Member briefing | Energy strategy, flexibility, and market developments
Battery storage is becoming a normal part of power-market design. Members should understand where batteries reduce costs, where they protect operations, and where they only move risk from one place to another.
A few years ago, many commercial battery discussions started with backup power or an isolated sustainability story. Today the conversation is broader. Batteries are being used to shift renewable generation, support local grids, reduce peak exposure, participate in balancing markets, and protect operations where power quality matters.
The IEA reports strong global growth in battery storage capacity, with power-sector batteries and data-centre UPS systems both expanding. That matters because battery economics improve when the same asset can serve multiple value streams. A battery that only avoids one peak a month may be hard to justify. A battery that manages peaks, supports a flexible contract, absorbs excess solar, and provides resilience can look very different.
The first question is not “what size battery should we buy?” It is “what problem do we want storage to solve?” A manufacturing site with sharp demand peaks has a different case than a cold-storage facility with thermal flexibility. A charging depot has different constraints again. The same technology can serve all three, but the control strategy, metering, and commercial arrangement will not be the same.
A useful storage assessment starts with interval consumption, contracted capacity, local grid constraints, onsite generation, operational limits, and market access. Without those inputs, the calculation becomes a generic spreadsheet. With them, the discussion becomes practical: which hours cause cost or risk, which processes can move, and which value streams can be stacked without disrupting the business.
In constrained grid areas, storage can sometimes reduce the size of a requested connection or make a non-firm connection more workable. It can also support co-location models where solar, wind, battery storage, and load share a connection point. Those models require careful design. The asset has to fit the operational reality of the site and the rules of the grid operator.
This is where documentation becomes surprisingly important. If a company wants to use a battery as part of a connection or flexibility arrangement, stakeholders need a clear record of what the asset does, where it is connected, what meter it relates to, and how performance is measured. File records, meter associations, and generated reports create the audit trail that makes the commercial arrangement easier to defend.
Battery projects can underperform when the assumed revenue stack is too optimistic, when dispatch control is separated from operational constraints, or when market rules change. The risk is not a reason to ignore storage. It is a reason to be precise. A storage project should describe which value streams are core, which are optional, and which require future market access.
Members should also pay attention to degradation, warranty conditions, safety requirements, and data ownership. A battery is a physical asset, a software asset, and a market asset at the same time. The contractual setup needs to reflect all three.
Before inviting suppliers, gather at least a year of interval data, the current connection agreement, peak demand history, onsite generation profiles, planned electrification projects, and operational rules for critical loads. Ask for a value case that separates energy arbitrage, peak reduction, grid services, resilience, and sustainability benefits.
Battery storage is no longer a niche technology, but that does not make every project automatically good. The best projects are the ones where data, operational control, and contract design line up. For Scholt members, that means the energy team should treat storage as part of a wider flexibility portfolio rather than a standalone box on the site map.