Europe’s clean energy deals: Volatility, flexibility and M&A

Europe’s electricity prices are bouncing between the floor and the ceiling, again emphasising the critical need for flexibility in power generation.

Explore our analysis this week for the underlying drivers, and take a look at the week’s key deals.

• VARO Energy has acquired Preem, now rebranded as VAROPreem, in a transaction that positions the group as Europe’s second-largest producer of renewable fuels.
• EnBW has sold its stake in the 1.5 GW Mona offshore wind project to JERA Nex bp following the UK CfD setback, underlining tighter capital discipline and a broader repositioning among offshore wind players.
• Alpiq has acquired the Cheviré battery storage facility (100 MW / 200 MWh) from Harmony Energy, securing France’s largest operating storage asset and expanding its exposure to flexibility assets in key markets.

Connect with me on LinkedIn to stay on top of Europe’s latest moves.

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Deals breakdown

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Europe’s power prices are sending a clearer signal: Flexibility is the new premium

Europe has just hit a milestone that would have sounded fanciful not long ago: wind and solar generated more electricity in the EU in 2025 than fossil fuels, with wind and solar at 30% of generation versus 29% for fossil fuels.

Now, the more instructive news is what happens next: the system is increasingly shaped by when renewables produce, not only how much they produce. 

And this is where price behaviour becomes the real story: dispersion across markets, sharper swings, and more frequent ultra‑low (and sometimes negative) price periods.

A new report from Ember Energy, European Wholesale Electricity Price, shows that between November/December 2025, the headline was not a single “Europe price” but how far apart markets can be on the same day. 

• In this two‑month window, the average daily spread between the cheapest and most expensive market was roughly €110/MWh, and the extremes were striking: from €0.42/MWh (Sweden, 27 Dec) to €275.76/MWh (Ireland, 26 Nov).

That widening gap is consistent with what Eurelectric flags at the structural level: Europe is entering a “second stage” transition where the challenge is less about building clean generation, and more about absorbing it, with electrification still relatively stagnant and flexibility still insufficient. 

• Eurelectric notes that negative price hours have surged in recent years, and ties the phenomenon to a combination of high renewable output, low/rigid demand, and limited flexibility (including storage and demand response).

What is driving the volatility (and why it matters for dealmaking)?

A useful way to frame it is: the system is learning to price “shape”.

• When supply is abundant and demand is not (especially during high solar or high wind periods) the market pushes prices towards ultra‑low levels.
  
• When the marginal unit is still fossil‑linked (often gas), prices can swing back quickly, and the system can revert to expensive hours. Reuters points to exactly this dynamic: gas generation rose due to lower hydro, lifting costs, and wholesale prices were higher during gas‑heavy hours.

Spain is a live case study of the renewables‑heavy version of this problem. Reuters reports that Spain recorded hundreds of hours of zero or negative prices over the year (UNEF’s warning), with the industry stressing that low and unstable capture prices can threaten the economics of the transition if flexibility does not scale with generation.

Europe is not one market, and that fragmentation is investable

This is where the story crosses even more with M&A: location and market design details increasingly drive value.

In the same November/December 2025 window, some markets were structurally lower (Nordics, Iberia), while others showed higher levels and sharper spikes (parts of Central/Eastern Europe and more constrained systems). That matters because it changes underwriting assumptions:

• Merchant risk is no longer a generic input. It is market‑specific and increasingly shape‑dependent.
  
• Capture prices and curtailment exposure become central, particularly for solar‑heavy portfolios.
  
• Route‑to‑market strategy (PPAs, CfDs, hedging structures, negative‑price provisions) becomes a valuation driver.

Eurelectric’s point is worth taking seriously here: ultra‑low and negative prices are not “a surprise bug”. They are a market signal that the system needs more flexibility and more electrification, not less renewables. 

The near‑term implication for investors is more practical than philosophical: the winners will be the platforms that can monetise volatility rather than be penalised by it.

Where BESS enters the picture: From “nice to have” to system infrastructure

ING Research highlights that battery system costs declined materially over 2020–2025, and frames this as a key enabler for rapid capacity growth in the years ahead. 

Lower capex does not eliminate risk, but it does change the dynamics: more projects can clear investment hurdles, and more grids can procure flexibility at scale.

Now combine that with the price reality: in a system with frequent low‑price periods and pronounced evening peaks, BESS is economically positioned to do three things at once:

1. Arbitrage (shift low‑price energy into peak hours);
   
2. Provide balancing and ancillary services, and;
   
3. Reduce curtailment and stabilise capture prices for solar and wind (especially in hybrids).
   

SolarPower Europe reports that Europe installed 21.9 GWh of BESS in 2024 (another record) although growth slowed to 15% as the market transitioned away from a residential‑led surge and towards a more grid‑scale‑driven phase.

Crucially, the same outlook expects growth to reaccelerate: under the Medium Scenario, annual deployments rise to 118 GWh by 2029, with grid‑scale BESS expanding its share of annual additions (SolarPower Europe).

That is a meaningful shift for M&A: The centre of gravity moves from fragmented behind‑the‑meter volumes to build‑to‑own grid‑scale assets, where revenue stacking, connection rights, permitting, and dispatch strategy become core diligence topics. 

According to Enerdatics, across key geographies, deal activity clusters around solar and wind, but the presence of BESS and solar+storage is increasingly visible.

The investment takeaway?

Europe’s clean power build‑out is not slowing: it is moving into a more operationally complex phase. The premium is shifting from “can you build renewables?” to:

• Can you secure grid access and dispatch optionality?
• Can you manage capture price risk?
• Can you monetise volatility through storage, hybrids, and sophisticated route‑to‑market structures?
  

What’s your answer?

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