Source
https://www.ea.govt.nz/projects/all/energy-competition-task-force/consultation/requiring-distributors-to-pay-a-rebate-when-consumers-supply-electricity-at-peak-times-definition-of-a-small-business/ — original source (opens in a new tab; the file is not redistributed)
Summary
The Electricity Authority’s decision paper Requiring distributors to pay a rebate when consumers supply electricity at peak times (16 July 2025, Energy Competition Task Force initiative 2A) amends the Code so that distributors must include negative charges (rebates) for mass-market injection at peak times, in force from 1 April 2026. The rebate must reflect the average long-run marginal cost (LRMC) of peak demand that injection can avoid — a broad regional signal (/kW-peak/yr), not an asset-specific one (targeted constraint management is left to contracted flexibility). The decision is the enacted basis for the **distribution-side avoided-cost credit** a community's solar/battery earns by exporting at peak — a third injection-value component alongside the retail buy-back ([[cr_011_nz-solar-buyback-2025-2026|CR_011]]) and distinct from the QSDEP retail price ([[rd_018_mbie-qsdep-domestic-electricity-prices|RD_018]]). Its most important quantitative message for this project is a **calibration that argues against relying on injection revenue**: the rebate is ~6/year for a self-consuming household battery, becoming material (~$175/year) only with heavy peak export. For the thesis it is a concrete instance of how energy-transition regulation rewards (and shapes) distributed/community generation.
Key claims
See key_claims frontmatter (8 claims, cited to section). The firm per-distributor rebate values are set via each distributor’s pricing methodology, not in this paper.
Neobiome Intelligence relevance
- Enacted basis for the distribution-side injection credit (D01). REG_005 establishes the avoided-cost-of-distribution rebate (= average LRMC of avoided peak demand, $/kW-peak/yr, zero where a region faces no demand growth), mandatory from 1 April 2026 — the regulatory anchor for valuing peak export in the NI financial layer, distinct from the retail buy-back (CR_011) and the retail price baseline (RD_018). REG_005
- ⚠ Calibration — treat injection rebate as a MINOR value stream for a self-sufficient community. Modelled at ~
6/yr for a self-consuming household battery (one cycle/day, offsetting own demand) and only ~175/yr under a high-export, symmetrical-rate scenario. Because a Neobiome community’s design goal is to minimise grid interaction and self-consume, the distribution rebate should be treated as near-negligible unless the community deliberately exports surplus at peak — NI should not weight injection revenue in a self-sufficiency case. The rebate is “part of a larger value stack” (cheaper self-generated energy, reduced peak consumption charges, resilience, environmental), not a standalone driver. REG_005 - Per-distributor values are exogenous to this paper. Actual c/kWh credits come from each distributor’s pricing methodology (Network Tasman — the pilot distributor — would set its own; Orion/Powerco already have 2025-26 negative pricing; Aurora trials count 50% of control-period exports against annual CPD). NI calibration of the pilot rebate awaits the Network Tasman methodology / EA LRMC guidance (RT_220). REG_005
Key thesis insights
- Regulation is actively reshaping the reward for distributed/community generation. The 2A decision is a concrete NZ instance of the energy-transition governance question — how the regulatory regime values and incentivises behind-the-meter generation — and of the centralised→distributed direction also traced in LIT_055 and REG_004. REG_005
- A deliberate efficiency-over-generosity choice. The Authority rejected symmetrical export tariffs (which would have paid injection at the full peak-consumption rate) in favour of a lower, LRMC-based signal — prioritising whole-system efficiency and guarding against over-investment / ‘battery dumping’ over maximising the reward to prosumers. A clear example of the political-economy trade-offs in distribution-pricing reform. REG_005
- Community-energy interest is organised and engaged. Submitters included Network Tasman, the Nelson Tasman Climate Forum, Community Energy Taranaki and Lightforce Solar — evidence of an active pilot-region and community-energy constituency in NZ distribution-pricing policy. REG_005
Research targets
Documents to retrieve
- EA decision on Task Force initiatives 2B & 2C (retailers to offer time-varying pricing plans + a platform to pass negative charges and buy-back through to consumers; July 2025) — the retail-side companion to this distribution-side decision; needed to complete the injection-value picture for NI. (RT_220.)
Research gaps
- The Network Tasman injection negative-charge rate (c/kWh, peak window) under its 1 April 2026 pricing methodology — the pilot-specific value of the avoided-cost-of-distribution credit; not in this paper (per-distributor). Pairs with REG_002. Track once Network Tasman publishes / EA issues LRMC guidance (folds into RT_220). [Update: RT_220 resolved → REG_028 (EA 2B/2C decision), which sets the mandate but no rate — this per-distributor gap therefore remains live here and is NOT re-raised as a separate RT.]
Connections
Links to
Referenced by