Flexibility is the third pillar of Australia’s energy transition
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Australia’s energy transition is usually described in physical terms: retire coal and gas, build new wind and solar, firm it with batteries, and strengthen the grid with new transmission. That picture is accurate, but incomplete.
What’s missing is a third pillar: flexibility from commercial and industrial (C&I) energy users. This includes flexibility from industrial plants, logistics hubs, cold storage, manufacturing lines, commercial buildings, embedded generation and behind-the-meter (BTM) batteries; orchestrated through modern energy management systems so it becomes measurable, dependable, and dispatchable.
At PowerSync Technologies, our view is simple: C&I customers are no longer passive energy users. They are effectively distributed energy plants that have already invested in sophisticated control systems and operational constraints and with the power of technology, can be translated into real market services. As the system moves away from the one-way energy mindset, where businesses were largely price-takers, businesses are already increasingly demand participation, not just exposure.
Why C&I flexibility matters: most electricity is used outside households
Australia’s electricity system is often discussed through a household lens, but the demand reality is broader with business and industrial energy usage comprising up to70% of all energy demand in the grid.
This is exactly where controllable load, process flexibility, and BTM storage are already widespread and where participation can scale quickly if the right systems and market pathways exist.
A GW is a GW: flexibility is equivalent to generation (when it’s dispatchable)
In power system terms, 1 GW of flexibility is the same as 1 GW of generation. If the grid needs 1 GW of balance, you can meet it by producing 1 GW more or consuming 1 GW less (or shifting 1 GW to a different interval). The physics doesn’t care whether the balancing comes from “supply” or “demand” - only that it is available, controllable, and verifiable.
Australia’s rules are already moving in this direction. The National Electricity Rules explicitly include wholesale demand response units in central dispatch alongside generating units. In addition, the wholesale demand response framework requires bidding and capacity declarations in a way designed to make load reduction behave like a scheduled, dispatchable resource.
A large amount of this capability already exists inside the grid today, it’s just not consistently “brought to market”. For example, Australian Energy Market Operator highlights that distribution networks can unlock 4 GW of latent consumer energy resources(CER) capacity through relatively lower-cost innovations like improved voltage management. That’s a concrete reminder that Australia doesn’t need to simply pushforward with constantly building more infrastructure to meet energy market demands, when technology is unlocking the enormous latent capacity that already exists in the grid.
Timing
A central tension in Australia’s transition is timing. AEMO’s Draft 2026 ISP points to ~6,000 km of new transmission by2050 under Step Change (with much of it needed in the next decade), and AEMO categorises typical network augmentation lead times as 3–5 years (short), 6–7years (medium), and >7 years (long). Yet where C&I sites already have(or can quickly add) interval metering, telemetry and control access, flexible load and behind-the-meter batteries can often be enabled for structured market participation in under a quarter (commonly 8–12 weeks). Crucially, orchestration technology doesn’t replace transmission or utility builds; it complements them by unlocking latent capacity inside the existing grid, making infrastructure work smarter, relieving constraints sooner, and extracting greater system efficiency during the years it takes to deliver major projects.
Flexibility reduces total system cost — especially network cost pressure
The transition is increasingly constrained by the cost and pace of “poles and wires” investment. Regulated network charges are becoming a dominant driver of bills in many outlooks, and regulators consistently identify wholesale and network costs as the two largest components of default prices. The Australian Energy Market Commission has also noted that network costs are the largest cost component in its residential price trends work.
Flexibility attacks that problem at its root by reducing the size and coincidence of peaks that drive augmentation, and it improves utilisation of existing assets.
The International Energy Agency frames demand flexibility as part of an “efficiency-first” approach: shifting or adjusting electricity use improves utilisation of existing generation and network assets, reduces peak stress, lowers curtailment, and supports cleaner integration.
In simple terms, if you can reliably shape demand and local supply behind the meter, you can often avoid (or defer) expensive network build, and you can make better use of what is already there.
Why businesses will demand a new deal
Historically, many C&I customers were forced into a blunt choice: accept exposure to wholesale volatility (directly or indirectly) or pay a premium for someone else to manage it through retail relationships. This ecosystem delivered limited visibility into how value was created and captured.
That model is breakingdown because capabilities inside businesses have changed:
- Modern C&I sites increasingly run advanced energy management systems, automation, and telemetry.
- Many already have onsite generation, controllable load blocks, and/or batteries.
- Operational constraints (production schedules, cold chain limits, safety margins, comfort bands, ramp rates) can be encoded so participation is reliable, not disruptive.
Unlocking the third pillar
Australia does not need to invent flexibility from scratch we simply need to leverage “latent capability” into dependable, dispatchable capacity. That requires three things:
- Systems to orchestrate and prove performance, including telemetry, control integration, constraint handling, dispatch logic, and measurement & verification that can stand up to market compliance expectations - capabilities PowerSync’s platform is built to deliver reliably at scale.
- Market pathways that treat flexibility as a first-class resource, across multiple value streams including wholesale optimisation, FCAS/ancillary services (where technically capable and compliant), and emergency/reliability response programs, not just WDRM. The Wholesale Demand Response Mechanism is still a key pathway for spot-market participation integrated with dispatch and bidding, but the next step is scaling participation beyond boutique programs through aggregation models and standardised onboarding that make it easy for diverse C&I sites to participate at scale.
- Network mechanisms that value local relief, recognising that AEMO’s ISP work highlights how much latent capacity depends on distribution-level enabling (such as voltage management and related innovations), which is a clear signal that flexibility and networks must be planned together, otherwise we keep paying for physical build where smarter coordination would do.
The bottom line is that Australia’s transition will absolutely be built on new wind, solar, batteries and transmission. Nevertheless, it will be cheaper, faster and more resilient if we fully recognise and operationalise the third pillar: flexibility from C&I and industrial customers. A gigawatt of flexible load (or BTM discharge) is a gigawatt of capacity, and much of it already exists inside our businesses and distribution networks. The remaining challenge is to deploy the orchestration systems and market mechanisms that can bring it to market reliably, at scale, and on timelines measured in weeks; not years.
Contact PowerSync Technologies today to discuss how your sites can participate safely and transparently - turning operational flexibility, BTM batteries, and embedded generation into measurable market services.
References
1. Australian Energy Market Operator (AEMO) (2025). Draft 2026 Integrated System Plan (ISP) (PDF).
2. Australian Energy Market Operator (AEMO) (2025). 2025 Electricity Network Options Report (Final) (PDF).
3. Australian Energy Market Operator (AEMO). Wholesale demand response mechanism (WDRM) – program overview (webpage).
4. Australian Energy Regulator (AER) (2025). Default Market Offer (DMO) 2025–26: Draft determination (news release).
5. Australian Energy Regulator (AER) (2025). Default market offer prices 2025–26: Final determination (PDF).
6. Australian Energy Market Commission (AEMC) (2024). Residential Electricity Price Trends 2024 (webpage).
https://www.aemc.gov.au/market-reviews-advice/residential-electricity-price-trends-2024
7. Australian Energy Market Commission (AEMC) (2024). Residential electricity price trends 2024 (report PDF).
https://www.aemc.gov.au/media/103032
8. Department of Climate Change, Energy, the Environment and Water (DCCEEW) (updated 12 Feb 2026). Residential buildings – Energy efficiency (webpage).
https://www.dcceew.gov.au/energy/energy-efficiency/buildings/residential-buildings
9. Department of Climate Change, Energy, the Environment and Water (DCCEEW) (updated 14 Oct 2025). Commercial buildings – Energy efficiency (webpage).
https://www.dcceew.gov.au/energy/energy-efficiency/buildings/commercial-buildings
10. International Energy Agency (IEA) (2026). The Value of Demand Flexibility – Analysis (webpage).
https://www.iea.org/reports/the-value-of-demand-flexibility
11. International Energy Agency (IEA) (2026). The Value of Demand Flexibility: Benefits beyond balancing (PDF).
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