet.
5) Social license is the gating item. 2025 reminded us that hydropower is as much about communities and rivers as it as about turbines and transformers. Successful projects in 2026 are likely to be the ones that engage early and prove benefits continuously.
