When I first read that Rio Tinto may close the Gladstone Power Station early, I felt mixed emotions. The shutdown could now happen in 2029, not 2035.
Part of me understands the move. Many large industrial players are shifting to cheaper renewable energy sources. They want to avoid the risks of fossil fuels, carbon costs, and high maintenance. From Power Maintenance’s view, supporting Queensland’s business energy users, this is not entirely good news. It must be managed carefully.
A reliable and affordable energy supply must be protected. Here’s what needs to happen next…
What Rio Tinto Has Announced
Here’s what we know so far, from publicly verifiable sources:
- Rio Tinto has formally notified AEMO (the Australian Energy Market Operator) of a potential retirement of the Gladstone Power Station in March 2029 — six years earlier than the previous schedule of 2035. (Source: Australia Fin Review)
- The company emphasises that no final decision has been made, and the life of the plant could be extended depending on market and other factors.
- Current power supply contracts — notably to the Boyne aluminium smelter and other users — will remain in place until their contractual expiry in March 2029.
- Rio Tinto has already taken significant steps toward renewable procurement: in March 2025 the company signed hybrid solar + battery agreements with Edify Energy for the Smoky Creek & Guthrie’s Gap projects in central Queensland (600 MW AC solar + 600 MW / 2,400 MWh battery storage). Under those agreements, Rio will purchase 90% of the power and battery capacity produced. (Source: Rio Tinto)
- These renewable contracts, combined with earlier wind and solar PPAs (e.g. Windlab’s 1.4 GW Bungaban wind project) bring Rio’s contracted renewable capacity in Queensland to around 2.7 GW, which is intended to meet ~80% of the Boyne smelter’s average electricity demand. (Source: Rio Tinto)
- To support the grid transition, Powerlink (the Queensland transmission network operator) has developed a Gladstone Priority Transmission Investment (PTI) project, which proposes new lines, transformer capacity, and non-network assets to compensate for loss of essential services (system strength, voltage control) when Gladstone Power Station eventually retires. (Source: Powerlink)
In short: Rio is signalling a transition away from coal generation in Gladstone, while locking in a blend of renewables + storage to underpin its industrial loads. But that transition is not without risk.
Why This Move Is Not Unequivocally Positive For Queensland Energy Users
From the perspective of commercial and industrial energy users and indeed residential users, several risks and challenges arise from Rio’s early closure plan. As Power Maintenance, we view some of these as manageable, others as requiring urgent intervention.
Pressure on wholesale energy prices and volatility
Coal-fired power stations, despite their drawbacks, have historically provided large baseload, firming capacity, and essential system services (inertia, voltage support) at relatively stable marginal cost (once sunk capital is amortised). The removal of that capacity compresses the margin of safe, reliable supply. As supply margins thin, the wholesale electricity market becomes more exposed to fuel price swings, intermittent generation variability, and demand peaks.
In effect, less coal may mean less buffer, and greater upward pressure (and volatility) in energy prices.
Many commercial electricity suppliers will have to factor in higher risk premiums or hedging costs, and those costs ultimately flow through to end users. Queensland, which already confronts elevated network and generation costs in some regions, cannot afford to absorb more price stress without consequences to industries, jobs and investment.
Reliability, grid stability and system services
The Gladstone plant contributes more than mere megawatts: it provides system strength, inertia, voltage control, and fault ride-through capabilities. These are critical in maintaining grid resilience, especially in a region with increasing penetration of wind, solar and battery assets. The removal of those services cannot automatically be replaced. They must be compensated through either new network investment or non-network solutions (e.g. synchronous condensers, large batteries with dynamic control). That is precisely the point of the Gladstone PTI work by Powerlink.
If the compensation and network reinforcement are underestimated or delayed, the grid could become more fragile. That means more frequent constraints or curtailments, higher augmentation costs, and potentially higher costs passed to commercial users in constrained regions.
Commercial supplier exposure and contract complexity
Commercial electricity suppliers in Queensland already face a complicated task. They juggle wholesale prices, service costs, network charges, and regulations. The closure of a major coal plant will make this harder. Suppliers will need to rethink forecasting, risk management, and contract design.
Some suppliers may seek to push more of the risk onto customers (e.g. through variable pass-through clauses or demand charges). Others may face margin squeeze if they misestimate the new generator market dynamics.
For many energy-intensive businesses, the future may mean more advanced ways of buying power. This could include onsite generation, direct supply deals, power purchase agreements (PPAs), or demand response programs. However, these changes take time, money, and technical skills. Not every business is ready for such a shift. Many still depend on commercial suppliers who may struggle in a changing market.
Regional inequality and transmission constraints
Queensland is not monolithic. The energy landscape in Townsville, Mackay, Gladstone or Western QLD faces quite different transmission constraints, line losses, and network investment needs. The geographic concentration of the Gladstone closure means the local region bears disproportionate risk.
If transmission upgrades lag or insufficiently account for the shift, local constraints may drive up prices or curtail renewable generation, harming commercial users in that region first.
It is not enough to ensure supply at a state or system scale; we must ensure locational reliability and affordability. Otherwise, commercial customers in more remote or constrained zones will disproportionately suffer.
Why This Might Be A Forced Move…And What Opportunities Lie Hidden
I do not believe Rio Tinto is acting for purely altruistic reasons; this is a strategic play to protect its industrial profitability amidst changing energy economics. Still, that does not mean the decision is without merit or potential upside, but the upside must be managed carefully.
- Coal plants are becoming more expensive to run. Fuel, compliance, maintenance, and capital costs all keep rising. As these plants age, the risk of sudden breakdowns also increases. These breakdowns can be very costly for businesses and energy suppliers. The Gladstone station alone has had thousands of hours of unplanned outages in recent years.
- Renewables + storage economics improving: The trajectory of declining cost in solar, wind and batteries (and improved control systems) is making firmed renewables more viable. Rio’s PPA deals with Edify and other renewable suppliers reflect this reality. (Source: Rio Tinto)
- Decarbonisation and regulatory risk: Policy pressure (domestic and international) is pushing heavy industry to decarbonise or at least hedge carbon exposure. Transitioning early provides Rio with more control over the cost curve and risk management, rather than being forced later under less favourable conditions.
- Industrial strategic resilience: By securing renewables and batteries, Rio attempts to lock in cost predictability, reduce exposure to volatile fuel markets, and gain leverage in energy negotiations. In a volatile energy future, that position offers optionality and defence.
From Power Maintenance’s viewpoint, we welcome investment in renewables, grid upgrades, and modern system services. But again: making the transition safely, affordably and equitably is the real test — not simply shifting risk or cost to others.
A Roadmap Of What Must Be Done
In my capacity as MD of Power Maintenance and longstanding industry participant, here’s what I believe stakeholders — government, regulators, network companies, commercial suppliers and users — must prioritise to avoid damage and create opportunity from this shift.
Transparent modelling and stakeholder collaboration
From now until 2029, energy modelling should be made public. Commercial confidentiality can still be protected. These models must show impacts on wholesale prices, transmission bottlenecks, reliability risks, network costs, and contract exposures. They also need stress-testing. What if energy demand grows faster than expected or if renewables underperform? What if batteries fail to deliver as promised?
Further, commercial suppliers, major industrial users, local government, network operators and energy services firms (like us at Power Maintenance) must be actively engaged. This is not a back-room transition; energy users must have line of sight, input and recourse.
Accelerated network upgrades and system services procurement
Powerlink’s Gladstone PTI project is a necessary initiative. But more must be done:
- Prioritise augmentation and new lines now (not later), so that when Gladstone capacity winds down, the infrastructure is ready.
- Procure synchronous condensers, large-scale flywheels or alternative inertia sources, advanced grid-forming inverters, and battery systems capable of providing voltage and dynamic support.
- Ensure that these services have predictable pricing and contract coverage so that commercial suppliers and consumers are not surprised by large pass-through costs.
Incentivise behind-the-meter and industrial generation / energy optimisation
Large energy users should be encouraged through grants, tax breaks, or supportive rules. They need to invest in solar, batteries, and smarter energy use. This includes load control, demand response, and efficiency improvements. Power Maintenance can guide industrial clients through these changes. Clear incentives and expectations are essential for success.
Transitional contract regimes for commercial suppliers
Regulators need to ensure that commercial electricity suppliers do not unduly pass volatile risks to customers without adequate safeguards. We may need temporary rules to make sure energy companies don’t sneak in extra fees or unfair charges while the market settles. Transparent reporting and risk buffers (e.g. hedging benchmarks) may be needed.
Phased, communicated decommissioning with fallback guardrails
Given Rio’s own caveat that the plant life could be extended if market or technical conditions allow, the decommissioning should happen in phases, not a sudden “lights out” shutdown. During each phase, fallback capabilities or spare standby capacity should be maintained to avoid supply gaps.
Clear, timely communication is essential. Energy users and suppliers need lead times spanning years, not months, to recalibrate infrastructure, contracts and risk models.
Why Queensland Should Treat This As A Wake-up Call, Not Merely Rio’s Problem
Queensland is often praised for its abundant renewable resources, sunlight, wind, and trajectory toward clean energy. Yet beneath the optimism lie structural challenges: network constraints, regional load patterns, remote generation costs, and legacy coal dependencies.
The early exit of Gladstone is a significant stress test. If Queensland cannot absorb the shock without inflicting steep price increases or grid reliability issues, our entire energy transition narrative loses credibility.
Commercial energy users in Queensland (and the industrial base more broadly) are watching this with alarm. They cannot bear open-ended cost escalation, nor sudden supply uncertainty. They need certainty, clarity and strong institutional leadership now.
At Power Maintenance, we view ourselves as more than a maintenance contractor. We see ourselves as energy infrastructure stewards. We are uniquely positioned to help industrial, commercial and institutional clients adapt, but only if the ecosystem moves in concert: government, network, regulators, suppliers, users and service providers.
Final Thoughts: Not All Doom, But Vigilance Required
Rio Tinto’s move is bold. It signals an industrial giant acknowledging the inevitability of transition and staking its claim in a lower-carbon future. I respect the ambition, but I cannot sugarcoat the risks.
From where I stand, this is not good news, at least not automatically, for Queensland’s energy users. The danger lies not in the decision itself, but in a botched transition: cost blowouts, hidden pass-throughs, grid fragility, regional inequities, and perverse incentives. If we allow that, we lose far more than we gain.
However, if stakeholders act decisively, transparently and collaboratively, deploying the right mix of network investment, system service procurement, industrial optimisation and transitional contract design, this could become a model of how a resource-rich state navigates the energy transition without sacrificing affordability, reliability or competitiveness.
Media Enquiries & Further Commentary
I welcome media interest and commentary requests. To ensure professionalism, consistency and accuracy, please direct all such enquiries via the Power Maintenance contact us page, and we will respond promptly.
Nick Halaris, Managing Director, Power Maintenance
