Massachusetts utilities sign 4.5 GWh storage contracts as supply chain risks mount
Eversource, National Grid and Unitil filed long-term agreements for 1,068 MW of battery capacity due by 2030, even as costs and China-dependent supply chains threaten delivery.
Three Massachusetts utilities filed long-term contracts on Tuesday (2026-07-07) covering 1,068 MW and 4,472 MWh of utility-scale battery storage with the state's Department of Energy Resources, committing to one of New England's largest coordinated storage procurements on record.5
The commitment lands at an awkward moment for the battery storage sector. Battery pack prices remain elevated and global shipping bottlenecks are compressing near-term project timelines, panelists at the BloombergNEF Summit noted in April, with supply chains still heavily weighted toward Chinese manufacturing.4,3
Eversource Energy, National Grid and Unitil, which together account for the bulk of Massachusetts electricity distribution, are contracting with developers of three separate projects to deliver 4,472 MWh by 2030. The state filing positions the procurement under the Massachusetts Department of Energy Resources' long-term storage program, one of several northeastern states pursuing mandatory utility storage targets as part of broader grid modernisation efforts.5
New England's grid topology gives the scale particular weight. Massachusetts sits at the tip of a constrained regional system with limited external power imports, and battery storage here performs a reliability function as much as a decarbonisation one. Retiring thermal generation and growing offshore wind capacity both require dispatchable backstop resources to manage output variability.5
Getting from signed contracts to commissioned megawatts is where the difficulty lies. Reuters reported in May that battery storage firms face both lengthy interconnection queues and a supply chain skewed toward Chinese-manufactured cells and modules, limiting the industry's ability to scale even as demand signals strengthen.3 Grid queue congestion has emerged as a rate-limiting constraint on storage deployment across US markets.
Fluence Energy illustrated both the appetite and the volatility in the market. Shares closed at $24.16 on May 8, 2026, up 98.2% in a single week after the company disclosed master supply agreements with two hyperscalers and reported a record $5.6 billion backlog.1 The move reflected investor pricing of AI data center load growth as a structural demand driver for power infrastructure adjacent to storage. Yet Fluence carries stockholders' equity of -$265.88 million and cash of just $36.59 million, a balance-sheet position that makes sustained execution of that backlog contingent on external project finance rather than internal resources.1
The Massachusetts contracts, if they reach commercial operation by 2030, would represent a meaningful addition to regional storage capacity. BloombergNEF panelists in April flagged that supply chain constraints are dampening near-term deployments industry-wide, and projects filed in mid-2026 face both procurement lead times and interconnection studies that can stretch two to three years.4
Smaller-scale procurement is accelerating elsewhere. Greece connected its first two battery systems totalling 16 MW and 32 MWh in May (2026-05-21), with a further 300 MW in development according to the country's energy storage lobby.2 The Greek deployment signals that utility-scale battery integration is extending into markets with essentially no installed storage base five years ago.
For the Massachusetts utilities, the more immediate pressure is regulatory cost pass-through. Long-term storage contracts require rate filings before state regulators, meaning the economics of elevated battery pack prices and potential tariff exposure on Chinese imports will eventually surface in ratepayer proceedings. How regulators balance storage reliability value against per-megawatt-hour procurement costs will determine whether the 2030 targets remain politically durable.4,3
The 2030 delivery date also sits ahead of a projected demand inflection from AI data centre load in New England, a dynamic several institutional investors are already pricing through positions in grid-adjacent power companies.1 Whether the Massachusetts storage fleet is sized and sited to capture that value, or ends up serving primarily as reliability backstop for an offshore wind ramp, is embedded in contract details that regulators will scrutinise over the coming months.