Australia set a national record for grid-connected clean energy in the 2025/26 financial year — but the data released by the country’s energy market operator on Sunday reveals a transition that is running hard in one direction while stalling in another. Battery storage is dominating every stage of the connections pipeline, three-quarters of new projects are being engineered to replace the grid stability functions once provided by coal’s spinning turbines, and real-world deployment records are falling across the country. Wind energy, the technology Australia actually needs to generate electricity at scale, is conspicuously absent from most of those milestones — and analysts now put the federal government’s 82% renewable electricity target for 2030 at serious risk as a result.
The Australian Energy Market Operator’s FY2026 Connections Scorecard, published July 20, reported that a record 9.1 GW of new generation and storage capacity reached full output in the financial year ending June 30 — more than double the 4.4 GW delivered in FY2025. The 34 projects that crossed the finish line also delivered 12.9 GWh of combined storage capacity. On paper, those are the strongest figures the NEM has ever recorded. In practice, more than half of that 9.1 GW figure — just over 5 GW — came from large battery installations, which store and shift electricity rather than generate it, according to analysis from RenewEconomy editor Giles Parkinson.
Australia Hits Its Best Connections Year, Powered by Batteries
The June 2026 quarter delivered 3.9 GW of capacity across 14 projects, including 400 MW of standalone solar, 500 MW of co-located solar-and-battery systems, 2.7 GW of standalone battery storage, and 200 MW of wind generation. Battery projects now account for 52% of total capacity in the broader connections pipeline, which grew 42% across the financial year — from 53 GW to 75.4 GW.
“A record 9.1 GW of new generation and storage capacity reached full output in the last financial year, more than double the result achieved in FY25,” said Margarida Pimentel, AEMO’s Group Manager for Onboarding and Connections.
Solar-plus-battery hybrid projects are becoming a structural force in the pipeline. Applications for co-located systems made up 18% of all new applications received during the financial year, representing 4.3 GW. In addition, developers behind 2.4 GW of existing standalone solar projects commenced or completed processes to retrofit battery storage — a direct response to the economics of shifting cheap midday solar generation into the higher-priced evening peak.
Wind did have one standout data point: AEMO received a record 12 wind project applications totaling 5.2 GW during FY2026 — the highest single-year application volume ever recorded for wind in the NEM. Applications, however, are a long way from project completions, and the gap between the two defines the central problem in Australia’s transition.
Grid-Forming Batteries Are Rewriting Grid Architecture
The most consequential technical development in the FY2026 scorecard data is not the total gigawatt figure — it is what type of battery technology is filling the pipeline. Around 74% of battery storage projects in Australia’s NEM connections pipeline are confirmed to be equipped with grid-forming inverters, according to AEMO’s Q1 2026 Connections Scorecard data.
The distinction between grid-forming and grid-following inverters is not a minor engineering detail. A conventional grid-following inverter — the type used in virtually all early-generation solar and wind projects — requires an existing stable grid signal to synchronize against. It cannot operate in isolation and contributes no stability to the grid during a disturbance. A grid-forming inverter, by contrast, creates its own voltage and frequency reference. It can operate into a de-energized grid, participate in black-start recovery, and — critically — provide synthetic inertia.
Inertia is the property that made coal and gas generators inherently stabilizing: the enormous rotating mass of a steam turbine takes time to decelerate when generation suddenly drops, giving grid operators a window to bring backup sources online before frequency collapses. As coal retires, that physical inertia disappears. Grid-forming battery inverters replace it through software-defined control algorithms — virtual synchronous machine logic that mimics the electromechanical behavior of a spinning turbine without any moving parts.
The cost premium for this capability has effectively disappeared. As of 2026, the price difference between grid-forming and grid-following systems has converged to negligible levels for new utility-scale battery projects, driven by scaling production volumes and the transition of grid-forming capability from specialized hardware to software-configurable features on standard power conversion platforms. That explains why 74% of the pipeline has adopted it: there is no longer any cost reason not to.
New South Wales transmission operator Transgrid recently opened a formal procurement pathway for 900 MW of grid-forming-equipped battery storage to meet the state’s minimum system strength requirements — a process triggered in part by a 38% cost blowout in the alternative approach of deploying synchronous condensers. Grid-forming batteries are no longer a grid-stabilization supplement; they are becoming the primary architecture for grid stability in a post-coal NEM.
The Record That Masks a Generation Problem
The FY2026 headline number — 9.1 GW — is genuinely historic. But Giles Parkinson, founder and editor-in-chief of energy news outlet RenewEconomy and a journalist for more than 40 years, put it directly in his analysis of the scorecard: not nearly enough new wind and solar capacity is being built to meet the 2030 renewable target or allow coal generators to close as scheduled.
Analysts at Nexa Advisory estimate that, at current build-out rates, only around 60% of electricity generated in Australia’s main grid is likely to be renewable by 2030. AEMO’s own 2026 Integrated System Plan, published June 25, projected that renewable energy would reach 75% of NEM supply by 2030 under its central scenario — missing the federal government’s 82% target by seven percentage points.
The gap is structural, not cyclical. Wind projects require remote-site connections to transmission lines, which means they are directly exposed to Australia’s largest and fastest-growing investment barrier: transmission buildout delays. According to the Clean Energy Investor Group’s 2026 Clean Energy Outlook — a survey of investors collectively controlling 18 GW of renewable capacity valued at more than AU$41 billion — transmission delays have overtaken planning approvals as the single largest challenge facing renewable energy investment in Australia. The survey, conducted by Oxford Economics on CEIG’s behalf, found that 77% of respondents said the investment landscape had worsened over the past 12 months, including 31% who said it had worsened “significantly” — the most downbeat reading in the survey’s three-year history.
Richie Merzian, CEO of the Clean Energy Investor Group, said Australia’s standing as a top clean energy investment destination was waning, noting in a statement that over three quarters of the group’s clean energy investors say the Australian landscape has worsened in the last year. Just 58% of CEIG members now view Australia as an attractive destination for clean energy investment, down from 69% a year earlier.
The proponent implementation phase — the developer-led period between connection approval and project registration, which sits outside AEMO’s direct control — stretched from a median of 14 months to 18 months in FY2026, with one-third of projects having remained in this stage for more than two years. Parkinson’s reporting identifies the underlying reason: the large utilities that would normally sign long-term offtake agreements have limited commercial incentive to do so while their coal generators remain profitable — and those coal generators become more valuable, not less, when renewable delivery falls short.
None of the initial 15 government-backed wind projects that were awarded contracts through the Capacity Investment Scheme have yet commenced construction.
Australia Is Now the World’s Third-Largest Battery Market
Despite the generation gap, Australia’s position in global battery storage rankings has risen sharply. The Clean Energy Council’s Clean Energy Australia 2026 Report, published May 26, confirmed that Australia became the world’s third-largest utility-scale battery storage market, behind only China and the United States, after 2 GW of new large-scale battery capacity was commissioned in 2025 — a 233% year-on-year increase. Battery capital costs fell 20% through 2025, and a further 4.3 GW of large-scale battery capacity reached financial close during the same year.
The real-world performance data reflects how quickly that capacity is being used. In Q1 2026, battery storage systems more than tripled their daytime-to-evening energy shifting compared to the same period in 2025, with average discharge reaching 359 MW against 98 MW in Q1 2025. Queensland became the first NEM state to discharge more than 100 GWh from battery storage within a single month, achieving that milestone in April 2026. And on May 9, 2026, Western Australia’s battery fleet supplied 37.2% of peak demand on the state’s isolated grid — among the highest battery penetration rates ever recorded on any isolated grid.
The International Energy Agency has noted that utility-scale battery power capacity increased more than twelvefold between 2020 and 2024, with markets including California, Germany, South Australia, Texas, and the United Kingdom all seeing rapid deployment. Australia’s trajectory reflects and amplifies that global trend.
Is Australia on Track for 82% Renewables by 2030?
The honest answer, as of July 2026, is no. AEMO’s own 2026 Integrated System Plan — the biennial grid blueprint published June 25 — projects 75% renewable electricity by 2030 under its central development scenario, short of the 82% federal government target, and private-sector analysts put the likely outcome even lower. The ISP is explicit that wind delivery is the primary bottleneck: rising costs, social license challenges, supply chain pressure, and — above all — transmission delays are preventing projects from reaching construction even as application volumes hit records.
The FY2026 Connections Scorecard does contain one genuine piece of wind-side optimism: AEMO received a record 12 wind project applications totaling 5.2 GW during the year — the most ever in a single year. Whether those applications translate to completions depends on whether the barriers that have stalled the prior cohort of wind projects can be resolved — faster transmission approvals, stronger financial certainty through offtake agreements, and state and federal planning coordination. AEMO’s ISP calls for utility-scale wind and solar to reach approximately 120 GW by 2050 — roughly five times current capacity. Getting there requires delivery well above anything Australia has demonstrated in generation capacity, even in its record-breaking FY2026.
For now, the FY2026 Connections Scorecard demonstrates that Australia can build energy storage infrastructure at an extraordinary pace when the conditions are right. The conditions that would produce the same result for wind and solar are not yet in place.
Frequently Asked QuestionsIs Australia on track to hit its 82% renewables target by 2030?
Not at current rates. AEMO’s own 2026 Integrated System Plan, published June 25, projects renewable electricity reaching 75% of NEM supply by 2030 under its central scenario — seven percentage points short of the federal government’s 82% target. Analysts at Nexa Advisory put the most likely outcome even lower, at approximately 60%, based on current wind and solar delivery rates. The main constraint is large-scale wind: projects are not reaching financial close or construction at the pace the 2030 timeline requires, largely because of transmission delays, offtake market gaps, and a lack of commercial incentive for major utilities to sign long-term contracts while their coal plants remain profitable.
What is a grid-forming inverter, and why does it matter for Australia’s energy transition?
A grid-forming inverter creates its own voltage and frequency reference, allowing it to operate into a de-energized grid and provide synthetic inertia — a software-defined substitute for the physical stabilizing effect produced by the massive spinning turbines in coal and gas power stations. Coal and gas generators stabilize the grid as a byproduct of how they work: rotating turbine mass resists sudden frequency changes, buying time for backup generation to respond. As coal retires, that physical inertia disappears. Grid-forming batteries replace it through control algorithms that mimic the behavior of a spinning turbine. Around 74% of battery storage projects in Australia’s NEM pipeline are now confirmed to include grid-forming capability, and the cost premium for this technology has effectively converged to zero — making it the default architecture for new utility-scale battery energy storage systems in Australia.
Why are batteries dominating Australia’s connections pipeline while wind lags?
Batteries earn revenue through multiple stacked mechanisms — daytime charging from cheap solar, evening-peak discharge at higher prices, and system strength service contracts — whereas wind projects earn primarily from energy sales and require long transmission connections to remote sites that are subject to Australia’s worst infrastructure bottlenecks. The Capacity Investment Scheme provides revenue support for both, but CIS Tender 8 (dispatchable storage) delivered contracted certainty for 7.6 GW of battery capacity in June 2026, while CIS Tender 9 (5 GW of generation including wind and solar) only opened in May 2026 with results not expected until November. Battery capital costs also fell 20% in 2025 alone, reducing financing risk further. The result is a pipeline structurally weighted toward batteries: lower risk, faster grid connection, stacked revenue streams.
What does Australia need to do to close the 2030 gap?
Three things, according to the Clean Energy Investor Group’s survey of investors managing AU$41 billion in Australian clean energy assets: accelerate transmission buildout, strengthen revenue certainty for wind and solar projects through deeper offtake markets, and turn available private capital into connected projects faster. Transmission delays — which overtook planning approvals as the single largest investment barrier in 2026 — are the most urgent near-term constraint. AEMO’s ISP also identifies data centers as a potential source of offtake demand that could unlock wind and solar project financings, though the scale and timing of that demand remains uncertain.