Battery storage has crossed a psychological line. BloombergNEF's 1H 2026 Energy Storage Market Outlook says the world installed 112 GW and 307 GWh of non-pumped-hydro storage in 2025, the first year annual deployments cleared 100 GW. The firm now expects 2026 to be bigger again, with 158 GW and 459 GWh of new storage capacity. 112 GW Global storage power added in 2025 307 GWh Global storage energy added in 2025 158 GW BNEF forecast for 2026 additions The 100 GW era is here For years, energy storage forecasts sounded large, but the installed base was still small compared with wind, solar, gas, and hydro. That is changing quickly. BNEF's 2025 number, 112 GW, was up 48 percent from 2024. The energy capacity number grew even faster as four-hour systems became more common and as developers built larger projects for evening ramps, renewable shifting, and capacity obligations. The distinction between GW and GWh matters. GW measures how much power a storage fleet can deliver at a moment. GWh measures how long it can keep delivering. A 100 MW battery with four hours of duration has 400 MWh of energy. BNEF's 158 GW forecast for 2026 translates to 459 GWh because the average project is no longer a short pilot built for frequency regulation. It is increasingly a grid resource meant to move solar output from noon into the evening or to provide firm capacity during peak demand. That shift changes how system operators think about batteries. Early batteries were often treated as fast gadgets on the edge of the grid. The new fleet is infrastructure. It sits in capacity auctions, transmission studies, utility resource plans, and corporate power procurement models. A technology that used to be measured in demonstration projects is now being measured against gas peakers, transmission upgrades, and reserve margins. China and the US still set the pace China remained the largest storage market in 2025, with roughly 61 GW and 173 GWh of additions, or about 54 percent of global power additions. The buildout is tied to massive solar and wind installations, provincial mandates, grid balancing needs, and a domestic battery supply chain that can deliver very low system prices. Chinese developers have also been willing to build enormous projects quickly, even when utilization and revenue rules are still evolving. The United States ranked second, with about 18 GW and 55 GWh added in 2025, around 16 percent of global power additions. US growth is concentrated in markets where batteries have clear jobs. California uses batteries to move solar into the evening net-load ramp. Texas uses them for price arbitrage, ancillary services, and reliability during extreme weather. Other regions are starting to add storage as solar queues expand and as utilities retire coal plants. Europe is more fragmented. Residential batteries remain important in Germany and Italy, while utility-scale storage is growing in the UK, Ireland, Spain, and parts of Eastern Europe. India is emerging as one of the most important next markets because solar growth, peak demand, and government tenders are converging. BNEF's global forecast rests on the idea that storage is no longer limited to a handful of early adopter grids. Key Insight The storage market is moving from scarcity to scale. The question is no longer whether batteries work on power grids. It is how fast markets, permitting, and interconnection rules can absorb them. Why 2026 is forecast to jump again BNEF's 158 GW and 459 GWh forecast reflects several forces hitting at once. Battery prices fell sharply in 2025, especially for stationary storage packs. Lithium carbonate prices have been far below the peaks of 2022. LFP chemistry has become the default for most grid systems. Manufacturers that built capacity for EVs are chasing storage orders. That combination gives developers cheaper quotes and more suppliers. Demand is also stronger. Solar buildouts create midday oversupply and evening scarcity. Data centers want power around the clock and are pressuring utilities to add capacity faster. Grid operators need resources that can respond in milliseconds but also sustain output for hours. Batteries are one of the few technologies that can be ordered, financed, built, and connected on timelines that are short enough to matter. Policy is helping in many markets. In the United States, standalone storage can qualify for investment tax credits. In China, renewable pairing rules and capacity mechanisms support large projects. In Europe, capacity markets and grid service reforms are making revenue stacks more bankable. In the Middle East, large solar tenders increasingly include batteries so that projects can deliver power after sunset. Utility scale dominates, but the mix is widening BNEF said utility-scale projects accounted for about 85 percent of 2025 storage installations. That share makes sense because large projects can buy equipment at lower prices, connect to high-value nodes, and secure professional financing. Four-hour lithium systems are the workhorse because they match many evening peak needs and have a deep supplier base. But the market is starting to widen. Commercial and industrial customers are using batteries for demand charge management and backup. Residential batteries remain attractive where retail electricity prices are high, rooftop solar penetration is strong, or outage risk is rising. Long-duration storage is still small, but BNEF expects deployments longer than six hours to quadruple to around 2 GW in 2026. That category includes iron-air, flow batteries, thermal storage, compressed air, and longer-duration lithium systems. Sodium-ion is another technology to watch. It is unlikely to replace LFP overnight, but it can reduce dependence on lithium and may fit lower-cost stationary applications if cycle life and bankability improve. Large Chinese manufacturers have already shown sodium-ion products, and storage is a more forgiving first market than premium EVs. The bottleneck is moving off the factory floor The 100 GW milestone proves that the battery industry can build at grid scale. The harder constraints in 2026 are increasingly outside the cell factory. Interconnection studies can take years. Transformers, switchgear, and high-voltage breakers remain tight. Fire codes and local permitting can slow projects that are otherwise ready. Market rules in some regions still do not pay batteries fully for the services they provide. That is the new storage story. The technology is no longer waiting for permission to be useful. It is waiting for power systems to catch up with a resource that can move faster than traditional grid planning.