Swiss investors see battery storage as bankable asset

Swiss investors are increasingly treating battery energy storage systems as bankable assets as new long-term contracts and multiple revenue streams reduce cash-flow volatility. Changes in contract design and market mechanisms in neighboring European countries are cited as influencing investment decisions in Switzerland.

The storage business model has shifted from relying on a single revenue source to stacking income from trading, capacity payments, leasing arrangements and ancillary services. Operators can allocate a battery to the most profitable services for a given asset. Multi-year contracts have emerged that fix part of future revenue and make projects more acceptable to lenders.

In Germany, tolling agreements allow battery owners to lease capacity to traders, utilities or renewable generators under contracts commonly lasting 5-7 years or longer. Traders use leased storage to balance positions and avoid imbalance penalties; utilities and generators can lease flexibility instead of investing up front.

Spain has run auctions for a capacity market that pay storage operators for being on standby to supply power during system shortages. The transmission system operator has set a target of about 1.5 hours of annual shortage; reported figures reached 2.41 hours in 2025 and projections show potential further increases. Winning auctions secures multi-year availability contracts that improve revenue predictability.

Italy operates an incentive scheme known as MACSE that pays storage for readiness to support grid stability in standby mode while allowing operators to pursue other revenue streams. Italy increased battery capacity from roughly 1.1 GWh to more than 7 GWh in approximately two years after launching the scheme.

Additional monetization options in Europe include payments for inertia and black-start capability, which require batteries to provide frequency support or help restore the grid after outages. Standby contracts typically involve fewer full cycles, which can slow battery degradation and extend useful life toward 15-20 years compared with assets used heavily for arbitrage.

Switzerland plans to retire nuclear units in the 2030s and to expand solar generation, creating greater need for flexible capacity to balance variable output. Publicly administered mechanisms and long-term agreements in nearby markets are presented as operational models that can create predictable revenue for storage projects.

Investors and lenders identify three main risk categories. Market risk covers future competition and price conditions; multi-year contracts reduce exposure by fixing part of revenues. Financial risk concerns stable cash flow and the capacity to service debt; banks increase scrutiny as revenue predictability improves. Operational risk relates to whether assets meet performance guarantees, availability targets and maintenance needs; outcomes depend on equipment selection, supplier warranties, spare-part access and operations quality.

Technology choice affects access to revenue streams. Grid-forming systems can provide stability services such as inertia and black start, while older grid-following systems generally cannot. Lithium iron phosphate (LFP) chemistry is widely used for its scalability and lower upfront cost. Alternative chemistries may offer longer life or lower degradation but come with higher costs and require certification and regulatory compliance.

Predictable multi-year contracts, the ability to stack services and wider availability of debt financing are factors changing how storage projects are financed and sized in Europe. Swiss investors evaluating the post-nuclear grid and growing solar capacity are examining these contract frameworks and market mechanisms as part of project planning.