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Contracts, liquidity and risk: The NEM Review through a commercial lens

Contracts, liquidity and risk: The NEM Review through a commercial lens

From visibility reforms to the ESEM, the Nelson Review puts contracts at the centre of the NEM’s future. We explore the implications for liquidity, risk allocation, and the bankability of new investment.

Updated
October 2, 2025
Published
October 2, 2025
Contracts, liquidity and risk: The NEM Review through a commercial lens

Why this review matters for market participants

The Tim Nelson-chaired Review of the NEM ('Nelson Review') has become a focal point of discussion across the energy sector.  

While earlier NEM reviews have often concentrated on spot market design and operational reliability, the Nelson Review places greater weight on the contracts market - swaps, caps, power purchase agreements (PPAs), and emerging structures such as battery tolling agreements - alongside broader reforms on resource visibility, reliability, and governance.

Much commentary to date has focused on governance and reliability. These are important themes but, for developers, they are not the issues that will determine which projects get financed.

The more pressing commercial question is how developers can obtain financeable (“bankable”) offtakes given two contexts:

  • Current context: offtake prices for renewables are sitting below project costs, especially in South Australia and Victoria; and  
  • Future context: a NEM increasingly dominated by variable renewables.

As advisors working directly with developers on the design of bankable renewable and storage contracts, we see the importance of offtake bankability for financing projects and, ultimately, advancing Australia’s decarbonisation.  

We also see the implications of the Nelson Review for bankability and liquidity of offtakes. For corporates and retailers, these reforms may eventually shift procurement tools, but the immediate weight of impact falls on developers and asset operators.

Short-term reforms: Greater visibility, modest impact

Review highlights

  • Recommendation to maintain the real-time energy-only spot market while giving AEMO greater visibility over a broader set of price-responsive resources, including unscheduled generation and flexible demand.
  • Support for the AEMC’s rule change process to ensure efficient and competitive functioning of the spot market, instead of relying on broader regulatory interventions.

Commercial implications

These recommendations represent continuity more so than disruption. No material change to the market framework is proposed, other than incorporating new categories of participants such as Virtual Power Plant (VPP) aggregators and demand response providers.

Commercial takeaway

  • Spot and short-term forward markets remain structurally fit for purpose. The bigger shift will be the extent to which demand-side visibility translates into meaningful market participation. Improved visibility may support better dispatch and spot price discovery, but it does not on its own create greater liquidity in medium- and longer-term forward markets.

Medium-term reforms: The push for new fungible contracts and the Market Making Obligations (MMO)

Review highlights

  • Proposed MMO to enhance transparency, liquidity, and accessibility of electricity derivatives in each NEM region.
  • In theory, the MMO would level the playing field by requiring larger players to quote buy and sell prices for standardised, fungible contracts on exchange-traded platforms.
  • These contracts are broadly grouped into bulk zero-emissions energy, shaping products, and firming services.
  • The design of these contracts will be left to an AER-convened working group, consisting of contract market participants (including generators, retailers, and electricity users), alongside their representative peak bodies, meeting bi-annually to define a small set of contracts under the MMO.

Commercial implications

The panel’s intent is clear, to improve liquidity by pushing participants toward contracts that can be more easily traded across the market. But fungibility is easier to describe than to achieve. There is also a trade-off between fungibility and bankability, especially for variable renewables like wind and solar.

A few years ago, CORE Markets introduced solar and wind shapes, which had pre-determined generation profiles. Our solar shape was a NEM-wide monthly product, meaning the underlying generation profile was the same across all mainland NEM regions for each day of a given month, and then varied from one month to the next.  

This structure aimed to balance liquidity and bankability:  

  • Bankability, by allowing generation profiles to vary monthly as opposed to having no intra-year variation  
  • Liquidity, by having the same generation profile across all mainland NEM regions and also having these profiles set for all days within a given month  

However, our experience brokering and trading the solar shape reveals a relatively one-sided market - with far more sellers than buyers (as covered further below).  

While market participants appreciated the greater standardisation of a solar shape product vs. a run-of-meter solar PPA, the solar shape was still not bankable: lenders, and ultimately project developers, continued to prefer run-of-meter contracts

This experience revealed fungibility is difficult when resources’ generation profiles vary significantly within and across regions. And solar output is more correlated across regions than wind – making a “standard” wind shape product even less bankable.  

All this experience suggests it will be difficult for the industry to develop fungible and bankable contracts for solar and for wind which is at the heart of the MMO’s consideration of fungible contracts for “zero emissions bulk energy” provision.

In addition to contract design, industry pushback is likely, particularly over features such as bid-ask spread limits and uncompensated costs for market-making, which could constrain market makers and lead to unintended liquidity distortions.  

That said, the drive for fungibility is likely to spur innovation in contract structures.  

In CORE Markets’ experience, striving for fungibility with respect to time of day is likely to be more fruitful than with respect to generation profile. The core of any contract – whether a swap, cap or run-of-meter contract – is an hourly 1MW ‘flat’ shape. These time-of-day products are easier to standardise and match against demand.  

And the growing hybridisation of projects – coupling BESS with solar and, increasingly, also with wind – make it easier for such projects to defend time-of-day contracts than standalone solar or wind.

Therefore, the Nelson Review’s drive for greater fungibility, with the attendant impacts on contract innovation, should be welcomed.

Commercial takeaway

  • The MMO signals that standardisation is coming, but it won’t erase the diversity of resources and risks across the NEM. Developers and buyers who treat fungibility as a design constraint - building projects and contracts with market demand in mind - will be better positioned. The opportunity lies in creating innovative, standardised contracts that balance liquidity, bankability and risk.

The contract design lens: What contract fungibility have we seen?


CORE Markets has already seen progress in making renewable contracts more fungible than the traditional run-of-meter contract. As mentioned, in 2019 we developed products that allowed solar and wind projects to move closer to standardisation, while still reflecting the characteristics of their generation profiles.  

Proxy revenue swaps also offer greater fungibility than run-of-meter structures, and these have gained some traction in recent years.

Similar innovation is occurring in storage.  

New structures such as “Heads & Tails” contracts and “Super Peak” swaps (with super peaks defined, for example, as a two-hour morning peak and a four-hour evening peak) have created ways to standardise storage value while still reflecting operational realities.  

These examples show that contract design can evolve to meet the market’s need for liquidity and risk transfer without relying solely on bespoke arrangements.

For developers, these innovations show that standardisation need not mean one-size-fits-all - bankability can be achieved while retaining alignment with asset characteristics.

These lessons are critical context for the Nelson Review’s proposed long-term reforms, particularly the Electricity Services Entry Mechanism (ESEM).

Long-term reforms: The Electricity Services Entry Mechanism (ESEM)

Review highlights

  • Establishment of the ESEM where a central body runs competitive reverse auctions for long-term contracts.
  • Contract structures are proposed to be similar to those under the MMO in the medium-term derivatives markets, i.e. one fungible contract for each of bulk zero-emissions energy, shaping, and firming services.
  • The ESEM implementation body will competitively procure contracts for the later years of a project’s life, covering a time horizon beyond which the bulk of the market contracts forward (e.g., from the 6th year following a project’s operations; this horizon remains to be determined). These contracts will initially be warehoused and sold back to the market when demand emerges.  
  • Participation would extend beyond traditional generators to CER and DER aggregators and demand-response providers, to bid into the ESEM’s reverse auction process.

Commercial implications

The competitiveness of later-stage projects has already been observed under the Capacity Investment Scheme (CIS) – reflecting the trumping of merit criteria over eligibility criteria.  

The ESEM’s design will similarly tilt toward projects that have already secured offtakes, while offering less certainty for those still at early stages. In this way, the ESEM’s de facto merit criteria will be financial value, rather than the various non-financial value criteria under the CIS including social licence and First Nations commitments.

The effectiveness of the ESEM will depend heavily on the success (or otherwise) of the above-noted reforms to make standardised and fungible contracts for wind and solar projects. Without that foundation, ESEM auctions risk limited uptake with attendant poor price discovery and limited impact on enabling new projects to enter the market.

This said, the ESEM may provide greater price transparency than the CIS in two important ways:

  • By buying fungible contracts there may be less concern about price outcomes being publicised relative to the CIS, where price information (namely, the Floor & Ceiling prices, and Annual Payment Caps) has not been published.
  • Fungible contracts are easier to on-sell than the collar structure under the CIS, and the swaptions under the NSW Government’s Long-Term Energy Service Agreements (LTESAs). This should promote liquidity relative to what has occurred under the CIS and the LTESA.

ESEM governance arrangements and cost-recovery mechanisms remain to be resolved, though precedents can be drawn from CIS and LTESA mechanisms. We expect the ESEM to benefit offtakers / contract buyers, and ultimately consumers, more so than potentially has been the case under the CIS and LTESA, for the following reasons:

  • As noted above, the ESEM’s key eligibility criterion that projects be contracted first means offtakers must be a key target for a development project before entering the ESEM. These considerations are not the same under the CIS and LTESA where, in CORE Markets’ experience, offtakers are typically ‘solved for’ after knowing the outcome of the CIS / LTESA tenders
  • Signing an offtake signals that consumers value that project. As a signed offtake is a key eligibility (and merit) criterion, the ESEM should encourage higher financial value projects than has been the case under the CIS or LTESA, to greater consumer benefit.

Commercial takeaways

  • The ESEM is intended to address the “tenor gap” by contracting over a project’s later-life operations (from precisely when is to be determined, but possibly from the 5th or 6th year following the project’s market entry). The ESEM’s effectiveness will depend on how well it complements other contracting options, including early PPAs and retailer agreements.  
  • Unlike the CIS and LTESAs, which provide underwriting from COD onwards and are therefore central to bankability at the point of financing, the ESEM pushes contracting risk into later years. This tilt toward later-stage projects means developers seeking early offtakes may not find the ESEM sufficient to secure financing.
  • For developers, the ESEM may complicate matters relative to the CIS and LTESA. As mentioned, early-stage capacity build-out may not be meaningfully advanced by the ESEM.  
  • Early-stage project developers may therefore have to take a larger ‘leap of faith’ with respect to potential support under the ESEM than what would be available under the CIS (if the CIS were to be extended post-2027) or under the LTESA, for a NSW project. That said, the size of this ‘leap’ will be smaller as the ESEM is proposed to be evergreen, unlike the CIS.

From review to market action

The Nelson Review makes clear that Australia’s energy transition will be shaped less by changes to the spot market and more by the evolution of contract markets.  

The introduction of fungible contracts under the MMO – and longer-tenor contracting through the ESEM – will define how liquidity, bankability, and risk allocation evolve.

For developers and buyers, the question now is how to position. That means stress-testing procurement and offtake strategies against evolving contract designs and exploring bespoke structures that can balance liquidity with bankability.

CORE Markets works with project developers and other market participants to structure innovative contracts suited to shifting market conditions. Get in touch to see how we can help.

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