Australia’s Capacity Investment Scheme is beginning to translate policy ambition into contracted capacity, with more than 2 GW of new renewable generation and nearly 500 MW of battery storage awarded across Western Australia at a time when the state is preparing to retire its remaining coal-fired power stations by 2030.
The scale of the latest tender results highlights both the urgency of the transition and the growing reliance on structured revenue mechanisms to de-risk large-scale clean energy deployment.
The federal government’s latest allocation under the Capacity Investment Scheme supports almost 1.9 GW of renewable generation and 482 MW of battery energy storage across 10 projects, representing more than $5 billion in investment. These assets are expected to be operational by the end of the decade, aligning directly with Western Australia’s coal phase-out timeline. The timing is critical. As dispatchable fossil capacity exits the system, replacement infrastructure must not only match energy output but also maintain grid stability in a system with increasing shares of variable generation.
The composition of the awarded projects reflects this dual requirement. Seven projects selected under the generation-focused tender include a mix of solar and wind assets, with wind accounting for approximately 1,536 MW of capacity and solar contributing through hybrid configurations. Among them is Trinasolar’s planned Killawarra project, combining 350 MW of solar with a 2,100 MWh battery system. This pairing signals a broader shift toward co-located generation and storage, where output smoothing and dispatchability are designed into projects from the outset rather than retrofitted.
Parallel to generation expansion, the storage-focused tender adds three large-scale battery projects designed to provide dispatchable capacity. Notable developments include the Collie hybrid project led by Plenary Group and Enpowered, integrating a 200 MW battery with 1,518 MWh of storage alongside a smaller solar component. Additional projects such as Neoen’s 1,600 MWh Yathroo battery and Frontier Energy’s Waroona installation further reinforce the emphasis on long-duration storage as a core system requirement rather than a supplementary asset.
The oversubscription of both tenders provides a clearer signal about market readiness. A total of 25 projects competed for capacity allocations, enabling the government to exceed its original targets. Generation awards increased from an initial 1.6 GW target to nearly 1.9 GW, while dispatchable storage capacity expanded from a planned 2,400 MWh to approximately 3,600 MWh. This level of competition suggests that project pipelines are not the primary constraint. Instead, the bottleneck lies in securing revenue certainty and grid integration pathways.
This is where the structure of the Capacity Investment Scheme becomes central. The program offers long-term revenue agreements with defined floor and ceiling price mechanisms, effectively underwriting projects against market volatility. For developers and investors, this reduces exposure to wholesale electricity price fluctuations and improves the bankability of capital-intensive assets such as utility-scale batteries. At the same time, it introduces a managed market dynamic in which government-backed contracts play a growing role in determining which projects advance.
Nationally, the scheme has already selected 65 projects, representing 13 GW of renewable generation and 21.6 GWh of dispatchable capacity. The broader target is 40 GW of new solar, wind, and storage capacity by 2030. These figures indicate a rapid scaling trajectory, but they also raise questions about system integration. As more capacity is added under contract, grid congestion, transmission availability, and connection timelines become increasingly critical variables that could delay project delivery even after financial close.
Western Australia presents a particularly complex case. Its grid is geographically isolated from the eastern states, limiting the ability to balance variability across wider regions. This increases the importance of localized storage and flexible generation assets. The concentration of new projects in regional areas such as the Wheatbelt and the state’s southwest introduces additional transmission considerations, as infrastructure must be capable of transporting energy from generation sites to demand centers without creating bottlenecks.
The transition also carries labor and economic implications. The awarded projects are expected to generate around 7,000 construction jobs, reflecting the scale of activity required to replace legacy generation assets. However, the long-term employment profile of renewable and storage projects differs significantly from coal-based systems, raising questions about workforce transition strategies in regions historically dependent on fossil fuel industries.
As contract negotiations proceed, the presence of a reserve list within the tender framework adds another layer of flexibility. Projects that demonstrated sufficient technical and commercial merit but were not initially selected may still be advanced if primary projects fail to reach execution. This mechanism acknowledges the execution risk inherent in large-scale infrastructure development and provides a buffer against potential delays.
