The $18 Billion Fight Over Who Pays to Toughen the Grid, and Why It Reaches Your Building
Utilities asked state regulators for a record $18 billion in rate increases in 2025, the most since the mid-1980s, and much of it is to toughen the grid against extreme weather. Regulators have approved about 64 cents of every dollar utilities requested over the past five years. That approval is the quiet machinery that turns a utility's spending plan into a higher power bill, and where those costs land, on energy charges or on the peak-demand fees a building can actually manage, decides how much room an owner has to fight back.
By Keith Reynolds | Publisher & Editor, ChargedUp!
The Number That Sets the Table
State regulators fielded a record $18 billion in utility rate increase requests in 2025, the highest level since the mid-1980s, according to Lawrence Berkeley National Laboratory, a federal research lab. The same analysis found that regulators approved 64 percent of the dollar value of what utilities asked for between 2021 and 2025. That approval rate is what matters, because it is the bridge between a request and a bill. When a utility proposes to spend money hardening its wires and substations, a rate case is the proceeding that decides how much of that spending customers ultimately pay, and the record shows regulators approve most of it.
For an owner, the takeaway is not the specific figure but the direction. Utility spending on the grid is running at a level not seen in four decades, most of it will be approved, and it flows to customers through the electric bill. That is a structural push on the cost of power that has nothing to do with the price of oil or the swings of any given month, and it is landing now.
Why the Cost Is Rising, and Where
Much of the new spending is aimed at protecting the grid from extreme weather, and the cost is not spread evenly across the country. Lawrence Berkeley National Laboratory found that spending on transmission and distribution, the high-voltage lines and the local wires that carry power to a building, much of it tied to wildfire protection, was a significant driver of rate increases in California, where retail rates rose more than 6 cents per kilowatt-hour from 2019 to 2025 after adjusting for inflation, the lab reported. Similar increases hit the Northeast and Mid-Atlantic, the regions with the largest rate jumps over that period.
That regional split has a direct planning consequence. A building's exposure to these rising costs depends heavily on where it sits and how aggressively the local utility is spending to toughen its grid. Two identical buildings in different states can face very different power-cost trajectories over the next five years, based entirely on their utility's capital plans and the rate cases moving through their state right now. Where a property is located has always mattered. Now the utility's spending plan is part of what location means.
A Real Case Shows How Slowly It Moves
A live example shows the machinery in motion. In 2025 the New York Public Service Commission approved a three-year rate plan for National Grid covering 2.4 million homes and businesses in upstate New York, following a review that included more than 1,600 formal information requests and multiple public hearings, according to National Grid. The plan includes about $1.4 billion in electricity delivery investment and $351 million in gas system investment in the first year alone, and it explicitly frames tougher, more reliable systems as tools to manage the impact of frequent severe weather.
The timing is the lesson for anyone planning a project. That rate filing was submitted in 2024, negotiated through 2025, and will be built out over several years after that. An owner deciding this year whether to add electric equipment, expand a building's power needs, or break ground on new construction is working on a far shorter clock than the utility's. The gap between when the utility's grid investment is approved and when it is actually built and switched on is exactly where connection delays and project-timing risk pile up. A building may need more power well before the utility's own upgrade schedule delivers it.
The Part an Owner Can Actually Control
How these costs are collected matters as much as how large they are, and this is where an owner has leverage. A rate case splits into two questions: how much total money the utility gets, and how that money is divided across the bill. Part of a commercial bill is the energy charge, based on how much power is used. Another part is the demand charge, a fee based on the single highest burst of power a building draws, measured over a window as short as 15 minutes, as utility regulators describe it. That difference is the whole game for a building's budget.
When grid-hardening costs flow into demand charges, the value of onsite tools rises sharply, because a battery, load shifting, or backup generation directly cuts the peak burst that the demand charge captures. A building that can shave its peak can shave that part of its bill. When the costs instead flow into fixed monthly charges that every customer pays no matter what, an owner's ability to manage the bill through efficiency or timing shrinks. Which path a given rate case takes depends on the tariff the regulators approve, and it varies by utility and state, so the only reliable way to know is to read the actual approved tariff rather than assume. But the principle holds: the more of the cost that sits in demand charges, the more a distributed-energy investment is worth.
The Decision the Rate Case Is Forcing
Put the pieces together and a rate case is no longer a regulatory footnote. It is the proceeding where the future cost of a building's power, the availability of that power, and the timing of the grid it depends on are all decided at once. Grid-hardening spending has moved from an occasional storm-recovery expense into a permanent line inside the utility bill, and it is large enough to matter to an operating budget for years.
The practical test for an owner is twofold. First, does the local rate design reward the load flexibility a building can actually deliver, meaning is there real money in cutting the peak? Second, does the utility's approved construction timeline line up with when the building will actually need more power? If the answer to the second is no, that gap is the owner's problem to solve, and onsite generation and storage are the fastest way to solve it. Reading the resilience section of a pending rate case has become a direct input into how a building's costs and power access will look for years. It is worth the read.
