Grid-scale battery storage is on a tear. In a single week, utilities and developers on opposite sides of the Pacific announced deals worth billions of dollars and thousands of megawatt-hours, reinforcing the idea that large batteries have moved from experimental curiosity to core infrastructure. Portland General Electric finalized contracts for 650MW of battery storage across Oregon, while Australian developer Edify Energy locked in an EPC partner for 3.6GWh of solar-plus-storage in Queensland. Together, these projects signal that 2026 may become the year grid batteries hit escape velocity. Modern grid management systems coordinate battery dispatch across entire regions. Image: AI-generated Portland General Electric: Oregon's Biggest Clean Energy Deal Oregon-based utility Portland General Electric (PGE) has completed what it calls the largest renewables acquisition in its history. The package spans 1,015MW of combined solar and battery capacity, split between utility-owned assets (42%) and power purchase agreements with third-party developers (58%). Projects are expected to begin serving customers in 2027 and 2028. The contracts emerged from three separate procurement rounds: PGE's 2023 all-source request for proposals, subsequent PPA negotiations, and its 2025 RFP. The Oregon Public Utility Commission oversaw each stage to ensure competitive, transparent bidding. Biglow Optimisation Sherman County, Oregon 125MW solar + 125MW BESS PGE-owned, ~$540M investment. Online late 2027. Wheatridge Expansion Morrow County, Oregon 240MW solar + 125MW BESS Joint ownership, PGE holds 110MW solar + 65MW storage. ~$490M. Meadowlark Battery Washington County, Oregon 200MW BESS Third-party owned, long-term PPA. Online late 2027. Nottingham Battery Washington County, Oregon 200MW BESS Third-party owned, long-term PPA. Online 2028. The four named projects alone account for 650MW of battery storage and 365MW of solar generation. PGE is using existing transmission at the Biglow and Wheatridge sites to reduce interconnection costs, a strategy that more utilities are copying as queue backlogs grow nationwide. PGE is not stopping here. The utility has shortlisted 12 non-emitting projects from its 2025 RFP, targeting roughly 2,500MW of new wind, solar, and storage. It aims to finalize those contracts by the end of Q3 2026, with commercial operation in 2028 and 2029. Australia's Queensland Push: 3.6GWh of Solar-Plus-Storage Large-scale BESS installations are becoming a common sight across Queensland. Image: AI-generated On the other side of the Pacific, Edify Energy has selected DT Infrastructure as the EPC contractor for two massive solar-plus-storage developments in Queensland. The combined capacity is 1,080MWp of solar paired with 900MW/3,600MWh of battery storage. The first cluster, Smoky Creek and Guthrie's Gap in Banana Shire, will feature 720MWp of solar and 600MW/2,400MWh of batteries. The second, Ganymirra and Majors Creek near Townsville, adds 360MWp of solar with 300MW/1,200MWh of storage. Both projects use DC-coupled hybrid configurations, where solar panels feed current directly to batteries through DC/DC converters before a single inversion step for grid connection. DC coupling offers several advantages over AC-coupled systems. It reduces conversion losses by eliminating a second inverter stage, and it allows excess solar generation that would otherwise be clipped to charge batteries directly. Both sites will also use grid-forming inverters, which can synthesize their own voltage and frequency reference rather than relying on synchronous generators. This capability is becoming critical as coal plants retire across eastern Australia. Why It Matters: Queensland's energy roadmap depends on replacing retiring coal capacity with a mix of renewables and storage. At 3.6GWh, these two projects alone could store enough energy to power roughly 300,000 Australian homes for four hours during evening peak demand. Construction is expected to begin in the first and second quarters of 2026, with Edify CEO Ben Warne noting the projects will create hundreds of construction jobs in regional communities. Australia Hits 250,000 Home Batteries Solar-plus-storage installations are scaling rapidly at both utility and residential levels in Australia. Image: AI-generated While utility-scale projects grab headlines, Australia's distributed storage sector is quietly building momentum of its own. The federal government's Cheaper Home Batteries Program has now surpassed 250,000 residential installations, delivering 6.3GWh of distributed energy storage across the country. Those 250,000 home batteries serve a dual purpose. Homeowners use them to store rooftop solar for evening consumption, cutting their electricity bills. Aggregated into virtual power plants, those same batteries can inject power back into the grid during demand spikes, reducing the need for gas peaker plants. The residential battery boom complements the utility-scale buildout. A grid with both centralized BESS facilities and thousands of distributed home batteries is more resilient than one relying on either alone. Centralized systems handle bulk energy shifting and frequency regulation; home batteries provide local backup and reduce transmission congestion. The Manufacturing Race Behind the Deployments Battery cell production lines are running at record throughput to meet surging grid storage demand. Image: AI-generated Behind every gigawatt-hour of deployed storage sits a supply chain racing to keep up. Global battery cell production capacity is expected to exceed 3,000GWh annually by the end of 2026, according to multiple industry trackers. LFP (lithium iron phosphate) chemistry dominates the grid storage segment, prized for its longer cycle life, lower fire risk, and freedom from cobalt and nickel price volatility. CATL, BYD, EVE Energy, and several other Chinese manufacturers account for over 80% of global LFP production. Western efforts to build domestic supply chains are progressing, though slowly. The U.S. Inflation Reduction Act continues to drive factory announcements in Georgia, Michigan, and Nevada, but most of those plants are targeting EV cells rather than the larger-format cells used in stationary storage. Cell prices for LFP grid storage packs have fallen below $70 per kWh at the pack level in early 2026, down from roughly $100/kWh two years ago. That price drop is a key reason utilities like PGE can justify billion-dollar storage investments: at current costs, a four-hour battery system can pay for itself within seven to ten years through energy arbitrage and capacity payments alone. What Comes Next for Grid Storage The PGE and Edify announcements fit a pattern that has been building for several years. According to BloombergNEF, global energy storage installations reached 185GWh in 2025, up from 120GWh in 2024. Projections for 2026 range from 250GWh to 300GWh, depending on how quickly interconnection queues clear and whether supply chain bottlenecks ease. Several factors could accelerate or slow that trajectory. On the positive side, falling cell costs, maturing grid-forming inverter technology, and strong policy support in the U.S., EU, and Australia are all pushing deployments higher. On the risk side, interconnection delays remain a persistent bottleneck, raw material prices (especially lithium carbonate) can spike unpredictably, and some regions still lack clear regulatory frameworks for storage compensation. The Bottom Line: Grid-scale battery storage crossed a threshold in early 2026. Utilities are no longer running pilot projects or hedging with small installations. They are committing billions to multi-hundred-megawatt systems. The question is no longer whether batteries will become a core part of the grid, but how fast the supply chain can deliver them. For the battery industry, the message is clear: the market is here, and it is growing faster than most forecasts predicted even two years ago.