Commercial & Industrial Energy Storage Market (2026-2036)

The commercial and industrial energy storage market covers battery storage systems installed behind the meter at commercial and industrial sites, together with the power conversion, control software and services supplied with them, across systems from below 100 kWh to above 2 MWh and the demand charge management, energy arbitrage, backup power, solar self-consumption, grid service and electric vehicle charging applications they serve. The growth of this market is driven by demand charges in commercial electricity tariffs, by widening time-of-use price spreads, by the cost of outages at sites that cannot interrupt production, and by the use of storage to connect electric vehicle charging without upgrading a site supply.

Revenue in this market comes from avoided cost on an electricity bill rather than from a market price. A commercial or industrial system earns its return by reducing the peak demand a site records, by shifting consumption from expensive to cheaper hours, or by avoiding the loss caused by an interruption, so the value of a system depends on the tariff the site is billed under. The addressable market is therefore defined by tariff design rather than by electricity consumption, and it is concentrated in the regions and utility territories where demand charges are high.

Two United States requirements now apply to projects in this market at the same time. Imported cells carry a 25% tariff from 2026, and a project claiming the investment tax credit must demonstrate that a rising share of its content comes from outside prohibited foreign entities. Both raise the cost of a system and the documentation needed to support it, and the documentation effort does not fall with project size.

A commercial and industrial storage system is installed behind the meter at a site that consumes electricity rather than at a point on the network. It is sized to the load of the site and to the tariff the site is billed under, and it is operated to reduce a cost rather than to sell into a market. These systems typically range from a cabinet of around 100 kWh serving a retail unit to containerised installations of several megawatt hours at a factory, and the control software that decides when to charge and discharge carries as much of the value as the battery.

Demand charges are the largest single source of value and the least understood part of the business. A commercial electricity bill in many territories contains a charge based on the highest level of demand recorded in the billing period, often measured over fifteen or thirty minutes, and that charge can account for a substantial part of the total bill at a site with an uneven load. A storage system that discharges during those few intervals reduces the recorded peak and therefore the charge, and it does so without changing how much electricity the site consumes. The saving depends entirely on the tariff, so an identical system installed at two sites in different utility territories can produce very different returns.

Time-of-use spreads provide the second source of value and have widened as more solar generation has been added to networks. Where the price of electricity differs between hours, a system can charge when prices are low and discharge when they are high, and the value of doing so depends on the size of the spread rather than on the average price. Sites with solar generation gain an additional benefit, since storage allows generation produced at midday to be consumed in the evening instead of exported at a low price, which has become more valuable as export rates have been reduced in several markets.

Trade measures now raise the cost of the equipment. Under the schedule set out in the United States Trade Representative four-year review of Section 301 duties, lithium-ion non-electric vehicle batteries carry a 25% rate applying from 2026, as do natural graphite and permanent magnets. Lithium-ion electric vehicle batteries carry the same rate applying from 2024.

The rate on lithium-ion non-electric vehicle batteries applies directly to this market, because the cells used in commercial and industrial systems fall into that category rather than into the electric vehicle category. Most of those cells are lithium iron phosphate produced in China, so the tariff raises the delivered cost of the largest component in a system from 2026, and the increase is passed into project capital cost at a point where the return is calculated against a bill saving that has not changed.

A second United States requirement applies at the same time and is more demanding to satisfy. Under the One Big Beautiful Bill Act, the material assistance restriction applies to energy storage technology that begins construction after 31 December 2025, and the specified foreign entity and foreign-influenced entity restrictions take effect for the taxable year beginning in 2026. A project must meet a material assistance cost ratio, measured against the cost of manufactured products incorporated into the storage system, with the cost of products mined, produced or manufactured by a prohibited entity subtracted from the numerator. The required share of content from outside prohibited entities rises by the calendar year in which construction starts, at 55% in 2026, 60% in 2027, 65% in 2028, 70% in 2029 and 75% in 2030 and in each year after. Treasury must issue safe harbour tables by 31 December 2026, and until those tables are issued taxpayers may use the tables in Internal Revenue Service Notice 2025-08 for construction beginning on or before 60 days after the new tables appear.

The effect on this market is distinct from the effect on utility-scale storage. A project must now establish where the manufactured products in its system were made, calculate a cost ratio and retain the evidence, and the work involved in doing so is broadly the same whether the system is 500 kWh or 500 MWh. A commercial and industrial project therefore carries a documentation cost that is large relative to its total capital cost, and the smallest systems carry it most heavily. Developers are responding by standardising equipment across projects so that one supply chain assessment serves many installations, which favours suppliers able to provide consistent documentation across a product line.

The rising content requirement also changes procurement over the forecast period rather than at a single point. A project beginning construction in 2026 must show 55% of content from outside prohibited entities, while one beginning in 2030 must show 75%, so a developer planning a pipeline is buying against a moving requirement and needs supply arrangements that improve over time. This favours cells and components produced outside China and gives suppliers with capacity in North America and Europe a position that the tariff alone would not create.

Ownership models matter more in this market than in utility-scale storage because the customer is a business rather than an energy company. A site owner that uses capital for its own operations is frequently unwilling to spend it on an energy asset, so third-party ownership arrangements in which a developer installs and operates the system and shares the saving have become an established route to market. These arrangements also place the tariff analysis and the operating risk with the party best able to assess them, and they are growing faster than direct purchase as a result.

Chemistry has consolidated on lithium iron phosphate for the same reasons as in utility-scale storage, namely cycle life and the absence of nickel and cobalt, with the added consideration that a system installed inside or beside an occupied building is assessed for fire safety by the site insurer and the local authority. Sodium-ion is growing from a small base and suits this market better than it suits vehicles, since weight and volume matter less at a fixed installation and the chemistry avoids lithium supply exposure, while flow batteries remain confined to the small number of sites requiring very long discharge duration.

Two conditions qualify the growth rate in this market. The value of a system depends on a tariff, and a utility that restructures its demand charges or narrows its time-of-use spreads can reduce the return on an installed asset without any change in the equipment or its operation. The second is that the content requirements and tariffs described here are applied by governments and can be changed by them, and the forecast assumes the schedule set out above holds through the period.