Meridian Energy: How a Hydro Giant Learned to Live With One Huge Smelter

Meridian Energy is a business built on water it does not control, selling to a customer it cannot replace. This article explains how a state-owned hydro generator became a listed company, why a single aluminium smelter at the bottom of the South Island shapes the whole New Zealand power market, how the two sides turned a decade of closure threats into a 20-year deal, and what the swing from a NZ$452m loss to a record profit says about weather risk. It is part of the New Zealand Company Stories hub.

How did Meridian Energy begin?

Meridian was created in 1999, when the government split the state generator, the Electricity Corporation of New Zealand, into three competing state-owned enterprises. Meridian received the big South Island hydro schemes; Genesis and Mighty River Power (now Mercury) took the North Island assets.

The inheritance was extraordinary. Meridian was handed the Waitaki chain of stations fed by Lakes Pūkaki and Ōhau, and Manapōuri, an underground station in Fiordland that is the country’s largest hydro plant at roughly 850MW. These assets were built by the state between the 1930s and the 1980s, are long since depreciated, and have no fuel bill. Lake Pūkaki alone is the single largest store of energy in the national system.

The split was intended to create rivalry in a wholesale market that had opened in 1996. In practice it produced three state generators that behaved commercially, paid dividends to the Treasury, and were eventually prepared for partial sale. Meridian also tried growing abroad, building wind farms and a retail business in Australia, before selling that operation in early 2022 for about A$729m to concentrate on New Zealand.

How does Meridian make money?

Meridian earns the gap between what its hydro and wind stations produce at near-zero marginal cost and the price it receives from retail customers, large contracts and the wholesale spot market. The company calls this the energy margin, and it reached NZ$1,471m in FY2026.

There are three sales channels. The first is the smelter contract, a large, low-priced, long-dated block. The second is retail: Meridian and its Powershop brand, plus Flick Electric, which it bought in 2025, served about 455,000 customer connections at June 2026, up 12% in a year. The third is the wholesale market and financial hedges sold to other retailers and industrial users.

The subtlety is that Meridian is a net seller in wet years and can be a net buyer in dry ones. When its lakes are low it must still honour fixed-price commitments to customers, buying power at spot prices that can exceed NZ$800/MWh, as they did in August 2024. A hydro generator with a retail book is therefore long rain and short drought. That is the opposite of a thermal generator, and it explains why Meridian spends money on insurance-like products that sit idle in good years.

Why does one aluminium smelter matter so much?

The Tiwai Point smelter near Bluff uses around 572MW continuously, roughly 12-13% of all electricity consumed in New Zealand. It sits at the far end of the grid from the main population centres, so if it closed the power could not easily be moved north.

The smelter opened in 1971 and was the reason Manapōuri was built. New Zealand Aluminium Smelters (NZAS) is now wholly owned by Rio Tinto, which bought out Sumitomo Chemical’s minority share of about 21% in 2024. It produces around 335,000 tonnes a year of high-purity aluminium, marketed as low-carbon because the electricity is hydro, and supports roughly a thousand direct jobs in Southland.

For Meridian the relationship is one of mutual hostage-taking. The smelter needs cheap, firm power to survive global aluminium cycles. Meridian needs a buyer for Manapōuri’s output, because transmission north is constrained and a sudden surplus of that size would depress wholesale prices for every generator in the country. Each party’s bargaining threat, closure on one side and a higher price on the other, would damage itself almost as much as its counterpart.

How did Tiwai go from closure threat to a 20-year deal?

Between 2013 and 2024 Rio Tinto threatened to close the smelter at least twice to win cheaper power, then signed 20-year contracts in May 2024 that secure supply to at least 2044 and give the generators the right to ask it to cut demand.

In 2013, just before Meridian’s share float, the government paid NZAS a NZ$30m subsidy to keep the plant open. In July 2020 Rio Tinto announced it would wind the smelter down; by January 2021 it had accepted a cheaper contract to the end of 2024. Each episode moved Meridian’s share price and stalled investment in new generation, because nobody would build a wind farm while 572MW of demand might vanish.

The 2024 agreements changed the bargain. Meridian supplies the bulk of the load, with Contact Energy providing 120MW and Mercury 50MW. Pricing is higher than the old contract, though undisclosed. Crucially, NZAS agreed to demand response: Meridian can require the smelter to reduce consumption by up to 185MW when hydro storage is low, paying for the privilege. In effect the smelter became a very large battery that discharges by not consuming.

Who owns and governs Meridian?

The Crown owns 51% of Meridian, a floor set in legislation, and private investors hold the rest through listings on the NZX and ASX. No shareholder other than the Crown may hold more than 10%, which makes a takeover impossible.

The partial sale came in October 2013 under the National-led government’s mixed-ownership model. It raised about NZ$1.9bn and was at the time the largest share float in New Zealand’s history, sold in two instalments to tempt retail investors unnerved by the smelter and by an opposition proposal to re-regulate the wholesale market. The same model was applied to the other two state generators, which is discussed in the article on the gentailers and the 2024 dry-year crisis.

Governance follows listed-company norms. The board is chaired by Mark Verbiest; Mike Roan, a long-serving Meridian executive, has been chief executive since 2025, and Mandy Binnie joined as chief financial officer during FY2026. The Crown appoints no executive and issues no operating instructions, but ministers set the rules the company lives under, and a majority shareholder that is also the regulator’s political master is never an entirely passive one. Meridian is one of the largest companies on a local exchange that is short of large companies, a problem examined in the piece on the NZX and its shrinking market.

What happened in the 2024-25 drought, and how strong was FY2026?

A dry sequence in 2024 and early 2025 pushed Meridian to a NZ$452m net loss in FY2025. A year later, with catchment inflows at 122% of average, it reported record EBITDAF of NZ$1,051m and a NZ$130m net profit.

The FY2025 loss was driven by low generation, expensive purchases to cover retail commitments, the cost of calling on smelter demand response, and large non-cash movements in the value of hedges. EBITDAF of NZ$611m covered a dividend that was, on Meridian’s own measure, 230% of free cash flow.

FY2026 reversed almost every line:

Hydro generation rose 14% to 12,571GWh and wind output hit a record 1,905GWh. Ordinary dividends rose 7.1% to 22.5 cents a share, and net debt fell to 1.6 times EBITDAF. Guidance for FY2027 is EBITDAF of NZ$1,040m-1,120m, assuming normal hydrology, which is the assumption that failed two years earlier.

What is Meridian building now?

Meridian is spending on solar farms, grid batteries and wind in the North Island, diversifying away from South Island rain. Capital expenditure was NZ$261m in FY2026 and is guided to NZ$370m-410m in FY2027, with a development pipeline of about 6,100MW.

The Harapaki wind farm in Hawke’s Bay is operating. The 100MW/200MWh Ruakākā battery near Whangārei was commissioned in FY2026 at a cost of about NZ$186m, and the adjoining 130MW Ruakākā solar farm, costing roughly NZ$227m, is due in 2027. Te Rahui, a 200MW first-stage solar farm near Taupō, is being built in a joint venture with Nova Energy, the retail arm of the Todd Corporation. A final decision on the Mt Munro wind farm is expected in December 2026.

Just as important are cheap gains from existing assets. Engineering upgrades added nearly 30MW of hydro capacity. Consents for the Waitaki scheme were renewed for 35 years. And in July 2026 Meridian won access to an additional five metres of contingent storage in Lake Pūkaki for three years; its modelling suggests that buffer alone could have cut peak winter 2024 prices from about NZ$800/MWh to nearer NZ$500/MWh.

Who does Meridian compete with?

Meridian competes with three other large generator-retailers, Contact Energy, Mercury and Genesis Energy, which together with Meridian account for the great majority of New Zealand’s generation and retail customers. Smaller independents are growing in solar and retail but remain marginal.

The rivals differ mainly in fuel. Contact is built on geothermal and Clutha hydro, a story told in the article on Contact Energy’s geothermal bet and the Manawa takeover. Mercury combines Waikato hydro with geothermal and wind and reported EBITDAF of NZ$1,068m in FY2026, narrowly ahead of Meridian. Genesis owns the Huntly thermal station, the system’s backstop.

Competition is oddly co-operative at the edges. All four firms signed the Huntly strategic energy reserve in 2025, under which Meridian holds a 75MW call option on coal- and gas-fired output for dry years. Meridian also competes with its own software supplier’s customers: it is moving retail accounts, 175,820 of them in FY2026, to the Kraken billing platform, replacing in-house systems. New Zealand has a habit of producing utility software, as the piece on Gentrack and Vista Group describes.

What are the main risks for Meridian?

The principal risks are hydrology, the smelter, politics and transmission. A dry year can remove hundreds of millions of dollars of earnings; a change of government can alter market rules; and South Island power still depends on a limited link to the North Island.

Smelter risk has receded but not disappeared. The 2044 contracts include termination rights with long notice, and aluminium remains a cyclical commodity. Political risk has shifted from nationalisation to intervention: the government’s 2025 response to a review of the electricity market stopped short of breaking up the gentailers, but strengthened the Electricity Authority and introduced rules requiring the big firms to offer hedges to independents on the same terms as their own retail arms.

There is also a build-out risk. Meridian expects net debt to peak at just over three times EBITDAF as its solar and wind programme proceeds. If many generators build at once, wholesale prices could fall faster than costs, and the returns on new plant would disappoint.

What can founders and CFOs learn from Meridian?

Meridian’s lesson is that concentration risk can be converted into an asset if the contract is redesigned. The firm stopped treating its largest customer as a threat to be priced and started treating it as flexible capacity to be bought.

• Turn a dominant customer into a partner in risk. The demand-response clause gives Meridian an option worth far more in a drought than a marginally higher tariff would have been.
• Price the tail, not the average. The Huntly call option, Pūkaki contingent storage and batteries all cost money in normal years. They exist because one bad winter cost more than a decade of premiums.
• Sweat existing assets before building new ones. Thirty megawatts from upgrades and five metres of lake access were won with engineering and consents, not billions of capital.
• Match the dividend to the cycle. A payout that was 230% of free cash flow in one year and 83% the next is sustainable only with a conservative balance sheet going in.
• Long contracts unlock investment. Once the smelter’s future was settled to 2044, Meridian and its rivals could commit to new generation.

What happens next for Meridian?

Meridian’s next phase is a capital-heavy expansion into North Island solar, wind and batteries, funded by a stronger balance sheet, while it waits to see whether electrification and data centres deliver the demand growth the whole sector is betting on.

Three decisions are close. The Mt Munro wind farm investment decision is due in December 2026, with further wind projects in 2027. A general election due in late 2026 will determine whether the present settlement, light-handed regulation plus Crown willingness to fund the state-controlled generators’ growth, survives. And the government’s plan for an LNG import terminal, described in the article on New Zealand’s gas shortage and Methanex, will influence how valuable Meridian’s stored water is in a dry year.

The deeper question is demand. New Zealand’s electricity consumption has been broadly flat for fifteen years. Meridian’s 6,100MW pipeline makes sense only if transport, dairy processing and industrial heat switch to electricity. If they do, the company that owns the cheapest stored energy in the country, and has a smelter willing to step aside when it is scarce, is well placed.

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