New York's First Storage Auction: 46 Bids, 8 Contracts, One Template

Forty-six battery projects bid into New York's first bulk storage auction. Eight came out with contracts: 950 megawatts and 4,360 megawatt-hours of lithium-ion capacity that the state has now promised to make financeable.

The rest of the field was not thin. Together the losing and winning bids offered 6.3 gigawatts and 30 gigawatt-hours, roughly six times what NYSERDA had room to sign. Seven non-lithium proposals were rejected outright. Two downstate zones absorbed more than half the winning capacity, while four upstate zones took nothing at all.

New York began the year with about 80 megawatts of operating bulk storage against a 1,500-megawatt target it had already missed. So what did the state actually buy with the Index Storage Credit — cheap megawatts, or a way to underwrite the risk that has kept batteries out of the ground?

The awards landed on 23 September. Flatiron Energy's two Bronx projects were confirmed on 21 October, giving the first detailed look at what a winning contract contains.

What the state bought was revenue certainty

The Index Storage Credit is a contract for revenue, not for steel. Developers bid the strike price they need to finance a project. NYSERDA then benchmarks actual market income against a monthly reference rate for 15 years, or 25 years for non-lithium designs. If the asset earns less, the state tops it up. If it earns more, the developer pays the difference back.

That structure attacks the specific reason large batteries have stalled in New York. A merchant battery earns from energy arbitrage, capacity and ancillary services, and every one of those revenue lines moves with markets the developer cannot control. Lenders price that volatility as risk, which raises the cost of capital and, often, kills the project before permitting.

ISC turns a volatile stack into a floored one. The developer keeps upside above the strike. The state caps its exposure at the top-up. Payments begin only after commercial operation, so New York does not wire money for projects that never get built.

The contract mechanism is where the risk moves. As we wrote in October, ERCOT turned grid-forming capability into a procurement specification for Texas batteries, a parallel attempt to make performance a condition of market access.

New York just took a major step toward the affordable, reliable grid our state needs.— William Acker, executive director, NY-BEST

The trade group's endorsement is not the number that matters. The number is $1.6 billion of private investment across the eight projects, with more than 500 jobs attached to construction and operations. That capital arrives on the strength of a 15-year counterparty promise rather than a grant.

Site selection still matters. Revenue is earned at a specific grid node, while settlement is benchmarked at the broader zonal level. A project sited where congestion is severe can beat the reference rate and keep the spread. The credit stabilises the floor; it does not equalise returns.

46 bids, 8 contracts, one table

Five developers won. GCI, Flatiron and Key Capture Energy each took two projects. Savion, a Shell subsidiary, took one. Zenobē took one.

Contracted projects in the first NYSERDA bulk storage round, September 2026. Source: NYSERDA; developer attribution by Energy-Storage.News and Modo Energy.

The losses say more about the auction than the wins. NextEra, Terra-Gen, Aypa Power, Origis and AES each entered at least two projects and received nothing. Key Capture Energy bid six projects totalling 674 megawatts and won two for 244 megawatts. GCI won both of its bids, and Flatiron won two of three New York City projects; its Brooklyn proposal, Battery Park Storage, was not selected. Selectivity paid. Volume did not.

Anatomy of the Bronx pair

Flatiron's two awards are the clearest template for what ISC money buys. Blue Spruce Storage is rated at 133 megawatts and 532 megawatt-hours and will interconnect with Con Edison. Palladium Storage is 123 megawatts and 492 megawatt-hours and will connect through the New York Power Authority. Both sit in Mott Haven, in the Bronx.

The chemistry is lithium iron phosphate, the same LFP family that dominates new grid-scale projects. LFP trades energy density for cycle life and thermal stability, which suits a daily-cycling asset inside a dense urban zone where fire risk carries political weight.

Commercial operation is targeted for 31 December 2030, subject to permitting, local approvals and the new fire-safety requirements. The contract pays nothing before that date.

"We are extremely proud to have two projects selected in New York's first bulk energy storage solicitation," said Juliana Mandell, Flatiron's chief commercial officer. The pride is understandable. A 15-year indexed contract on 256 megawatts in the most constrained load pocket in the state is the kind of asset a developer can finance.

The template also shows the limits. Two projects in the same neighborhood share interconnection, permitting and political risk. A fire-safety dispute or a local moratorium would hit both at once.

Zones J and K took 54% of the capacity

NYISO Zones J and K, which cover New York City and Long Island, took 54% of the awarded capacity. Zones D, E, F and H received no contracts, despite 14 bids totalling 2.1 gigawatts.

That is a map of reliability need, not of developer enthusiasm. The downstate load pocket is where peakers are old, where transmission is constrained, and where a four-hour battery can displace the most expensive hours on the system. The ISC is indexed to zonal markets, so a project in a constrained zone can clear a higher strike and still look attractive to a lender.

State policy also pushed in that direction. NYSERDA's programme is designed to prioritise downstate communities with the greatest reliability needs, and the first round delivered exactly that. Upstate developers with cheaper land and shorter queues could not compete on value per ratepayer dollar.

Seven of the eight winners are four-hour systems. That duration fits the New York City evening peak and captures most of the capacity value available from four hours of discharge. It also tells you what the state thinks it is buying.

One eight-hour battery in a four-hour field

Lighthouse Energy Storage in Chautauqua County is the outlier: 140 megawatts and 1,120 megawatt-hours, an eight-hour asset developed by GCI with Neoen as co-bidder. It entered the auction as a four-hour project and was upsized before award.

Duration changes what a battery is for. A four-hour system shifts midday solar into the evening peak. An eight-hour system can ride through a longer wind lull or a transmission outage, which puts it closer to firm capacity than to peak shaving.

One eight-hour project out of eight is a data point, not a policy. The second round will show whether New York is buying peak capacity or something more durable.

80 MW operating against a 6 GW target

The delivery problem sits behind the procurement. In March, New York had about 80 megawatts of operating bulk storage and roughly 335 megawatts of smaller batteries. The 2025 target was 1,500 megawatts.

Six of the eight winners remain in NYISO's 2024 Transitional Cluster Study. Every project must reach commercial operation by the end of 2030 under the 2024 Public Service Commission storage order. Between the contract and the interconnection are permits, local approvals and fire-safety review.

The safety codes became effective on 1 January 2026, following the Inter-Agency Fire Safety Working Group. They are among the most demanding rules in the country. That raises cost and time, and it is the price of avoiding the kind of failure that can stop a storage market for years.

Technology reliability is no longer the weak link. EPRI data released this month shows battery failure rates down roughly 98% from their early peak, measured across 149 gigawatt-hours of cumulative installations. Interconnection, siting and contract terms now bind harder than cell chemistry.

The trade-off buried in the strike price

Someone has to carry the basis risk. Under the ISC, that someone is the New York ratepayer, through a programme funded by utility customers and authorised by the Public Service Commission.

The exposure is bounded in theory. If NYISO revenues run above the strike, developers pay the excess back. If they run below, the top-up covers the gap. The design keeps developers exposed to siting and operating decisions while removing exposure to market direction.

The residual question is calibration. A strike set too high turns the credit into a subsidy. A strike set too low fails to clear the financing hurdle and produces another empty auction. NYSERDA published the aggregate outcome, not the clearing prices, so the first round's true cost per megawatt remains an estimate.

Term length compounds the question. Fifteen years covers most of a lithium-ion asset's useful life, but not all of it. After the contract expires, the project becomes a merchant battery, and its residual value depends on markets that will look very different in 2046.

Europe offers a comparison. The UK's contracts for difference pay a strike price against a market reference over 15 years, with a similar clawback. New York's version indexes to a monthly reference rate rather than a single wholesale price, which narrows the basis between settlement and actual nodal revenue. The trade-off is more administrative complexity for a tighter hedge.

Texas runs the opposite experiment. ERCOT batteries live on merchant revenue, and the winners are the ones that site well and dispatch precisely. New York has chosen to pay for certainty rather than reward that skill directly.

What the second round will test

NYSERDA plans a second solicitation by the end of 2026, with three annual rounds through 2027, each targeting about a gigawatt. Three questions will decide whether the first round was a template or an exception.

Duration comes first. If the next round repeats seven four-hour projects for every eight-hour one, the state is buying peak capacity. If longer assets multiply, it is buying firm capacity and will pay for it.

Geography comes second. Upstate zones offered 2.1 gigawatts and won nothing. A second round that again concentrates in J and K leaves transmission congestion and upstate generation unaddressed.

Price discovery comes third. Strike prices from the first round were not published project by project. Investors pricing the next round need the clearing levels to judge whether ISC contracts are cheap insurance or an expensive hedge.

The 6-gigawatt goal for 2030 is now a scheduling problem. 950 megawatts contracted, 80 megawatts operating, four years to close the gap.