A battery storage project financed in Europe today will likely still be running in the late 2040s. The debt behind it almost certainly won’t be. That gap, unremarkable in most infrastructure financing, has become one of the more awkward questions facing lenders to battery energy storage systems (BESS) since the EU’s Extended Producer Responsibility rules for batteries took effect on 18 August 2025.
Regulation (EU) 2023/1542 makes producers responsible, in law, for what happens to a battery once it dies. Under Article 56, that means financing the collection, treatment and recycling of every battery placed on the market, not just offering to take it back. Herbert Smith Freehills Kramer, which has tracked the phased rollout since 2024, notes that producers can delegate the operational side to authorised Producer Responsibility Organisations, but the financial obligation itself sits with them by law. Crucially, as Freeths partners Suriya Edwards and Deborah Harvey point out, the regulation doesn’t let that cost simply get passed down the chain: contractually shifting recycling costs onto end-users, standard practice under the old Battery Directive, is no longer straightforward and may not hold up to legal scrutiny.
That single change reshapes how the liability sits on a project’s balance sheet. A BESS asset typically runs for 15 to 25 years, a range Pinsent Masons cites in its recent analysis of the regulation’s financing implications. Debt doesn’t run nearly that long. Even the more aggressive structures in today’s storage finance market, mini-perm loans stretched toward the 20-year mark, are built around the idea that the loan gets refinanced once the asset has a track record, not that it survives to decommissioning. Sunraise Capital’s underwriting notes for 2026 put it bluntly in the context of tenor mismatches on storage deals generally: a shorter contracted period sitting inside a longer debt tenor “leaves a refinancing tail,” forcing lenders to amortise harder or impose a cash sweep once the gap opens up. The EPR liability is a version of that same problem, except the tail here can run for decades after the debt itself has vanished entirely, refinanced, sold on, or simply repaid.
Pinsent Masons partner Kanyi Lui frames the deeper issue as one of identity as much as timing: “producer status may attach not only to manufacturers but also to importers, distributors, EPC contractors and, in some cases, project owners,” depending on how the supply chain is structured. Foot Anstey’s energy team, advising on UK and EU deals, describes the commercial fight this triggers in practice: importers try to push the obligation onto manufacturers or onto the end-user operating the asset, and end-users resist taking it on precisely because of the financial and regulatory exposure involved. The compromise increasingly seen in contracts, according to the firm, is to leave the formal obligation with the BESS provider but compensate them for the added compliance cost, an arrangement that at least clarifies who owns the risk, even if it does nothing to solve the underlying timing mismatch.
That mismatch is what should worry a credit committee more than the compliance cost itself. A counterparty backing an EPR obligation today, whether a battery manufacturer, an EPC contractor, or a producer responsibility organisation, is being assessed for solvency against a liability that might not crystallise until the 2040s or 2050s. Corporate structures, ownership and creditworthiness over that horizon are close to unknowable at financial close. Pinsent Masons’ own conclusion is that “bankability increasingly depends on whether such liabilities are identified, allocated and adequately reflected in project economics,” which is a polite way of saying that a risk nobody can price with confidence is now expected to sit somewhere in the model regardless.
Other tail-liability sectors offer a comparison, if not a template. Nuclear decommissioning has decades-old, and in some jurisdictions state-backed, funding mechanisms designed for exactly this kind of horizon problem: money set aside during the operating life of an asset to cover costs that fall due long after it stops generating revenue. Battery storage has no equivalent yet. There’s no requirement in the current EU framework for a producer to pre-fund or escrow its future recycling liability against a specific project; the obligation exists in law, but the money to meet it is assumed to come from whatever entity holds producer status when the bill actually comes due.
DNV’s advisory work on battery decommissioning offers one practical, if partial, fix already being adopted: revisiting the decommissioning plan and cost estimate roughly three years before end of operations, rather than leaving it fixed at financial close. That at least keeps the number current. It doesn’t answer who’s still solvent enough to pay it.
The scale of the exposure is only going to grow. Wood Mackenzie forecasts Europe’s cumulative storage capacity expanding at roughly 23% a year over the next decade, according to figures cited by Trina Storage’s own market analysis. Every gigawatt-hour added under the new regime carries this same structural feature: a real, legally assigned liability, sitting decades outside the credit horizon lenders actually underwrite against. From February 2027, that picture gets one layer more concrete, as mandatory battery passports for industrial batteries above 2kWh start generating exactly the kind of lifecycle data, on composition, carbon footprint and recycled content, that will eventually be used to work out who owes what, and how much, when the batteries being financed today finally come off the grid.
