Grow a Clean Economy

Design rationale

Electricity consumption and electricity reliability are related but distinct services. Consumers primarily pay for electricity used, while the system must also maintain enough stored energy to deliver that electricity when generation is unavailable or insufficient.

At present, grid-scale batteries rely heavily on differences between low and high wholesale prices to recover their investment. As more storage enters the market and smooths those price differences, successful storage can weaken the price volatility on which further storage investment depends.

Separating reliability revenue from energy pricing allows storage to earn from making electricity dependable without requiring wholesale prices to remain highly volatile.

Market structure and fund flows

A household or business would continue receiving a single electricity bill, but the bill would contain three conceptually distinct components:

1. Energy Usage — payment for the electricity consumed, with retailers continuing to purchase electricity through the wholesale market and generators and storage operators continuing to buy and sell electricity through AEMO's existing settlement system.
2. Network Connection — payment for the transmission and distribution infrastructure used to deliver electricity, passed through by retailers to the relevant network managers.
3. Reliability — payment for the consumer's selected level of dependable grid supply, passed through by retailers to AEMO for administration through a national reliability pool.

AEMO would distribute reliability-pool revenue among eligible grid-scale storage and firming providers according to their share of electricity supplied back into the grid.

Storage operators would therefore continue participating normally in the wholesale electricity market when charging and discharging, while also earning reliability revenue for shifting electricity from times of abundance to times when dependable supply is needed.

Reliability choices

Standard reliability classes would allow consumers to select the level of grid reliability appropriate to their circumstances.

Ordinary household service would continue to provide a high level of reliability. Consumers with substantial household batteries, backup systems, or genuinely flexible electricity needs could select lower-cost reliability classes because they require less guaranteed supply from the wider grid.

Each reliability class would carry corresponding service conditions so the amount charged reflects the reliability the electricity system is actually required to provide. Retailers could compete in the products and prices they offer around these standard classes without redefining the underlying reliability service.

Reliability pool and storage incentives

Reliability charges would form a fixed revenue pool distributed among eligible grid-scale storage providers. Each operator's share would be determined directly by its share of electricity discharged back into the grid.

The pool would not increase because more storage operators enter the market or because an individual operator incurs higher costs. Additional competition would instead divide the available reliability revenue across a larger amount of supplied storage.

This creates pressure for storage investment to expand while returns remain attractive and moderate as the market becomes more crowded. Operators with lower capital costs, better efficiency, lower degradation, or more effective operating strategies would be better able to remain profitable as competition increases.

Storage operators would still bear the wholesale cost of charging, round-trip energy losses, degradation, and operating costs. Cycling storage solely to increase its share of the reliability pool would therefore carry real costs while also increasing the total output across which the fixed pool is divided, acting as a natural disincentive to prevent "gaming" the system.

Interaction with the wholesale market

Storage operators would continue buying electricity when wholesale prices are lower and selling it when prices are higher, progressively smoothing differences between periods of abundant and scarce supply.

As storage competition expands, those wholesale price differences should narrow. In a highly effective system, storage would shift enough electricity through time that wholesale prices become substantially flatter, while reliability revenue continues supporting the storage capacity that makes that price stability possible.

This separates the commercial value of storage from the persistence of wholesale price volatility: batteries can succeed by reducing price swings rather than depending on those swings remaining large.

Behind-the-meter storage

Household and business batteries would primarily provide private reliability by reducing how much dependable grid supply their owners need. Consumers with sufficient backup capacity could therefore choose a lower-cost reliability class without giving up the reliability they personally value.

Owners could also choose to make their batteries available to the wider electricity system through an eligible retailer or aggregated virtual power plant. Verified stored-energy discharge that either supplies electricity to the grid or reduces grid demand when reliability support is required would contribute to that aggregator's share of the reliability pool.

Participation in grid reliability would remain voluntary. A consumer could use a battery entirely for their own needs, make some capacity available to the grid, or participate more extensively where the resulting payments made that worthwhile.

Residual risks and implementation

A throughput-based reliability pool may favour storage that cycles frequently over storage whose value lies principally in covering rare, long-duration shortages. The system may therefore still need to demonstrate that market incentives sustain an appropriate mix of storage duration as generation becomes more variable.

Reliability choices could also produce different levels of interruption exposure between households. Standard service conditions would need to ensure that consumers understand the reliability product they select and that lower-cost options represent genuine choice rather than nominally equivalent services with hidden differences.

The reform would require electricity settlement and retail billing to distinguish energy, network, and reliability charges, establish nationally consistent reliability classes, and transition existing grid-scale storage arrangements into the new settlement framework without duplicating reliability payments.

References

Australian Energy Regulator — Wholesale electricity market performance report 2026 | Australian Energy Market Commission — 2026 Reliability Standard and Settings Review | Australian Energy Market Commission — New rule to make the invisible visible across the distribution network

Design rationale

The objective of electricity policy should be to secure low-emissions electricity at the lowest sustainable cost, rather than to predetermine which technologies will provide it.

Different generation technologies have different combinations of capital cost, operating cost, fuel requirements, lifespan, availability, location, and environmental impacts. These relative advantages also change as technologies improve. Government policy should therefore establish the outcomes generators must meet and allow competition to determine which technologies can meet them most efficiently.

Technology-neutrality does not mean treating unlike technologies as physically identical. Safety, environmental, waste-management, and other requirements can differ where technologies create genuinely different risks. The principle is that a technology should not receive preferential treatment, or be excluded from consideration, simply because of the technology class to which it belongs.

Competing on the real cost of power

Competition should reflect the costs a generation project actually imposes on the electricity system, rather than comparing generation costs in isolation.

A project should not appear cheaper by shifting substantial connection, transmission, emissions, or other necessary costs onto consumers elsewhere in the system. Conversely, generation that can use existing infrastructure, locate close to demand, operate more consistently, or otherwise avoid wider system costs should retain the resulting competitive advantage.

This allows different technologies to compete on their complete economic merits without requiring government to prescribe the generation mix.

Interaction with carbon compliance

Technology-neutral generation depends on emissions being treated as a cost rather than controlled principally by prescribing eligible technologies.

Under the carbon-compliance framework, generators producing greenhouse emissions would remain responsible for the carbon compliance associated with those emissions. Low-emissions technologies would therefore retain an economic advantage because they avoid those costs, while technologies capable of reducing or capturing their emissions could compete where they can do so economically.

The electricity market could then pursue decarbonisation through competition over how cheaply emissions can be eliminated, rather than relying on technology-specific eligibility rules to determine which forms of low-emissions generation receive public support.

Interaction with electricity reliability

Generation and reliability would remain distinct economic functions.

By separating reliability from energy pricing, storage can earn revenue for shifting electricity through time and providing dependable supply without requiring large wholesale price swings to remain profitable.

Generators can therefore compete primarily on producing electricity efficiently, while the reliability system separately rewards the storage needed to make variable generation dependable. This avoids judging a low-cost generator as though it must independently provide every characteristic required by the complete electricity system.

Government support and market access

Where government policies support investment in new electricity generation, eligibility should be based on common emissions, performance, safety, and system requirements rather than being restricted to nominated generation technologies.

Technology-specific legal prohibitions that prevent an otherwise compliant generation technology from competing would also be inconsistent with a genuinely technology-neutral market. Removing such exclusions would not exempt that technology from appropriate licensing, safety, environmental, waste-management, or planning requirements.

Existing contractual commitments should not be retrospectively withdrawn merely to implement technology-neutrality. The reform should instead change the basis on which future generation investment is supported and regulated.

Nuclear generation

We would repeal the federal prohibition on civilian nuclear power generation and allow nuclear projects to compete under the same technology-neutral principles as other low-emissions generators.

This is because the existing prohibition limits meaningful price discovery. Because nuclear projects cannot legally proceed, producing an accurate Australian project cost has little commercial value: developers cannot build the project, financiers cannot fund it, and customers cannot contract for its output.

Cost estimates therefore have value primarily within the political debate over nuclear power. This creates an unusual incentive environment in which favourable and unfavourable estimates can have political consequences, while being wrong about the eventual construction price has no commercial consequence.

Repealing the prohibition would change that. Developers claiming nuclear can compete would need to test those claims through real sites, designs, supply contracts, financing, regulatory requirements, and willingness to commit capital. If nuclear cannot attract investment at competitive prices, the market would establish that without requiring a statutory prohibition.

Interaction with innovation policy

Technology-neutral electricity policy should not require every emerging technology to be commercially mature before research or demonstration can occur.

Early-stage technologies can continue to receive support through Australia's broader research and commercialisation systems. Once technologies reach commercial deployment, electricity policy should allow them to compete on their actual performance rather than protecting either established or emerging technologies from competition.

Residual risks

Technology-neutrality can become nominal rather than real if planning rules, network access, underwriting arrangements, taxation, or other policies continue to advantage particular technologies indirectly. Implementation would therefore need to assess electricity-market settings as a whole rather than merely removing technology names from individual programs.

Comparing projects solely by their plant-level generation cost could also favour projects that impose greater costs elsewhere in the electricity system. Cost comparisons must therefore preserve incentives for generators to minimise the wider infrastructure and system costs attributable to their investment.

Some technologies may also involve uncommon or long-duration risks that are difficult to represent through ordinary market prices. Technology-neutral competition does not remove the need for proportionate regulation of genuine safety, environmental, decommissioning, and waste-management risks.

References

Department of Climate Change, Energy, the Environment and Water — Capacity Investment Scheme | Clean Energy Regulator — Eligibility for the Renewable Energy Target | Environment Protection and Biodiversity Conservation Act 1999 | Australian Renewable Energy Agency — Advancing Renewables Program | CSIRO — GenCost

Design rationale

Australia has already begun a broad transition from direct fossil-fuel use towards electricity across transport, buildings, and other parts of the economy. Existing national strategies address electric vehicles, building electrification, energy efficiency, and fuel switching, while states and territories are implementing complementary measures.

The central policy task is to maintain this direction, complete the programs already underway, and remove barriers that prevent otherwise practical electrification.

Scope and sequencing

Households and businesses should be able to switch from fossil-fuelled equipment and vehicles to electric alternatives when those alternatives can meet their needs practically and economically. Where suitable electric technologies are not yet available, or remain disproportionately costly, existing technologies can remain in use until better electric or other low-emissions alternatives emerge.

The transition would generally occur through normal replacement and investment cycles rather than requiring consumers to discard functioning equipment prematurely. Consumers could still choose to replace equipment earlier where lower running costs, improved performance, or other benefits make doing so worthwhile.

Buildings and transport

For new light vehicles and new buildings, substantial national and state policy frameworks are already in place. We would maintain their progression rather than replace them with competing schemes, while removing remaining barriers that unnecessarily restrict consumer choice or make electric alternatives more difficult or expensive to adopt.

Those barriers are more significant for existing buildings and harder-to-electrify transport. Households can face upfront retrofit costs, landlord-tenant incentives, strata constraints, and the practical complexity of replacing established gas equipment. Heavy road freight faces different constraints, including vehicle availability, high-capacity charging, depot electricity supply, and charging infrastructure along freight routes.

As technologies mature and these barriers diminish, households and businesses should increasingly be able to adopt electric alternatives on their own economic merits rather than depending on continuing government incentives.

Energy-system transition

As households and businesses choose electric technologies, demand will progressively shift from petroleum and gas networks onto the electricity system. Electricity generation, storage, and network planning therefore need to accommodate that changing demand without making electrification harder through higher prices or reduced reliability.

Separating reliability from energy pricing and allowing generation technologies to compete on their full economic costs would help the electricity system absorb this additional demand more cheaply and dependably.

Declining gas demand creates a separate transition problem because the fixed costs of gas networks can otherwise fall on progressively fewer remaining customers. Where this eventually makes continued network operation disproportionately expensive, government assistance should help remaining households and businesses switch to practical alternatives rather than requiring them to carry the rising cost of maintaining an increasingly under-used network.

Transition discipline

Government should remove structural barriers to electrification without trying to dictate replacement decisions that households and businesses are better placed to make themselves.

Policies that remain necessary to expand access, correct split incentives, or overcome infrastructure constraints should continue while those barriers remain. Where electric alternatives become practical, competitive, and widely accessible without additional intervention, transitional support should be allowed to wind down.

This keeps the objective focused on giving consumers better energy choices rather than treating electrification itself as an outcome that must be pursued regardless of cost or circumstances.

References

Department of Climate Change, Energy, the Environment and Water — National Energy Performance Strategy | Department of Climate Change, Energy, the Environment and Water — Trajectory for Low Energy Buildings | Department of Climate Change, Energy, the Environment and Water — National Electric Vehicle Strategy | Department of Infrastructure, Transport, Regional Development, Communications, Sport and the Arts — New Vehicle Efficiency Standard | Australian Renewable Energy Agency — Electrifying Road Freight: Australia’s Blueprint for a Cleaner Transport Future | Australian Energy Market Commission — AEMC proposes gas network reforms for an uncertain future

Design rationale

Farmers face some of the most difficult challenges in the modern economy: being asked to decarbonise while climate change is already making food and fibre production harder through greater heat, drought, rainfall variability, extreme weather, and other pressures on agricultural systems. On top of those challenges, many agricultural emissions arise directly from biological production and cannot simply be switched off without affecting how farms operate. Enteric methane from livestock is the largest source, followed by emissions from agricultural soils and manure.

Australia already has substantial research, measurement, and industry programs aimed at reducing these emissions. The central gap is therefore not the absence of agricultural climate research, but ensuring that promising solutions move from research through farm-scale testing, regulation, commercialisation, and adoption with their economic performance tested alongside their emissions performance.

We would coordinate these stages around a common objective: develop practical ways for farms to produce the same or greater economic value with fewer emissions, rather than treating lower agricultural output as the default pathway to decarbonisation.

Policy scope

The primary focus would be production emissions that are not readily addressed through ordinary electrification, including livestock methane, manure emissions, and emissions associated with fertiliser and agricultural soils.

On-farm energy use would continue to transition through broader electrification and clean-energy policy. Carbon sequestration through vegetation, soils, wetlands, or other land-management activities would remain distinct from reducing the emissions created by agricultural production.

Productivity-first development

Agricultural emissions technologies would be assessed on both their emissions performance and their effect on farm economics.

Priority would be given to technologies and practices that can reduce input requirements, improve feed or nutrient efficiency, increase productive output, reduce waste, or otherwise strengthen farm performance while lowering emissions.

Technologies that initially impose an additional cost would not be excluded where unresolved research, commercialisation, scale, or delivery problems could plausibly make them economically viable. They could progress through the broader innovation-commercialisation pathway while those risks remain.

Once a technology is commercially established, continuing adoption should increasingly depend on its underlying economics rather than permanent government support.

Coordinating the pathway to farms

Existing agricultural research organisations, Rural Research and Development Corporations, the Zero Net Emissions Agriculture Cooperative Research Centre, regulators, commercialisation programs, industry organisations, and agricultural advisers would perform different stages of the pathway rather than being replaced by a new parallel innovation system.

Research would establish technical potential, farm-scale trials would test performance under Australian production systems, regulatory processes would address safety and product requirements, and the broader commercialisation system would support technologies where unresolved scale-up risk prevents ordinary investment.

Once technologies are sufficiently proven, existing agricultural extension and advisory networks would help farmers understand where they are suitable, what they cost, and how they perform under local farming conditions.

The objective is to prevent commercially promising technologies from becoming stranded between successful research, regulatory approval, commercial production, and practical farm adoption.

Livestock methane as an initial priority

Livestock methane would be an initial priority because enteric fermentation is Australia's largest source of agricultural emissions and also represents lost feed energy.

Australia already has feed additives capable of producing large methane reductions under suitable conditions, together with research into low-methane genetics, feeds, forages, vaccines, and other approaches. However, effectiveness, delivery, cost, and animal-performance outcomes vary substantially, particularly in extensive grazing systems.

The coordinating objective would therefore not be to prescribe a particular methane technology. It would be to accelerate approaches that can reliably reduce methane under real Australian farming conditions while maintaining or improving animal performance, and to develop delivery methods that make effective technologies commercially practical outside controlled feeding systems.

Success would be judged by commercially usable reductions in methane rather than the largest reduction demonstrated under laboratory or tightly controlled conditions.

Other agricultural emissions

The same productivity test would apply to other production emissions.

Precision fertiliser application can reduce excess nitrogen fertiliser use, and the associated nitrous oxide emissions, while lowering input costs and maintaining crop nutrition. Improved fertiliser-use efficiency, appropriate crop rotations, and other regenerative agriculture practices can similarly reduce emissions where they allow producers to obtain more useful production from each unit of input.

Manure management can create comparable opportunities where captured methane can be converted into useful energy or other products. Where an emissions-control measure produces no corresponding commercial value, the development pathway should focus on reducing its cost rather than assuming farmers will adopt it voluntarily.

Biochar may also have agricultural value where suitable products improve soil water or nutrient retention, reduce fertiliser requirements or nitrous oxide emissions, or improve farm productivity. Its use would be assessed on demonstrated farm and emissions performance rather than treated as a universal soil treatment. Any durable carbon stored in biochar would be accounted for separately through the carbon-removal framework rather than being treated as a reduction in the farm's production emissions.

Different agricultural systems would therefore use different combinations of technology and practice rather than being required to follow a single prescribed pathway.

Transition to carbon compliance

Agricultural emissions should not remain permanently outside carbon compliance simply because practical abatement options have historically been limited. Equally, imposing full liability before producers have viable ways to reduce those emissions would primarily increase production costs rather than drive productive change.

Carbon compliance would therefore be delayed for an agricultural emissions source until its emissions can be measured with sufficient reliability and producers have practical, sufficiently available, and economically viable pathways for reducing them.

Once those conditions are met, the relevant emissions would progressively enter the broader carbon-compliance framework. Producers that adopt effective abatement would reduce their remaining emissions and therefore reduce the number of sequestration credits they need to purchase. Producers that continue using unnecessarily emissions-intensive practices would increasingly bear the cost of that choice.

Where a production system remains substantially more emissions-intensive because of its location, production method, or operating model after viable alternatives are established, carbon compliance should expose that disadvantage through normal market incentives.

Commercial incentives and market access

Lower-emissions production may also become commercially valuable where customers, processors, financiers, or export markets place value on verified emissions performance. The policy would not depend on those premiums emerging or assume that every producer can obtain one.

Broader competition policy would separately address concentrated purchasing power where dominant processors or other buyers can prevent producers from retaining the commercial value created by improvements to their farms.

Residual risks

1. Agricultural systems vary substantially across climate, geography, production method, and scale. Compliance should not begin until viable abatement pathways are genuinely available for the relevant production system, but this should not become a permanent exemption for production models that remain unusually emissions-intensive once practical alternatives exist elsewhere in the industry.

2. Productivity improvements can reduce emissions per unit of output while also making additional production profitable. If the resulting expansion outweighs the efficiency gain, absolute emissions can still rise. Bringing residual emissions into carbon compliance once viable abatement exists preserves an incentive to reduce total emissions rather than treating lower emissions intensity alone as sufficient.

3. Biological emissions cannot always be measured with the precision available for fossil-fuel combustion. Improved Australian accounting methods can reduce this uncertainty, but some estimation error will remain and may affect the liability assigned to individual producers.

References

Department of Agriculture, Fisheries and Forestry — Agriculture and Land Sector Plan | Department of Agriculture, Fisheries and Forestry — National partnership to spur sector emissions cuts | Department of Climate Change, Energy, the Environment and Water — Reducing methane from livestock | Department of Agriculture, Fisheries and Forestry — Improving Greenhouse Gas Accounting | Department of Agriculture, Fisheries and Forestry — Reducing emissions | Meat & Livestock Australia — Optimising Australian feedlot cattle performance and reducing emissions with a low dose 3-NOP | Clean Energy Finance Corporation — Variable Rate Fertiliser

Design rationale

Achieving negative emissions requires removing carbon dioxide already in the atmosphere and storing it durably, not merely reducing the rate of new emissions.

Nature-based sequestration through forests, soils, and other ecosystems will remain important, particularly as stronger carbon compliance increases demand for genuine sequestration.

However, biological carbon stores can be reversed by bushfire, drought, flood, ecosystem decline, and other disturbances. Engineered carbon removal can complement them with mineral, geological, and other forms of storage that are less exposed to worsening climate risks.

Australia has particular opportunities through its geology, mining and agricultural industries, renewable-energy resources, and existing industrial infrastructure. The aim is not to permanently subsidise carbon removal, but to establish the measurement, certification, resource knowledge, and shared infrastructure needed for emerging methods to compete in the carbon market.

What counts as carbon removal

Engineered carbon removal must produce a measurable net transfer of carbon from the atmosphere into durable storage. This can include direct air capture with permanent storage, durable storage of carbon originally absorbed by biomass, mineral carbonation, enhanced weathering, and future methods meeting the same standard.

Capturing fossil carbon before it reaches the atmosphere is instead emissions reduction. It can reduce a facility's carbon liability, but does not create sequestration credits.

Crediting would account for material emissions from energy, transport, processing, and other parts of the removal process.

Mineralisation

Mineralisation is particularly promising for Australia because suitable magnesium- and calcium-rich minerals can permanently bind carbon dioxide as stable carbonates.

Mine tailings can offer an unusual advantage: the rock has already been mined, crushed, transported, and concentrated as part of an existing industrial process. Suitable mining operations may therefore be able to turn waste material into a valuable source of permanent sequestration.

The opportunity depends heavily on local mineralogy, reaction rates, water and processing requirements, and cannot be assumed to exist at every mine. National mapping would identify where suitable tailings, reactive rocks, and associated infrastructure create credible opportunities.

Mineralisation would receive particular attention because of Australia's mining strengths, while remaining in competition with other engineered-removal technologies.

Other removal pathways

Biochar can convert suitable biomass residues and wastes into a durable carbon store while also producing a useful soil amendment. Credit eligibility would depend on sustainable feedstocks, the stability of the stored carbon, lifecycle emissions, and an end use that preserves the carbon over the credited period.

Direct air capture offers highly measurable removal but currently requires substantial energy and capital.

Biomass removal can combine biological capture with durable storage, but must account for competing uses of land and biomass.

Enhanced rock weathering may use suitable minerals, including industrial by-products, but faces transport and measurement challenges.

Ocean-based methods may eventually provide additional capacity, but would require strong evidence of both net removal and environmental safety before large-scale deployment.

Future methods could qualify where they meet the same requirements for genuine, durable, and measurable removal.

Measurement, mapping, and infrastructure

Different removal methods require different measurement approaches. Certification would therefore be technology-specific while applying common requirements for net removal, durability, independent verification, and conservative accounting.

National mapping would identify where suitable geology, mine wastes, biomass resources, storage formations, energy, water, and existing infrastructure make different approaches practical.

Where multiple viable projects depend on common infrastructure, such as carbon transport, geological storage, electricity connections, or shared processing facilities, coordination would allow those assets to serve multiple users rather than being duplicated project by project.

Interaction with carbon compliance

Emerging technologies could use Australia's broader innovation-commercialisation pathway while technical and scale-up risks remain.

Once they become commercially viable, demand should increasingly come from businesses purchasing genuine sequestration to meet carbon-compliance obligations rather than continuing government support.

A mining operation that can economically remove atmospheric carbon through its tailings could therefore turn that capability into a commercial asset, while ordinary carbon compliance continues to determine the value of the sequestration produced.

Residual risks

1. Engineered removal can itself require substantial energy, water, minerals, biomass, or infrastructure, so lifecycle accounting and normal environmental regulation remain necessary.

2. Measurement uncertainty will remain greater for some dispersed processes, such as enhanced weathering or atmospheric mineralisation, requiring conservative crediting where direct measurement is not possible.

3. Australia's mineralisation potential is unevenly distributed, so strong opportunities at some mining operations should not be assumed to generalise across the industry.

References

CSIRO — Australian Carbon Dioxide Removal Roadmap | Clean Energy Regulator — Permanence obligations | CSIRO — Putting Australian enhanced mineralisation on the map | International Journal of Greenhouse Gas Control — Offsetting of CO₂ emissions by air capture in mine tailings at the Mount Keith Nickel Mine, Western Australia | Department of Climate Change, Energy, the Environment and Water — BHP and Arca carbon mineralisation ACCU method proposal | University of Queensland Sustainable Minerals Institute — Mineral carbonation of mine tailings for CO₂ sequestration and heavy metal immobilization

Design rationale

Climate change is already exposing valuable ecosystems to periods of extreme heat faster than emissions reduction alone can prevent the resulting damage. Technologies that temporarily reduce heat or light stress could provide an additional tool for protecting vulnerable ecosystems while longer-term decarbonisation continues.

Australia already has substantial research capability in this field, particularly through work on marine cloud brightening, seawater fogging, environmental modelling, and monitoring for the Great Barrier Reef. This creates an opportunity not only to protect Australian ecosystems, but to develop technologies and expertise that can be sold internationally wherever similar climate pressures occur.

We would use Australia's existing research lead as the foundation for a domestic climate-cooling industry, with public support concentrated on proving technologies and establishing their environmental performance before commercial markets take over.

Research and field demonstration

Research would continue from laboratory development through increasingly realistic field trials, with environmental monitoring incorporated alongside engineering development.

Initial opportunities include marine cloud brightening, seawater fogging, and other technologies capable of reducing acute heat or light stress in vulnerable ecosystems. Support would remain open to other approaches that demonstrate credible environmental benefits.

Field testing would establish not only whether a technology works, but where it works, what conditions affect its performance, what environmental effects accompany it, and what equipment, modelling, and operational capability are needed for reliable deployment.

Successful technologies facing further commercial or industrial scale-up risk could progress through the broader innovation-commercialisation pathway rather than requiring a separate funding system.

Verified environmental outcomes

Where cooling interventions produce environmental benefits that can be reliably quantified and attributed, we would establish independent measurement and certification methods for those outcomes.

Verified outcomes could support environmental credits or other forms of results-based finance where a sufficiently robust methodology can be established. Existing Australian environmental markets demonstrate how independently measured environmental improvements can attract government, private, and philanthropic investment.

Cooling outcomes would remain separate from carbon sequestration credits. Reducing heat stress can protect ecosystems and create substantial environmental value, but does not itself remove carbon dioxide from the atmosphere.

Technologies whose benefits cannot be reduced to a reliable tradeable unit could still be commercially deployed as environmental services where customers value the demonstrated outcome.

Building an Australian export industry

Commercial capability would include more than the physical cooling equipment. Australian businesses could develop and export modelling, forecasting, environmental monitoring, deployment systems, engineering, operational services, and other expertise required to use these technologies effectively.

A targeted company-tax incentive would apply to qualifying income from climate-cooling technologies and services where substantial research, intellectual property, and core operational capability are retained in Australia.

Eligibility would depend on productive activity retained in Australia rather than the nationality of shareholders or the destination of sales. This would allow Australian businesses to attract international investment and serve both domestic and overseas customers while preserving the productive capability that creates the tax advantage.

The incentive would complement, rather than replace, ordinary research and commercialisation support. Once technologies are proven, international customers and environmental finance should increasingly fund deployment.

Residual risks

1. Cooling technologies may perform differently between locations because weather, ocean conditions, ecosystems, and other environmental factors vary. Successful deployment in Australia would therefore not guarantee equivalent performance elsewhere without local assessment and adaptation.

2. Some useful environmental outcomes may remain difficult to quantify precisely enough for tradeable credits even where the underlying intervention is demonstrably beneficial. Commercial services and direct environmental investment would remain available without requiring every technology to support a credit market.

3. Climate-cooling interventions necessarily alter local environmental conditions. Field testing, monitoring, and ordinary environmental approval processes can identify and control foreseeable impacts, but some uncertainty will remain as technologies progress to larger scales.

References

Southern Cross University — Marine Cloud Brightening | Reef Restoration and Adaptation Program — Cooling and Shading | Reef Restoration and Adaptation Program — Publications | ARIA — Exploring Climate Cooling: Funded Projects | Eco-Markets Australia — Reef Credits | Eco-Markets Australia — Reef Credit Rules and Requirements