Access, Risk and Bankability: The Real Test for Renewable Energy Zones

Renewable Energy Zones (REZs) are one of the most important tools available to support Australia’s energy transition. 

The logic is compelling: deploy renewable generation, storage and transmission in the right locations, and do it in a coordinated way as our ageing fleet of coal generation exits the system. But as REZs move from concept to delivery, the challenge is becoming much clearer.  

The test is no longer whether the planning logic makes sense. It is whether REZs can deliver transmission in time, create a bankable pathway for renewable energy and storage projects, and provide real value for consumers and host communities. 

This challenge is no longer a theoretical one. It is playing out right now as New South Wales moves from access allocation into REZ delivery, and as Victoria develops its own access and connection frameworks. 

The REZ balancing act 

REZs must balance a wide range of objectives and often competing incentives. 

Governments and network planners are trying to optimise system outcomes, reliability, consumer value and social licence. They also need to deliver transmission and supporting infrastructure that is technically robust, efficient and sequenced with new generation and storage. 

Host communities are focused on land use, environmental impacts, cumulative disruption and local benefit. 

Developers face a different set of pressures. They need to secure land, approvals, access, connection, offtake, financing, equipment and construction contracts — all under a risk allocation that can be financed. 

Each of these objectives is legitimate. But they are not always naturally aligned. 

A project that looks attractive to a developer may not be the best fit from a whole-of-system perspective. A corridor that looks optimal on a map may still be difficult to deliver. A coordinated access framework may improve system outcomes, but also introduce new dependencies and risks for individual projects. 

This is the core challenge of REZ delivery. It is not just about building transmission or connecting projects. It is about aligning different incentives, risks and timeframes well enough that the system outcome improves and projects can still get built. 

Access rights are more than a capacity allocation process 

Access rights sit at the heart of this balancing act. They are often described as a mechanism for allocating transmission capacity. In practice, they do much more than that.

REZ access rights effectively decide who gets access to scarce transmission capacity, when they get access, and on what terms. That means they shape project sequencing, investment decisions, system outcomes, risk allocation and community impacts.

Done well, access regimes can help avoid disorderly connection queues, enable investment in transmission infrastructure, support the right mix of generation and storage, coordinate development across a region and improve host community outcomes. 

Under a more open, project-by-project development model, communities can be approached repeatedly by different developers, each consulting on projects that may or may not proceed. Over time, that creates fatigue and frustration. A coordinated REZ model has the potential to reduce duplication, minimise disruption and create clearer pathways for local benefit. That is one of the most important benefits a coordinated REZ model can provide.  

Access regimes also involve trade-offs 

They do not remove risk from the system, rather, they reshape it. For developers, access frameworks can introduce new risks around allocation, timing, coordination of shared infrastructure, project interdependencies and sequencing. 

That matters because renewable energy and storage projects are financed project by project. A REZ may make sense from a system-planning perspective, but a developer still needs a bankable pathway through access, connection, planning approvals, supporting infrastructure, workforce, offtake, financing, procurement and construction. 

If that pathway is unclear, projects may stall. In some cases, developers and offtakers may look outside REZs for projects with a clearer or more flexible pathway to financial investment decision. That does not undermine the REZ model. It simply shows why access frameworks need to be designed with this commercial reality in mind. 

Coordination must support bankability 

The debate is often framed as market-led development versus coordinated planning. That framing is too simple. A purely market-led approach can often move more quickly and reward projects that are commercially advanced or well positioned. But it may not deliver the best whole-of-system outcome. It may not deliver the right mix of generation and storage, most efficient use of transmission capacity, or the best outcome for host communities. 

Equally, an overly controlled framework can slow investment, reduce flexibility and make projects harder to finance. The right answer is balance. But finding that balance is complicated. 

Market conditions are fluid. Planning and delivery timeframes are long. Technology and construction costs change. Demand forecasts change. Offtake markets change. The needs of communities also evolve. Good access frameworks should feel enabling, not restrictive. They should: 

• reward projects that are genuinely ready – technically, commercially and socially; 

• give investors clear, durable and workable rules; 

• facilitate coordination without creating unnecessary friction; 

• improve certainty without locking projects into pathways that cannot adapt as the network, project and market conditions evolve; and  

• support projects to reach financial close and be constructed. 

That is the commercial test. If access frameworks improve coordination but make projects less bankable, the system will not get the investment it needs quickly enough. 

First movers carry real delivery risk 

Foundation projects play an important role in unlocking broader REZ development. But they can also carry disproportionate risk. They may face unresolved questions around access costs, shared infrastructure (road upgrades, water, workforce accommodation etc), connection sequencing, system studies, construction interfaces and timing dependencies with the broader network.  

The experience gained in the Central-West Orana and South-West REZs matters because these projects are creating the practical lessons that will shape future REZs, including New England and the emerging Victorian framework. 

Aligning incentives to drive system-wide outcomes  

A REZ brings projects together geographically and electrically. But each project remains an independent commercial development, with its own owners, contracts, timeframes, risk appetite and investment hurdles.  

Designing a regime with the right incentives for multiple independent developers to coordinate is a unique challenge for REZs. Coordination does not happen simply because projects are located in the same zone. It needs clear frameworks, aligned incentives and disciplined delivery governance. 

New demand can help too 

The next evolution of REZ planning will not only be about generation and storage. It will also need to consider new demand. Increasingly new large loads, in particular data centres, are in search of significant connection capacity. This creates an opportunity for renewable energy projects and REZs. 

If planned well, large loads – particularly where they are genuinely flexible – can improve utilisation of existing and new transmission infrastructure, provide stronger offtake opportunities, reduce curtailment risk and help projects achieve financial close. If not planned well, these new large loads can compete for connection capacity, increase planning complexity and introduce new land-use and community considerations. 

The value comes when demand, generation, storage and network delivery are planned and coordinated together. REZs create an opportunity to do this in a more coordinated way.  

Getting the balance right 

REZs remain a powerful and necessary part of Australia’s energy transition. 

They provide a framework for coordinating generation, storage and transmission in a way that a market-led or project-by-project approach cannot always achieve. They can support better use of network capacity, improved community outcomes, more efficient infrastructure delivery and an orderly transition as coal exits the system. 

But their success will depend on execution. 

The frameworks must reduce uncertainty rather than add complexity. Access rights must support coordination without undermining bankability. Enabling infrastructure must be planned as part of the delivery model, not left as an afterthought. 

That is a difficult balance to strike. But it is also why REZs are so important in Australia’s energy future.

If we get that balance right, REZs will not just connect individual renewable energy projects. They will help shape the next generation of Australia’s energy system – one that is more coordinated, resilient, investable and aligned with the needs of consumers and communities.