A SAPS removes the customer’s dependence on a long, fault-prone distribution feeder, which is why distributor led SAPS programmes are usually justified on reliability as much as on cost. The customers who receive SAPS are typically the worst-served on the network, end-of-feeder, high line-length-per-customer, slow to patrol and slow to restore, so their outage minutes carry disproportionate weight in network-level SAIDI and SAIFI.

Two design factors determine whether the improvement is realised in practice rather than on paper:

Redundancy inside the SAPS. A single-string system with one inverter and no generator has moved the single point of failure from the feeder to the site. Vantara is built with built-in redundancy and hot-swappable inverters, battery modules and chargers, so a component failure degrades output rather than removing supply.

Visibility. An unmonitored SAPS fails silently until the customer calls. A monitored one raises an alarm before the outage. The reliability benefit of a SAPS fleet is directly proportional to how quickly the network learns that a system needs attention.

Approximately 90% outage reduction on SAPS-served properties is a network’s own published figure, not a supplier claim. That distinction matters for a business case – it is a utility’s own assessment of its own performance.

Vantara delivers 30 kVA of continuous inverter output per unit at 25 °C, standard and configurations available up to 90 kVA continuous. AC output is 230/240 V with total harmonic distortion under 2% and maximum efficiency of 96%.

Surge capability is usually the deciding specification, not continuous rating, and it is where most off-grid systems fail in service. Inductive loads, bore pumps, irrigation, compressors, workshop machinery, refrigeration, draw three to six times their running current at start. 

Vantara’s connection capability:

That 200 A five-second surge is what lets a Vantara start a pump without oversizing the whole system to cover a two-second event. The alternative, specifying a system twice as large as the continuous load requires, is how off-grid projects end up with capital cost that kills the business case.

Tell us at design stage what the largest single motor on site is and whether it has soft-start. During initial system start-up, sequence the load bring-up in steps rather than applying all loads at once. This manages inrush current and protects the system from unnecessary stress at commissioning.

Three mechanisms handle it, in order.

Storage. 55 kWh of usable lithium capacity as standard, expandable in 25 kWh increments, at up to 95% depth of discharge, so the nameplate capacity is very nearly all available, rather than half of it as with a lead-acid design.

Generator backup. Where fitted, the generator starts automatically on low state of charge and stops once the battery is recharged, without site attendance. The battery management system holds the inverter’s shutdown threshold well above zero, so the system recovers rather than collapsing.

Design margin. This is the part that actually decides the outcome, and it happens before anything is installed. AS/NZS 4509.2 guides autonomy at 2 days with automatic generator control, 2–3 days with manual control, and 4–5 days for a system with no generation backup, but the number that governs is the maximum contiguous run of low-solar days at your specific site, in the worst month, at end-of-life battery capacity rather than nameplate.

Any supplier who answers “how many cloudy days?” without asking for your location and load profile is guessing. Ask what solar resource dataset they used and what year of degradation they modelled.

Yes, Vantara is modular by design, and expansion is a defined product step rather than a redesign. Three upgrade paths:

• Energy Store Upgrade, 25 kWh packages of five 5 kWh lithium modules
• Additional Solar, 12.9 kWp ground-mount arrays with fencing
• High Demand Kit, 15 kVA of additional inverter capacity plus 30 kWh of storage

Inverters, battery modules and chargers are hot-swappable, so capacity can be added without taking the site off supply.

The practical value of this shows up in two situations. The first is load growth you did not forecast, a customer adds a shed, a comms site adds equipment, a pump is upsized. The second, and more valuable for a network, is evidence-based augmentation planning: because the energy management system logs generation, load and state-of-charge history, the decision to add capacity is made from measured data rather than from a complaint. Over a fleet, that is the difference between augmenting the sites that need it and augmenting all of them.

The architecture also accommodates future additions such as EV charging, which is worth knowing if the site is a depot, a community facility or a remote workshop.

Solar generation

Battery storage

Enclosure and environment

It depends on the delivery model, and the distinction matters for both regulatory and commercial reasons.

Under a distributor-led model, the DNSP owns, installs, operates and maintains the SAPS as a network asset, and the customer continues to be supplied and billed as a network customer. Essential Energy, for example, installs, owns, maintains and operates its SAPS at no additional charge to eligible customers. Eligibility is typically limited to existing connections with an established retail account, not greenfield sites or new developments.

Under a customer-owned model, which is how most telecommunications, mining, rail and water SAPS are procured, the asset owner owns the system and maintains it directly or under a service agreement.

Valen supplies into both. What changes between them is not the hardware but the documentation, the monitoring architecture and the maintenance regime, because a network asset carries obligations a private asset does not.