Maximising benefits from local electricity generation
Submission to the Electricity Authority. Consultation on Distributed Generation Export Limits (10 kW Single Phase)
Summary
Three of New Zealand’s most forward‑thinking electricity distribution businesses — Aurora Energy, Powerco, and Northpower — have already raised their single‑phase export limits to 10 kW without waiting for regulation. This submission supports adopting the 10 kW limit nationally, followed by an urgent consumer‑centric transition: Distribution System Operators (DSO) publish real‑time visibility and price signals so flexible Home Energy Management Systems (HEMS) can respond automatically. As homes electrify and adopt EVs, some will need systems larger than 10 kW — ideally three‑phase and V2G‑ready — so exports are phase‑balanced, winter‑capable and locally useful. Shared‑savings with EDBs (not subsidies) should recognise avoided upgrades.
1. Background and Context
New Zealand’s very high penetration of smart meters means low‑voltage (LV) visibility already exists at most ICPs. If the Electricity Authority and Government unlock ICP‑level power‑quality and voltage data via the new Consumer Data Right (CDR) framework, EDBs can perform a Distribution System Operator (DSO) role without installing thousands of new monitoring devices. This enables transparent feeder dashboards, near‑real‑time hosting‑capacity maps, and automated price/voltage signals for HEMs.
Experience in Australia shows that lifting export limits works best alongside visibility and coordination. DNSPs like SA Power Networks and Energex have implemented flexible exports and dynamic connections based on live voltage and congestion data. Early movers in New Zealand are proving the same approach is practical here.
2. Six Supporting Measures
2.1 Collaborative visibility and consumer participation
Consumers and networks should work together using shared data. DSOs can publish simple online dashboards showing local voltage, congestion, and available capacity in near‑real‑time. This allows flexible HEMs to automatically choose the best times to charge EVs, heat water, or export solar energy. Instead of blunt export limits or curtailment, households respond to transparent price and voltage signals. This participatory approach turns consumers into partners in stability, not passive users restricted by static limits.
2.2 Dynamic Operating Envelopes (DOEs)
DOEs should be published as open, near-real-time visibility and price signals, rather than enforced as direct control commands inside each inverter.
In practice, the Distribution System Operator (DSO) publishes per-phase hosting capacity and locational price information through an open API.
Each Home Energy Management System (HEMS) then optimises solar, battery, and EV operation around those signals and the household’s preferences. Dynamic Operating Envelopes should be implemented carefully to avoid conflicts between inverter software, distributor controls, and consumer energy management systems (HEMS).
The Electricity Authority should set clear guidance on control hierarchy — where inverters manage safety functions, HEMs optimise household energy use, and DSOs provide visibility and price signals rather than issuing direct control commands.
This will prevent overlapping instructions and ensure consumers retain control of their own systems while still supporting network stability.
2.3 Phase balance and three‑phase evolution
As households electrify and add EVs, some will naturally need systems larger than 10 kW. Encouraging these homes to upgrade to three‑phase connections and appropriate inverters spreads load evenly, reduces voltage rise, and helps the grid run more smoothly. Rather than viewing this as a burden, distributors can treat it as a co‑investment opportunity — every home that upgrades reduces the need for transformer and feeder reinforcement. This is a fair trade‑off: consumers invest in better connections, while DSOs save on avoided upgrades.
2.4 Price‑neutral three‑phase and shared‑savings credits
Today, many households that install three‑phase supply pay higher daily fixed charges, even when their overall capacity is no greater than a single‑phase home. This penalises behaviour that actually helps the network. Three‑phase should be price‑neutral for standard residential capacity. Instead of subsidies, distributors and consumers should share the savings from deferred upgrades. For example, homes that provide proven phase balance or voltage stability could receive small export uplifts or annual credits reflecting the avoided cost of new infrastructure.
2.5 Vehicle‑to‑grid (V2G) and peer‑to‑peer trading
Electric vehicles hold the key to large‑scale flexible storage. When connected through bidirectional chargers, EVs can export power back into the grid during evening peaks or local shortages. Three‑phase chargers make this process smoother by balancing export across all phases. With DSOs providing open data and fair market rules, households will be able to trade their stored energy peer‑to‑peer, supplying nearby homes or businesses. This creates a resilient, community‑based energy ecosystem — not one controlled solely from the top down.
2.6 Dynamic Locational Marginal Pricing (DLMP)
Dynamic Locational Marginal Pricing (DLMP) represents a fundamental change in how distributors earn revenue and manage efficiency. Instead of being rewarded for building more assets, distributors would earn revenue for operating their networks efficiently — keeping supply close to demand. This reflects the physical reality of electricity: it flows along the path of least resistance, and the closer generation is to consumption, the lower the losses and costs. DLMP turns these local efficiencies into transparent price signals. When prices rise in an area, it invites nearby consumers, batteries, or V2G systems to help; when prices fall, it signals that capacity is available. This model rewards collaboration, not expansion.
3. Implementation Pathway
The Authority could begin with a one‑year pilot involving several feeders operated by early‑moving EDBs such as Aurora Energy, Powerco, and Northpower. Each would publish live voltage and capacity data, implement per‑phase dynamic envelopes, and offer price‑neutral three‑phase connections. Participating households could receive modest credits for providing phase balance or supporting local voltage stability. Performance would be measured by reduced voltage excursions, improved phase symmetry, and avoided reinforcement expenditure.
4. Conclusion and Recommendation
The 10 kW single‑phase limit is an enabling milestone, but it should also signal a new direction. New Zealand can move from centralised control toward a consumer‑centric grid built on data transparency, local participation, and shared benefits. Unlock ICP‑level smart‑meter data via CDR so DSOs can coordinate CER using open standards and price signals, not blunt curtailment. By codifying what forward‑looking EDBs have already demonstrated — and by promoting DSOs that publish real‑time grid visibility and price signals — the Electricity Authority can accelerate electrification, strengthen resilience, and empower households to generate, store, and trade clean, home‑grown energy.
References
- EA consultation on export limits (default 10 kW, inverter settings, etc.). Electricity Authority – Consultation: Maximising benefits from local electricity generation (export limits)
2. Aurora Energy: raising single-phase export limit to 10 kW (media release). Aurora Energy – media release: single‑phase export limit to 10 kW
3. Powerco: policy page (now allowing 10 kW) + NODS agreement with Bluecurrent (≈250k meters). Powerco – DG up to 10 kW (policy + standard) Powerco – NODS agreement with Bluecurrent (250,000 meters)
4. Northpower: 10 kW single-phase announcement + renewable energy page. Northpower – single‑phase export limit to 10 kW
5. WEL Networks: 5-minute AMI data across 68,600 meters (LV visibility). WEL Networks – 5‑minute data across 68,600 meters (LV visibility)
6. Orion ViSION: 5-minute operational data via Bluecurrent; lessons on access. Orion – ViSION project report: 5‑minute operational data via Bluecurrent
7. MBIE: Consumer Data Right / CPD Act and Open Electricity designation pages. MBIE – Customer and Product Data Act (Consumer Data Right) overview MBIE – Open electricity designation (CDR for electricity)
8. EA: “Data for better performance—unlocking smart meter value” (SPE 2024/25). EA – Statement of Performance Expectations 2024/25 (unlock ICP data)
9. AEMO Project EDGE (final report hub + ARENA knowledge bank). AEMO – Project EDGE (Final Report + resources)
10. SA Power Networks Flexible Exports (program & eligibility checker). SA Power Networks – Flexible Exports (program, eligibility, results)
11. CSIP-Aus (IEEE 2030.5 profile). CSIP‑Aus – Common Smart Inverter Profile (IEEE 2030.5 based)