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Data centers add large, concentrated electricity loads. Connecting them can require new generation and upgrades to substations, distribution lines, or regional transmission—and can affect reliability planning and wholesale capacity costs. Whether those costs reach household or business bills depends on local utility tariffs, regional market rules, regulatory decisions, and whether the forecast data-center load actually arrives. There is no established single national figure for how much data centers have raised everyone’s bills.
Why can data centers put pressure on local power supply?
A large data center can draw enough electricity to make it a major new customer for a utility or a regional grid. The size and timing of the load matter: a facility’s demand may ramp up in stages, while the equipment and supply needed to serve it can take years to plan, approve, and build.
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Connection and local network capacity
Serving a new facility may require a dedicated substation, changes to feeders or other distribution equipment, and upgrades to transmission connections. A project’s actual requirements depend on where it connects and what capacity is already available. The relevant tariff and interconnection agreements determine which costs the customer pays directly and which may be included in broader utility or regional cost pools.
Generation and reliability planning
Utilities and regional grid operators plan for enough supply to meet expected demand. Large-load forecasts can affect how much generation or capacity they seek, but the outcome also depends on factors such as generator retirements, new generation coming online, delays in interconnection queues, and forecast accuracy. If supply and network capacity do not keep pace with demand, reliability and resource-adequacy concerns can arise.
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Growth is concentrated, and forecasts are not guarantees
Lawrence Berkeley National Laboratory’s 2026 update projects that data centers could use 11.8% of total U.S. electricity in 2030, with a scenario range of 9.5% to 15.3%. These are projections, not measured 2030 consumption. A separate historical statistic cited in a 2025 Berkeley Lab/Department of Energy technical brief says the Electric Power Research Institute estimated that 12 states accounted for 84% of U.S. data-center growth since 2020. That figure describes concentration in past growth, not a forecast of where future growth will occur.
How can data-center costs reach electricity bills?
The path from a data center’s electricity use to a customer’s bill varies by state, utility, and regional market. Some costs may be assigned directly to the large customer; others may be recovered through utility rates or regional charges. A local connection project and a regional capacity or transmission charge are different mechanisms, even if both are associated with serving new load.
Customer-funded connections and upgrades
Tariffs and service agreements can require a large customer to pay for some connection work or network upgrades. Regulators may also consider minimum payment commitments, financial security, or exit fees. These protections matter if a project is delayed, downsized, or cancelled after a utility has made investments to serve it.
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Capacity-market costs
In regions with capacity markets, grid operators procure resources intended to help ensure enough capacity is available in a future period. Forecast demand can affect that procurement and its price. The effect is not determined by data-center demand alone: supply availability, retirements, queue delays, forecasts, and market rules also matter. How those costs are allocated among customers depends on the applicable market and rate design.
Transmission costs and cost shifting
Regional rules can spread the cost of transmission projects across multiple zones. As a result, a utility or state may receive an allocation even when the load that helped drive a project is elsewhere. Whether a particular allocation is justified—and what it means for customer bills—depends on the project, the governing rules, and regulatory decisions.
Risk if forecast load does not materialize
If infrastructure is built for demand that arrives later than expected or never arrives, it may be underused. Regulators then have to decide how much of that investment customers should bear. Minimum contract terms, customer contributions, collateral, and exit charges are among the tools used to address that risk; their availability and details vary by jurisdiction.
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What does the bill evidence show?
The available figures show why national averages and local outcomes should not be confused. A national price trend does not prove a data-center effect in any particular service territory, while a regional rate increase does not establish a single cause.
| Evidence | Reported figure | What it does—and does not—show |
|---|---|---|
| U.S. retail prices, 2019–2023 | Average retail electricity prices rose 4.8% per year nominally, according to Lawrence Berkeley National Laboratory’s 2024 review; after inflation, averages were mostly flat. | The review says nationwide retail sales were nearly flat and were not a major driver of national cost growth in that period. It also notes substantial data-center and industrial load growth at some utilities, so the national picture does not rule out local effects. |
| U.S. distribution investment, 2019–2023 | Distribution capital expenditure increased 50%, according to Lawrence Berkeley National Laboratory’s 2024 review. | This describes a national investment trend; it does not identify data centers as the cause of the increase. |
| New Jersey residential Basic Generation Service (BGS) | On February 12, 2025, the New Jersey Board of Public Utilities projected bill increases of 17.23% to 20.20%, or $22.67 to $28.02 per month for a residential account using 650 kWh monthly, in affected service territories. New supply rates were to take effect June 1, 2025. | The BPU named data-center-driven demand as one factor affecting PJM capacity costs, alongside supply growth and market-design issues. The projections are specific to the affected New Jersey customers and do not isolate data centers’ share of the increase. |
| Maryland transmission allocation claim | In a May 7, 2026 announcement, Maryland’s Office of People’s Counsel said its FERC complaint estimated $1.6 billion in added transmission costs for Maryland customers over ten years, including $823 million for residential customers. | These are estimates attributed to the consumer advocate’s complaint and expert affidavit. They are contested claims in a regulatory dispute, not a final FERC finding or proof that customers have already paid those amounts. |
What are regulators doing about large-load costs?
Recent state and federal actions address who pays for connections and upgrades, how utilities protect other customers if a project does not proceed, and how large loads affect regional grid planning. These actions are jurisdiction-specific; they do not establish one uniform national tariff.
Pennsylvania’s model tariff guidance
On April 30, 2026, the Pennsylvania Public Utility Commission adopted a final order; model tariff guidance followed on May 30. The record addresses minimum service terms, financial security, construction contributions, demand charges, phased load ramping, exit fees, firm or interruptible service, backup generation, transparent cost structures, and customer-funded upgrades. The details relevant to a particular project depend on the applicable tariff and utility proceeding.
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Maryland’s pending complaint
Maryland’s Office of People’s Counsel announced on May 7, 2026 that it had asked FERC to change how PJM allocates certain transmission costs. Its estimates are allegations in a pending dispute, rather than an adjudicated finding.
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Potential responses include shifting some electricity use to different hours, on-site energy, storage, or flexible service arrangements. These options may change when or how much a data center draws from the grid, but their effectiveness depends on technical feasibility, commercial terms, costs, and regulation. They are not automatic bill savings.
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The U.S. Department of Energy’s 2024 transmission assessment modeled $320 billion in present-value savings through 2050 in an enhanced-transmission scenario. That is a modeled benefit across the power system, not a forecast of savings from data centers or a promise that a particular utility’s customers will pay less.
How to assess a local data-center proposal
To understand the likely consequences for a community, utility customers, or a proposed project, look for the same information in the utility’s filings, tariffs, interconnection materials, and relevant grid-operator records:
- How many megawatts the facility expects to use, and how quickly its demand is scheduled to ramp up.
- What generation and network capacity is available locally, and what new generation, transmission, substation, or distribution upgrades are proposed.
- Which tariff or market mechanism assigns the cost of each upgrade and any capacity or transmission charges.
- Whether the customer has a minimum payment commitment, financial security, or an exit obligation if its planned load does not arrive.
- Whether service is firm or interruptible, and what curtailment or backup-generation arrangements apply.
- Whether a cited bill figure is an actual charge, a forecast, a modeled scenario, or an allegation—and which customers, territory, and effective dates it covers.
Those distinctions help separate the physical need for new supply or equipment from the policy choice about who pays for it.
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