There is a particular kind of reckoning that arrives not as a sudden rupture but as a slow accumulation of pressures — economic, climatic, geopolitical — that cannot be resolved by any single policy decision or election cycle. Queensland is living through precisely that kind of reckoning now. The state has built one of the most consequential export industries in the southern hemisphere on the foundations of coal, and it is now confronted with a global energy system that, by every serious projection, will consume less of that coal with each passing decade. The question of what decarbonisation means for Queensland is therefore not a question with a simple answer. It is a question about fiscal architecture, about the futures of regional towns, about the pace of technological change, about sovereignty over natural resources, and about the kind of economy a state of five million people can realistically build in the decades ahead.

This article does not belong to the debate about whether coal should exist or whether the transition is morally urgent. Those arguments are well rehearsed elsewhere. What follows instead is an account of what the transition is actually doing to Queensland — to its power grid, to its export revenues, to its workforce, and to the policy framework that governs all of the above — as of 2026. The picture is considerably more complicated than either the most ardent advocates of rapid decarbonisation or the most committed defenders of the industry are inclined to acknowledge.

THE DOUBLE STRUCTURE OF QUEENSLAND COAL.

Any serious account of Queensland’s energy transition must begin with a distinction that is often lost in national and international commentary: Queensland’s coal industry is not one thing. It has two fundamentally different components with different global demand outlooks, different policy vulnerabilities, and different futures.

Metallurgical coal accounted for approximately 70% of Queensland’s total coal production in 2021–22, which is approximately 90% of Australia’s total met coal production. This is the coal used to make steel — a function for which no commercially scalable replacement currently exists at the scale the global economy requires, though that may change within the coming decades as green hydrogen-based steelmaking matures. The outlook for met coal is somewhat more resilient than for thermal coal. After a decline in 2025, met coal trade in 2030 is forecast to return to 2024 levels — a revision upward from previous forecasts, largely due to slower than anticipated deployment of low-carbon steelmaking technologies, such as hydrogen-based direct reduction furnaces.

Thermal coal — used for electricity generation — faces a structurally different prognosis. The IEA’s Net Zero Emissions by 2050 scenario projects a 90% fall in thermal coal use by 2050, and unabated coal-fired power generation phased out by 2040. Japan, South Korea and Taiwan — historically among Queensland’s most reliable thermal coal customers — are advancing their own clean energy transitions. There are no obvious replacement markets for Australia’s high calorific value coal as these nations phase out coal-fired power.

Most of Australia’s black coal is produced in Queensland, which accounts for 57% of national output, with New South Wales contributing 42%. Within that Queensland output, the distinction between the two types of coal matters enormously for how the transition plays out — and for how long the industry retains both political and economic legitimacy.

THE DOMESTIC GRID: COAL POWER AND ITS EXTENSIONS.

Within Queensland’s own electricity system, coal remains the dominant generating source. The state’s coal fleet currently generates approximately 65% of Queensland’s electricity needs, highlighting continued dependence on fossil fuels despite global pressure to transition to cleaner energy sources.

The story of Queensland’s domestic coal-fired power stations is one of repeated schedule revisions. The Gladstone Power Station — Queensland’s oldest, commissioned in 1976, was scheduled to close in 2035, while the Tarong power stations were expected to close by 2037, and the Stanwell Power Station was scheduled to close by 2046. In October 2025, that calculus shifted when Rio Tinto notified the Australian Energy Market Operator that the Gladstone Power Station was expected to close in March 2029 — years earlier than its official schedule. The 2021 explosion at Callide C, which caused a significant power outage affecting over 375,000 premises and increased power prices for weeks, was a stark demonstration of what the Climate Council and others have documented more systematically: analysis of the grid over recent years has revealed that both planned and unplanned coal outages have been a primary driver of power outage risk, with the majority of recent power outage risk conditions occurring in New South Wales and Queensland — the states most dependent on coal generators.

Although electricity demand is forecast to grow modestly at 0.6% per year, ageing coal infrastructure is proving increasingly unreliable. This reliability problem is not simply an argument for accelerating the exit from coal; it is also a reason why successive Queensland governments, regardless of political colour, have been reluctant to commit to firm closure dates without knowing that replacement capacity is available to fill the gap.

The policy response to this tension has been the subject of significant realignment following the October 2024 Queensland state election. After the Liberal National Party, led by David Crisafulli, came to power, the new government scrapped renewable energy targets and introduced a more coal-focused plan. State-owned coal plants are now expected to operate until at least 2046 — about a decade longer than previously planned. The Queensland Energy Roadmap 2025, released in October of that year, formalised this position. The Roadmap formally repeals Queensland’s previous renewable energy targets, while maintaining the commitment to net zero 2050.

This approach drew significant criticism from the clean energy sector. The Clean Energy Council noted that it is deeply concerned by the decision to remove Queensland’s renewable energy targets and delay the planned exit of coal-fired generation — changes that represent a significant change of direction and risk undermining both investor confidence and the state’s contribution to national decarbonisation. The council also observed that with 32% of Queensland’s electricity currently sourced from renewables, below the national average of 42%, there is a pressing need for the state to keep pace with its peers.

The practical consequences for renewable investment were measurable. In 2024, the transition had been moving quickly — the state backed seven solar and wind projects and seven storage developments, adding 3,202 megawatts, equal to about four mid-sized coal plants. It was a record year for clean energy investment. Industry leaders report that the policy shift has slowed investment, with only two projects reaching financial close in 2025, delivering just 510 megawatts — a steep drop from the previous year.

THE REVENUE PROBLEM: ROYALTIES AND THE BUDGET BIND.

Of all the dimensions of Queensland’s relationship with coal, none is more structurally consequential — or more politically difficult — than the fiscal one. Queensland collected a record $15.36 billion in coal royalties in 2022–23 following the introduction of higher tiers, with revenue declining to an estimated $5.49 billion in 2024–25 as coal prices moderated, according to Queensland Treasury’s official budget papers. That arc — from record revenues to near-halving in two years — captures in a single figure the volatility problem that confronts any government attempting to plan a fiscal transition away from coal dependence.

The decline is partly driving an $8.6 billion budget deficit. State royalty revenues will remain depressed until at least the 2028–29 financial year because of continued coal price weakness, with the government expecting to collect between $5.8 billion and $6.2 billion per year over the next four financial years. Meanwhile, the export value of Queensland’s coal has fallen sharply: the value of Queensland coal exports fell from AUS$52.3 billion in 2024 to AUS$38.9 billion in 2025, the first time since 2021 that the value of coal exports has been less than AUS$40 billion.

The royalty structure itself has become a contested terrain. Queensland’s coal royalty system consists of six progressive tiers, with a base rate of 7% applying to the first $100 per tonne, and a top tier of 40% applying to any value above $300 per tonne. The system automatically adjusts to market conditions, collecting more revenue during price booms while reducing the burden during downturns. Mining companies argue that the structure is punishing in a low-price environment; the Queensland Resources Council has positioned the royalty regime as a threat to investment and employment. But independent analysis from the Institute for Energy Economics and Financial Analysis found that there is not sufficient data or evidence to support the claim that Queensland royalty rates are causing a decrease in income and investment across the industry, though there are indicators showing the rise of other risk factors for the industry that far outweigh royalty costs.

What is beyond dispute is the structural dependency the royalty system has created. As Central Queensland University professor John Rolfe has observed, the fiscal situation is tight enough that any reduction in royalties creates direct pressure on other parts of the state budget, making it hard for government to adjust the numbers because the fiscal situation is tight, and if they do try to reduce royalties back to a more sensible position, it then puts other parts of the budget into trouble. This is the binding constraint that makes Queensland’s energy transition so much more complex than a simple substitution of one energy source for another.

THE EXPORT HORIZON: ASIA'S DEMAND AND ITS LIMITS.

Queensland’s coal industry is overwhelmingly an export industry. Queensland exports approximately one-eighth of the world’s coal. Its principal markets — Japan, India, South Korea, and China — are themselves in the midst of energy transitions of varying speed and ambition, and the signals they are sending to Australian coalfields are mixed enough to resist easy summary.

For metallurgical coal, the near-term picture remains reasonably stable. Global trade in metallurgical coal reached an all-time high of 369 million tonnes in 2024, supported by strong demand from key steel-producing countries in Asia. Australia, the world’s largest exporter of metallurgical coal, maintained stable export volumes at 153 million tonnes. India, in particular, is expected to remain a significant buyer of Queensland’s premium coking coal for the foreseeable future: “Metallurgical coal exporters, led by Australia, appear to have the stronger prospects due to the relatively robust demand outlook in India,” according to the IEA’s Coal 2025 report.

But the structural trajectory is less reassuring for the long run. The IEA expects global met coal consumption to decline gradually to 1.06 billion metric tons by 2030, from 1.11 billion metric tons in 2025, reflecting structural changes in steelmaking and slower growth in industrial activity. The most pronounced reductions are expected in China, which accounts for 67% of global met coal demand. China’s demand could fall by 77 million tonnes by 2030, only partially offset by increases from India and Indonesia.

For thermal coal, the picture is more sharply negative. Looking ahead to 2030, global thermal coal trade is expected to continue its downward trajectory to a level of 936 million tonnes. This trend is primarily driven by developments in China and India, where slightly declining coal demand combined with strong domestic production is likely to reduce the need for imports, and where India’s ongoing expansion of domestic thermal coal output is expected to outpace demand growth, further curbing import requirements.

The uncertainty around Queensland’s policy environment has led India’s steelmakers to look elsewhere. Australia’s exports are facing the reality that India is diversifying met coal imports away from Australia, while China lowers steel production. Queensland’s competitive position — built on the premium quality of its hard coking coal from the Bowen Basin — offers some insulation against this trend, but not immunity.

THE WORKFORCE QUESTION: COMMUNITIES AT THE TRANSITION'S EDGE.

Behind every royalty figure and export volume lies a human geography. The coal sector directly employed 27,002 Queenslanders and supported 387,285 direct and indirect jobs across the state. These jobs are concentrated in Central Queensland — in towns like Moranbah, Dysart and Clermont that were built, in many cases, specifically to service the Bowen Basin’s mines. The transition, whatever form it takes, will not be evenly distributed in its consequences.

The combined announcements from Anglo American and BHP in 2025 represented more than 950 job losses across Queensland’s coal sector. These job losses will reverberate throughout Central Queensland’s mining communities, creating economic and social challenges that extend beyond the directly affected workers, and will be particularly felt in communities like Dysart, home to the Saraji South mine.

The question of how coal communities transition is one of the most contested and under-resolved aspects of the broader debate. The term “just transition” is a problematic one in Australia, where it tends to provoke responses of feeling threatened rather than feeling included, particularly from workers and communities engaged in the coal mining sector. The British Academy’s analysis of Australia’s transition landscape observed that market and investor pressures are increasing on coal businesses, while the 2019 bushfires and COP26 in Glasgow shifted opinion on the need for transition planning — yet progress remains challenging and dependent on broad dialogue among different interest groups working in the absence of strong government policy.

Central Queensland is an economic powerhouse, underpinned by manufacturing and mining industries. It is one of the most emissions-intensive places in Australia, accounting for around 14% of national scope 1 emissions. The emissions-intensive industries in Central Queensland include alumina and aluminium production, coal mining, liquefied natural gas, cement, ammonia and other chemical manufacturing. These have been the backbone of the regional economy, and transitioning these sectors to clean energy will be critical to Australia’s net zero target.

The federal Net Zero Economy Authority has identified Central Queensland as one of its focus regions, alongside the Hunter, the Latrobe Valley and Collie. The Authority is working closely with regions that will be most affected by Australia’s transition to a net zero economy, helping workers in coal and gas facilities to prepare for and find new well-paid, safe and secure jobs, while supporting affected communities to prosper through economic development and investment.

Renewable energy can meaningfully help in the transition for coal regions. But it will not replace all lost coal jobs, and planning and investment are needed to avoid social and economic harm. Coal regions need industry development plans and investment to diversify their economies. The skills overlap between coal mining and renewable energy construction is real but partial: there is occupational overlap in construction and project management, engineering, electrical trades, mechanical trades and contract administration — but no direct job overlap for semi-skilled machine operators such as drillers, which account for more than one-third of the coal workforce.

THE RENEWABLE BUILD: AMBITION AND ITS OBSTACLES.

Queensland’s renewable energy sector has expanded substantially in recent years, even as its trajectory has become subject to political uncertainty. Rooftop solar and home batteries are now well established across Queensland. Over 1.1 million rooftop solar systems have been installed — the highest number of any Australian state. At the utility scale, the Western Downs Green Power Hub — a 400 megawatt facility completed in 2025 and currently Australia’s largest operational solar farm — uses one million bifacial panels to generate clean electricity for approximately 235,000 homes.

As of September 2025, Queensland’s greenhouse gas emissions were 35% below its reported 2005 levels, placing it ahead of its state target of 30% reduction, but still 8% behind the national target of 43% reduction by 2030. The gap between state and federal ambitions has become a source of friction, with the Queensland Energy Roadmap 2025 drawing criticism for the signals it sends to clean energy investors nationally.

The obstacles to accelerating the transition are not merely political. Grid congestion is a growing issue, particularly in the Darling Downs, where solar curtailment reached 12% in 2024 due to voltage instability. Without urgent investment in network upgrades, additional generation risks being stranded. Capital costs are also rising. Higher interest rates drove up the levelised cost of solar from $45 per megawatt-hour in 2022 to $68 per megawatt-hour in 2025. This contributed to delays in final investment decisions, especially for larger projects.

Meanwhile, Queensland is positioning itself for the post-coal commodity economy that may eventually follow. Queensland is positioning itself as a global leader in renewable hydrogen production and export. At the centre of this strategy is the Central Queensland Hydrogen Project, a flagship initiative designed to scale green hydrogen output while unlocking significant trade and employment opportunities. The state’s North West Minerals Province holds substantial deposits of the critical minerals — copper, cobalt, vanadium, rare earths — that the global energy transition itself will require in growing quantities. Queensland has many of the world’s critical minerals, such as copper, cobalt and vanadium, essential for the technologies needed to transition energy systems and decarbonise local, national and global economies.

Regional communities historically dependent on coal mining, such as those in the Bowen Basin, stand to benefit significantly from resource diversification. Towns like Emerald and Clermont are already seeing early-stage exploration for critical minerals within their regions, potentially providing economic continuity as coal operations mature. The degree to which this diversification can substitute for the specific economic density that a working coalmining district represents — the wages, the contracts, the supply chains — remains to be tested against actual investment outcomes rather than prospective modelling.

THE STATE-FEDERAL TENSION: POLICY MISALIGNMENT AND ITS COSTS.

Queensland’s energy transition debate cannot be understood in isolation from its relationship with the federal government. Queensland’s policy reversal creates significant challenges for Australia’s federal climate goals: it threatens the national target to reduce emissions by 62–70% below 2005 levels by 2035, complicates the federal goal to more than double renewable generation by 2030, creates policy misalignment between state and federal governments, and sends contradictory signals to renewable energy investors.

The state government’s position that “affordable, reliable, and sustainable energy” can only exist where there is also the fallback of coal and gas energy production is in contrast with renewable energy policies in other states and territories, and the policies of the federal government which emphasise the need for an orderly closure of coal-fired generation plants.

The decision to extend the operating life of coal and rely on more gas for firming could create a potential misalignment with future market or policy drivers concerning emissions intensity. The irony is that this misalignment creates risks not only for climate outcomes but for Queensland’s own long-term investment environment. International capital markets are increasingly integrating energy transition risk into their assessments of sovereign and sub-sovereign creditworthiness. A state whose energy policy diverges sharply from the direction of its national government and from the policy trajectories of its major export markets faces questions about stranded asset exposure that will compound over time.

Historically, Queensland has relied on carbon-based industries — coal mining and coal-fired power stations — as a source of electricity generation, employment and trade. Queensland’s economy is now shifting to diversify its energy mix and meet the challenges presented by climate-related impacts. Decarbonisation is a global economic force, and capturing the associated opportunities presents a new wave of economic growth for the state. That framing, from Queensland’s own Department of State Development, Infrastructure and Planning, captures the dual reality that any honest accounting of the transition must hold simultaneously: the costs of moving away from coal are real and concentrated, but the costs of refusing to move are accumulating in the background.

PERMANENCE, IDENTITY, AND THE LEDGER OF TRANSITION.

Queensland’s coal industry has been recorded, debated, celebrated and contested across more than a century of public life. The fact of that industry — its fiscal contributions, its communities, its infrastructure, its place in the global supply of the metals that built Asia’s cities — belongs to the permanent historical record of the state, regardless of what the coming decades bring. The civic namespace coal.queensland exists as part of the permanent onchain identity layer for Queensland’s institutions, industries and landscapes — a recognition that the coal industry’s meaning for this state is not conditional on its future commercial trajectory. Its history is already made.

The transition now underway is not the first time Queensland has been asked to restructure an economy built on a single commodity. It is, however, the first time the restructuring has been driven by a planetary-scale constraint rather than simply by changing market prices. The IEA has observed that “the outlook for coal is heavily dependent on the strength of the world’s resolve to address climate change” — but in all of the IEA’s scenarios, global coal consumption falls by both 2030 and 2050. The direction of travel is not genuinely in dispute among the institutions that model energy systems. What is in dispute is the pace, the instruments, and the distribution of burden between those who benefit from the current system and those who would bear the cost of changing it.

Queensland, as of 2026, is navigating that dispute without the luxury of time. Its coal-fired power stations are ageing and increasingly prone to failure. Its export revenues have fallen sharply from the windfall years of 2022–23. Its coal-dependent regional communities are watching workforce numbers contract. Its renewable pipeline — substantial as it was before the 2024 election — has slowed. And the global demand curve for the thermal coal that underpins so much of the state’s domestic electricity generation is pointing in only one direction.

None of this resolves easily. The hard coking coal of the Bowen Basin has a genuinely different future from the thermal coal burned in Tarong or Callide. The financial dependency of Queensland’s budget on royalty revenue is a constraint that no government, of any political colour, can simply wish away. The legitimate interests of mining communities in the Bowen Basin and the Galilee are not served by a transition agenda that treats workers as an afterthought to a decarbonisation schedule.

What the transition demands of Queensland — honestly understood — is not the end of the coal industry on any particular timetable, but rather the building of a fiscal, economic and social architecture that is capable of surviving coal’s eventual diminishment. That architecture does not yet exist in the form required. The work of building it is the defining public policy challenge of Queensland’s coming generation.

The civic record of that challenge — the decisions made, the communities affected, the revenues collected and spent, the alternative industries built or not built — will endure in the public record long after the last Bowen Basin mine is either operating or reclaimed. The namespace coal.queensland marks that record’s permanent address: not a memorial, and not a promotion, but a coordinate in the permanent ledger of what Queensland has been, and what it is now becoming.