European shift to 15-minute markets boosts battery storage arbitrage profits amid rising renewable variability

Since the European day‑ahead market moved from hourly to 15‑minute Market Time Units on October 1, the economics of battery energy storage systems (BESS) in Europe have improved materially, creating larger and more frequent arbitrage opportunities for storage operators, industry analysts say.

According to the original Rystad Energy analysis, the shift to quarter‑hour pricing has increased arbitrage potential by about 14% on average across European power markets. The gain is uneven: Austria and Slovakia recorded increases of more than 20%, while Portugal, Norway and Sweden saw only modest improvements. Rystad’s modelling shows examples where quarter‑hour trading materially outperforms hourly trading , in Lithuania, 15‑minute shifting earned roughly $263/MWh, about 14% more than hourly trading, and in Germany quarter‑hour arbitrage was roughly 16% more profitable than hourly. The company said in a statement that in markets with large shares of intermittent wind and solar generation, rapid output swings create price moves within an hour that 15‑minute intervals now capture.

Sepehr Soltani, Senior Analyst, Energy Storage at Rystad Energy, summarised the effect: “In countries with less flexibility in power generation and consumption, a high share of intermittent renewables can cause large price swings. Rapid changes in wind or solar generation mean electricity prices can shift noticeably even within a single hour. Shorter 15‑minute trading intervals capture these quick shifts, creating more opportunities for flexible assets. In contrast, in places with a flexible electricity supply, such as Norway with hydropower and Portugal with hydropower and gas, prices are more stable over an hour. As a result, the difference between profits from 15‑minute and hourly trading is much smaller.”

Rystad’s scenarios compare a four‑step charge/discharge arbitrage cycle under 15‑minute markets with a single charge/discharge step under hourly markets, and conclude that finer market granularity expands revenue opportunities for storage. Industry data in the report indicate that if a battery can capture about 20% higher yearly revenues from the added intra‑hour volatility, the project’s cumulative return could rise by roughly three percentage points over a 20‑year horizon.

The analysis also tempers immediate enthusiasm with a realistic view of long‑run margins. Today’s elevated arbitrage spreads , on the order of +$150/MWh in some windows , are unlikely to persist over the next one to two decades. Rystad estimates a more plausible long‑term average of about $60/MWh from pure energy arbitrage, equivalent to roughly a 6% internal rate of return (IRR); increased market granularity could lift that to approximately $70/MWh, adding around three percentage points to IRR. “The biggest challenge for earning money through arbitrage is that price volatility is unpredictable. In Europe, 15‑minute markets only started two months ago. Australia, however, switched from 30‑minute to 5‑minute markets in 2021, and since then the finer time intervals have consistently increased arbitrage profits,” Soltani added.

The Australian precedent is instructive for project planners and investors. Rystad cites New South Wales, where 5‑minute pricing has produced about 20% higher yearly arbitrage revenues than the previous 30‑minute regime, and Victoria, where revenues for 1‑hour arbitrage rose by about 15% since the market tightened its settlement interval. Those outcomes suggest the EU change could deliver persistently higher returns where system flexibility is constrained and renewable penetration is high.

Practical project economics will, however, diverge from theoretical arbitrage maxima. The report notes real‑world revenues on day‑ahead markets will be reduced by conversion inefficiencies, asset availability, market liquidity and hedging strategies that intentionally avoid dependence on occasional extreme price spikes. For developers, operators and corporates pursuing industrial decarbonisation, the implication is clear: finer market granularity strengthens the business case for storage as a system‑level flexibility resource, but reliable, investable revenues still depend on diversified value stacks , capacity, ancillary services, contract revenues and integrated asset operation , rather than pure day‑ahead arbitrage alone.

For asset owners evaluating pipelines or retrofit opportunities, the change raises strategic priorities. Shorter settlement intervals increase the value of fast‑response, high‑round‑trip‑efficiency systems and sophisticated optimisation software capable of exploiting intra‑hour price differentials. Policymakers and market designers should also note that outcomes will vary by member state depending on resources and flexibility: where hydropower and flexible thermal capacity remain dominant, the incremental benefit of 15‑minute pricing is likely to be smaller.

In sum, Rystad’s assessment positions the EU’s move to quarter‑hour pricing as a meaningful structural improvement for BESS revenue potential, particularly in markets with high renewable variability. The enhanced arbitrage opportunity strengthens the storage investment case, but prudent project underwriting will continue to rely on multiple revenue streams and realistic assumptions about long‑term price volatility.