Advances in battery technology are expected to play an important role in enabling our energy future. Distributed Battery Energy Storage Systems (BESS) in New Zealand examines the operational impact on the power system of the widespread adoption of these systems in conjunction with the large-scale uptake of solar PV and electric vehicle charging and identifies what is required to enable a successful integration and ensure a reliable fit-for-purpose power system.
This page provides information about pricing, rentals and transmission agreements.
We have undertaken an investigation of the Value of Lost Load (VoLL) to inform our expenditure decisions and regulatory applications.
VoLL represents the economic value, in dollars per MWh, that a consumer places on electricity they plan to consume but do not receive because of a power interruption. It is different in concept to the price consumers pay in the wholesale and retail markets for electricity. Both the wholesale and retail prices reflect consumers’ demand for electricity, whereas VoLL reflects consumers’ demand to avoid power interruptions and its consequences.
In a series of reports published in March 2016, we highlighted that transmission capacity from Bunnythorpe to Whakamaru is constrained by the capacity of the 110 kV Bunnythorpe–Mataroa and 220 kV Tokaanu–Whakamaru circuits. With the decommissioning of thermal generation in the Auckland region, the risk of these constraints binding increases.
We have identified some low cost options to relieve these constraints in the short-term which include:
Latest update: January 2018
In June 2017, we released an Invitation to Comment on a possible Operational Review 2 of the Transmission Pricing Methodology (TPM). This was following the Electricity Authority announcement that it needed to prepare a new cost-benefit analysis before any decisions could be made about its review into the TPM Guidelines.
The methodology to allocate the HVDC costs to South Island (SI) generators was changed in 2015. This change involved transitioning from the peak-based metric (HAMI) to an average-based metric (SIMI) from the 2017/18 pricing year (PY). The allocation based on HAMI resulted in a strong incentive for SI generators to maintain generation below established HAMI levels (HAMI limits) thus avoiding increased allocation of HVDC costs. The change to SIMI was intended to reduce this incentive, thus increasing the availability of SI generation capacity.
This publication presents an update to the ten year forecast fault levels report. The Connection Code contained in Schedule 8 to the Benchmark Agreement requires Transpower to publish a ten year forecast of the expected fault levels at each customer point of service annually.
Transpower last published the Ten Year Forecast of Fault Levels in September 2015.
Revenue is controlled using regulatory control periods. Our second control period (RCP2) runs for five years from 2015/16 to 2019/20.