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To determine whether a new data center can get the power it needs, build a verified, time-based load forecast and have the serving utility and relevant transmission provider study the proposed connection. A national demand projection, nearby power plant, or preliminary capacity estimate cannot establish that a particular site can receive dependable service. The decision also depends on when power is needed, what upgrades are required, how the facility behaves during disturbances, and what service and curtailment terms apply.
How much power will a new data center need?
Start with a load profile, not a single peak-demand figure. A facility’s requested maximum, its typical operating demand, and the pace at which it reaches full operation are different inputs. Utilities and grid operators need project-specific information to assess whether the system can serve the site and what changes or operating conditions may be necessary.
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Separate IT demand from facility demand
Where possible, report the expected IT load separately from supporting electrical loads such as cooling and other facility systems. State the expected maximum demand and describe the expected operating profile, utilization assumptions, power factor, cooling approach, redundancy design, and planned use of backup generation or energy storage. Explain how those systems will operate during normal service, transitions, and outages.
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Provide time-series demand data at the resolution requested by the utility, along with expected major ramp events and phased energization dates. A facility may initially draw less than its eventual operating load, so the forecast should show the path from first service to full operation rather than treating them as one date or one number. NERC’s May 2026 Reliability Guideline: Risk Mitigation for Emerging Large Loads calls for detailed, verified site characteristics and accurate dynamic-model data, including as-planned information and updates as the project is built.
Prepare low, reference, and high cases, and state what assumptions distinguish them—for example, deployment pace or utilization. Ask the utility and grid operator for their required data formats and models; the project team’s forecast is an input to their analysis, not a substitute for it.
What do national data center demand forecasts tell you?
National estimates help explain why utilities and planners are paying attention to large loads. They do not show whether a particular substation, feeder, or transmission corridor can serve a particular project. The figures below come from different studies, methods, assumptions, and forecast horizons; they should not be combined into a single trend line.
| Source and date | Estimate or scenario | How to interpret it |
|---|---|---|
| Lawrence Berkeley National Laboratory, as reported by the U.S. Department of Energy in December 2024 | 176 TWh, about 4.4% of U.S. electricity in 2023; estimated 325–580 TWh, approximately 6.7–12%, by 2028. | A national estimate and range, not a project forecast or a local capacity finding. |
| Electric Power Research Institute, 2026 scenario study | Data centers could use 9–17% of U.S. electricity by 2030, compared with 4–5% “today” in the study’s framing. | EPRI describes the 2030 range as 60% higher than its prior scenarios, reflecting accelerated development. It is a scenario range, not a firm prediction for any site. |
| U.S. Energy Information Administration, 2026 analysis | U.S. net electricity demand grew about 1.7% annually during 2020–2025, compared with 0.1% annually during 2005–2019. | This is economy-wide demand context, not a data-center-only estimate or a local grid assessment. |
The Department of Energy notes that data center demand is growing rapidly, varies by region, and can be concentrated because of where facilities need to locate. Future demand also depends on changing AI use and efficiency assumptions. Project announcements and national scenarios therefore cannot be treated as evidence that a specific project will proceed on a particular schedule or receive the requested service.
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How do you check whether the grid can support the site?
Capacity is local and conditional. The study must examine the proposed connection and the relevant system conditions, reliability impacts, and necessary upgrades. The exact study names, sequence, responsibilities, and service rules vary by utility and region.
1. Identify the service path and decision-makers
- Contact the serving utility early. Provide the proposed site, load profile, phasing, and target service dates, and ask what process applies to a new large load.
- Establish the proposed point of connection and voltage level. Identify the distribution and transmission owners, the relevant balancing authority, and whether a regional transmission organization or independent system operator (RTO/ISO) process applies.
- Ask who owns each study and what the process requires. Request the application data, study sequence, milestones or deposits, and current rules for the proposed service arrangement. Do not assume that one entity handles every part of the assessment.
The Federal Energy Regulatory Commission (FERC) reported regional differences in rules and responsibilities. In actions announced June 18, 2026, it directed six regional operators under its jurisdiction to justify or reform large-load tariff rules. Processes are evolving, so confirm the rules in effect for the project and region instead of relying on a timeline or procedure from another market.
2. Request a location-specific system assessment
Ask the utility and relevant transmission provider to determine what load can be served, when, and under what conditions. The analysis should address existing and forecast system conditions, contingencies, voltage and stability impacts, protection coordination, operating ramps, and any required upgrades or operating limits. NERC recommends comprehensive transmission planning for large loads using as-planned steady-state and dynamic models.
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Ask which assumptions the study uses, what its results establish, and what remains contingent on later studies, construction, approvals, or service agreements. A preliminary indication of capacity is not the same as a completed study or a commitment to deliver full requested load on a specific date.
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For each proposed connection, obtain the identified transmission and distribution work, the dependencies and schedule assumptions behind initial and full service, and an explanation of how costs are allocated. Clarify who bears the cost or schedule risk if the project is delayed, changes its load forecast, or is cancelled. A nearby generation project does not by itself prove that power can be delivered to the data center: transmission, distribution, reliability, and applicable tariff questions still require review.
There is no universal interconnection timeline, upgrade cost, or MW threshold that can be applied to every U.S. project. Results depend on the utility, region, point of connection, study findings, service terms, and rules in effect when the project applies.
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What reliability and operating behavior should the study cover?
Grid impact depends on how the facility operates, not only on its MW request. Coordinate facility controls, uninterruptible power supplies (UPS), backup generation, and transfer behavior with utility protection and operating requirements.
- Ramping and load changes: Identify large or rapid changes in demand and ask whether ramping limits or other operating conditions are needed.
- Disturbance response: Address ride-through behavior and the facility’s voltage and frequency response, as applicable to the connection and equipment.
- Protection and power quality: Coordinate protection settings and evaluate power quality, stability, and potential oscillation concerns.
- Backup and transfer behavior: Explain how the facility transfers to backup generation or storage, and how it returns to utility supply. NERC’s March 2026 gap assessment identifies coordination risks when utility and facility protection settings are not aligned and notes that backup transfer and return choices affect grid-facing behavior.
- Monitoring and communications: Establish telemetry, high-resolution monitoring, and communication requirements, including any applicable load-shedding participation.
Have the utility and project engineers agree on the relevant control, protection, and operating assumptions. A design that can keep the data center running through a disturbance may still need to be assessed for how its transition affects the grid.
How should you compare candidate sites and service options?
Use the same load cases, service assumptions, and target dates for every candidate site. Compare the delivered service and the conditions behind it, rather than ranking sites only by an estimated MW figure.
| Comparison item | What to establish |
|---|---|
| Dependable capacity | How much load the study finds can be served, at what point of connection, and under which system and operating conditions. |
| Service schedule | Expected dates for initial and full service, dependencies, construction assumptions, and the staged ramp-up the plan supports. |
| Upgrades and cost allocation | Required transmission and distribution work, who pays, how costs may change, and who bears delay or cancellation risk. |
| Firm or flexible service | Whether service is firm, interruptible, or otherwise flexible; any curtailment amount, duration, notice, and frequency; and the project’s obligations during curtailment. |
| Operating requirements | Reliability, power quality, protection, telemetry, ramping, and other requirements that affect facility design or operations. |
FERC’s June 2026 materials describe regional differences in services, cost transparency, study processes, and upgrades. Do not assume that a service model, cost arrangement, or curtailment practice available in one region applies in another. Have the utility and project advisers explain how each site’s stated capacity and energization date depend on its particular studies and commitments.
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