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Residential Flexibility

#1 · 30 March 2026, 5:24 pm

Quote from Graeme Weston on 30 March 2026, 5:24 pm

Residential DER Flexibility Trial – Case Study

This trial demonstrates how a standard residential solar and battery system can operate as a controllable flexibility asset using existing tariffs and simple time-based control. The site consists of a 6 kW rooftop PV system and an 8 kWh battery, with current operation exporting energy into peak pricing periods at approximately 23c/kWh. The next phase introduces a controlled overnight charging window between 02:00 and 04:00 at approximately 10c/kWh, enabling a second daily battery cycle.

The system will charge overnight when network demand is low and discharge during morning (07:00–11:00) and evening (17:00-21:00) peaks, reducing grid import and exporting energy when it is most valuable. The objective is to achieve near-zero grid import when battery energy is available, while increasing peak-period export.

This trial introduces a four-layer value stack. Solar generation provides low-cost energy. The battery shifts energy in time. Retail pricing (via Supa) creates arbitrage opportunities. Distribution signals (via PowerCo) reward behaviour that reduces network stress. The current distribution credit (–7c/kWh) is static and does not reflect real-time network conditions. The trial proposes replacing this with simple time-bound credits aligned to peak demand periods.

Voltage data from the site shows clear correlation with network stress, with elevated voltage during solar export periods and reduced voltage during peak demand. The trial uses voltage as a proxy for constraint, targeting a flatter profile around 238 V through coordinated charging and discharging.

Expected incremental financial benefit is approximately $500–$800 per year. This is not the primary objective. The purpose is to demonstrate that consumers can respond to price signals and provide measurable network support using existing assets, without requiring new infrastructure or complex systems.

The trial is initially manual, using scheduled control within the inverter. The next phase is automation, where retailer or network signals directly control device behaviour. This creates a pathway toward a scalable model where residential consumers participate in energy markets as active providers of flexibility.

The outcome will inform future pricing design, including the potential to replace fixed network charges with cost-reflective, time- and constraint-based pricing aligned with actual system conditions.

Residential DER Flexibility Trial – Case Study

This trial demonstrates how a standard residential solar and battery system can operate as a controllable flexibility asset using existing tariffs and simple time-based control. The site consists of a 6 kW rooftop PV system and an 8 kWh battery, with current operation exporting energy into peak pricing periods at approximately 23c/kWh. The next phase introduces a controlled overnight charging window between 02:00 and 04:00 at approximately 10c/kWh, enabling a second daily battery cycle.

The system will charge overnight when network demand is low and discharge during morning (07:00–11:00) and evening (17:00-21:00) peaks, reducing grid import and exporting energy when it is most valuable. The objective is to achieve near-zero grid import when battery energy is available, while increasing peak-period export.

This trial introduces a four-layer value stack. Solar generation provides low-cost energy. The battery shifts energy in time. Retail pricing (via Supa) creates arbitrage opportunities. Distribution signals (via PowerCo) reward behaviour that reduces network stress. The current distribution credit (–7c/kWh) is static and does not reflect real-time network conditions. The trial proposes replacing this with simple time-bound credits aligned to peak demand periods.

Voltage data from the site shows clear correlation with network stress, with elevated voltage during solar export periods and reduced voltage during peak demand. The trial uses voltage as a proxy for constraint, targeting a flatter profile around 238 V through coordinated charging and discharging.

Expected incremental financial benefit is approximately $500–$800 per year. This is not the primary objective. The purpose is to demonstrate that consumers can respond to price signals and provide measurable network support using existing assets, without requiring new infrastructure or complex systems.

The trial is initially manual, using scheduled control within the inverter. The next phase is automation, where retailer or network signals directly control device behaviour. This creates a pathway toward a scalable model where residential consumers participate in energy markets as active providers of flexibility.

The outcome will inform future pricing design, including the potential to replace fixed network charges with cost-reflective, time- and constraint-based pricing aligned with actual system conditions.