New Zealand’s electricity grid is now more renewable than it has been in fifty years. The share of generation coming from hydro, geothermal, wind, solar and biogas reached 84 percent in 2024, up from a low of 63 percent in 2001. The cost of that recovery has been carried almost entirely by households. The average residential customer pays 123 percent more for electricity in real terms than the average residential customer did in 1975. Industrial customers pay only 23 percent more. Commercial customers actually pay less in real terms than they did in 1980.
The reason is not in the wires or the generation mix. It is in the ownership structure.
The distributional split is the headline finding
| Customer class | Real price 1975 | Real price 2025 | Real-terms change |
|---|---|---|---|
| Residential households | 15.5 c/kWh | 34.6 c/kWh | +123% |
| Commercial users | 37.0 c/kWh (1980) | 23.6 c/kWh | −36% |
| Industrial users | 18.4 c/kWh (1980) | 22.6 c/kWh | +23% |
All figures in 2025 cents per kilowatt-hour. Source: MBIE Energy Prices real annual series for residential, commercial and industrial customers.
Pick almost any year from the late 1980s through to 2020 and the same pattern holds. Households paid more for power in real terms than they did a decade earlier. Industry paid the same or less. The recent rise in industrial prices since 2020 is a separate phenomenon driven by wholesale spot prices spiking in dry winters, not by anything households were spared from.
If the headline cost of the system were the renewable transition — paying for new geothermal stations, wind farms, transmission upgrades — that cost would be visible in industrial bills too, since industrial users buy the same kilowatt-hours from the same generation fleet. It is not visible. The price burden has been distributed by customer class, not by physics.
Why the burden was distributed this way
New Zealand spent 1987 through 1999 breaking up a single state-owned electricity system. The Electricity Corporation of New Zealand was created in 1987 to corporatise the assets of the old Ministry of Energy. Contact Energy was separated out of ECNZ in 1996, around the same time the wholesale market opened. The remainder of ECNZ was split into Meridian, Mighty River Power and Genesis Energy in April 1999. Contact was sold to private investors in 1999. Meridian, Mighty River (now Mercury) and Genesis were partially privatised through public share offerings in 2013 and 2014. The result is a market of four large vertically integrated companies known as “gentailers” — a term meaning a company that both generates electricity and sells it directly to households and businesses.
Gentailers exist to earn returns for their shareholders. The state-owned vertically integrated system they replaced did not. A single point of accountability for the cost of power to households was replaced with a wholesale market in which the customer with the strongest bargaining position gets the best deal. That customer is industry, not the household.
This is not a hidden mechanism. The four big gentailers paid out just over $1.3 billion in shareholder dividends in 2024 alone. The New Zealand Council of Trade Unions calculates that since the partial privatisations of 2013 and 2014, the three listed gentailers — Mercury, Meridian and Genesis — have paid roughly $9 billion in dividends to shareholders against $1.4 billion invested in new renewable generation. That is $2.41 paid out in dividends for every dollar invested in new generation. A dividend is by definition cash that left the system and is no longer available to lower prices or to fund new generation.
That is the structural cost of the ownership model. Hydro built in the 1960s and 1970s under crown finance — Manapouri, Aviemore, Benmore, the Waikato chain — was paid for at sovereign borrowing rates with no equity return on top, and is now fully depreciated. Every kilowatt-hour it produces costs only the maintenance and operating expense. New generation built since 1996, including the geothermal expansion at Kawerau, Nga Awa Purua, Te Mihi and Tauhara, and the wind farms at Tararua, West Wind, Mahinerangi and Turitea, has required private commercial capital with a weighted-average cost of capital of seven to nine percent. That margin is added to every wholesale price for the life of the asset. It does not get worked off.
Australia followed a similar reform path with a different timing and held real residential prices flat for 27 years
A useful counterfactual sits across the Tasman. Australia’s electricity sector was state-owned and state-regulated for most of the postwar period, with reform arriving from the mid-1990s onward but more slowly than in New Zealand. According to the Australian Energy Market Commission, residential electricity prices in Australia were roughly flat in real terms from 1980 to 2007 — a 27-year period of stability that New Zealand did not experience. Australian residential prices then doubled in real terms between 2006 and 2015, driven primarily by network over-investment under regulated asset base rules, before continuing to rise on gas wholesale prices.
The Australian and New Zealand markets are not identical and the comparison has limits. But Australia’s 27 years of flat real residential pricing under a more state-dominated structure, followed by sharp rises once private capital and aggressive network investment took over, is consistent with the New Zealand pattern read in reverse: the price burden on households tracks the introduction of commercial return requirements into the system.
The renewable transition is real but is not the headline cause
It is true that building new generation costs money, and some of that cost shows up in retail prices. New Zealand’s renewable share fell from 80 percent in 1974 to a low of 63 percent in 2001 as the Māui gas field was developed and gas-fired generation expanded, then recovered to 84 percent by 2024 as geothermal output nearly tripled and wind grew from effectively zero to almost ten percent of generation. That recovery required capital. Some of the residential price rise is genuinely the cost of the cleaner grid.
But the renewable transition would have raised industrial prices too if that were the dominant force. It did not. New geothermal output and new wind capacity supplies the same wholesale market that industry buys from. The fact that industrial customers were paying less in real terms in 2010 than they were in 1980, while residential customers were paying nearly fifty percent more, is not consistent with a renewable transition story. It is consistent with a market structure that distributes costs to the customer class with the least power.
Hydro and wind that did not get built
The same ownership structure helps explain why New Zealand has not built the storage and backup capacity that an 84-percent-renewable grid actually needs to ride through dry winters. The country has roughly 1.3 gigawatts of installed wind capacity in 2026. Australia has 15.4 gigawatts in a country with broadly similar wind resource. The reason is partly that New Zealand’s total electricity demand has been almost flat since 2010 — total generation rose from 43,571 GWh in 2010 to 43,872 GWh in 2024 — so the gentailers had limited commercial reason to add capacity that would compete down wholesale prices on their existing hydro and geothermal positions.
Major hydro proposals have been withdrawn repeatedly. Project Aqua, a 570 MW scheme on the lower Waitaki, was abandoned by Meridian in 2004 over Resource Management Act consenting risk and public opposition. The Mokihinui dam on the West Coast was cancelled by Meridian in 2012 over conservation land issues. The Waitaha scheme was declined by the Government in 2019.
The clearest case is the Lake Onslow pumped hydro scheme. Pumped hydro is a storage technology, not a generation source. It uses surplus electricity at times when wind and water are abundant to pump water uphill into a reservoir, then releases it through turbines when the country needs the power. The result is a giant battery that can absorb a windy summer and discharge in a dry winter. The Government cancelled the project in December 2023, with the official explanation citing the $16 billion price tag, consenting risk, and the concern that a state-funded battery would have a “chilling effect” on private investment in renewables.
That last reason is the key sentence. The state could not build the public-good infrastructure households need to escape dry-winter spot price spikes because doing so would have harmed the commercial returns of the listed gentailers. A privately-financed consortium has since picked up the project at an estimated $8 to $10 billion, targeting commissioning in 2035. The choice between cheap household power and protected gentailer returns has been made.
The honest reading
The data shows three things confidently. Residential electricity prices have more than doubled in real terms over fifty years. Commercial and industrial prices have not. The distributional split aligns with the period in which a state-owned vertically integrated electricity utility was replaced with a market of profit-driven gentailers operating under regulated network charges.
What the data cannot prove is the precise counterfactual — whether real residential prices would have stayed flat under continued state ownership, or risen by a smaller amount. The Australian comparison suggests the answer is closer to flat than to current New Zealand levels, but Australia is not a perfect control.
What the data does prove is that the choice to bring profit-extracting capital into the electricity system was a choice with distributional consequences. Households were the customer class that paid for it. Industry was not. The gentailer model is now structurally embedded — the assets are on private balance sheets, the dividend streams are committed, the regulatory regime exists to protect investor returns — and cannot easily be reversed. Once profit-extracting capital is inside a utility sector, it tends to stay there.
The grid is cleaner than it has ever been. That is a real achievement. But it was paid for by the people with the least bargaining power, while the people with the most bargaining power benefited. That is not a renewables story. It is an ownership story.
Methods
Real electricity prices are MBIE’s annual series in 2025 cents per kilowatt-hour for residential, commercial and industrial customers, covering 1975 to 2025 for residential and 1980 to 2025 for commercial and industrial. Generation data is from MBIE’s Energy in New Zealand annual statistics, generation by fuel 1974 to 2024. Renewable share is calculated as the sum of hydro, geothermal, wind, solar PV and biogas, divided by total generation. The $9 billion dividends versus $1.4 billion capex figure is from the New Zealand Council of Trade Unions analysis of the three listed gentailers’ (Mercury, Meridian, Genesis) annual reports since partial privatisation in 2013-14. Contact Energy was already private during this period and is reported separately. Reform dates are from the MBIE Chronology of New Zealand Electricity Reform. Australian residential price history is from the Australian Energy Market Commission Residential Electricity Price Trends 2025 report. Installed wind capacity figures are from the World Wind Energy Association 2025 statistics. Counterfactual claims about what prices would have been under continued state ownership are not provable from this data alone; the article confines such claims to the comparative evidence available.
What proportion of your monthly bill do you think is going to gentailer shareholders rather than to keeping the lights on? Have your power costs kept up with this national average or run ahead of it? Tell us in the comments.
This article was written by AI, briefed to report the facts, hopefully without some of the bias people bring to the job 🙂
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