Valo's 1.6 GWh Teebar Battery Will Steady Queensland's Grid Like a Power Plant

On October 9, Atmos Renewables announced it had chosen a new name in battery storage to build one of the biggest batteries in Queensland. Valo, the joint venture that Finnish technology group Wartsila and German engineering firm RCT Solutions launched eight days earlier, will deliver the 400 MW / 1,600 MWh Teebar battery energy storage system in the Fraser Coast region, adjacent to the Teebar Creek Substation. The project is expected to reach commercial operation in late 2028, and at its size it ranks among the largest battery systems currently committed to construction in Queensland.

The headline numbers, 400 megawatts of power and 1,600 megawatt-hours of storage, mean the battery can discharge at full power for four hours. But the more consequential detail sits further down in the announcement: Teebar has secured Generator Performance Standards approval to operate in grid-forming mode on Australia's National Electricity Market. In plain terms, the battery will not just buy and sell electricity on price signals. It will actively hold the grid's frequency and voltage steady, performing a job that once belonged almost exclusively to spinning turbines in coal and gas plants.

That shift, from battery as merchant to battery as infrastructure, is the story behind the story. As Australia retires coal plants and floods its grid with wind and solar, somebody has to keep the lights stable when clouds cross the sun or the wind drops off at dinner time. Teebar is a bet that batteries, properly controlled, can do that job at utility scale.

The Teebar deal, in numbers

Teebar is a four-hour battery: 400 MW of power capacity and 1,600 MWh of energy. The distinction matters. Power capacity determines how much electricity the battery can push onto the grid at once; energy capacity determines how long it can keep pushing. Four hours covers the evening demand peak that now stresses grids with heavy solar penetration, when output from rooftop and utility solar collapses just as households switch on appliances.

The project's location is deliberate. Siting it next to the Teebar Creek Substation plugs it directly into high-voltage transmission, which minimizes new wiring and lets the battery respond to grid disturbances in the microsecond timescales that matter. Valo will also support Atmos Renewables in meeting the performance, reliability, and social license requirements of Australia's Capacity Investment Scheme, the federal government program designed to accelerate investment in reliable clean energy infrastructure. The scheme effectively underwrites a revenue floor for projects like Teebar, which is why batteries of this scale are now clearing financial commitment in Australia.

Commercial operation is targeted for late 2028, which sounds far off but reflects the reality of grid-scale projects: land, permits, grid connection studies, and equipment procurement all take time. The Generator Performance Standards approval, already secured, is one of the harder milestones, because it certifies that the battery's control systems can behave correctly under fault conditions instead of tripping offline when the grid needs them most.

What Valo actually is

Valo is barely a week old as a company, but it is not a startup. Wartsila announced the joint venture on June 15 and closed it on October 1, transferring its entire global energy storage business into a company owned equally with RCT Solutions. The new integrator starts life with more than 20 GWh of projects across more than 130 sites worldwide, and in Australia alone it holds 7.5 GWh across 10 utility-scale projects. Peter Fath, formerly chief executive of RCT Solutions, leads the company as CEO, with Luke Witmer as chief technology officer.

The logic of the deal is vertical integration. Wartsila contributes battery storage technology, controls and optimization software, and a global customer base; RCT Solutions contributes engineering depth, manufacturing experience, and supply chain capability. Customers should not have to manage a collection of technologies and vendors and hope everything works together as intended, Witmer said when the venture launched. The performance of an energy storage project depends on how effectively every element of the system is managed altogether.

There is also a harder business reality. Wartsila has been open that the joint venture will lose money in 2026, estimating a 40 to 50 million euro hit to its full-year operating result, driven by low recent order intake and transformation costs including a write-down of capitalized research and development. It expects Valo to turn positive toward the end of 2027. That candor is unusual and worth noting: even as the storage market booms, the business of integrating these systems is getting more complex, not less, and scale has not yet delivered comfortable margins.

Grid-forming: the battery's second job

Most batteries on the grid today are grid-following. They watch the grid's voltage and frequency, set by big spinning generators, and inject or absorb power in response to price signals. Grid-forming batteries do something harder: their inverters establish the voltage waveform themselves, providing what engineers call system strength, the grid's resistance to disturbances.

Teebar will not just store electricity for later. It will hold the grid together the way a coal plant's spinning turbines once did, except it can respond in milliseconds rather than seconds.

That capability is increasingly the point of building big batteries. Queensland's grid, like grids everywhere with rising renewable shares, needs stability services as much as it needs stored energy. A battery that can only arbitrage prices is a trading asset; a battery that can also form the grid is infrastructure, and grid operators pay accordingly. Teebar's GPS approval for grid-forming operation in the NEM is the regulatory confirmation that the project has crossed that line.

Australia's storage arms race

Teebar is one project in a much larger build-out. Industry forecasts cited by the companies value Australia's battery storage market at 2.24 billion US dollars by 2030, driven by coal retirements and the rapid growth of wind and solar. Batteries are increasingly being specified not only to shift energy from midday to evening but to respond in microseconds to fluctuations in supply and demand and to meet technical requirements set by grid operators.

The pattern is visible in the numbers Valo carries into the market: 7.5 GWh across 10 projects in Australia alone, against a global portfolio of more than 20 GWh. A decade ago, a 400 MW / 1,600 MWh battery would have been a world-record project; today it is one committed project in one state of one country's pipeline. The technology has crossed from novelty to procurement category, and Teebar's grid-forming approval suggests the next frontier is not bigger batteries but batteries that do more.

Whether Valo's integrated model proves better than the fragmented supply chains it wants to replace is still an open question, and its own projected 2026 losses are a reminder that delivering these systems at scale remains genuinely hard. But if Teebar comes online in late 2028 doing what its approvals promise, Queensland will have one of the clearest demonstrations yet that a battery can be a power plant in everything but name.