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There is no defensible national ranking that makes data centres, factories, farms, mines or other large electricity users universally “better” or “worse.” A sound local decision compares the same evidence for every proposal: peak demand, annual electricity, timing and flexibility, grid-connection costs and risks, water and site impacts, emissions, and enforceable public benefits. The available evidence is primarily U.S.-specific, so national figures and state examples must not be treated as a forecast for your utility or a particular site.
Use the framework below to put a proposed data centre (also spelled “data center” in U.S. sources) on the same footing as any other large load. Keep the geography, dates, utilization assumptions and accounting boundary consistent, and label projections separately from measured results.
Why an apples-to-apples comparison is difficult
Large electricity users do not present demand in the same way. A factory may report a relatively stable operating load, a farm may have seasonal peaks, a mine may have a large motor load, and a data centre may run continuously but expand in stages. One proposal may quote nameplate capacity while another reports metered consumption. Comparing those figures directly can make a smaller user look larger or hide the amount of grid capacity that must be built.
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- Geography: the site, utility territory, balancing area, state or national system being evaluated.
- Time horizon: construction, first operation, full build-out and a realistic contract or asset life.
- Accounting boundary: the customer meter, the whole campus, backup generation, water facilities and associated transmission or distribution work.
- Status: measured operating data, an approved interconnection request, a developer projection, or a scenario that has not yet been committed.
Without those definitions, a national forecast can be mistaken for a local load, or a promised job count can be mistaken for a verified outcome.
1. Compare electricity scale with matching metrics
Peak demand shows the grid capacity requirement
Ask for expected maximum demand in megawatts (MW), not only the facility’s transformer or generator nameplate. Peak demand determines how much generation, transmission and distribution capacity may be needed at the same time. Request the forecast for each phase, the date by which it is expected, and the assumptions behind it.
Annual energy shows total consumption
Request annual megawatt-hours (MWh) or terawatt-hours (TWh). Annual energy answers a different question from peak demand: it indicates how much electricity is consumed over time. A facility with a high peak but low utilization can require substantial capacity while using less annual energy than a steadier facility. Do not substitute annual energy for peak demand, or vice versa.
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Use utilization and load-factor assumptions transparently
For a projection, show low, base and high cases where available. State the expected operating schedule, ramp-up period, expansion probability and utilization assumption. If one proposal supplies actual meter data and another supplies a full-build-out estimate, label the difference rather than presenting the figures as comparable measurements.
National context, with dates attached
| Figure | What it measures | Qualification |
|---|---|---|
| 176 TWh in 2023; about 4.4% of U.S. electricity | Estimated U.S. data-centre electricity use | DOE summary published December 20, 2024, based on the 2024 Lawrence Berkeley National Laboratory report; a national estimate, not a local utility measurement. DOE announcement |
| 325–580 TWh in 2028; 6.7–12% of U.S. electricity | Modeled national data-centre demand range | Scenario range in the same 2024 DOE summary. It is not a guaranteed outcome for any project or utility. DOE announcement |
| 9.5–15.3% of U.S. electricity by 2030 | Later modeled national scenario range | Reported in a later LBNL report record in 2026. Do not splice this 2030 range into the 2024 forecast as if it were one continuous forecast series. LBNL report record |
| 54 billion kWh in 2025 | Baseline forecast for Texas “large flexible load” customers | EIA defined the category as facilities with expected peak demand capacity of at least 75 MW. The forecast included uncertainty about queued projects and was not data-centre-only consumption. EIA Texas analysis |
The national figures establish scale, not a ranking against factories, farms or mines. The Texas figure is a state-specific forecast under stated baseline assumptions, not current measured use.
2. Examine timing and flexibility, not just size
Describe the operating shape
Obtain hourly or seasonal demand profiles when possible. Ask whether the load is steady, weather-sensitive, production-driven, or concentrated in a few high-price hours. A steady load may use energy predictably but leave fewer opportunities to relieve an emergency; a peaky load may create sharper local constraints.
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Test curtailment claims
Ask whether the customer can reduce consumption during emergencies, high-price periods or low generator availability. The answer should identify:
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- the maximum reduction in MW and the time needed to achieve it;
- how long the reduction can last and how often it may be called;
- whether participation is voluntary or contractually required;
- the payment, penalty or reliability terms; and
- which equipment or operations remain online.
EIA reported that some large-load facilities in Texas—mainly cryptocurrency miners, but also data centres and some industrial factories—had voluntary agreements to reduce consumption during stressed conditions. That practice is specific to arrangements reported in ERCOT and should not be assumed to exist in another utility territory. Read the EIA analysis.
Separate flexibility from backup generation
A proposal that owns generators or batteries is not automatically flexible for the grid. Ask whether those assets can operate legally and reliably, what fuel and emissions limits apply, who dispatches them, and whether the interconnection study counts them as firm capacity. A written operating procedure is more informative than a general promise to “support the grid.”
3. Make grid connection and cost allocation explicit
List the required electrical work
Request the interconnection study, its assumptions and a schedule of upgrades. The list may include substations, transformers, transmission lines, distribution feeders, protection equipment, voltage support and new generation or storage. Identify which work is required for the initial phase and which is triggered only by later expansion.
Show who pays
For every upgrade, identify the customer, utility, transmission provider, taxpayers or other ratepayers responsible for the cost. Ask whether the customer pays an upfront contribution, a recurring tariff, a minimum bill, a reservation charge, or a security for unfinished construction. Include costs for network upgrades that benefit multiple users, not only the line that reaches the site.
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Address stranded-investment risk
DOE’s January 2025 discussion of large-load rate design highlights fair allocation, the risk of underused utility investments, resource adequacy when demand exceeds supply, and options such as carbon-free matching or onsite generation. These are questions for the utility and regulator, not evidence that a particular project has already raised everyone’s bill. Read DOE’s rate-design brief.
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Ask what happens if the load arrives late, is smaller than forecast, closes, or never materializes. Useful protections can include phased construction, milestone payments, minimum demand commitments, financial security, exit charges and a plan for recovering costs if the customer defaults. Confirm which protections are enforceable rather than relying on a presentation or nonbinding memorandum.
Understand the current federal rulemaking context
In June 2026, the Federal Energy Regulatory Commission (FERC) directed six regional grid operators under its jurisdiction to justify or reform rules for data centres, manufacturing facilities and other large energy users. The listed topics include faster and more transparent transmission-service studies, transparent transmission costs and avoidance of cost shifting, co-location and behind-the-meter generation, transmission service for flexible large loads, and studies of generation serving electrically proximate or co-located loads. This is an active federal proceeding, not a single final national tariff. Check the current regional rules before stating what a project must pay. Read the FERC release.
FERC Chairman Laura V. Swett described the agency’s stated goal this way: “We are setting the stage for a resilient, reliable, and forward-thinking grid that empowers communities and safeguards consumers by transforming the way large energy users access the grid.” The quotation expresses an agency objective; it does not establish the outcome for a local project. FERC release, June 18, 2026.
4. Compare water, land and operating impacts at the site
Use a site-specific water balance
Request annual and peak direct water withdrawals and consumption, the source (municipal, surface, groundwater or reclaimed), seasonal limits, discharge requirements and drought contingencies. Describe the cooling system, including evaporative, air-cooled or hybrid equipment, and account for water used by power generation or a shared utility service when it falls inside the agreed boundary.
A national estimate of data-centre water use cannot answer whether a particular community has enough water. Compare the proposal with the local basin or utility’s available supply, competing demands, permit conditions and projected dry-year availability. Require the same water accounting method for a factory, mine, farm or other alternative project.
Evaluate land and construction disruption
Map the permanent site, substations, transmission corridors, roads, water lines and generator compounds. Quantify clearing, impervious surface, storm-water controls, traffic, construction duration, noise, lighting and vibration. A large campus can have impacts beyond the building footprint, while a mine, factory or farm may have a different but equally material land-use pattern.
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Account for backup generation and local air impacts
List each generator’s fuel, rated output, testing schedule, permitted operating hours, emissions controls and emergency-use limits. Include diesel storage, fuel deliveries and noise. “Backup” does not mean zero impact: the permit and actual dispatch conditions determine local emissions and disturbance.
EPRI’s community framework presents both possible local economic support and increased electricity, water, construction and operating disruption. Treat those as issues to investigate with local measurements and enforceable conditions, not guaranteed benefits or harms. See EPRI’s community framework.
5. Separate direct emissions from electricity-related emissions
Measure onsite emissions
Request permitted annual and short-term emissions from boilers, generators, vehicles and other equipment. Identify whether the figures are potential-to-emit limits, expected operation or verified monitoring results. Compare the same pollutants and reporting periods for every candidate project.
Describe purchased-electricity emissions accurately
Electricity-related emissions depend on the actual grid serving the load and, where relevant, the hour and season of consumption. A renewable-energy certificate or annual renewable purchase does not by itself describe the physical generation mix at every hour. Ask for the contractual product, matching interval, delivery region, eligibility rules and treatment of backup power.
Also ask whether the project proposes onsite generation, a dedicated supply, storage or carbon-free matching. These arrangements affect both emissions accounting and the amount of grid capacity that remains necessary.
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Distinguish current-law revenue from incentives
Prepare a before-and-after fiscal statement using taxes actually due under current law. Then show each exemption, credit, sales-and-use-tax preference, infrastructure grant and fee waiver separately, with its duration, eligibility conditions and clawback provisions. A projected tax base is not the same as collected revenue.
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Count job quality, duration and verification
Separate temporary construction jobs from permanent operating positions. Report headcount, wage level, benefits, occupational mix, local hiring requirements, apprenticeship commitments and the date by which jobs must exist. Identify who verifies the numbers and what happens if targets are missed.
Use Washington’s JLARC review as a caution about scope
Washington’s 2026 Joint Legislative Audit and Review Committee review concerned a sales-and-use-tax preference in three urban counties, not data centres nationwide. It estimated beneficiary savings of $42.4 million over 2023–26. Beneficiaries reported 53 family-wage jobs and nearly 300 temporary construction jobs. JLARC said no new urban data centres had been built under that pilot at the time of review and described future job creation as uncertain. These figures are not a jobs-per-facility average. Read the JLARC review.
JLARC also found a measurement problem: the reviewed data centres were not required to report electricity use in a form that allowed actual utility use and taxes paid to be compared over time. The review estimated electricity use at about 427,000 MWh, or 1.4% of sales by the two serving utilities in 2024. That is a scoped estimate, not a general data-centre load factor. Ask your local agencies what is measured, what is confidential, who verifies it and whether reporting continues after an incentive or permit is granted. JLARC data and limitations.
How to run a fair local comparison
- Define the alternatives. List the proposed data centre and realistic alternative large users—such as a factory, mine, farm operation, warehouse or industrial plant—at the same site or within the same planning area.
- Set one accounting sheet. Create fields for peak MW, annual MWh, utilization, hourly profile, water withdrawal and consumption, land area, direct emissions, purchased-electricity assumptions, grid upgrades, customer contribution, incentives, taxes, construction jobs and permanent jobs.
- Request source documents. Obtain interconnection studies, load forecasts, water assessments, air permits, site plans, tax agreements, labor commitments, curtailment contracts and emergency operating procedures.
- Label evidence by status. Mark each entry as metered, independently verified, regulator-approved, contractually enforceable, developer-projected or scenario-based.
- Run low, base and high cases. Vary build-out date, utilization, water availability, electricity price, curtailment and project completion. Show who bears the cost in each case.
- Check public commitments before approval. Put reporting frequency, audit rights, deadlines, penalties, clawbacks and dispute procedures in the permit, tariff or development agreement.
- Publish a plain-language comparison. Explain material uncertainties and disclose unavailable or confidential data instead of filling gaps with national averages.
A practical evidence worksheet
| Question | Evidence to request | Decision test |
|---|---|---|
| How large is the load? | Phased peak MW, annual MWh, utilization and forecast dates | Are the figures measured or projected, and are all alternatives using the same boundary? |
| When does it operate? | Hourly/seasonal profile and curtailment terms | Can the customer reduce demand under defined emergency conditions? |
| What grid work is needed? | Interconnection study, upgrade list, schedule and cost allocation | Who pays if the project is delayed, downsized or cancelled? |
| What local resources are affected? | Water balance, drought plan, land map, traffic, noise and generator permits | Are impacts within enforceable local limits under realistic conditions? |
| What are the emissions? | Onsite permits, expected dispatch and electricity-supply accounting | Are direct and purchased-electricity emissions shown separately? |
| What does the community receive? | Tax analysis, incentive schedule, wages, jobs and reporting clauses | Which benefits are current-law, enforceable and independently verified? |
Common comparison errors and how to correct them
- Comparing nameplate with consumption: use peak demand and annual energy for every facility.
- Mixing years: attach the date to every forecast and measured value; do not combine the 2024 DOE scenarios with the later 2030 LBNL range as one trend.
- Treating a queue as a commitment: identify whether a project has a signed agreement, an approved permit, an interconnection position or only an announced plan.
- Assuming flexibility: require a dispatchable, enforceable curtailment arrangement and its operating limits.
- Using a national water number locally: commission a site and basin assessment with the same method used for alternatives.
- Counting promises as public value: separate projected jobs and taxes from collected revenue, verified employment and enforceable commitments.
- Ignoring missing data: state what the utility, agency or developer does not report and explain how that uncertainty affects the decision.
- Assuming a federal proceeding is a final rule: FERC’s 2026 action describes reforms under development; regional outcomes still need to be checked.
What the evidence can—and cannot—support
The available sources support a disciplined comparison method, not a universal verdict. National data-centre demand estimates show why utilities are examining large loads, while the Texas example illustrates how flexible-load agreements may work in one market. DOE and FERC materials identify rate-design, reliability and cost-allocation questions. The Washington JLARC review demonstrates why incentive claims and electricity-use reporting must be tested locally. None supplies a normalized statistic ranking data centres against factories, farms, mines and other large users on electricity, water, jobs or net public cost.
A community can still make a rigorous decision: require matched metrics, verify the local resource and grid studies, allocate costs before construction, and make public benefits measurable and enforceable. The result should be a documented choice among specific projects and conditions—not a claim that one category of electricity user is inherently preferable everywhere.
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