Energex Dynamic Business Tariff Trial: What Queensland Businesses With Solar and Batteries Should Know

Most commercial battery business cases in Queensland rest on a simple idea: charge when electricity is cheap, discharge when it is expensive, and pocket the difference. Energex's Dynamic Business Tariff Trial changes that arithmetic for Brisbane and South East Queensland businesses weighing up solar and storage — but not in the way a headline figure suggests.

The trial's most eye-catching number is a critical peak import charge of about $2.16 per kilowatt-hour — roughly 73 times the trial's ordinary evening peak energy charge. It can make a battery look like a money-printing machine, until you read the conditions: the charge applies only during notified events, each event type is capped at 40 hours across the trial year, entry is at Energex's discretion, and the network tariff is not your electricity bill — your retailer sits between Energex and your business, and is under no obligation to pass the network structure through.

This blog explains what the trial is, who can take part, exactly how it charges, what is confirmed and what is not, and what a battery owner should model before treating it as a revenue stream. Every figure comes from one published source — a Tekmor Intelligence analysis by Kevin Qian, published 9 November 2026, drawing on Energex's Expression of Interest (EOI), Energex's notification to the Australian Energy Regulator (AER), and Energex's 2026-27 Network Price List — plus the dated updates in Section 12. Where Tekmor publishes an illustration, we say so: illustrations are not savings forecasts, and they are not EServices4U's figures.

The short version: the trial rewards batteries that can respond to a notified event at the right time, on the right day, with the right amount of charge held in reserve. It does not reward simply owning a battery.

1. What the trial is — and what it is not

The Dynamic Business Tariff Trial is a network tariff trial run by Energex, the electricity distributor for South East Queensland — Brisbane, the Gold Coast, the Sunshine Coast, Ipswich and Toowoomba — aimed at business sites that combine battery storage with solar generation or on-site load. It is scheduled to run from 1 July 2026 to 30 June 2027.

Its purpose, as described in Energex's EOI and reported by Tekmor Intelligence on 9 November 2026, is to test dynamic, event-based network pricing: during a small number of notified events, the price of importing electricity — or the reward for exporting it — jumps dramatically. The learnings are intended to inform a dynamic critical-peak tariff Energex intends to offer in the 2030-35 regulatory period; its EOI describes a possible submission of a final design to the AER for potential implementation from mid-2030. That is not a confirmed launch date, and it should not be quoted as one.

Three things the trial is not are worth stating plainly:

• It is not a tariff any business can simply switch to. Entry is discretionary: Energex keeps the right to include or exclude any customer "at its absolute discretion" (EOI, as reported by Tekmor), and a retailer letter of support is also needed in most cases (Section 2).

• It is not a retail tariff. Energex bills the retailer, not the business, and what appears on your bill depends on the retail product your retailer offers — which could differ in rates or in how events are handled.

• It is not a revenue stream you can count on. The number of priced events, their timing, and whether your site is called are all uncertain, and Energex forecasts only small trial revenue — about $70,000 low voltage and about $130,000 high voltage, according to Tekmor.

2. Who can take part: eligibility and entry conditions

Eligibility is narrow, defined by the customer's connection and equipment. According to Tekmor's analysis of Energex's EOI, a site must meet all of the following:

• Customer type: the site must be a Standard Asset Customer (low voltage) or a Connection Asset Customer (high voltage).

• Export capacity: the site's export capacity must be greater than 30 kW. This is an entry condition, not permission to export at any particular level — confirm your export limit and connection agreement separately.

• Battery plus generation or load: the site must have battery storage together with either on-site generation (such as solar) or a load.

• Retailer support: a retailer's letter of support is needed, committing to a retail version of the tariff, to data sharing and to facilitation — unless the customer is itself the Financially Responsible Market Participant (FRMP).

• Energex discretion: Energex keeps the right to include or exclude any customer "at its absolute discretion".

The low-voltage version carries tariff code 94500 and the high-voltage version tariff code 92500. The rates in this article are the low-voltage rates; the high-voltage tariff uses different rates plus a connection-unit charge, so do not apply the figures in Section 3 to a high-voltage site.

The trial term is scheduled for 1 July 2026 to 30 June 2027. Energex may extend it, amend it on extension, or end it early with reasonable notice. Afterwards, the retailer nominates a standard network tariff for the site — and a battery sized and operated for the trial must still make sense on that standard tariff. Verify which standard tariff would apply to your site, and model the battery on that tariff as well as on the trial tariff.

The practical entry path runs through your retailer: if your retailer does not offer a retail version of the trial tariff, you cannot access it, however suitable your site and battery may be. As of 9 November 2026, there was no public information on which retailers offer a retail version. Verify with your retailer whether it supports the trial before spending time or money on an application.

3. How it charges: the published low-voltage rates

The trial's charging structure has four parts: a fixed daily charge, an ordinary evening peak energy charge, three critical peak pricing components that apply only during notified events, and a monthly shoulder demand charge. The rates below are the low-voltage rates (tariff code 94500) from Energex's 2026-27 Network Price List, as reported by Tekmor Intelligence on 9 November 2026. All rates are exclusive of GST unless stated otherwise.

Charge component	Rate (ex GST)	When it applies
Fixed daily charge	$9.134 per day	Every day of the trial
Peak energy charge	2.947 c/kWh	All energy consumed weekdays 5pm–8pm; none on weekends
CPP import charge	$2.15788/kWh	Only during notified CPP import events
CPP export charge	17.738 c/kWh	Only during notified CPP export events
CPP export reward	$2.15788/kWh credit	Only during notified CPP export-reward events
Monthly shoulder demand charge	$4.08/kW/month	Highest 30-minute kW demand in shoulder windows (see below)

The shoulder demand windows are weekdays midnight–11am, 1pm–5pm and 8pm–midnight, and weekends midnight–11am and 1pm–midnight. The charge is based on the highest 30-minute kW demand in those windows during the month, so a single half-hour of high demand can set the charge for the whole month — a point that matters for battery recharging (Section 9).

One element remains unresolved: Energex's EOI also lists an off-peak demand charge for the 11am–1pm window, but the AER notification does not mention it and the price list shows no rate for it — an unresolved discrepancy, not a confirmed exemption. Verify the current position with Energex or your retailer before building a charging schedule around that window.

Two features deserve attention. First, the ordinary evening peak charge — 2.947 cents per kilowatt-hour — is small: shifting a kilowatt out of the 5pm–8pm window every weekday for a year is worth only about $23 in network charges (Section 7). Second, the CPP charges are very large but very rare — each event type capped at 40 hours over the whole trial term — so the trial's value, if any, is concentrated in a small number of half-hours you cannot predict in advance.

4. Critical Peak Pricing events: how they work

Critical Peak Pricing is the heart of the trial, and the part most easily misunderstood. According to Tekmor's analysis of Energex's EOI and AER notification:

• Three event types, each capped at 40 hours. The import charge, the export charge and the export reward are separate event types, each capped at 40 hours — 80 half-hours — over the trial term. Different types can be called at the same time, and charges are applied interval by interval, each half-hour priced on its own terms.

• Notice by email, "best efforts" at a day ahead. A day ahead is the aim, not a guarantee — a business that needs more notice to hold battery charge in reserve should not assume it will always get it.

• Some events may be unpriced tests. A battery that discharges for a test event earns nothing for it.

• Import charges and export rewards are expected during high network demand; export charges during low demand, per the AER notification. In practice, import-charge events are likely on hot summer evenings when the network is under strain, while export-charge events are likely at sunny middays when solar output is high and network demand is low.

A battery's value therefore depends on three things happening together: an event is called, your battery has charge available, and your site's load and export position let you use it. A battery empty from discharging earlier, or full when an export-charge event arrives, cannot help you (see the example in Section 8).

5. What is confirmed — and what is not

As of 9 November 2026, when Tekmor Intelligence published its analysis, the confirmed facts were:

• Energex has notified the AER of the two trial tariffs (low voltage 94500 and high voltage 92500).

• The AER approved Energex's overall 2026-27 pricing proposal on 22 April 2026.

• Trial rates appear in the published price list — Energex's 2026-27 Network Price List.

• An application form is online.

What was not publicly known at that date — and what any business should check before acting — was:

• How many sites have been accepted into the trial. There was no public information on this.

• Which retailers offer a retail version of the tariff. There was no public information on this either.

• Whether any priced CPP events have been called. Again, no public information.

That is a thin public record for a trial running since 1 July 2026: a business cannot verify from public sources whether events have been called, how often, or what participants have experienced. Before committing capital, verify the current position directly — ask your retailer whether it supports the trial, ask Energex about the application process and current status, and ask for any published event history.

6. Your network tariff is not your bill

The network tariff is not your bill.

Energex bills the retailer, not the business, and the retailer then bills the business under a retail product. Retailers are under no obligation to pass network structures through: a supporting retailer's product could differ from the network tariff in its rates, in how it handles events, or in both. Retail energy charges also sit on top of network charges — the network price list is only one layer of what you pay.

In practice, the $2.15788/kWh CPP import charge is what Energex charges the retailer for network use during an event — not necessarily what appears on your bill. Your retailer might pass it through in full, in part, smooth it into a different structure, or not offer a trial product at all. The $2.15788/kWh CPP export reward is likewise a network credit to the retailer, not a payment your business is assured of receiving.

The correct way to assess the trial is to model the actual retail offer, not the network price list alone. Before you make any decision, verify whether your retailer offers a retail version of the trial tariff and ask for its rates and event-handling terms in writing; verify how event charges and rewards are passed through; verify what happens to your other charges under the retail product; and verify what happens when the trial ends — which standard retail and network tariff you move to, and what that does to the battery's economics.

7. What 1 kW is worth: Tekmor's published illustrations

Tekmor Intelligence published a set of illustrations in its 9 November 2026 analysis, showing what each charging mechanism is worth for a single kilowatt using the published network rates only. They are Tekmor's published illustrations — not EServices4U's figures, and not savings forecasts.

• Removing 1 kW of import from every weekday 5pm–8pm window for a year is worth about $23 in network charges (261 weekdays × 3 hours × 2.947 cents) — small, because the rate is small.

• Holding monthly shoulder demand 1 kW lower all year is worth $48.96 (12 months × $4.08 per kW per month) — but it is a monthly charge, so a single half-hour of high demand can undo a month of careful management.

• If all 40 capped CPP hours were called and the battery avoided 1 kW of import in each, the network saving would be about $86 (40 hours × $2.15788) — a ceiling, not a forecast, assuming every capped hour is called and the battery avoids a full kilowatt of import in each.

• An illustrative incremental retail spread of 10 cents per kWh across 783 evening hours gives $78.30 per 1 kW shifted before losses (783 hours × 10 cents) — an illustrative spread, not a typical rate claim and not a net saving, and it excludes the cost of recharging the battery.

These figures illustrate different charging mechanisms, and they must not be added together: if a retail spread already includes network charges, do not add network savings on top of it again. Adding the $23, the $48.96, the $86 and the $78.30 together would produce about $236 per kilowatt with no basis in any single, coherent scenario. Each illustration isolates one mechanism; a real dispatch has to satisfy all of them at once, in one schedule, with one battery.

The trial's value is concentrated, conditional, and capped: a kilowatt available for a CPP event is worth far more than one shifted out of the ordinary evening peak — but only if the event is called, the battery is charged and ready, and the retail product passes the value through.

8. The event-day example: why timing beats capacity

Tekmor Intelligence published a hypothetical event-day example in its 9 November 2026 analysis: two batteries of the same size, discharging the same amount of energy, can produce very different results depending on when they discharge and how they recharge. This is Tekmor's hypothetical, with its assumed parameters, covering selected network charges only — not a full bill, not a payback calculation, and not a forecast for any real site.

The assumed parameters: a 100 kW / 200 kWh usable battery, 90% round-trip efficiency, 100 kW charge limit; both strategies start full; evening load steady at 200 kW import 5–8pm on a weekday; a CPP import event 6–8pm, notified a day ahead; the rest of the month the highest shoulder demand otherwise 150 kW, and overnight load 70 kW.

Strategy A — fixed spread: discharge evenly 5–8pm at about 66.7 kW, then recharge at 100 kW after midnight on top of the 70 kW overnight load.

Strategy B — event-aware: hold charge until 6pm, discharge at 100 kW through the event, and recharge without creating a new demand peak.

Both discharge the same 200 kWh and need about 222 kWh of AC recharge input at 90% round-trip efficiency (200 ÷ 0.90 ≈ 222). The difference is entirely in timing.

Selected network charges	No battery	Strategy A (fixed spread)	Strategy B (event-aware)
Peak energy charge (5–8pm)	$17.68	$11.79	$11.79
CPP event imports (6–8pm)	$863.15	$575.43	$431.58
Incremental shoulder demand charge	$0.00	$81.60	$0.00
Total selected charges	$880.83	$668.82	$443.36
Saving vs no battery	—	$212.01	$437.47

The $225.46 difference — more than doubling the saving — comes from two sources: $143.86 from discharge timing, because Strategy B puts the full 100 kW into the event window, when each kilowatt-hour avoided is worth $2.15788; and $81.60 from the recharge path, because Strategy A recharges at 100 kW after midnight on top of a 70 kW overnight load, creating a new monthly shoulder demand peak of 170 kW — 20 kW above the previous 150 kW peak (20 kW × $4.08).

Excluded from these totals are the fixed daily charge, the base shoulder demand charge on the first 150 kW, the recharge energy cost, the opportunity cost of solar used for charging, battery capital and operating costs, and any off-peak demand charge for the 11am–1pm window. Results also change with event timing, notice, load shape, and retail pass-through; a real event may be called with less notice, at a different time, or not at all.

A battery on a fixed "discharge every evening" schedule can leave significant value on the table under this trial, and can even create a new demand charge through its recharging. An event-aware dispatch is worth materially more — but it requires reliable event notification, a control system that can act on it, and a battery not already committed elsewhere at the critical moment.

9. The conflicts: one battery, several jobs

A commercial battery is a single store of energy that several value streams all want to use at the same time. Under the trial, those conflicts sharpen, because the trial's rewards are concentrated in a few half-hours while the battery's other jobs run every day. Tekmor identifies four conflicts any Queensland business should understand before modelling the trial.

• Event reserve versus daily cycling. Holding charge in reserve for a possible CPP event means not using that energy for ordinary evening peak shaving — and keeping a reserve costs something on every day no event is called, which, given the 40-hour cap and possible unpriced test events, will be most days. A battery fully cycled every day has nothing left when an event arrives; one that always holds a full reserve underperforms on ordinary days.

• Export reward versus site load. The CPP export reward pays only for energy actually exported: a 100 kW battery at a site drawing 200 kW can only reduce import, and the reward is only available where load falls below combined solar and battery output during the event window. Verify your site's load during likely event windows — typically hot summer evenings — before counting any export reward.

• Export charge versus solar soak. Export-charge events are expected during low network demand — in Queensland, typically sunny middays, when solar output is high. If the battery is already full from morning solar, surplus solar has nowhere to go: the site must either pay to export it (17.738 cents per kilowatt-hour during an export-charge event) or curtail it. Filling the battery early creates this exposure; leaving headroom avoids it but may leave the battery short for the evening.

• Recharging versus demand windows. Recharging is itself a load, and if it creates a new monthly demand peak it incurs the $4.08/kW/month shoulder demand charge. The 11am–1pm window is sometimes proposed as a recharge window, but the AER notification does not mention an off-peak demand charge there and the price list shows no rate for it. Even if the window were free of demand charges, it lasts only two hours: at an assumed 100 kW charge limit, a battery can take at most 200 kWh of AC charge input, while restoring 200 kWh usable needs about 222 kWh at 90% round-trip efficiency.

These conflicts are why adding up each mechanism's value separately overstates the benefit: one battery cannot simultaneously hold a full event reserve, cycle fully every evening, absorb all midday solar, and recharge without touching a demand window.

10. What a proper model should cover

Tekmor's analysis sets out what a credible model of the trial should include. If you engage an adviser, installer, or developer to model a battery for your site, ask whether their model covers each of the following — and if it does not, treat its results with caution.

• Kilowatts and kilowatt-hours separately, sized on 30-minute interval data. The trial charges on 30-minute intervals — the demand charge is set by the highest 30-minute demand, and CPP charges apply interval by interval — so a model built on monthly averages or daily totals cannot capture it. It must use your site's actual 30-minute interval data for load, solar output, and export.

• Losses, throughput, and warranty throughput limits versus actual dispatch. A battery that cycles more often, or more deeply, uses up its warranted throughput faster: check the dispatch against the warranty throughput limit, and include the cost of energy lost in each cycle.

• Forecast error. Real operation involves wrong load and solar forecasts, wrong event timing, late notice, and unpriced test events, so a model that assumes perfect foresight will overstate the benefit. Ask for a sensitivity case: what happens if half the events are missed, or if notice arrives only hours ahead?

• Connection constraints. Confirm your export limit and connection agreement: the trial's entry condition of export capacity greater than 30 kW is not permission to export at any particular level, and a model that assumes export your connection agreement does not allow is not a model of your site.

• Fallback behaviour. What happens if communications fail, if the event email is missed, or if the trial ends early? The model should show what the battery earns on the standard tariff that would apply afterwards. A battery that only makes sense if every event is caught is a fragile investment.

• One combined dispatch. Above all, model all value streams in one constrained dispatch rather than adding separate estimates together. The battery has one state of charge, one charge limit, and one discharge limit: optimise a single schedule against all the charges at once — peak energy, CPP import, CPP export, CPP reward, and demand — and report the result of that single schedule, not the sum of five separate best cases. If a proposal presents a single "annual saving" figure without showing the dispatch, the interval data, the losses, and the fallback case, ask for them.

11. What this means for Brisbane and Queensland businesses

For a Brisbane business, the trial sits inside the Energex network, which covers South East Queensland. For a business in regional Queensland on the Ergon Energy network, the trial itself does not apply — Ergon is a separate distributor with its own tariffs. The principles still travel: event-based pricing, demand charges set by a single half-hour, and the gap between network and retail tariffs are features of the Queensland market generally.

Within South East Queensland, the businesses most likely to use the trial are those with, or planning, a battery of meaningful size alongside solar, whose load shape leaves room for the battery to act. A warehouse with a large roof, a daytime load, and a battery that can cover the evening peak is the classic candidate. A site whose load is flat and high through the evening, like a cold-storage facility, may find its battery can only reduce import and never export, removing the export reward from the picture.

Three practical points:

• Check your export capacity first. The trial requires export capacity greater than 30 kW, yet many commercial sites have export limits well below their solar capacity, and some have zero-export arrangements. Verify your export limit and connection agreement with Energex first.

• Talk to your retailer early. Your retailer's willingness to offer a retail version is decisive: if it does not support it, the trial cannot reach your bill. Ask for the retail terms in writing — including how events are notified, how charges and rewards are passed through, and what happens when the trial ends.

• Do not buy a battery for the trial alone. The trial runs to 30 June 2027, may end early, and covers at most 40 hours of each event type. A battery is a 10-to-15-year asset: its business case must stand on the ordinary tariff, self-consumption, demand reduction, and resilience — with any trial benefit as upside, not as the foundation.

12. Three dated updates that sit alongside the trial

• AER final decision, 30 October 2026: optional demand tariffs and flexible load tariffs stay. The Australian Energy Regulator's final decision of 30 October 2026 refused Energex's and Ergon Energy's requests to remove optional demand tariffs (from 1 July 2027) and flexible load tariffs (from 1 July 2028), so those structures remain available on those dates — a reminder that tariff structures change by regulatory decision, not by assumption.

• Clean Energy Regulator: SRES eligibility expanded from 100 kW to 1 MW, from 1 October 2026. The Clean Energy Regulator expanded Small-scale Renewable Energy Scheme (SRES) eligibility from 100 kW to 1 MW from 1 October 2026, with STC (small-scale technology certificate) applications expected in mid to late November 2026. Verify the current SRES position for your system size and installation date before including any certificate value in a business case.

• Federal Cheaper Home Batteries Program, from 1 July 2025. The federal Cheaper Home Batteries Program has applied from 1 July 2025. It supports batteries, not solar panels, and eligibility depends on the installation's circumstances — do not assume a commercial battery qualifies. Verify eligibility before including any program benefit in a business case.

13. How This Works for Both Sides

A tariff trial only works if it works for the business that hosts the battery, the installer or developer that builds the project, and the network that runs the trial. Here is how it looks from each angle.

• For the business owner: the trial offers a chance to be paid — via the network and retail chain — for helping the network at its most stressed moments. But the benefit is conditional, capped, and uncertain, and the costs of being ready are real: holding a reserve, managing a more complex dispatch, and accepting that events may be called when you least expect them. The owner's interest is a battery that pays its way on ordinary days and treats the trial as a bonus; the worst outcome is one bought for the trial that cannot pay for itself once the trial ends.

• For the installer and developer: the trial creates a genuine point of difference for a well-designed system: an event-aware battery with a reserve policy and a demand-safe recharge plan is worth more than a battery on a fixed schedule (Section 8). But it also raises the bar on what a credible proposal must contain: one that quotes the $2.16/kWh figure without the 40-hour cap, without the retail pass-through question, and without a single combined dispatch is not credible.

• For the network (Energex): the trial is a learning exercise. Energex is testing whether very high-priced events change the behaviour of flexible customers, and whether that behaviour helps manage network peaks. The small forecast revenue — about $70,000 low voltage and about $130,000 high voltage — shows the trial is designed to produce evidence for a possible dynamic tariff in the 2030-35 regulatory period, not to raise money.

Frequently Asked Questions

Can my business join the Energex Dynamic Business Tariff Trial?

Possibly, but not automatically. Your site must be a Standard Asset Customer (low voltage) or Connection Asset Customer (high voltage), have export capacity greater than 30 kW, and have battery storage with on-site generation (such as solar) or a load. You also need a retailer's letter of support — unless you are yourself the Financially Responsible Market Participant — and Energex may include or exclude any customer at its absolute discretion.

How much is the critical peak charge, and how often does it apply?

The low-voltage CPP import charge is $2.15788 per kWh, and the CPP export reward is a credit of the same amount. The CPP export charge is 17.738 cents per kWh. Each event type is capped at 40 hours (80 half-hours) over the trial term, notified by email with best efforts at a day ahead. Some events may be unpriced tests. As of 9 November 2026, there was no public information on whether any priced CPP events had been called.

Will the $2.16/kWh charge appear on my electricity bill?

Not necessarily. Energex bills the retailer, not your business, and retailers are under no obligation to pass network structures through. Verify with your retailer whether it offers a retail version of the trial tariff, and how event charges and rewards are passed through, before counting on any trial benefit.

Does the trial apply to businesses on the Ergon Energy network?

No. The trial is an Energex trial for South East Queensland; regional Queensland businesses on the Ergon Energy network are on a different distributor's tariffs, so the trial's rates do not apply to them — though the principles in this article still apply.

What happens when the trial ends on 30 June 2027?

Energex may extend it, amend it on extension, or end it early with reasonable notice. Afterwards, the retailer nominates a standard network tariff: verify which one would apply, and model your battery on that tariff as well as on the trial tariff.

Is a battery worth buying just for this trial?

On the published evidence, no. The trial's value is concentrated in at most 40 hours per event type, is conditional on events being called and on your battery being ready, and depends on retail pass-through that is not assured. A battery should be justified on its ordinary value — self-consumption, demand reduction, and resilience on the standard tariff — with any trial benefit as upside.

What should I check before signing a battery proposal that mentions the trial?

Ask for the model behind the numbers: 30-minute interval data, kilowatts and kilowatt-hours modelled separately, losses and warranty throughput included, a sensitivity case for missed or late-notified events, confirmation of your export limit and connection agreement, the fallback tariff after the trial, and one combined dispatch rather than separate added-up estimates. Ask your retailer, in writing, whether it offers a retail version and on what terms.

Where do the figures in this article come from?

All trial figures come from Tekmor Intelligence's analysis by Kevin Qian, published 9 November 2026, drawing on Energex's Expression of Interest, its notification to the Australian Energy Regulator, and its 2026-27 Network Price List. The 1 kW illustrations and the event-day example are Tekmor's published illustrations — not EServices4U's figures and not savings forecasts. The regulatory updates are the AER's final decision of 30 October 2026, the Clean Energy Regulator's SRES expansion from 1 October 2026, and the federal Cheaper Home Batteries Program from 1 July 2025.

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