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How much electricity do data centers use?
Lawrence Berkeley National Laboratory (LBNL) estimated that U.S. data centers used 4.4% of the nation’s electricity in 2023. Its 2024 report projected a 6.7%–12% share by 2028. A later LBNL update estimated an 11.8% share by 2030, with a scenario range of 9.5%–15.3%.
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| Estimate | What it covers | How to read it |
|---|---|---|
| 4.4% | Estimated U.S. electricity use by data centers in 2023; LBNL, 2024 | Historical estimate. LBNL’s 2024 U.S. Data Center Energy Usage Report |
| 6.7%–12% | Projected U.S. electricity share in 2028; LBNL, 2024 | Projection from the 2024 report, not a local utility forecast. LBNL’s 2024 report |
| 11.8%, with a 9.5%–15.3% scenario range | Estimated U.S. electricity share in 2030; LBNL, 2025 | Later estimate with a different time horizon and report vintage; it should not be combined with the 2024 report’s 2028 range as if both came from one model. LBNL’s data-center energy work |
These figures describe U.S.-wide estimates, not the demand forecast for a particular town, utility, or power market. Local effects depend on where new facilities connect and on how much of their proposed demand materializes.
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A large new load can change what utilities and grid operators need to plan for. If existing supply or network capacity is insufficient at the relevant time and place, meeting the demand may involve new generation, transmission lines, substations, or local distribution upgrades. The connection itself can require studies and construction, and a project in a constrained area may face different limits or timelines from one elsewhere.
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- Generation and reliability planning: Planners must consider whether enough electricity will be available when demand is high, not just how much energy is used over a year. If forecast load grows faster than supply, resource-adequacy concerns become more important.
- Transmission and distribution: Power must be delivered to the facility. Upgrades may be needed on high-voltage transmission networks, local utility equipment, or both.
- Interconnection queues and timing: Studies, approvals, and construction can affect when a facility can connect. Forecasts of announced projects are not equivalent to completed construction or operating load.
- Local concentration: Several large projects seeking service in the same area can create a different planning challenge from the same amount of load spread across a wider grid.
These are possible pathways, not proof that every data center makes service less reliable for nearby customers. Reliability depends on the actual load, available supply and network capacity, project timing, and the measures utilities and grid operators put in place.
Will a data center make household electricity bills go up?
There is no national bill-increase figure that can responsibly predict what a household will pay. The bill effect depends on local rates and market rules, which investments are made, and how regulators or utilities allocate their costs. A large customer may pay for dedicated facilities or contribute to shared system costs, while other costs may be recovered through rates paid by a broader group of customers. The details vary by jurisdiction and tariff.
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Two rate-design risks are underused investment and cost shifting. If a utility builds capacity for a forecast project that is delayed, scaled back, or never completed, some equipment or contracts may be underused. If large customers do not pay the costs assigned to their service, other ratepayers could bear a share. Conversely, a large customer’s payments may contribute to system costs; the effect cannot be inferred from the project’s size alone. LBNL’s review of large-load rate designs discusses these issues, along with resource adequacy, technology risk sharing, and options such as carbon-free matching and onsite generation. Read LBNL’s analysis of electricity rate designs for large loads.
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Who should pay for grid upgrades?
There is no single tariff that fits every utility or power market. Regulators and utilities have to weigh the costs of dedicated equipment against shared network investments, while accounting for the uncertainty of future demand. The Pacific Northwest National Laboratory (PNNL) describes state and federal policy activity around rates, interconnection, permitting, and reporting, and notes both the potential for local economic benefits and concern about costs shifting to other ratepayers. Read PNNL’s review of policy and cost allocation for large-load interconnections.
When evaluating a proposed large-load tariff or utility plan, these questions help reveal how risk and cost are treated:
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- Which upgrades are dedicated to the project, and which serve the wider system? Who pays for each?
- Must the customer provide deposits, accept a minimum bill, or make another financial commitment if the project uses less power than forecast or does not proceed?
- How credible are the projected load and construction schedule, and what happens if either changes?
- Can the facility curtail or shift demand during tight system hours, and are those commitments enforceable?
- What evidence shows that generation and other resources will be adequate to maintain reliability?
- What information about costs, usage, and contract terms will be public?
Can data centers help the grid manage their demand?
Some responses can reduce or reshape the burden of new demand, but none is an automatic fix. Their value depends on what a specific facility can do and whether it helps at the time and location the grid needs it.
- Flexible operations: Optimized controls, workload management, and storage may let some facilities shift electricity use or reduce demand during constrained periods. Whether workloads can move depends on the task and the operator’s commitments.
- Onsite generation and storage: These resources can provide electricity or reduce grid draw in some circumstances. Their contribution depends on the equipment, operating arrangements, and how reliably it is available when needed.
- Efficiency and rate structures: More efficient equipment and rates that reward useful load flexibility can help manage demand, provided the savings or response occur when the system is constrained.
- Use of existing infrastructure and new generation: Redeveloping existing energy sites and developing emerging generation technologies are among the approaches identified by the U.S. Department of Energy, alongside efficiency, storage, and flexibility. See the DOE Electricity Demand Growth Resource Hub.
A corporate clean-energy purchase, by itself, does not show that local grid capacity is unaffected or that household bills will not change. The relevant question is what electricity is available to the local system, when it is available, and how the project’s costs and operating commitments are handled.
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- 24/7 ENERGY MANAGEMENT AND MONITORING: Automate, manage and control your home's real power anywhere, anytime to prevent costly repairs, conserve energy, and save costs. Monitor solar / net metering. PROTECTED BY A 1-YEAR WARRANTY.
- LOWER YOUR ELECTRIC BILL: Configure settings in the Emporia Energy App to automate energy management for time of use, peak demand, excess solar, and rewards programs. You can even see live reporting and invaluable savings opportunities instantly. Gauge real-time spending and get actionable notifications and automated energy management to help you reduce costs.
- REAL-TIME ENERGY DATA: REQUIRES 2.4 GHz WIFI WITH AN INTERNET CONNECTION to monitor energy use with iPhone / Android / Web app. Vue sensors collect energy data and are accurate from ±2%. The Vue is UL and CE Listed for your safety. 1 second data is only available in the app (when actively open) and retained 3 hours. Minute and hour data are retained in the cloud. 1 minute data is retained 7 days, 1 hour data is retained indefinitely. Export cloud data whenever you want in the app.
What is FERC doing about large electricity loads?
On June 18, 2026, the Federal Energy Regulatory Commission (FERC) announced tailored show-cause orders to PJM, MISO, SPP, CAISO, ISO-NE, and NYISO. It asked each regional grid operator to justify its existing rules or propose tariff changes for large energy users. The requested areas include more efficient transmission applications and studies; transparency into transmission costs and protections against cost shifting; rules for co-location and behind-the-meter generation; services for flexible loads; and processes for studying generation serving nearby or co-located large loads. FERC also requested information on ensuring adequate generation. Read FERC’s June 18, 2026 announcement.
This is a set of region-specific proceedings, not a single national household electricity rate or a finding that every data center has the same effect. FERC’s announcement says a one-size-fits-all approach is not necessarily efficient. The orders seek to address how large loads connect and how associated costs and reliability needs are handled; they do not by themselves settle the bill impact for a particular customer.
How to check the likely impact in your area
A national forecast cannot answer a local bill question. To assess a specific proposal, look for documents about the utility, state, and regional market that serves the site:
- Identify the serving utility and regulator. Your bill names the utility; the state public utility commission’s filings and decisions can show how rates and proposed investments are treated.
- Check the utility’s plans and rate filings. Look for projected large-load demand, proposed generation or network upgrades, cost-recovery requests, and any commitments the customer must make.
- Look for the project’s status and timeline. Distinguish an announcement or forecast from an approved interconnection, construction, and operating facility.
- Review regional grid information. The relevant grid operator’s planning and market materials can help explain capacity constraints, reliability planning, and how large-load connections are studied.
- Trace cost allocation rather than relying on the headline load number. Ask whether dedicated upgrades are charged to the project, how shared costs are divided, and what happens if the expected demand does not arrive.
The most useful local conclusion comes from those rate filings, grid plans, regulatory decisions, and verified project timelines together. Without them, a claim that a particular data center will raise—or will not raise—your bill goes beyond what national estimates establish.
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