At Bell Bay, on the Tamar River north of Launceston, the industrial precinct that has smelted zinc and rolled aluminium since the 1950s spent 2022 and 2023 fielding a queue of hydrogen developers — Woodside, Fortescue, Origin Energy — each promising to turn Tasmania's cheap, green power into an export fuel for Asian ships and steelmakers. By August 2024, the biggest of them was gone. Woodside withdrew its roughly 300-megawatt H2TAS hydrogen project from the federal environmental approval process, telling regulators that Tasmania did not have enough new renewable generation to support it (approx.; Woodside project withdrawal reporting, Aug-2024). Fortescue's and Origin's own Bell Bay hydrogen plans stalled around the same time. For the tradespeople and engineers who had been promised the jobs, the lesson was blunt: Tasmania's renewable-export ambition is not one project but a chain of them — hydro, wind, transmission, storage, industry — and if one link runs short, the whole chain can snap before it reaches a customer.
What the government did
The export ambition was formalised in November 2020, when the Tasmanian Parliament passed the Energy Co-ordination and Planning Amendment (Tasmanian Renewable Energy Target) Act 2020, legislating the Tasmanian Renewable Energy Target (TRET): 200 per cent of the state's 2020 electricity needs — 21,000 gigawatt-hours a year — from renewable sources by 31 December 2040, with an interim target of 150 per cent (15,750 GWh) by 2030 (Parliament of Tasmania; Act No. 41 of 2020). The starting point was itself a milestone Hydro Tasmania and the state government have promoted heavily: Tasmania reached 100 per cent renewable self-sufficiency in 2020, two years ahead of an earlier 2022 goal, one of only a handful of jurisdictions worldwide to meet all of its own electricity needs from renewables in an average year (approx.; ReCFIT, "100% target achievement").
The Tasmanian Renewable Energy Action Plan (TREAP), released in draft in May 2020 by the Office of the Coordinator-General, set out how: new onshore wind across the state's west and north-west, new pumped-hydro storage layered onto the existing dam network, and a second Bass Strait cable, Marinus Link, to carry the surplus to the mainland. The plan projected an economic contribution of roughly $7.1 billion to the Tasmanian economy through 2030 and around 2,350 jobs across construction and operations (approx.; TREAP, May-2020). A companion Tasmanian Renewable Hydrogen Action Plan added a second export leg, aiming to make Tasmania a globally significant green hydrogen exporter from 2030 (approx.; State Growth, Renewable Hydrogen Action Plan); the Commonwealth backed the Bell Bay hub with up to $70 million and the state added a further $11.9 million across 2024-27 (approx.; Australian Government Regional Hydrogen Hubs Program, Jan-2024; Tasmanian Government). On wind, approvals have followed: in August 2025 the federal Environment Minister approved the Robbins Island wind farm in the state's far north-west — up to 100 turbines, expected to generate enough power for around 422,000 homes — subject to 88 conditions, after a process that had run for roughly eight years (approx.; Minister for the Environment and Water, media release, Aug-2025).
The strongest case
An island that already did the hard part once
Put the government's case at its strongest, and it starts from an advantage no mainland state has: Tasmania is not proposing to build a renewable-energy system from nothing — it already runs one. The 2020 self-sufficiency milestone was not spin. Hydro Tasmania's dam network, built over more than a century, plus early wind farms at Woolnorth, Musselroe and Cattle Hill, genuinely meets the state's own demand in an average year. Doubling that output is a scaling exercise on proven technology, not a bet on something unproven, and it lines up with what the market's own independent planner says the wider grid needs: the Australian Energy Market Operator's Integrated System Plan has repeatedly treated new Bass Strait transmission capacity as necessary as coal-fired power stations retire nationally, not merely convenient for Tasmania. On hydrogen, the government's conduct has arguably been more cautious than its 2020 rhetoric: when Bell Bay proposals threatened to consume renewable generation at a scale that risked pushing up Tasmanian household power bills, hydrogen grants were steered toward domestic-market projects rather than subsidising export-scale electrolysis competing with Tasmanian consumers for the same power (approx.; reporting on state hydrogen grant policy, 2023-24). And the wind projects that have survived have not been waved through — Robbins Island cleared eighty-eight federal conditions, including new protections against Tasmanian devil disease transmission. That is a government making the ambition real, with real safeguards, rather than simply announcing it.
The evidence: a legislated trajectory, and a drought that interrupted it
Two different data sets sit inside the TRET story, and the government's own language tends to blend them: the target Tasmania has legislated, and the year-to-year reality of a power system still mostly run on rainfall. The 2024-25 water year was the sharpest test of that gap since the target passed. The Tasmanian Economic Regulator's Annual Energy Security Review recorded Hydro Tasmania generation of just 6,330 gigawatt-hours for the year — the lowest output on record for the hydro system in its current configuration — through what Hydro Tasmania itself described as the biggest multi-year drought in its recorded history (approx.; Tasmanian Economic Regulator, Annual Energy Security Review 2024-25 Water Year). To protect dam storages, Hydro Tasmania drew a net 1,910 gigawatt-hours through the Basslink interconnector — gross imports of roughly 2,458 GWh — a sharp reversal from 2021-22, when imports and exports were close to balanced (approx.; Tasmanian Economic Regulator, Energy Security Dashboards, 2025). For part of that year, the state marketed to the mainland as a clean-power exporter was, in practice, a net importer of mainland electricity to keep its own lights on. Hydro Tasmania's underlying profit fell 96 per cent over the same period, from $193.7 million to $7.5 million (Hydro Tasmania, Annual Report 2024-25).
The wind pipeline meant to make that trajectory achievable without relying purely on rainfall has moved more slowly than the 2020 plan assumed. In November 2023, TasNetworks split its North West Transmission Development — the onshore works needed to connect new wind farms to the grid — into two stages after Marinus Link itself was scaled back; developers behind six projects, including Robbins Island, Guildford, Hellyer and St Patricks Plains, publicly warned their connections were now in doubt, with one developer calling the delay "hard to fathom" (secondary source; RenewEconomy, reporting on TasNetworks transmission staging, Nov-2023). St Patricks Plains, a roughly 272-300 megawatt project in the Central Highlands, had its federal approval decision deferred three times before Ark Energy sold it to turbine manufacturer Vestas, which is now targeting a 2027 construction start subject to financing (approx.; industry reporting, 2025-2026). Robbins Island cleared federal approval in August 2025, but its own construction is not due to start until 2027, with first generation targeted for 2030 — a full decade after the TRET legislation passed.
The critique: who is paying for the infrastructure ahead of the export revenue
The steelman holds for the underlying resource: Tasmania's hydro and wind advantage is real, and the caution shown on hydrogen is creditable. It holds far less well for the sequencing the government has actually delivered, and for who is carrying the cost of the parts still running late. The transmission capacity needed to connect the new wind projects that make the 2030 interim target achievable is still being built in stages, was still being contested by developers as recently as 2023, and is now costing more than first budgeted: TasNetworks revised the cost of the North West Transmission Development from $800 million to $1.5 billion in November 2025 — the Tasmanian onshore works, distinct from the Marinus Link cable itself, that exist specifically to carry new wind and pumped-hydro output to market (approx.; Parliament of Tasmania, Government Business Enterprises Scrutiny Committee, 25-Nov-2025). The Australian Energy Regulator then approved $921.3 million of that spending into TasNetworks' regulated asset base in February 2026 — a cost that flows into network charges on every Tasmanian power bill, whether or not the wind farms it enables are finished (AER, Final Decision, Feb-2026).
That is the mechanism behind the 4.23 per cent rise in Aurora Energy's regulated standing offer from 1 July 2026, adding roughly $108 a year to a typical Tasmanian household bill. The Tasmanian Economic Regulator's own determination attributes the rise mainly to higher approved network costs, while noting the direct cost component tied to the Renewable Energy Target actually fell over the same period (Office of the Tasmanian Economic Regulator, price determination, 25-Jun-2026). Read plainly, that split says something the government's promotional language tends to blur: the 200 per cent target's most immediate cost on household bills today is not the renewable generation itself, which remains comparatively cheap, but the transmission and connection infrastructure built to move an export surplus that, in the state's driest year on record, briefly did not exist. Tasmania's regulated prices remain among the lowest in the national market — a fact the Premier's office noted alongside the June 2026 increase (Premier of Tasmania, media release, 25-Jun-2026) — which is true and worth crediting, but it does not change the direction the state's own bills are moving, or resolve who is meant to eventually recover the network spending: mainland export customers who do not yet exist, or Tasmanian ratepayers who already do.
The hydrogen leg of the export strategy has fared worse again. Woodside's August 2024 withdrawal — after telling regulators Tasmania lacked the new renewable generation to support export-scale electrolysis — was followed by Fortescue's and Origin's own Bell Bay ambitions stalling in the same period (approx.; reporting on Bell Bay hydrogen withdrawals, 2024). The government's May 2025 replacement — naming Abel Energy's Bell Bay Powerfuels, a roughly 240-megawatt, largely domestically-focused green methanol project, as the hub's provisional proponent — is smaller and more cautious than the export-scale hydrogen vision the 2020 action plan described, and even its enabling infrastructure is not due for completion until 2028 (approx.; Tasmanian Government, Bell Bay Tasmanian Green Hydrogen Hub updates, May-2025). That caution may be the right call, and it is consistent with the steelman case above, but it also means the second export pillar the government spent several years promoting has been quietly scaled back to something closer to a demonstration project.
Tasmania's power bills already carry the network cost of an export capacity that, in the state's driest year on record, briefly wasn't there to export.
The risk to the future
Export-scale network costs, on a still-domestic-scale export business
The clearest risk is a timing mismatch already visible in the government's own documents. The 2030 interim target — 150 per cent, 15,750 gigawatt-hours — was legislated in 2020 on the assumption that new wind and pumped-hydro capacity would be connected well before then. Four years on, the transmission works meant to connect that capacity have already had their cost roughly double, the state's highest-profile wind project by turbine count will not begin construction until 2027, and a second major project has changed developers after three deferred federal approvals. If 2030 arrives with the interim target missed — a real possibility on the pipeline's current pace — Tasmanians will by then have paid several years of higher network charges for connection infrastructure whose export revenue has not yet arrived to offset them.
The 2024-25 drought adds a second, less-discussed risk: the export thesis assumes Tasmania's hydro system reliably produces a surplus to sell, but the state's own Economic Regulator has now recorded a year in which it did not, requiring a net 1,910 gigawatt-hours of mainland power just to meet Tasmanian demand. A bigger renewable system exporting more aggressively in wet years is also a bigger system more exposed in dry ones, and the "Battery of the Nation" framing — Tasmanian hydro as flexible mainland backup — works only if there is water behind the dam wall when the mainland needs it. Tasmania is not choosing whether to become a renewable exporter; it has already committed, by statute, to a 2040 target and the network spending that comes with it. What remains open is whether the export revenue and the reliable surplus arrive on the same timeline as the bills already going out to Tasmanian households.