Batteries sweep Australia grid tender as gas fails to compete on cost

Batteries sweep Australia grid tender as gas fails to compete on cost Long-duration storage and battery hybrids dominate the latest firming auction, leaving gas-fired capacity on the sidelines. Australia’s Capacity Investment Scheme awarded 19 projects in its latest tender, with battery hybrids and the 1.45 GW Yanco Delta wind farm capturing the bulk of capacity, Renew Economy reported on Friday (2026-05-22). Not a single gas-fired generator made the cut.^4,5 That matters for New South Wales and Victoria power markets, where baseload coal retirements are accelerating. The CIS tender was explicitly open to gas peakers and combined-cycle plants alongside storage, yet every winner that will provide dispatchable firming capacity is a battery or battery-backed renewable hybrid.⁴ Origin Energy secured the largest single project award to date in the program, the 1.45 GW Yanco Delta wind farm in south-west New South Wales. Origin hopes to reach a final investment decision by year-end or early 2027, subject to state planning approvals.⁵ The outcome marks a shift in Australia’s firming market. Battery costs have fallen far enough that grid-scale storage can undercut gas on a levelised basis for short-duration peaking and intraday shifting. The CIS tender design pays for firm capacity, not energy, which advantages quick-responding batteries over thermal plant that must recover fuel costs.⁴ Regulators and the federal government are watching closely. Climate Change Minister Chris Bowen’s recent comments on the Energy Insiders podcast triggered speculation that tender 9 could include adjustments to the CIS framework. Those tweaks may aim to ensure gas still has a pathway for multi-day firming that batteries cannot yet economically address.⁴ The longer-duration storage tender, expected soon, will be the real test. If battery projects with four-to-eight-hour durations win that round too, it will confirm that the economics have flipped even for overnight capacity. Gas generators would then be limited to seasonal or emergency-only roles.⁴ France is facing a different version of the same calculus. EDF said on Wednesday (2026-05-20) that electrification is “imperative” for France after the latest energy shock from the Iran war, announcing a plan to increase power demand by 5.5 TWh, or 1% per year. New heat pumps and electric trucks could add 0.5 TWh annually, while EDF would offer “turnkey sites” with grid connections to new industrial customers.² EDF OA, the division handling renewable assets under feed-in tariffs, will stop production at 842 MW of solar and wind farms during negative spot price periods from the week of 2026-05-25. That is a direct admission that renewable oversupply is already a grid management problem in France, even as the utility pushes electrification.¹ The French experience echoes wider European grid strain. Increasing frequency of negative prices forces operators to curtail renewable output when storage and transmission capacity are insufficient. That dynamic reinforces the value of flexible capacity, exactly the role batteries are filling in Australia.³ The CIS result is not a policy decision against gas; it is a market outcome. When the tender rules are technology-neutral but the bids come in with batteries cheaper than gas peakers, the technology with the lower cost wins. The question for tender 9 is whether the government decides that neutrality is enough to maintain security through the coal exit.⁴ Watch the long-duration storage tender results and any adjustments to the CIS framework announced later this year. If the rules shift to include capacity credits for multi-day or seasonal firming, gas may get a targeted role. If they do not, batteries will keep sweeping the pool.⁴