Latitude Media reports that the physical realities of the electric grid are “setting in” for the data center development pipeline. The April 26, 2026 piece frames a shift the industry has been circling for two years: the constraint on new AI-driven data center capacity is increasingly not capital, land, or chips, but whether the grid can physically deliver the power — and how long interconnection and transmission upgrades take.
Executive Summary
The report’s core observation is that the announced data center pipeline — the sum of projects developers have declared — is colliding with what the transmission system can actually serve. Interconnection (the formal process of connecting a large new load or generator to the grid) and transmission capacity (the physical ability of high-voltage lines to move power to a given location) operate on utility timescales measured in years, while hyperscale demand has been announced on timescales measured in quarters.
Why it matters: if grid physics is the binding constraint, then the familiar metrics of the buildout — megawatts announced, acres acquired, capital committed — stop predicting what actually gets energized and when. Siting strategy shifts from “where is land and fiber” to “where is deliverable power,” and the advantage moves to players who secured interconnection positions early or who can bring their own generation.
Announced Megawatts Are Not Energized Megawatts
A recurring pattern in this cycle is the gap between the announced pipeline and deliverable capacity. A developer can buy land, order equipment, and issue a press release in months; a utility must study the new load’s effect on the surrounding network, plan any needed substation and transmission upgrades, and build them — a sequence that routinely runs on multi-year timelines. The Latitude Media framing, that physical realities are “setting in,” suggests the market is starting to discount announcements accordingly. For readers of industry news, the practical takeaway is to treat energization dates, not announcement dates, as the real milestone.
Why Transmission Is the Hard Constraint
Transmission is unforgiving because it is physics plus process. Physically, a high-voltage line can carry only so much power before thermal and stability limits bind, and a concentrated gigawatt-scale load changes flows across an entire region, not just one feeder. Procedurally, upgrades require engineering studies, regulatory approvals, cost-allocation fights over who pays, and often new rights-of-way. None of these steps compresses easily with money. That is what distinguishes this bottleneck from earlier ones like GPU supply or land: you cannot pay a premium to make load-flow studies and line construction happen in a quarter.
Winners: Whoever Holds Deliverable Power
If interconnection position is the scarce asset, several groups benefit. Incumbent data center operators with existing utility relationships and already-energized capacity hold something new entrants cannot quickly replicate. Sites with surplus deliverable power — including brownfield industrial locations with legacy grid infrastructure — gain value relative to greenfield land. And “bring your own power” strategies, from on-site generation to co-location with existing plants, move from novelty to mainstream consideration, though they introduce their own permitting, fuel, and regulatory questions. Conversely, late-arriving developers whose projects sit deep in interconnection queues face the risk that their capacity arrives after the demand it was meant to serve has been placed elsewhere.
The Siting Map Is Being Redrawn
For two decades, data center geography followed fiber routes, tax incentives, and cheap land. A grid-constrained era redraws that map around electrical headroom: regions with spare transmission capacity, faster-moving utilities, or generation-rich locations become competitive even without a legacy data center cluster. This also raises a policy dimension — utilities and regulators must decide how much speculative load to plan for, and how to protect other ratepayers from paying for infrastructure serving projects that may not materialize. How that risk gets allocated will shape which regions court this demand and which slow-walk it.
Background
Data center development historically treated electricity as a routine input: sites were chosen for fiber connectivity, land cost, and tax treatment, and utilities absorbed the load growth without drama. The AI buildout that accelerated from 2023 onward broke that assumption, with individual campuses proposed at power levels comparable to heavy industry and developers announcing capacity far faster than grid infrastructure has historically been built.
By 2026 the conversation across the industry had shifted from chip supply and capital availability to power delivery — interconnection queues, transformer and equipment lead times, and transmission planning. The Latitude Media piece discussed here sits in that context: an energy-sector publication documenting the moment when the announced pipeline meets the grid’s physical and procedural limits.
The Midcontinent Independent System Operator (MISO) — the grid operator coordinating electricity across a footprint spanning 15 U.S. states and the Canadian province of Manitoba — expects electric load to jump roughly 35% by 2035, according to an April 2026 report from Utility Dive. The primary driver named in the forecast is data center growth.
A 35% increase over roughly a decade represents a dramatic break from the era of essentially flat U.S. electricity demand that prevailed from the late 2000s through the early 2020s, and it puts one of the largest grid operators in North America on record quantifying the scale of the AI-and-cloud buildout.
Executive Summary
MISO’s forecast is a planning document, not a press release from a company selling something — which makes it one of the more consequential data points in the ongoing debate over how much electricity the data center boom will actually consume. Regional transmission organizations (RTOs) like MISO exist to keep supply and demand balanced in real time and to plan the wires and generation needed years ahead. When an RTO raises its ten-year demand outlook by more than a third, that number flows directly into transmission planning, capacity auctions, and the resource plans of dozens of utilities.
The significance is twofold. First, it validates what individual utilities across the Midwest and Gulf South have been reporting piecemeal: hyperscale data center projects are arriving in interconnection queues at a pace with no modern precedent. Second, it sets up a decade of hard trade-offs. Meeting 35% growth requires new generation, new transmission, and new large-load interconnection rules — all on timelines that historically run slower than the two-to-three-year construction schedule of a data center campus.
For the infrastructure industry, the headline number is both an opportunity signal and a warning: the grid is now the binding constraint on digital infrastructure growth, and the regions that solve power delivery fastest will win the next wave of siting decisions.
The End of Flat Demand Is Now Official Planning Doctrine
For roughly fifteen years, U.S. grid planners could assume that efficiency gains — LED lighting, better HVAC, industrial offshoring — would offset economic growth, keeping total electricity demand nearly flat. That assumption underpinned everything from utility rate cases to power plant retirement schedules. A 35% load-growth forecast from MISO formally retires it for one of the largest grid footprints in North America.
What makes an RTO forecast different from a consultant’s projection is accountability: MISO must plan transmission and resource adequacy against this number. If the forecast is right and the buildout lags, the result is capacity shortfalls and price spikes. If the forecast is wrong and infrastructure is overbuilt, ratepayers carry stranded costs. Either error is expensive, which is why the assumptions behind the number — how much announced data center load actually materializes — deserve as much scrutiny as the number itself.
Data Centers as the Marginal Buyer of Power
A data center is, from the grid’s perspective, an unusual customer: it demands large blocks of power (often hundreds of megawatts per campus), runs at high utilization around the clock, and wants to connect years faster than traditional industrial load. When such customers become the dominant source of demand growth, they effectively set the terms of grid expansion — and grid operators, utilities, and regulators are still working out who pays for the upgrades those connections require.
The economics cut in several directions. Utilities in MISO territory gain a growth story they have not had in a generation, which supports investment in wires and generation. Existing ratepayers face the risk of subsidizing infrastructure built for loads that may not fully arrive — a concern regulators in several states are already addressing through special large-load tariffs and financial-commitment requirements. Data center developers, meanwhile, face the reality that power availability, not land or fiber, now determines where and when they can build.
Winners, Losers, and the Speed Mismatch
The core tension in a 35%-by-2035 scenario is timing. Gas turbines face multi-year order backlogs, new nuclear operates on decade-plus horizons, and large transmission projects routinely take seven to ten years from planning to energization. Data center campuses go from groundbreaking to load in two or three. That mismatch favors whoever can bridge it: developers with early interconnection positions, utilities with spare capacity or fast-track large-load processes, suppliers of grid equipment, and operators pursuing on-site or co-located generation.
It also raises competitive stakes between regions. MISO’s footprint — stretching from the upper Midwest to the Gulf Coast — competes with PJM, ERCOT, and the Southeast for hyperscale siting. A credible, well-executed plan to serve 35% more load is itself an economic-development asset; a forecast without matching buildout is a queue of frustrated customers who will site elsewhere.
Forecast Versus Reality: The Phantom Load Question
Every load forecast in the current environment must grapple with duplicate and speculative requests. Developers commonly file interconnection requests in multiple jurisdictions for the same project, and some announced campuses will never be built. Grid operators know this and apply screening assumptions, but the industry has little historical data on what fraction of AI-era announced load converts to actual consumption. The honest read of any 35% figure is that it is a planning scenario with meaningful uncertainty in both directions — actual growth could undershoot if projects evaporate, or overshoot if AI demand keeps compounding.
That uncertainty is not a reason to dismiss the forecast; it is a reason to watch how MISO and its member utilities structure commitments. Mechanisms that require large customers to put capital at risk — minimum-take contracts, collateral requirements, contribution to network upgrades — are the market’s way of separating real load from phantom load, and their adoption across the footprint will be a better indicator of true demand than any single projection.
Background
MISO was founded in 1998 and became the first FERC-approved regional transmission organization in the United States in 2001. It coordinates generation and high-voltage transmission across a footprint stretching from the upper Midwest down through the Gulf South, serving tens of millions of people through its member utilities. Like other RTOs, it does not own power plants or lines; it operates markets and plans the system that its members build.
The forecast arrives amid a broader U.S. re-acceleration of electricity demand after more than a decade of stagnation, driven by AI and cloud data center construction, manufacturing reshoring, and electrification. Grid operators across the country have been revising load outlooks upward repeatedly since the early 2020s, and interconnection queues for both large loads and new generation have swelled to historic levels — making forecasts like this one central to the industry debate over how much of the announced boom is real.
