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1Fix the driver behind crashes, sound loss and screen glitches2Repair Windows errors before they cause bigger problems3Scan for outdated or missing drivers - takes under a minuteAssess a proposed data center using its expected and maximum demand, its schedule for reaching full load, and the capacity of the specific utility and regional grid that would serve it. A national estimate can show why the issue matters, but it cannot establish whether a particular site can be connected reliably, when upgrades would be ready, or who would pay for them.
The practical test is to compare credible load and timing scenarios against local supply, transmission and distribution constraints, resource adequacy, and the terms of the proposed utility service. This guide focuses on U.S. planning; processes and market rules differ in other countries.
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Start by separating power from energy
Power describes the rate of electricity use at a moment or over an averaging interval, usually measured in megawatts (MW). Energy describes use over time, usually measured in megawatt-hours (MWh) or terawatt-hours (TWh). A data center can have a high peak MW requirement even if its annual energy use is lower than a simple 24-hour-at-peak calculation would suggest.
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Ask for both. Peak and expected MW help planners evaluate the capacity needed to serve the facility; annual MWh helps describe total consumption. The operating profile connecting those figures matters: a nearly constant load has different implications from one that changes substantially by hour or season.
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What national estimates can—and cannot—tell you
Lawrence Berkeley National Laboratory’s 2024 report estimated that U.S. data centers used 176 TWh in 2023, up from 58 TWh in 2014, and accounted for about 4.4% of total U.S. electricity in 2023. LBNL estimated data-center use could reach 325–580 TWh, or 6.7–12% of U.S. electricity, by 2028. Those 2028 figures are estimates, not measured outcomes, and their range reflects uncertainty in demand and efficiency. The U.S. Department of Energy (DOE) summarized the report in its December 20, 2024 release.
These national figures are context, not a forecast for a particular utility or region. DOE describes data-center load growth as regionalized; location can be shaped by latency and network needs, and facilities often seek continuous, firm power. A national total cannot reveal a site’s available transmission capacity, local congestion, interconnection status, or the supply available at the hours it needs power.
1. Define the proposed load and its timeline
Request a documented load forecast, not just a single headline MW figure. The following is a practical assessment checklist, not an official standardized DOE questionnaire.
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- Annual energy and operating profile: Give estimated MWh per year, operating hours, expected load factor, and any daily or seasonal variation.
- Ramp and phases: Show commissioning dates, each construction or expansion phase, the load expected at each stage, and the schedule for reaching full operation. Include delayed, reduced, or cancelled buildout possibilities.
- Computing and cooling assumptions: Explain the amount and type of computing capacity assumed, how utilization affects the forecast, and how cooling and other facility overhead are included. Identify the efficiency assumptions used.
- Flexibility: Specify which loads could be shifted or curtailed, by how much and for how long, how quickly a response could occur, and the operational limits. Count flexibility only where the operator can credibly commit to it.
- Onsite resources and grid imports: Separately describe backup generation, any generation intended to serve routine load, storage, and the expected electricity imported from the grid. Clarify when each resource can operate and whether its output is firm for the hours being assessed.
Keep the assumptions with the forecast. A demand figure without its ramp schedule, operating conditions, and treatment of onsite resources is not enough to determine what service the project requires.
2. Establish the site-specific grid baseline
Identify the serving utility and the relevant regional transmission organization (RTO) or independent system operator (ISO), where applicable. Ask the utility for the planning information and load forecast it uses for the area, and review regional materials on transmission constraints, planned generation, and resource adequacy. Also establish the status of the project’s interconnection process and any utility distribution or substation review.
DOE’s Office of Electricity describes the need to consider regional demand, clean energy resources, and firm power together. DOE’s Grid Deployment Office resource-adequacy page frames the question as whether supply and forecast generation development can support expected demand growth through 2030. A resource-adequacy assessment is a system-planning input; it does not by itself confirm that a particular site has an approved connection or deliverable capacity.
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Location can be a real constraint, not just a preference. Determine whether latency, fiber access, or other network requirements limit alternative sites or a different phase schedule. If relocation or delaying load is not practicable, say so explicitly in the scenarios rather than assuming that demand can move.
3. Compare scenarios instead of relying on one forecast
Build at least three internally consistent cases. Each should state its load assumptions, commissioning schedule, efficiency level, and availability of any flexible demand. Use the cases to test how both the size and timing of the load affect the system; do not attach invented facility-specific values to a scenario without project data.
| Case | What it represents | Questions to test |
|---|---|---|
| Conservative | Delayed, partial, or slower buildout; include only efficiency improvements and load flexibility supported by credible assumptions. | What upgrades can be deferred if the project ramps slowly? What happens if only some phases proceed? |
| Central | The project’s best-supported expected demand, phase dates, and operating profile. | Can the utility and regional system serve the forecast load on the stated timeline, including necessary upgrades? |
| High demand | Faster or fuller buildout, higher utilization, or less available flexibility than the central case. | Would the system need additional capacity or earlier upgrades, and what risks arise if they are not ready? |
Test each case against relevant peak and adverse operating conditions using applicable utility and regional studies. The cases should make clear which assumptions change between them. A broad national projection is not a substitute for this local comparison.
4. Trace interconnection, upgrades, and reliability
Map what would be required to deliver electricity to the site: generation, transmission, substations, and distribution upgrades. For each anticipated investment, establish where it is needed, the constraint it addresses, the expected in-service date, and what happens if it is delayed. Consider how the new load interacts with existing customers and planned generation.
Distinguish carefully between stages of interconnection. A request is not a completed study; a study is not an approved agreement; and an agreement is not proof that all required capacity and facilities are already available. Ask what work remains before the project can take service at each phase.
Evaluate resource adequacy and congestion as well as the amount of energy procured. A contract for annual energy does not, on its own, establish that electricity and delivery capability will be available at every hour the data center needs them. DOE’s July 9, 2026 announcement described a draft National Transmission Needs Study examining transmission needs as new loads and generation interconnect and the role of transmission in relieving congestion. The announcement said comments were due September 7, 2026; it described a draft study, not a final rule or a site-specific grid assessment. Its discussion of congestion should not be generalized to every local grid.
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5. Examine who pays—and who carries the risk
Review the applicable tariff, special contract, or proposed utility service arrangement alongside the physical plan. DOE’s January 17, 2025 brief, Electricity Rate Designs for Large Loads: Evolving Practices and Opportunities, identifies five useful issues for comparison:
- System-cost allocation: How are the costs of generation and network upgrades assigned between the project and other customers?
- Stranded-asset risk: If the facility uses less power than forecast or never reaches full operation, who bears the cost of investments made for it?
- Supply and operational risk: How does the arrangement address the risk that demand exceeds available supply or that promised capacity is not available when needed?
- Risk sharing for newer technologies: Who bears performance, cost, or delivery risks associated with technologies proposed as part of the supply plan?
- Supply and capacity alignment: How does the contract address matching load to carbon-free supply or using onsite generation to contribute to system capacity?
Use these as review questions, not as a predetermined answer about what a project should pay. DOE’s brief discusses rate-design issues and possible design elements; it does not endorse one tariff or determine the cost allocation for a specific facility. Compare contract terms on both the expected case and the possibility that load arrives late, grows faster than planned, or fails to materialize.
6. Assess mitigation as a portfolio
Mitigation can reduce emissions, ease certain constraints, or help align supply and demand, but no single technology automatically resolves a local capacity or delivery problem. Assess each option for its location, cost, permitting, delivery timing, operating profile, and contribution during the hours that matter.
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- Flexible or shifted demand: Where computing workloads can move, demand response may reduce or shift load during constrained periods. Identify the workload, duration, notice, and operational limits rather than treating flexibility as unlimited.
- Storage: Batteries or other storage can shift energy or support specific operating needs, subject to charging supply, duration, location, and system requirements.
- Onsite generation: Generation at the facility may reduce grid imports when available, but distinguish routine supply from backup equipment and account for when it can operate.
- Clean generation: DOE’s materials identify solar and wind as potential scalable options and discuss next-generation geothermal and nuclear as potential sources of clean firm power. Their suitability depends on project-specific costs, timing, location, and reliability needs.
- Transmission and grid improvements: Network expansion or upgrades may relieve constraints and enable delivery, but require planning, approvals, and construction time.
DOE’s Office of Electricity Electricity Demand Growth Resource Hub gathers federal resources on clean generation, grid infrastructure, efficiency, and demand-side flexibility. DOE also lists technical assistance options for states, regulators, large energy users, and data centers, including the Onsite Energy Program. These resources can help frame an evaluation; they do not replace utility and regional review of a proposed site.
Use one comparison sheet for alternative sites or proposals
If there is more than one site, supply plan, or contract proposal, compare them on the same basis. Record the assumptions and geography behind each entry so that a large annual energy commitment is not mistaken for firm, deliverable service.
| Comparison area | What to record |
|---|---|
| Demand | Peak and expected MW, annual MWh, ramp profile, phase dates, operating hours, and load growth schedule. |
| Grid access | Interconnection status, transmission and distribution capacity, congestion, required upgrades, and expected upgrade schedule. |
| Reliability and supply | Resource-adequacy findings, supply firmness, hourly availability, and the roles of onsite generation and storage. |
| Flexibility and efficiency | Energy-efficiency assumptions and how much load can actually shift or curtail, for how long, and with what limits. |
| Costs and risk | Who pays for grid and generation investments, and who carries underutilization, delivery, or supply risk. |
| Emissions goals | Clean-energy matching goals, including the time period and geographic basis used to claim a match. |
What a defensible conclusion should say
A useful assessment states whether the project’s forecast load and timing can be served under the scenarios examined, what infrastructure and approvals are still needed, when they are expected, and which parties bear the financial and reliability risks. It also identifies assumptions that could change the answer, such as higher utilization, delayed upgrades, or less available flexibility.
Public federal sources provide context on national demand, transmission, resource adequacy, and potential mitigation. They cannot establish the engineering result for a particular project. That conclusion depends on project data and review by the serving utility and the relevant regional planner.
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