Google signed a long-term deal to buy electricity from Constellation Energy, the biggest owner of nuclear power plants in the United States. The total is roughly what three large nuclear reactors produce.
The surprise: only about a quarter of it is described as new power that does not exist today. The companies have not said whether the rest is new.
That matters because the giant computer buildings that run artificial intelligence are straining the power grid across a large part of the eastern United States. New plants add electricity for everyone. Buying power that already exists mostly changes who gets it.
Google has entered a long-term power agreement with Constellation Energy that Reuters reported totals 3.6 gigawatts (GW), a gigawatt being a thousand megawatts, or roughly the output of one large nuclear reactor. Google’s announcement says the agreement will bring 890 megawatts (MW) of new nuclear capacity to the PJM grid, the regional power system covering the Mid-Atlantic and parts of the Midwest. Bloomberg, which reported the talks before the announcement, put the deal’s value at roughly $1 billion or more.
Executive Summary
The headline number is 3.6 GW, which makes this one of the larger power agreements a technology company has signed for its data centers. But Google’s own framing singles out a smaller figure: 890 MW of new nuclear capacity on PJM. That is about a quarter of the total. The companies have not described the remaining roughly 2.7 GW as new supply.
The distinction matters because data centers built for artificial intelligence (AI) are adding electricity demand faster than grid operators are adding generation, and PJM is where that pressure is most visible. New capacity increases the amount of power the grid can deliver to everyone. A contract for output from plants that already run changes who is credited with that power, but does not, on its own, add megawatts to the system.
So the useful question about this deal is not how large it is, but how much of it is additive. On current disclosures, the answer is 890 MW, with the composition of the rest still unexplained.
The 890 MW Is the Only Slice Labeled as New Supply
Subtract the new nuclear capacity from the total and roughly 2.7 GW of the 3.6 GW agreement remains without a public description. If that remainder is drawn from reactors already running and already selling into the grid, it is a reassignment: the same electrons are produced, but a contract now ties their output, or the clean-energy credit attached to it, to Google rather than to the open market. Energy analysts call the difference ‘additionality’, meaning whether a purchase causes new generation to exist that would not otherwise have been built.
The 890 MW is different in kind. Whether it comes from upgrading existing reactors to produce more power (known as ‘uprates’), restarting idle capacity, or something else, the companies describe it as new, which means it should expand what PJM can actually supply once it comes online. For the utilities, data center developers and households that share that grid, the 890 MW is the part of this deal that eases supply. The rest primarily determines who holds a claim on supply that was already there.
That is why the 890 MW, not the 3.6 GW, is the operationally meaningful number. It is the portion that shows up as added capacity in grid planning, and it is the portion other large power buyers on PJM will feel.
Why PJM Is Where Additionality Matters Most
PJM Interconnection coordinates wholesale electricity for 13 states and Washington, D.C., and its territory includes Northern Virginia, the densest concentration of data centers in the world. PJM runs an auction that pays power plants to commit capacity years in advance, and prices in recent auctions rose sharply as forecasts of data center demand climbed. Meanwhile, new generators wait in an ‘interconnection queue’, the line of projects seeking permission to connect to the grid, which has been slow to clear.
In that setting, contracts that lock up existing output for one large buyer can tighten the market for everyone else, because the total available supply does not change while one claimant’s share does. Co-location arrangements involving existing nuclear plants in PJM have already drawn regulatory scrutiny over who pays for grid services. A deal anchored in new capacity sidesteps much of that argument, which may be one reason Google’s announcement leads with the 890 MW figure.
The Case for Contracting Existing Nuclear Output
Reassignment is not worthless, and it is fair to say so. Long-term contracts give a plant owner price certainty, which can justify the spending needed to extend a reactor’s licensed life or fund the very uprates that create new capacity. A reactor kept online through a contract is supply the grid does not lose. For Google, which has set a goal of running on carbon-free energy around the clock by 2030, contracted nuclear output also supports that target in a way intermittent wind and solar cannot fully match.
Constellation has used this model before, with Microsoft for the restart of a reactor at the former Three Mile Island site, now called the Crane Clean Energy Center, and with Meta for output from its Clinton plant in Illinois. The pattern suggests technology companies are willing to pay a premium for firm, carbon-free power, and that Constellation can convert that willingness into investment in its fleet. The open question is how much of each contract funds new megawatts versus securing existing ones, and this deal is the clearest case yet where the split is visible in the headline numbers.
What the $1 Billion Figure Cannot Yet Explain
Bloomberg’s figure of roughly $1 billion or more has not been broken down publicly. It is unclear whether it represents total contract value, annual spending, or capital tied specifically to the new capacity. Without a contract length or price per megawatt-hour, readers cannot judge whether Google is paying a premium for new supply, a market rate for existing output, or a blend.
That matters to investors comparing Constellation’s tech-sector contracts, and to other buyers trying to benchmark what firm, carbon-free power now costs on PJM. Until the companies disclose more, the dollar figure is best read as a signal of scale rather than a basis for valuation.
Background
Technology companies have become some of the largest buyers of electricity in the United States as they build data centers to train and run AI models. Nuclear power is attractive to them because it runs around the clock without carbon emissions, unlike wind and solar, which vary with the weather. Google has set a goal of matching its electricity use with carbon-free energy every hour of every day by 2030, and has previously signed a deal for future small modular reactors with Kairos Power.
Constellation Energy, spun off from Exelon in 2022, owns the largest fleet of nuclear plants in the country, much of it inside PJM. It has signed long-term agreements with Microsoft and Meta, making it a central player as AI-driven demand collides with a grid that is slow to add new generation.
Equinix runs giant buildings full of computers that firms like Microsoft, Google and Amazon use. Its Irish business saw profit before tax fall by more than a third last year, to 4.4 million euros.
That sounds alarming, but the drop mostly reflects a one-off payment the company received the year before. Sales actually grew 9%.
The real worry is electricity. The company’s own directors warn that power suppliers may not be able to give it more in the places it wants to grow.
In Ireland, where these computer buildings already lean heavily on the national grid, power may decide how fast they can expand.
RTÉ reported that newly published accounts for Equinix (Ireland) Ltd, the Irish arm of the California-based data centre operator, show pre-tax profit fell 36% to €4.4m in 2025, even as revenue rose 9% from €75.3m to €82.4m. The decline was due mainly to €2.9m of dividend income booked in 2024 that did not recur. Operating profit fell 6% to €5.43m, gross margin rose from 23% to 25%, and EBITDA (earnings before interest, tax, depreciation and amortisation) came to €13.2m.
During the year, Equinix bought BT Group’s Irish data centre business, including facilities in Citywest and Ballycoolin, Dublin, for €61.27m, a deal the Competition and Consumer Protection Commission cleared in August 2025. Headcount rose from 101 to 110, and the directors flagged the risk that electricity providers may not be able to supply further capacity where the company expects to expand.
Executive Summary
Equinix’s Irish subsidiary reported a sharp fall in pre-tax profit for 2025, to €4.4m from the prior year, on revenue that grew 9% to €82.4m. The directors attribute the fall mainly to a €2.9m dividend received in 2024 that was not repeated. The operating business tells a steadier story: gross margin improved to 25% on growth in recurring colocation and interconnection revenue, and operating profit slipped only 6% to €5.43m.
That steadier story carries a cost signal. Staff costs rose by about a quarter, from €14.18m to €17.8m, while headcount grew 9%, absorbing roughly half the year’s €7.1m revenue gain and thinning the operating margin even as gross margin widened. The company also added capacity through its €61.27m purchase of BT’s Irish data centre business.
The most consequential line in the accounts is not a number. The directors say they intend to keep increasing capacity, and they name electricity supply as the risk to doing so. In Dublin, where grid connections for new data centres have been restricted for years, that makes power availability, not customer demand, the variable to watch for Equinix, its customers and anyone pricing data centre capacity in Ireland.
A Dividend Explains the Headline, Not the Business
The 36% headline compares two years that are not like for like. In 2024, Equinix (Ireland) Ltd booked €2.9m of dividend income, money received rather than earned by running data centres, and that income did not recur in 2025. The directors identify it as the main reason for the fall. Measured on operations alone, the business held up: operating profit fell 6% to €5.43m, and after €1m of net interest the company reported pre-tax profit of €4.4m.
The cash-generation picture is firmer still. EBITDA, a rough proxy for the cash the operations throw off before financing and accounting write-downs, was €13.2m. The gap between that figure and operating profit is mostly €7.7m of depreciation, the non-cash charge that spreads the cost of buildings, generators and cooling plant over their working lives. Heavy depreciation is normal in a capital-intensive asset class like data centres and says little about demand, which the directors describe as having “remained solid.”
Wider Gross Margins, Thinner Operating Margins
Gross margin rose from 23% to 25%, which the directors credit to growth in recurring interconnection and colocation revenue. Colocation, renting space, power and cooling so customers can house their own servers, brought in €67.25m, more than four-fifths of revenue. Interconnection, directly linking customers to networks, clouds and each other inside the same building, contributed €9.44m, about 11%. Managed infrastructure added €3.6m and non-recurring revenue €1.85m, so nearly all income is recurring. Interconnection is valued in the colocation model because each new link adds revenue while using little extra floor space or power.
Below the gross line, costs grew faster than sales. Revenue rose by about €7.1m, while staff costs rose by €3.6m, roughly 25%, against a 9% rise in headcount, from 101 to 110 people (79 engineering and technical, 29 sales and administration, two directors). On the reported figures, operating margin fell from roughly 7.7% to about 6.6%. The accounts do not break down the staff cost increase; the year also included the integration of BT’s Irish data centre business, but the company has not linked the two.
Power, Not Demand, Sets the Pace of Expansion
The 9% revenue growth matters less than what it takes to repeat it. The directors say the company “intends to continue to increase its capacity,” and in the same accounts they name the risk that electricity providers may not be able to provide further capacity in locations where it expects to expand. In Dublin that is a live constraint: Ireland’s grid operator, EirGrid, has for several years restricted new data centre connections in the region, and the energy regulator has moved toward requiring new large energy users to bring their own generation or storage. For an operator that wants to grow, a grid connection, not a customer contract, is the scarce input.
The link to the AI buildout runs through power density. Equinix markets its 282 data centres worldwide as “AI-ready,” and the Irish directors list rising “requirements for power and cooling” among the market’s growth drivers. Denser computing, of which AI training and inference are the leading example, draws more electricity per rack, so customer growth consumes grid capacity faster than it consumes floor space. The Irish directors do not attribute demand to AI specifically; they cite internet traffic, financial services computing, cloud and software-as-a-service. But whatever the workload, more compute per site pushes power to the front of the queue.
Two consequences follow for the people who buy and finance this capacity. First, capacity that is already connected and powered becomes more valuable, which is consistent with the directors calling theirs “premium” and with the widening gross margin; buying BT’s operating Citywest and Ballycoolin facilities added capacity without waiting on a new connection, though the company has not framed the deal that way. Second, energy costs are moving toward customers: the directors say price increases are embedded in the budget and partly hedged, that “communication has started towards the customers,” and that a task force is looking for ways to cut primary energy use. Dublin tenants should expect power terms, not just space, to drive renewals.
Background
Equinix Inc., headquartered in California and listed under the ticker EQIX, owns and operates 282 data centres in 75 locations worldwide. Its model centres on colocation, renting secure, powered and cooled space for customers’ servers, and interconnection, which lets those customers link directly to networks, cloud platforms and one another inside the same facility. Its client list includes Oracle, Nvidia, Google Cloud, Microsoft, Dell Technologies and Amazon Web Services.
Dublin is one of Europe’s main data centre hubs, home to large cloud and technology operations, and also one of its most power-constrained. Ireland’s grid operator has restricted new data centre connections in the Dublin region for several years, making existing grid capacity a strategic asset. Equinix’s Irish subsidiary runs five Dublin sites and, in 2025, added BT Group’s Irish data centre business, including facilities in Citywest and Ballycoolin.
Denton, a Texas city north of Dallas, is weighing a 90-day pause on new data centers. These are giant buildings full of computers that run online services and artificial intelligence.
The surprise: the pause may not reach the biggest one already there. Core Scientific’s site is built to handle 391 megawatts, about as much electricity as a sizable city uses. Its growth depends more on the city-owned power company, which sells it electricity and owns the land it wants to rent.
Residents are split between worries about the power grid and a $3 billion rise in the value of local taxable property.
Denton City Council held the first of two required public hearings on a proposed moratorium on new data center development during its Sept. 22 meeting, Community Impact reported. The moratorium would halt all new data center development and permitting in city limits for 90 days, with an option to extend for another 90. A second hearing is set for Oct. 27, and the council could vote as early as Dec. 2.
At the same meeting, city officials said Core Scientific, which operates a 391-megawatt (MW) data center in Denton, had asked Denton Municipal Electric (DME), the city-owned utility, to lease additional public land south of its facility. A second project, Qumulus AI’s 20 MW data center, is planned to start operating in 2028 but has not begun construction.
Executive Summary
Denton is moving through the legal steps to pause new data center development, a process the council started with a unanimous vote on Aug. 18. The city attorney, Mack Reinwand, told the council that “a moratorium being passed does not necessarily stop an existing project from being built out.” Whether the pause would apply to an operator expanding or needing more land to meet its agreement with the city will depend on what that project’s original submission included.
That distinction matters because Denton is not only a zoning authority. Through DME, it sells electricity to its largest data center under a power purchase agreement (PPA, a long-term contract for electricity) and owns the land that operator wants to lease. The hearing also landed days after Texas Gov. Greg Abbott ordered state environmental regulators to stop issuing new data center permits while ERCOT, the state grid operator, audits proposed projects.
For data center operators, including bitcoin miners repositioning as hosts for AI and high-performance computing, Denton shows how local, state and grid-level controls now stack on the same site. For an existing operator, the most precise controls sit with the utility, not the moratorium.
What a Moratorium Can and Cannot Reach
A moratorium is a temporary pause on accepting or processing new development applications. Denton’s version would stop new data center development and permitting in city limits as soon as it passed. That is a blunt tool aimed at what has not been built yet. The city attorney’s caution that it “does not necessarily stop an existing project from being built out” means the pause bites hardest on projects that have not yet secured approvals.
That puts the two projects in different positions. Core Scientific’s 391 MW facility is operating. Qumulus AI’s 20 MW data center has a 2028 target, according to Charlie Rosendahl, Denton’s director of development services, but has not started construction. Whether Qumulus falls under the pause depends on the same question Mayor Chris Watts raised: what was submitted, and what the city already approved. Until the council answers that, the moratorium’s practical reach is unclear at both ends.
The Utility Is Also the Landlord
The headline point rests on what DME officials said about Core Scientific. DME Assistant General Manager Chris Lutrick said Core Scientific’s PPA limits how many megawatts it can consume. Those limits are controlled by ERCOT. He also said the company “ha[s] not got there” and has not asked for more power than the contract allows. So the operator’s electrical ceiling is already set by a contract with the city’s utility and by the state grid operator, whatever the council decides on the moratorium.
Land is the second lever. Lutrick said Core Scientific asked three to four months earlier to lease public land just south of its facility. He said the company did not say how it would use that land, and that it had been renting space at a private residence to park contractor vehicles. He added that the company “never mentioned another data center.” Rosendahl said the city is not discussing future data center development while the moratorium process continues. Interim City Manager Cassey Ogden said Core Scientific had not contacted the city about leasing more land, which does not match the utility’s account.
Taken together, the city’s decisions on whether to lease that parcel and how to administer the PPA will shape the 391 MW site more precisely than a pause on new applications. For operators on municipal utilities, the city can be regulator, power supplier and landlord at once. Each role gives it a separate point of leverage.
State and Grid Controls Stack on Top
Denton’s process does not run alone. According to the same reporting, Gov. Abbott said on Sept. 21 that state environmental regulators must stop issuing new data center permits. His order expands an existing state pause while ERCOT audits proposed data center projects. Rosendahl told the council that any interconnection, meaning the physical and contractual hookup to the grid, requires a study. Loads over 75 MW also need ERCOT approval, and that category is now under closer review at the governor’s direction.
The grid itself is the backdrop. Rosendahl said recent studies show Denton’s transmission system was already running near its limits before the large data center developments came online. That gives the moratorium’s supporters a concrete argument. It also suggests that any large new load would face capacity questions even without a local pause. For developers, the practical result is three layers of review: city permitting, state permits and ERCOT interconnection approval. Any one of them can set the schedule.
A $3 Billion Tax Base Against Unanswered Questions
The trade-off residents described is real on both sides. Denton saw a $3 billion increase in property tax value from data center development, according to earlier reporting. That is a direct fiscal benefit to the city and other local taxing bodies. Opponents cited long-term community effects and grid strain. Council Member George Ferrie said the city lacks long-term data on questions such as air quality because data centers “haven’t been this dense, this present for two decades.”
Neither side’s case is settled by what was presented at the hearing. The tax figure is a documented gain, but the grid concerns are backed by the city’s own transmission findings. A 90-day pause, extendable once, is a way to buy time for those studies rather than a final verdict. For AI infrastructure investors, the signal is that Texas sites near constrained municipal grids now carry local political review as a scheduling risk alongside power and equipment lead times.
Background
Denton, a fast-growing city in the Dallas-Fort Worth area, runs its own public power utility, Denton Municipal Electric. It currently has two data center operators: Core Scientific, with a 391 MW facility already operating, and Qumulus AI, with a 20 MW project planned for 2028. The moratorium effort began with a two-minute pitch from Mayor Pro Tem Nick Stevens on May 14. The council approved the pitch June 2 and voted unanimously on Aug. 18 to start the legal process.
Core Scientific built its business on bitcoin mining and has been repositioning toward hosting AI and high-performance computing workloads, part of a wider shift among miners with large power allocations. Most of Texas is served by the ERCOT grid, which has become a central gatekeeper for large new electricity loads such as data centers.
Texas cannot connect every giant computer warehouse that wants to plug into its power grid. So the agency running the grid has started rationing, deciding who gets electricity first by paperwork and start dates rather than by who asks loudest.
One company, Cipher, cleared an early hurdle for enough power to run a large city. Its shares jumped about nine percent.
A filing from rival Core Scientific shows the catch. Sites switched on before March 2022 skip the line. Everything newer waits, even after the concrete is poured.
Yahoo Finance reported that shares of Cipher Digital rose roughly 9% after the company received conditional status from the Electric Reliability Council of Texas (ERCOT), the operator of the Texas power grid, for 3.2 gigawatts of capacity in the state, with Core Scientific up about 4% and IREN slightly higher on the same read-across.
The move landed days after Core Scientific furnished an 8-K to the Securities and Exchange Commission on September 10, 2026, disclosing the ERCOT power status of each of its existing and proposed Texas data centers site by site: 371 megawatts at Denton, 600 megawatts at Pecos and 431 megawatts planned at Hunt. That filing is the clearest public description yet of how ERCOT is now sorting large data center loads — and of how much of a miner’s announced capacity is conditional rather than secured.
Executive Summary
The news event is a share price move, but the substance underneath it is regulatory. ERCOT is running an allocation exercise it calls Batch Zero, which assigns large new electrical loads to defined pathways and only releases a final allocation and load ramp when the process concludes. Conditional status inside that process is now the gating item between a developer’s announced gigawatts and energized, billable capacity.
Core Scientific’s 8-K sets out how the sorting works in practice. Denton’s existing 297 megawatts was conditionally approved as “Base Load, Pathway (a)” — longstanding existing load — purely because it energized before March 25, 2022, and is exempt from Batch Zero altogether. A further 74 megawatts at Denton is also exempt, because ERCOT had already incorporated it into the 2025 Regional Transmission Plan study cases. Pecos, by contrast, sits inside Batch Zero: 300 megawatts as “Base Load, Pathway (b)” for load energized after March 25, 2022, and another 300 megawatts as “Studied Load.” Hunt’s planned 431 megawatts qualified under Pathway (e) for demonstrated maturity, which the company earned by completing interconnection studies, clearing a 431-megawatt stability study, posting collateral, ordering long-lead equipment and starting construction.
For anyone buying, financing or underwriting Texas compute capacity, that hierarchy is the story. Two identical 300-megawatt blocks at the same site carry different regulatory certainty because of when they switched on. Cipher’s 3.2 gigawatts of conditional status is a real milestone; it is not the same thing as a final allocation, and the market repriced three companies on the distinction in a single session.
The Scarce Asset in Texas Isn’t a Megawatt. It’s a Date.
Core Scientific’s filing is unusually legible about a mechanism the industry usually discusses in the abstract. At Denton, 297 megawatts of existing power was conditionally approved as “Base Load, Pathway (a)” on one qualification: it was energized prior to March 25, 2022. That single fact takes it outside the Batch Zero allocation process entirely. At Pecos, 300 megawatts of existing power — physically comparable capacity, already operating — was conditionally approved as “Base Load, Pathway (b)” because it energized after that cutoff and before July 10, 2026. It sits inside Batch Zero, and the company states plainly that it will not receive its final allocation and load ramp until the process concludes.
The same asymmetry shows up in a quieter form on Denton’s additional 74 megawatts, which is exempt not because of an energization date but because ERCOT had already validated it inside the 2025 Regional Transmission Plan study cases. Presence in the grid operator’s own planning model functions as an entitlement. This is what makes interconnection paperwork the scarce input: it cannot be bought with capital on a short timeline, it cannot be manufactured, and it is not fungible with megawatts sourced elsewhere.
Run the arithmetic across the three Texas sites and the exposure becomes concrete. Of 1,402 megawatts described in the filing, 371 megawatts — just over a quarter — is outside Batch Zero and effectively settled in status terms. The remaining 1,031 megawatts is conditional and awaiting final allocation. Anyone underwriting Texas capacity, whether a lender sizing a facility, a GPU cloud tenant signing a multi-year lease or an investor modelling ramp, now has to ask which bucket a given block sits in, because the headline gigawatt figure no longer distinguishes them.
Pathway (e) Turns the Queue Into a Capital Test
Hunt is the instructive case, because it shows the alternative route for capacity that has no date advantage. Its planned 431 megawatts was conditionally approved as “Base Load, Advancing Large Load, Pathway (e)” — demonstrated maturity and advancement through the interconnection process. Core Scientific earned that by doing five specific things: completing interconnection studies with its utility partner, obtaining ERCOT approval of a 431-megawatt stability study, posting financial collateral, ordering long-lead equipment, and commencing construction.
That is a queue that rewards irreversible spend. Long-lead equipment orders — transformers, switchgear, generation and cooling plant — are placed years ahead and are difficult to cancel cleanly. Posting collateral ties up cash. Starting construction commits site capital before final allocation is known. The effect is to sort applicants by balance sheet and by willingness to accept sequencing risk, which advantages incumbent operators with existing land, utility relationships and financing access, and disadvantages speculative filings that exist mainly to hold a position.
The policy logic is defensible: a queue clogged with phantom load helps nobody, and requiring proof of advancement filters it. The commercial consequence is that developers must now fund a substantial portion of a project before they know what load ramp they will be granted. That is a materially different risk profile from the pattern of the past several years, and it is a cost that eventually shows up in the price of Texas capacity.
Why Three Companies Repriced on One Company’s Filing
Cipher’s 9% move, Core Scientific’s 4% and IREN’s smaller gain describe a market re-rating regulatory position rather than operating performance. Nothing about hash rate, bitcoin price or a new customer contract changed that day. What changed was information about who is likely to be allowed to energize large load in ERCOT, and the read-across was applied to peers with Texas portfolios.
The spread between those moves is worth reading carefully rather than dramatically. A one-day share price reaction is not a valuation, and conditional approval is several steps short of revenue. The chain runs: conditional status, then final allocation and load ramp, then energization, then a signed tenant, then billable capacity. Core Scientific’s own history illustrates the far end of that chain — its February 2025 expansion with CoreWeave added 70 megawatts of contracted power at Denton, took the site to 260 megawatts of critical IT load, brought CoreWeave’s contracted total across six locations to 590 megawatts, and carried an expected $10.2 billion of revenue over 12-year contract terms against $104 million of company capital expenditure. Note that critical IT load and electrical power are different measures, the former excluding cooling and electrical overhead, so the 260-megawatt figure and the filing’s 297 megawatts are not directly comparable.
There is a neat coincidence in that pairing: Denton, the site carrying the deepest contractual commitment, is also the site with the cleanest queue position. That is the combination the market is now hunting for, and it is rarer than announced gigawatt totals suggest. Capacity that is both contracted and exempt from allocation risk is the genuinely scarce product; capacity that is conditional and uncontracted is an option on a process whose conclusion has not been dated publicly.
Background
Bitcoin miners built large, power-hungry sites in Texas over the past decade because the state combines abundant generation, an independent grid and a market that rewards flexible load. After the 2024 halving cut mining rewards, several of those operators pivoted their footprints toward hosting artificial intelligence and high-performance computing, where tenants pay long-term contracted rates rather than exposing the operator to commodity price swings. Core Scientific’s February 2025 Denton expansion with CoreWeave was an early template: $1.2 billion of investment, 70 additional megawatts of contracted power, and a stated intent to run 900 megawatts of its contracted capacity as HPC hosting against 400 megawatts of mining.
The constraint on that pivot has shifted from capital to connection. As requests for hundreds of megawatts per site multiplied, ERCOT moved to formalise how large loads are approved and sequenced, creating the pathway definitions and the Batch Zero allocation process that Core Scientific’s September 10 filing describes. The practical effect is that a developer’s position in that process — its energization dates, its completed studies, its posted collateral, its presence in the grid operator’s transmission planning model — now determines how much of its announced capacity it can actually energize, and when.
Ontario’s largest electricity company wants to string a new high-voltage power line across the province’s north, from a station near Wharncliffe to the city of Sault Ste. Marie. It would cost $1.3 billion and switch on in 2029. The provincial regulator has to approve it first.
Nine First Nations have been offered the chance to own half of the line itself, not merely to be consulted about it.
Why an ordinary person should care: factories, mines and computing sites cannot open where there is no spare electricity. This line is being planned before those customers show up.
Hydro One Networks Inc. and Hydro One Sault Ste. Marie LP filed a joint leave-to-construct application with the Ontario Energy Board on September 11, seeking approval to build the North Shore Link, according to the company’s announcement. The project is a new 230-kilovolt transmission line running from Mississagi Transformer Station near Wharncliffe to the Third Line Transformer Station in Sault Ste. Marie, which Hydro One Sault Ste. Marie LP owns.
Hydro One put the investment at $1.3 billion and said the line is expected to be in service in 2029. The work also includes upgrades at Mississagi and an expansion of nearby Algoma Transformer Station, with the Sault Ste. Marie partnership handling upgrades at Third Line. Nine potential First Nation partners have been offered the opportunity to take a 50 per cent equity stake in the transmission line component through Hydro One’s First Nation Equity Partnership Model.
Executive Summary
A leave-to-construct application under Section 92 of the Ontario Energy Board Act is the gate every transmission project in the province has to pass through. It obliges the applicant to lay out route, design, timing and cost, and it puts the need for the line in front of a regulator, intervenors and ratepayer advocates. Hydro One has now placed a $1.3 billion northern reinforcement into that process.
The stated rationale is broad rather than specific. Ryan Docherty, Hydro One’s executive vice president for capital portfolio delivery, framed the project around rising provincial demand, aging infrastructure and more frequent severe weather, and described the line as strengthening the link between Ontario’s northeast and northwest. No customer, industrial project or contracted load appears in the announcement.
That is the interesting part. Transmission takes the better part of a decade from concept to energization, while a large industrial or computing load can commit to a site in months. A regulator that waits for signed commitments before approving wires guarantees the wires arrive late. A regulator that approves ahead of them puts capital at risk of sitting underused. The North Shore Link asks the Ontario Energy Board to make that call on a $1.3 billion scale.
Building Wires Before the Load Signs
The economics of transmission run backwards from the economics of the customers it serves. A 230-kilovolt line, meaning a circuit that moves power at 230,000 volts so it can carry bulk energy over long distances with modest losses, is a multi-year construction project with a multi-decade asset life. Hydro One’s own timeline puts the North Shore Link in service in 2029, roughly three years after filing, and that clock only starts once the regulator says yes. Large electricity consumers do not work on that horizon. They pick a site, want power within a couple of years, and go elsewhere when the answer is a queue position.
This is why the need case in a filing like this one tends to rest on system arguments rather than customer arguments. Hydro One’s announcement cites demand growth, asset age and storm resilience, and says the line strengthens the northeast-to-northwest connection. Those are real engineering rationales and they stand on their own. They are also, notably, rationales that do not require anyone to have signed a connection agreement.
The honest framing is that the filing is a bet on capacity being wanted rather than proof that it is already claimed. That bet can be entirely sound. Ontario has publicly signalled load growth across electrification, industry and computing, and pre-building headroom is cheaper than retrofitting a constrained corridor later. But it is a bet, and the Section 92 proceeding is precisely where the strength of the underlying forecast gets tested by parties whose job is to protect ratepayers.
Fifty Per Cent, Nine Nations
The equity structure is the most concrete commitment in the announcement. Nine potential First Nation partners have been offered the chance to invest in a 50 per cent stake in the transmission line component of the project, through a model Hydro One has applied to other northern lines. This is ownership, with the returns that regulated transmission assets generate, rather than a consultation process or a community benefits fund.
For a project developer, the practical value is schedule. Linear infrastructure across northern Ontario crosses traditional territories, and objections surfacing late in permitting are among the most reliable ways to lose a year. Aligning economic interest at the planning stage does not eliminate that risk, but it changes the negotiating posture from opposition to partnership on projects where the model takes hold.
Two things are worth noting evenly. The word Hydro One uses is potential, and the offer covers the transmission line component rather than the station work. Whether all nine participate, on what financing terms, and how the equity is funded are not addressed in the announcement. Those are ordinary details for a structure at this stage, and they are also the details that determine whether the 50 per cent figure translates into real returns for the communities involved.
What This Means for Anyone Shopping for Power in Algoma
For site selectors, whether in steel, mining, manufacturing or compute, the useful signal is not the dollar figure. It is the direction of capacity in the Sault Ste. Marie area and the date. A reinforced 230-kilovolt path into Third Line Transformer Station, plus expanded capability at Algoma Transformer Station, changes what a region can physically absorb. Until the line energizes, the constraint is whatever exists today.
That produces an awkward window. Anyone evaluating a northern Ontario site now is evaluating against a grid that gets materially better in 2029 if the regulator approves and construction holds, and does not if either slips. Buyers negotiating connection today should be asking how their service depends on this project and what happens to their in-service date if the proceeding runs long or the build encounters the transformer and equipment lead times that have stretched across the industry.
For investors, the read is simpler. Hydro One reported $39.7 billion in assets and $9 billion of revenue for 2025, and invested $3.4 billion in its networks that year. The North Shore Link sits alongside filings the company made earlier in 2026 for projects in central, eastern and Ottawa-area Ontario. This is a regulated utility adding to a rate base through a steady cadence of approvals, and the pace of that cadence matters more to the equity story than any single line does.
Background
Hydro One Limited, listed on the Toronto Stock Exchange under the ticker H, is Ontario’s largest electricity transmission and distribution provider, serving 1.5 million customers through its subsidiaries. Its transmission business owns the high-voltage backbone that moves power across a province stretching more than a thousand kilometres from the Manitoba border to the St. Lawrence, including the long, sparsely populated northern corridors that connect the northwest to the load centres of the south. Hydro One Sault Ste. Marie LP is the Hydro One entity that owns Third Line Transformer Station, the northern end point of the proposed line.
Every transmission expansion in Ontario runs through the Ontario Energy Board under Section 92 of the Ontario Energy Board Act, 1998. The proceeding is adversarial by design: the applicant files route, design, timing and cost, and intervenors including consumer groups and industrial customers can challenge whether the investment is needed and whether the cost is prudent. Sault Ste. Marie sits in the Algoma district, a northern industrial region where heavy industry, mining and, increasingly, electrification of everything from transport to industrial heat all compete for the same finite grid capacity.
NVIDIA, the company whose chips power most artificial intelligence work, is teaming up with eight Australian data centre operators to build a large amount of new computing capacity.
The plan could draw up to two gigawatts of electricity by 2027. That is roughly the output of a very large power station, spent on machines that learn from data.
The point is that Australians could build and run these systems at home instead of renting foreign computers. What has not been said: who pays, where the electricity comes from, and who has signed up to use it.
NVIDIA said on September 9, 2026 that it is working with a group of Australian cloud and data centre partners to expand land, power and shell capacity for its DSX artificial intelligence factories, targeting what the company describes as a buildout of up to 2 gigawatts by 2027. The named partners are Firmus, Sharon AI, IREN, Megaport, ResetData, CDC, NEXTDC and AirTrunk.
Under the arrangement described in NVIDIA’s announcement, the partners operate the facilities while NVIDIA supplies the DSX platform, accelerated computing, networking, software and ecosystem support. Sharon AI said it is deploying up to 68,000 NVIDIA graphics processors, and IREN pointed to its 800-megawatt Bundey campus in South Australia as the first place it will apply the DSX reference design. On the demand side, NVIDIA named Heidi and Atlassian as Australian companies building on its Nemotron open models.
Executive Summary
The announcement is best read as a capacity envelope rather than a purchase order. NVIDIA and its partners have described land, power and “shell” capacity, meaning buildings and electrical infrastructure prepared for computing equipment that has not yet been installed. Two gigawatts is the stated ceiling for 2027, not a contracted figure, and the release does not break the total down by site, partner or year.
What is substantiated is the alignment of a whole national ecosystem behind one vendor’s reference architecture. Every significant Australian and Australasian data centre developer of scale appears on the list, alongside newer entrants building graphics-processor clouds. That matters commercially: it standardises the power, cooling and networking specification that Australian AI capacity will be built to, and it makes NVIDIA the arbiter of what qualifies.
What is not substantiated is the economics. No capital cost, financing structure, contracted offtake, grid connection agreement or customer commitment accompanies the capacity figures. Those are the variables that determine whether two gigawatts is a plan or a press release, and they are the ones the participating companies have kept to themselves.
Ceilings, Not Contracts
The phrase doing the most work in this announcement is “up to.” Up to 2 gigawatts by 2027. Up to 68,000 graphics processors at Sharon AI. In infrastructure disclosure, an upper bound is a statement of ambition constrained by permits, power and money, none of which have been detailed here. It is not a criticism of the participants to say so; it is how early-stage capacity announcements are conventionally worded.
Some of the underlying numbers are also pre-existing rather than new. CDC said it operates more than 550 megawatts across Australia and New Zealand with a further 800 megawatts under construction, and IREN’s Bundey campus in South Australia is a 800-megawatt development it was already pursuing. Neither company said how much of that capacity is earmarked for NVIDIA DSX deployments. Readers cannot tell from the announcement how much of the headline 2 gigawatts is incremental to plans already in motion, or how much overlap exists between partners counting the same grid connections.
The more concrete commitment is architectural. NVIDIA is supplying DSX as a full-stack reference design spanning facilities, compute, networking and software, and partners are building to it. That has a real effect regardless of how the gigawatt arithmetic resolves: it sets the density, cooling and interconnect standard that Australian AI capacity will be procured against, and it shortens design cycles for operators who would otherwise engineer each hall from scratch.
Two Gigawatts Meets a Constrained Grid
A gigawatt-scale computing load is an industrial electricity customer of the first rank, comparable to a large smelter or a small city, and it must be connected to a transmission network that was not planned with it in mind. Australia’s grid is in the middle of a generation transition, and large new loads compete for connection studies, network capacity and firm supply. The announcement acknowledges this obliquely, noting that expanding capacity would support “additional power generation projects,” but it names no project, no megawatt of new generation and no timeline.
The cooling detail in the announcement is the most technically specific material in it, and it is where operator differentiation actually lives. CDC described direct liquid-to-chip cooling and what it called zero water advanced cooling on 100% renewable electricity. AirTrunk described direct-to-chip liquid cooling in AI-ready powered shells, meaning buildings with power and cooling delivered but computing equipment still to come. NEXTDC described liquid-cooled, high-density halls interconnected to major clouds. Liquid cooling matters because the current generation of accelerators dissipates more heat per rack than air can economically remove, and water-free designs matter in a country where drought risk is a live planning consideration.
Location strategy is the quiet variable. South Australia, where IREN’s Bundey campus sits, has a high share of wind and solar generation and periods of surplus, which is attractive for a load that can tolerate some siting distance from population centres. Training workloads travel well; inference does not, which is why Megaport’s approach, extending access through its Latitude.sh subsidiary across a software-defined global network, is a different bet on the same demand. Where compute lands in Australia will be decided by transmission and land availability more than by customer preference.
The Fungibility Pitch and Who Carries the Risk
NVIDIA’s Raj Mirpuri framed DSX as making AI factories “more productive, fungible and durable, and a new investable asset class.” That language is aimed squarely at the people who finance data centres. Fungible means the capacity can be re-let to a different customer running a different workload; durable means software upgrades extend the useful life of hardware that would otherwise depreciate on a punishing schedule. Both properties, if they hold, raise the residual value that lenders will underwrite against.
The claim is reasonable in principle and unproven in this context. Whether an accelerator installed in 2026 remains rentable at an economic price in 2032 depends on what competitors ship in between, and no software layer fully insulates an owner from a step change in performance per watt. Investors evaluating IREN, NEXTDC or Megaport on the back of this announcement should note that the depreciation question is precisely what the announcement asserts rather than demonstrates.
Risk allocation is also unstated. The partners operate the facilities; NVIDIA delivers the platform. That division suggests the balance-sheet exposure of building shells and buying accelerators sits with the operators, but the announcement does not describe any purchase commitment, capacity reservation, revenue guarantee or equity participation flowing the other way. In a sector where vendor financing arrangements have become common enough to draw scrutiny, the absence of detail is itself the thing worth watching.
Sovereignty Runs on Open Models
The second half of the announcement is about demand, and it is the part most relevant to buyers. Capacity without applications is a stranded asset, so NVIDIA paired the buildout with named users of its Nemotron open models: Heidi, whose chief technology officer Yu Liu described post-training Nemotron 3 Ultra for clinical reasoning, and Atlassian, which is applying the models to semantic search in its Rovo product. ResetData made the sovereignty case most directly, pitching Australian data residency, meaning customer data that stays under domestic jurisdiction, to government, enterprise and research buyers.
Open models are strategically central to NVIDIA rather than incidental. In an 8-K filed with the Securities and Exchange Commission on September 3, a current report companies use to disclose material events, NVIDIA said it had entered a definitive agreement two days earlier to acquire Hugging Face, the main distribution platform for open-source models and datasets, for roughly $11.9 billion plus an equity retention program of up to about $1.0 billion, with closing expected in the first half of 2027. NVIDIA committed to keeping the platform open, including continuing to support other silicon vendors.
That same filing contains a risk disclosure that bears directly on the sovereign AI thesis. NVIDIA warned that governments may impose new requirements on the development, release, distribution and use of AI models, including open-source ones, and that restrictions on models derived from any region could materially affect its business. Sovereign capacity is often sold as insulation from exactly that kind of policy risk. It is worth being clear that domestic data centres address where data and computation sit, not which models remain legally available to run on them.
Background
Australia has built a substantial data centre industry relative to its population, anchored by operators such as NEXTDC, which is listed on the Australian Securities Exchange, hyperscale developer AirTrunk, and CDC, which serves government and critical infrastructure customers across Australia and New Zealand. Megaport, also Australian-founded, built a global software-defined network that lets customers provision connections between clouds and data centres on demand, and now extends compute through its Latitude.sh subsidiary. IREN began as a bitcoin mining business and has been redirecting its power and land portfolio toward AI data centres, a transition several miners have attempted as accelerated computing outbid hashing for electricity.
The sovereign AI idea, that countries should host the computing capacity their economies and institutions depend on rather than rent it from foreign providers, has been a policy theme for several years. It has produced far more strategy documents than energised megawatts. This announcement is notable because it puts named operators, named sites and a dated ceiling behind the concept in one market, and because it arrives while Australia’s electricity system is simultaneously absorbing a generation transition and a new class of very large industrial loads.
Primary sources: NVIDIA Corporation, Form 8-K filed September 3, 2026, disclosing the definitive agreement to acquire Hugging Face and NVIDIA’s risk disclosure on government restrictions affecting open-source models.
The Swiss engineering group ABB and the consultancy Boston Consulting Group published a report saying the electricity inside data centers should increasingly flow the way it does in a battery, not the way it does in a wall socket.
Computers, solar panels and batteries all run on that kind of power already. Every time electricity is converted from one form to the other, a little is lost as heat, like a phone charger warming up.
Artificial intelligence machines use so much power that those small losses now add up to real money and real capacity.
ABB sells the equipment, so it has a stake in the argument.
ABB said on September 9 that it has published The Strategic Case for Hybrid AC/DC Power: Shaping the Transition to the Next Electrical Architecture, a report developed with Boston Consulting Group. The Zurich-headquartered electrification and automation group argues that direct current, or DC, is moving from the periphery to the center of industrial, commercial and digital infrastructure, and that choices made by executives and policymakers over the next two to three years will decide who shapes the transition and who simply inherits it.
The report singles out AI data centers as one of the most immediate drivers of DC adoption, finding that 800-volt DC distribution is emerging as the defining architecture for next-generation AI infrastructure. It frames the outcome not as a contest between DC and alternating current, or AC, but as a hybrid system: AC remains the backbone of transmission and regional distribution, while DC spreads inside facilities where the major sources and loads already run natively on it.
Executive Summary
The argument rests on a piece of electrical plumbing that most people never see. Grids deliver alternating current, in which the flow reverses direction many times a second, because that form is cheap to push over long distances and easy to step up and down in voltage with transformers. Almost everything now growing fastest, though, is natively direct current: solar photovoltaic panels, batteries, electric vehicles, industrial automation gear and the graphics processors inside AI servers. Each handoff between the two forms runs through a converter, and each converter throws off a percentage of the energy as heat.
ABB and BCG contend that stripping conversion steps out of the chain does three things at once: it raises efficiency, it increases the usable compute capacity behind an existing grid connection, and it simplifies the integration of on-site generation and storage. That middle point is the commercially interesting one. In markets where new grid capacity is the scarce input, an efficiency gain converts directly into more revenue-generating hardware behind the same meter.
The report also reframes the obstacle. Concerns about DC at scale, its safety and its economics reflect outdated assumptions rather than the capabilities of current equipment, ABB and BCG conclude. What actually slows deployment, they say, is fragmented standards and a shortage of engineers and technicians trained on DC systems. That is a claim about institutions and labor markets rather than about physics, and it points to a slower, less predictable fix.
Why AI Racks Are Rewriting the Electrical Diagram
Conventional data center power design has been remarkably stable for two decades. Utility alternating current arrives at a substation, passes through switchgear, an uninterruptible power supply and a power distribution unit, then reaches a server whose internal supply finally converts it to the low-voltage direct current the chips actually consume. Each stage was tolerable when a rack drew a few kilowatts. The report’s contention is that at AI power densities, conventional architectures are reaching practical limits, and the accumulated conversion overhead stops being a rounding error.
The 800-volt DC figure is the specific technical claim worth understanding. Raising the distribution voltage lets a given amount of power travel through thinner conductors, because power is voltage multiplied by current and it is current that dictates copper cross-section and resistive heating. Delivering high-density racks at low voltage means either enormous busbars or unacceptable losses. Pushing distribution to 800 volts DC and converting close to the load is the same trick the automotive industry adopted for fast-charging electric vehicles, applied to a data hall.
The practical consequence is that the change does not stop at the rack. It touches switchgear, protection, uninterruptible power supply topology, on-site storage and the interface with the substation. That is a supply-chain shift as much as an engineering one, and it favors vendors who already hold the protection and conversion portfolios.
The Real Prize Is the Grid Connection
Read commercially, the strongest line in the release is not about efficiency in the abstract. It is that DC distribution lets operators maximize compute capacity within constrained grid connections. In the markets where AI capacity is being built hardest, the binding constraint is rarely capital or land. It is the megawatts a utility will actually deliver, and when they will deliver them.
Under that constraint, the economics change character. An efficiency improvement in a power-abundant market is a cost saving measured against the electricity bill. The same improvement behind a fixed, fully subscribed grid connection is a capacity unlock, measured against the revenue of the additional accelerators it lets you energize. Those two framings can differ by an order of magnitude in value, which explains why an argument about conversion losses is landing now rather than a decade ago.
It also explains the report’s two-to-three-year window. Electrical architecture is set early in a data center’s design and is expensive to revisit. Operators committing to buildings that will be energized late this decade are choosing their topology now, which is precisely when a vendor wants the conversation to happen.
Standards and Skills Are the Stated Bottleneck
ABB and BCG place the constraint on adoption in two unglamorous places: fragmented standards and a shortage of DC-specific skills. Both are credible. Direct current has no natural zero crossing, the instant of zero flow that lets a conventional breaker extinguish an arc, which is why DC protection historically demanded different hardware and different design practice. ABB says it launched the industry’s first solid state circuit breaker in 2022, and holds more than 700 DC-related patents.
That patent position is also why the call for harmonized standards deserves to be read with clear eyes. Common standards genuinely enlarge a market and reduce buyer risk, and buyers should want them. They also tend to reward whoever arrives with the deepest existing portfolio in the standardized technology. Nothing about that is improper, and ABB is not alone in it, but a customer evaluating this report should treat it as a well-argued position paper from an interested party rather than as neutral market research.
The skills point may be the more stubborn of the two. Standards can be negotiated on a schedule. A workforce of electricians, commissioning engineers and facility staff fluent in high-voltage DC protection is built over years, and its scarcity would constrain even operators fully convinced by the argument.
What Is Substantiated and What Is Asserted
The quantified evidence in the announcement is drawn from marine propulsion, where ABB says a DC-based onboard vessel power system achieved fuel savings of up to 27 percent. That is a real, specific result, and it is not a data center result. Ships run isolated power systems with variable-speed loads and their own economics; the number establishes that ABB has long-running DC field experience, not that a data hall should expect a comparable gain.
For the data center case itself, the announcement offers direction rather than magnitude. It says 800-volt DC is emerging as the defining architecture and that efficiency and usable capacity improve, without published percentages, capital-cost comparisons or named deployments in the summary. The conclusion that scale, safety and economic objections are now outdated is likewise stated as a finding, with the supporting analysis sitting in the full report published on ABB’s site.
None of that undercuts the thesis, which aligns with where high-density computing and on-site storage are visibly heading. It does mean the announcement is best treated as a framing document. The buyer’s question is not whether DC distribution helps, but by how much, at what installed cost premium, and with which protection and service ecosystem behind it.
Background
The choice between alternating and direct current was settled commercially in the late nineteenth century, when transformers made it cheap to step alternating voltage up for long-distance transmission and back down for use. Direct current never disappeared, though. It survived in specialist niches such as long submarine transmission links, traction systems and shipboard power, and it returned quietly through the back door as solar panels, batteries and electronics proliferated, each of them a direct current device tethered to an alternating current grid through a converter.
ABB sits on both sides of that history as one of the largest electrification and automation suppliers globally, selling switchgear, drives, protection and power distribution equipment into utilities, industry and data centers. The AI buildout has made its data center segment strategically prominent, because the constraint on new compute has shifted from chips and capital toward electrical delivery. This report, produced with Boston Consulting Group, is the company’s argument that the resulting architecture will look meaningfully different from the one the industry has built for the past twenty years.
Swedish construction group Skanska announced on August 20, 2026 that it has signed a contract with an existing client to build four new data centers in the southeast United States. The contract is worth USD 1.2 billion (about SEK 11.2 billion) and will be booked in Skanska’s US order bookings for the third quarter of 2026.
The four facilities total approximately 75,000 square meters (808,000 square feet). Skanska’s scope covers the building shell plus interior fit-out for technical spaces, support areas, and offices. Construction begins in the third quarter of 2026 and is expected to finish in the third quarter of 2028.
Executive Summary
Skanska’s announcement is short on specifics — the client, the exact locations, and the facilities’ power capacity are all undisclosed — but the headline numbers tell a clear story: a single customer is committing to four buildings at once, worth $1.2 billion in construction value alone, on a two-year delivery clock. That is a program, not a project, and it reflects how hyperscale and large-enterprise data center buyers now procure capacity in multi-site batches rather than one building at a time.
The deal also reinforces the southeast US as a serious data center growth corridor. As land, power interconnection queues, and community pushback tighten conditions in established hubs like Northern Virginia, developers have increasingly looked south for available land, comparatively faster utility timelines, and business-friendly permitting. A four-facility award in the region — from a repeat client, no less — suggests that migration of demand is continuing.
For the construction industry, the contract underscores that data centers have become a core revenue engine for major contractors. Skanska separately announced an additional $238 million data center contract in Virginia, indicating a pipeline of repeat data center work across multiple US regions.
A Program Buy, Not a Building Buy
The most telling detail in this release is not the dollar figure but the structure: one client, four facilities, one contract. Data center customers with large, predictable capacity needs — typically cloud platforms, AI companies, or the developers who serve them — increasingly bundle construction into multi-site programs. Bundling locks in contractor capacity, standardizes designs across sites, and compresses delivery schedules, all of which matter when the constraint on growth is how fast physical capacity can be stood up rather than how much capital is available.
The ‘existing client’ framing matters too. Repeat awards are how construction firms build durable data center franchises: a contractor that has already delivered for a customer carries proven designs, familiar subcontractor networks, and established safety and quality track records into the next award. For Skanska, converting one relationship into a four-building, $1.2 billion follow-on is evidence that this flywheel is working — though it also concentrates revenue exposure in a single customer relationship, a tradeoff worth noting.
Why the Southeast, and What It Strains
The southeast US has become one of the fastest-growing data center regions because the traditional hubs are congested. Northern Virginia — the world’s largest data center market — faces multi-year waits for grid interconnection (the process of getting a utility to deliver large blocks of power to a new site), rising land costs, and local zoning battles. States across the southeast have courted the industry with available land, tax incentives, and utilities willing to plan for large new loads.
But four facilities landing at once in one region illustrates the strain this growth creates. Data centers are extraordinarily power-dense buildings, and every new campus adds load that regional utilities must generate, transmit, and balance. Meanwhile, the specialized trades that data center construction depends on — electricians, mechanical fitters, controls technicians — are in short supply nationally, and the southeast’s simultaneous boom in chip plants, battery factories, and other industrial projects competes for the same workers. The release does not say how these projects will be powered or staffed, and those are precisely the variables that determine whether a Q3 2028 completion date holds.
The Economics of Shell and Fit-Out
Skanska’s scope — shell construction plus interior fit-out of technical, support, and office spaces — works out to roughly $300 million per building, or on the order of $1,500 per square foot across the 808,000-square-foot program based on the disclosed figures. That is far above typical commercial construction costs, which reflects what a data center actually is: the building is effectively a machine, dense with structural, electrical, and mechanical infrastructure long before any servers arrive. It is worth remembering that construction cost is only one layer of total project cost; the IT equipment the eventual owner installs typically represents a further large investment not captured in a construction contract.
For Skanska, the award lands in Q3 2026 order bookings, giving investors a concrete signal about the health of its US commercial pipeline. For the broader market, it is one more data point that data center construction spending remains robust — a useful counterweight to periodic debate about whether AI-driven infrastructure investment is decelerating. One contract cannot settle that debate, but a repeat client committing to four buildings through 2028 is not the behavior of a customer pulling back.
Background
Skanska, founded in Sweden and headquartered in Stockholm, is one of the world’s largest construction and development companies, with the United States among its most important markets. Data centers have become a growing line of business for major contractors as cloud and AI operators race to add physical capacity; alongside this award, Skanska announced a further $238 million data center contract in Virginia and a $957 million light rail contract in California, illustrating the breadth of its US order book.
The US data center market has historically concentrated in hubs like Northern Virginia, but constraints on power, land, and permitting there have pushed a growing share of new development into the southeast, where utilities and state governments have actively courted the industry. Multi-building, single-client construction programs like this one have become a hallmark of how hyperscale capacity is now procured.
Meta, the company behind Facebook and Instagram, is turning its artificial intelligence data center in Richland Parish, Louisiana, into its biggest anywhere. It says it will spend more than $50 billion there.
The surprising part is the electricity. At full size, the site is planned to use about as much power as five large nuclear reactors produce. To supply it, Meta’s deal with the local utility, Entergy, pays for seven new natural gas power plants and three giant batteries.
Meta says local households will save money as a result. It has not published how it calculated that.
Meta announced on July 13, 2026 that it is expanding its Richland Parish, Louisiana data center to 5 gigawatts (GW) of compute capacity. That makes it the largest site in Meta’s fleet. The campus will house Hyperion, which Meta calls its largest multi-gigawatt AI training cluster. Meta puts the total investment in the region at more than $50 billion, supporting over 7,500 jobs at peak construction and 1,000 permanent roles once the site is operating.
The announcement also describes a new agreement with Entergy Louisiana. It will fund seven new natural gas-fueled generating plants, three grid-scale batteries, nuclear uprates and other purchased power. Meta says the agreement will deliver about $2 billion in customer savings, on top of $650 million it announced earlier, for a total of $2.65 billion over 20 years.
Executive Summary
Meta is scaling a single campus in rural northeast Louisiana to 5 GW and committing more than $50 billion to it. The site is being built to host Hyperion, a training cluster of the kind used to build large AI models, which runs tens of thousands of processors near full load around the clock. Alongside the headline figures, Meta lists $1.6 billion in contracts with Louisiana businesses to date, more than $1 billion in roads, water and wastewater improvements, a $5 million gift to Louisiana Delta Community College, and $215 million for Entergy’s affordability and efficiency programs.
The most consequential part of the announcement is the power arrangement, more than the jobs or the grants. At this scale, a data center is no longer a customer that plugs into existing grid capacity. It is a reason for a utility to build new generation. The Entergy agreement funds a portfolio of gas plants, batteries, nuclear upgrades and purchased power. Meta has also committed to help fund up to 2.5 GW of clean and renewable energy. How fast, and on what terms, that generation arrives will largely decide when Hyperion reaches full scale and who carries the cost.
At Five Gigawatts, the Utility Sets the Schedule
A gigawatt is a billion watts, and the data center industry uses it to size how much electricity a campus can draw. A large nuclear reactor produces roughly one gigawatt. Meta’s expanded Richland Parish site is rated at 5 GW of compute capacity. It will host Hyperion, described as a multi-gigawatt AI training cluster. Training clusters are an unusually demanding kind of load: thousands of accelerator chips running together for weeks at a time, drawing close to peak power continuously. A regional grid does not keep that much idle capacity in reserve, so a load of this size has to arrive with its own new generation.
That is what the Entergy agreement is for. According to Meta, it funds seven new natural gas-fueled generating plants, three grid-scale batteries, nuclear uprates and other purchased power. Nuclear uprates are upgrades that raise the output of existing reactors. Read that list next to the construction figures and the order of work becomes clear. Server halls, contractors and workforce programs are the visible part of the project. The pace, though, is governed by when the plants, batteries and grid connections come online. Construction crews can be scaled up relatively quickly. New generation depends on equipment deliveries, utility engineering and regulatory processes that a data center builder does not control.
This affects several groups. Entergy Louisiana’s other customers have bills tied to how costs are allocated. The state regulators who oversee the utility’s resource plans must weigh a single customer’s demand against system-wide reliability. And anyone forecasting Meta’s AI capacity needs to know when Hyperion actually reaches multi-gigawatt scale. Meta has not said how the seven plants’ combined output compares with the 5 GW figure. That is the number that would show how much of the campus the new generation actually covers.
The $2.65 Billion Savings Claim Needs Its Arithmetic
Meta says the new agreement is expected to deliver about $2 billion in savings to Entergy Louisiana customers, on top of $650 million announced previously. Spread over 20 years, the combined $2.65 billion averages roughly $130 million a year. The usual argument for such savings is that a very large, steady customer helps pay a utility’s fixed costs, which lowers the share left for everyone else. That argument can hold. It depends, however, on contract terms: who pays for the new plants, over what period, and what happens if the anchor customer’s demand falls short of plan.
Meta did not lay out that mechanism or the assumptions behind the figure. Its broader commitment is that it will pay for the energy, water and related infrastructure it uses so that other customers’ bills do not rise. That is a meaningful policy statement, but its strength sits in contract language that has not been published. The $215 million contribution to Entergy’s Power to Care and residential energy efficiency programs is more concrete: it is a direct transfer with a stated amount. Until the underlying terms are visible, the headline savings figure is best read as a projection, not a guarantee.
Clean-Energy Matching Next to New Gas Generation
Meta says it will match 100% of the Richland Parish site’s energy use with clean and renewable energy, as it does at its other data centers. It also commits to help fund up to 2.5 GW of clean generation. Matching is an accounting method: a company funds or buys clean electricity equal to what it consumes over a period. It does not require the clean power to be produced at the same hour or on the same grid as the consumption. The gas plants and batteries in the Entergy agreement exist because a round-the-clock training load needs power that can be supplied on demand, including at night and during low-wind periods.
Both statements can be true at once, but readers should hold them together. Up to 2.5 GW is a ceiling, not a commitment to 2.5 GW. Renewable plants also typically produce well below their rated capacity averaged over a year. Clean generation tied to this agreement alone would therefore not obviously cover the annual consumption of a 5 GW campus running near full load. Meta has not said where the balance will come from, or whether it is matched annually or hour by hour.
$50 Billion In, 1,000 Permanent Jobs Out
The job figures follow the usual pattern for hyperscale data centers, which are capital-heavy and need relatively few staff to run. Meta cites 7,500 jobs at peak construction and 1,000 operational roles, or about $50 million of investment per permanent job. The larger local effects are construction spending, tax revenue and infrastructure. Meta reports $1.6 billion contracted with Louisiana businesses to date and more than $1 billion spent on roads, water and wastewater systems. It also says Richland Parish teachers received yearly bonus checks 400% higher than the previous year because of increased tax revenue from the project.
The workforce measures are aimed at the gap between the two job numbers. They include full scholarships for data center trade certificates for Richland Parish high school graduates starting with the class of 2026, contractor-run programs at Louisiana Delta Community College, and a reported 37% rise in enrollment at the University of Louisiana at Monroe’s construction management school. Making the state’s Source Louisiana portal the default subcontracting platform widens access for local firms. The general contractors (DPR Construction, Turner Construction Company and Mortenson Construction) and in-state subcontractors benefit most directly during the build. The open question for the parish is what that construction workforce does when the peak ends.
Background
Meta Platforms, the parent of Facebook, Instagram and WhatsApp, operates a global fleet of data centers. It is one of the handful of hyperscalers, the companies that build computing capacity at the largest scale. Meta broke ground on its Richland Parish campus in northeast Louisiana in December 2024, and the July 2026 announcement expands the site to 5 GW, making it the largest in Meta’s fleet. The area is served by Entergy Louisiana, a regulated electric utility, and Meta has worked with Entergy on power supply since before the site came online.
AI training clusters have changed data center planning. Earlier facilities drew tens or hundreds of megawatts. Clusters built to train frontier AI models are now planned in gigawatts, which brings power generation, transmission and utility regulation into the center of each project. Meta has partnered since 2022 with the Center on Rural Innovation on programs near its data centers and says it is extending that partnership to Northeast Louisiana.
New York has become the first U.S. state to pause new hyperscale data center approvals above a 50-megawatt (MW) threshold, according to a July 13, 2026 report from Inside Climate News. The action targets the largest facilities — the class typically used for cloud and AI training workloads — rather than smaller enterprise or edge sites.
The reporting frames the move as a state-level response to rapid growth in data center power demand. The underlying article is the sole dated source available to us; specifics on scope, duration, exemptions, and enforcement are not restated here beyond what the headline confirms.
Executive Summary
A hyperscale data center is a very large facility — commonly tens to hundreds of megawatts of IT load — operated by or for cloud and AI providers. A 50 MW site can draw roughly the power of a small city. New York’s decision to pause approvals above that line puts a hard ceiling on the class of build that has driven most of the industry’s recent capacity growth.
The significance is less about one state’s queue and more about precedent. Utilities across the country are absorbing multi-gigawatt interconnection requests, and several governors and public service commissions are actively rewriting siting, tariff, and interconnection rules. If New York’s approach holds up politically and legally, other states facing similar grid stress may borrow the template.
For operators, hyperscalers, and their real estate partners, the immediate question is routing: whether projects earmarked for New York shift to neighboring PJM and New England markets, to the Midwest, or to the Southeast — each of which has its own transmission and permitting constraints.
Why 50 Megawatts, and Why Now
Fifty megawatts is a meaningful line. It is well above a typical enterprise data hall and squarely in the range where a single customer campus starts to look like a large industrial load to a utility. Regulators drawing the line there are, in effect, saying that facilities of this size deserve a different review than a warehouse or office park — even if the underlying zoning treats them alike. The threshold also captures the vast majority of AI training and cloud region builds announced over the last two years, which is presumably the point.
The timing tracks with a broader shift. Grid operators from ERCOT to PJM have published sharply revised load forecasts driven by data center interconnection queues, and several utilities have asked commissions to rewrite the rules for how large new loads are studied, priced, and prioritized against existing customers. A statewide pause is a blunter instrument than tariff reform, but it buys time to design the finer tools.
Winners, Losers, and the Map of AI Capacity
In the near term, the clearest beneficiaries are markets that can credibly offer power, land, water, and a permitting path in the next 18 to 36 months. That short list currently includes parts of Virginia (despite its own constraints), Ohio, Indiana, Georgia, Texas, and a handful of Midwestern and Mountain West locations with generation headroom. Operators who already control land and interconnection queue positions in those regions gain optionality; those who were counting on New York capacity face a re-plan.
The losers are more nuanced. New York loses some tax base, construction spend, and long-term operations jobs, but keeps grid capacity for other uses — including electrification of heat and transport, which the state has committed to under its climate law. Hyperscalers lose a latency-advantaged East Coast site option, though metro New York’s colocation footprint for latency-sensitive workloads is largely unaffected because those buildings are typically well under 50 MW.
The Precedent Risk for the Industry
The industry’s stated position for years has been that data centers are good grid citizens: predictable loads, willing to pay for infrastructure, and increasingly matched with clean generation. New York’s pause is a signal that at least one state is not persuaded that the current pace can be absorbed without displacing other public priorities. Whether that view spreads depends on how the pause is structured — a narrow, time-boxed study period reads very differently from an open-ended moratorium — and on how the industry responds.
There is a real opportunity here for operators willing to negotiate: bring-your-own-generation deals, firm demand response commitments, waste-heat reuse, and transparent water reporting are all on the table in other jurisdictions and could shape what a post-pause approval regime in New York looks like. The alternative — treating the pause as a political problem to be waited out — invites more states to adopt similar caps before the industry has a seat at the design table.
Background
Data centers are the physical buildings that house the servers, storage, and networking equipment behind cloud services, streaming, enterprise software, and — most recently — generative AI. Hyperscale facilities are the largest tier, built by or for a small group of very large operators, and they have grown from tens to hundreds of megawatts per campus over the last decade. Their power draw has become large enough to reshape utility planning in several U.S. regions.
New York has among the most ambitious state climate mandates in the country, with statutory targets for electrification and emissions reduction. The state also hosts the NYISO grid, dense metro loads, and a mix of nuclear, hydro, gas, and growing renewable generation. Reconciling large new industrial loads with those commitments is the policy backdrop for the reported pause.
