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Scan for outdated or missing drivers - takes under a minuteDriver Scan →Clear out junk files and repair common Windows errorsFree Scan →Fix the driver behind crashes, sound loss and screen glitchesFind Drivers →Ask the serving utility for a current, site-specific capacity study at the proposed point of delivery—not a general statement that the area has power. Request the study assumptions, firm capacity before and after upgrades, the circuit and substation limits, transmission constraints, applicable tariff, outage records for the facilities that would serve the site, and a written schedule and cost allocation for every required upgrade. Also identify which utility, transmission provider and regional grid operator is responsible for each answer.
No national source can tell you whether an unspecified parcel has enough capacity or a particular outage risk. Those answers depend on the serving utility, the exact circuit and substation, the upstream transmission path, the project’s demand shape, the current interconnection queue, local planning criteria and dated utility records.
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Start by defining what “enough power” means
“Is there enough power for a data center here?” is incomplete until the location and service level are defined. Capacity can mean the physical capability of nearby equipment, capacity reserved for your project, or service available under a particular tariff. A utility may have generation or transmission capacity in a broad area while the feeder, transformer, substation or delivery path serving your parcel still requires work.
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Put the proposed point of delivery (or point of interconnection), requested megawatts, expected maximum demand, load factor, commissioning phases and ultimate build-out in writing. Ask the utility to state the boundary of each study: customer facilities, distribution, substation, transmission and any supply analysis. A dated study with explicit assumptions is evidence; an area-wide planning figure is not a service guarantee.
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Use the utility’s own terminology
Ask whether the request is treated as distribution service, transmission-level service, a large-load request or another category. The Federal Energy Regulatory Commission (FERC) large-load docket generally describes loads greater than 20 megawatts (MW), but that is a description used in that proceeding, not a universal threshold for every utility’s rules. The controlling process is the serving utility’s tariff, service agreement and jurisdiction.
Identify every organization that controls part of the answer
Before discussing capacity or reliability, establish who serves the parcel and who controls upstream facilities. Put each responsibility in the meeting notes.
- Which electric distribution utility serves the parcel?
- Which transmission owner or provider carries power to the serving substation?
- Is a regional transmission organization or independent system operator involved?
- What is the proposed point of delivery or interconnection, and can it change after a study?
- Which utility, grid operator, regulator or other party must approve the service arrangement?
- Which tariff, large-load procedure, transmission service agreement or special contract governs the request?
Ask for the name and version or effective date of every controlling document. FERC’s large-load proceedings address how large loads can interconnect in a timely, orderly, reliable and non-discriminatory manner, but they do not determine capacity at your site. On June 18, 2026, FERC announced show-cause orders to the six RTOs and ISOs under its jurisdiction about tariff rules for large-load interconnection and consumer safeguards. Those proceedings can evolve, and the applicable tariff still depends on the service territory.
Request a documented capacity study
Ask for the utility’s current study at the exact point of delivery, or for a written explanation of why it cannot provide one. Request a summary if the full study is confidential. The summary should identify assumptions, modeled facilities, contingencies, constraints, required upgrades and unresolved issues.
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Questions about the study basis
- What firm MW can be served at this point today, before customer or network upgrades?
- What demand level, power factor, load factor and operating profile were modeled?
- Does the analysis include each construction phase, the ultimate build-out and the date each block is expected to energize?
- How are the data center’s ramp-up, rapid changes and maximum coincident demand represented?
- Which circuit, transformer, substation, transmission path or supply resource limits service?
- What normal and contingency conditions were tested, and which planning criteria were applied?
- Which constraints are confirmed, which are assumptions, and which require a follow-up study?
- Does “available capacity” mean physical capability, capacity reserved for this project or service offered under a specific tariff?
FERC Form No. 715 instructions describe transmission-planning criteria used to assess transmission availability, identify constraints and anticipate technical-study outcomes. Examples include contingency performance, facility overloads and voltage limits. Ask the utility to identify the criteria it used and to provide the study date; criteria and network conditions can change.
Separate pre-upgrade and post-upgrade service
Have the utility show two distinct cases: what can be served without upgrades and what can be served after each proposed upgrade. For every phase, record the MW, expected in-service date, limiting facility and conditions on operation. Do not combine a future, conditional capability with capacity available today.
Find out what “firm” service actually promises
A connection may be firm, non-firm, interruptible or curtailable. The label matters less than the written trigger, amount and restoration terms. Ask whether the service is guaranteed through normal peak conditions, transmission contingencies, emergency events or only within specified limits.
Questions about curtailment and emergencies
- What conditions permit the utility or grid operator to reduce or interrupt the load?
- Is curtailment planned for summer peak, winter peak, transmission emergencies, local equipment failures or other conditions?
- How much MW may be curtailed, and can the utility curtail only part of the campus?
- What notice is provided, through which communications channel and for how long?
- What restoration sequence and target time apply after the event?
- Are testing, telemetry, dispatch or performance penalties required?
- Does a flexible-service option change the study, construction sequence, upgrade scope or deposit?
FERC’s large-load docket specifically raises whether loads that agree to curtail could be treated differently in interconnection studies. That does not mean flexibility automatically produces faster service or fewer upgrades. Request the proposed tariff language or contract section and have the utility state exactly what benefit, if any, applies to this project.
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Compare arrangements only with matching assumptions
| Item | Firm service | Interruptible or curtailable service |
|---|---|---|
| Availability promise | Defined in the tariff or agreement; confirm the stated contingencies and limits. | Service is conditional on specified interruption rights. |
| Interruption trigger | Usually limited to events and conditions listed in the governing documents. | May include peak, emergency or locally defined constraints; obtain the exact trigger. |
| Customer obligation | May require protection, telemetry and operating standards. | Requires verified ability to reduce load, respond to notice and restore operations safely. |
| Study or schedule effect | Not stated without the utility’s study and tariff. | May affect study assumptions or upgrades, but no universal schedule advantage is established. |
| What to compare | MW delivered under the same peak and contingency assumptions. | MW available, curtailment duration, notice, restoration and any credits or charges. |
Ask for outage records for the actual serving facilities
A reliability claim is meaningful only when its denominator is clear. Request records for the actual serving circuit and substation, then ask how upstream transmission events are represented. A utility territory average may conceal conditions on the feeder that would serve the campus.
Define the data before comparing sites
- What facilities and customers are included: the site, feeder, substation, district or entire territory?
- What measurement period is covered, and is it the same for each site option?
- Are planned and unplanned interruptions separated?
- How are momentary interruptions counted?
- How are major storms, wildfires or other exceptional events treated?
- Are transmission-caused interruptions identified separately from distribution failures?
- Can the utility provide event counts, duration, affected customers and the calculation method?
Ask the utility to explain known equipment condition, maintenance, redundancy, protection settings and planned construction that could affect the site. Request a list of planned outages or major work during the proposed energization period.
The general federal sources available for this topic do not provide a site-specific outage rate, a national data-center outage statistic or a capacity figure for your parcel. Do not substitute a national average or a utility-wide number for local records. If a utility withholds detailed data for security or confidentiality reasons, ask for an aggregated summary, the reason for the limitation and the boundary represented by the substitute metric.
Study the data center’s distinctive load behavior
Large data centers can present a different operating profile from ordinary commercial customers. Ask what information the utility needs to model the equipment and controls rather than assuming a flat load.
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Submit a defensible load description
- Expected maximum MW for each phase and the ultimate campus.
- Hourly or representative load shapes, load factor and seasonal variation.
- Ramp rates during startup, workload changes and transitions between operating modes.
- Power factor, voltage characteristics and major power-electronic equipment.
- On-site generation, storage, backup systems and the conditions under which they operate.
- Protection and control settings, automatic transfers and the behavior of cooling and computing systems during disturbances.
Ask whether validated dynamic models, telemetry, commissioning tests or operating data are required. Confirm how the study handles a rapid load increase, a rapid decrease or the sudden trip of a large block of load.
Clarify ride-through and coordination requirements
FERC’s 2025 reliability conference materials identify modeling, visibility, monitoring, coordination, ramp rates and voltage- and frequency-ride-through as issues raised by rapidly fluctuating or suddenly disconnected large loads. Treat these as questions for the utility, not as proof that a particular project will cause an outage.
- What voltage and frequency ride-through expectations apply to the customer equipment?
- What telemetry, real-time data, alarms or control interfaces must be installed?
- Who can issue a dispatch or curtailment instruction?
- What commissioning tests demonstrate that controls respond as modeled?
- How are customer protections coordinated with utility reclosing and transmission protection?
Get a written upgrade, cost and schedule package
Capacity is not feasible until the physical work, money and critical path are documented. Ask for a facility-by-facility itemization covering customer-owned equipment, distribution work, substation additions and transmission network upgrades.
Cost-allocation questions
- Which facilities will the customer own, build, operate and maintain?
- Which facilities will the utility or transmission provider own and maintain?
- What project costs are assigned directly to the customer?
- Which network costs are allocated under a broader transmission or distribution formula?
- Are deposits, financial security, letters of credit or milestone payments required?
- Are any upgrade costs eligible for credits, refunds or future-load offsets, and what conditions apply?
- What happens to deposits if the project is delayed, downsized or canceled?
FERC’s large-load docket identifies upgrade cost responsibility and possible credits as policy issues, but the project’s obligations come from the applicable tariff, study and agreement. Do not rely on a verbal estimate.
Schedule and readiness questions
- What is the sequence from application, feasibility study and system-impact study through design, permitting, procurement, construction, testing and energization?
- Which transformers, breakers, conductors or protection systems have long lead times?
- What decision or payment unlocks each stage?
- What assumptions could move the in-service date?
- What evidence of project readiness is required before the utility reserves capacity or begins construction?
FERC Chairman Mark C. Christie’s large-load forecasting letter points to contracts, financial-security deposits and physical site control as objective commercial-readiness milestones. Ask which of these—or other milestones such as permits and construction commitments—the utility uses in its study and planning process. A forecast without a defined site, security or project commitment may be treated differently from a project that can demonstrate readiness.
Build a utility-meeting evidence checklist
Send questions before the meeting and ask for dated documents afterward. Your file should contain:
- A map identifying the parcel, point of delivery, serving circuit, substation and upstream transmission path.
- The current tariff, service agreement template and large-load or interconnection procedure.
- The capacity-study summary, assumptions, modeled demand, contingencies and unresolved constraints.
- A pre-upgrade and post-upgrade MW table for each construction phase.
- An outage-data definition sheet showing facilities, period, planned-event treatment, momentary-event treatment and exceptional-event rules.
- The firm, non-firm or curtailable-service terms, including triggers, notice, MW reduction and restoration.
- The load-model and telemetry requirements, including ramp-rate and ride-through assumptions.
- An itemized upgrade scope, cost allocation, deposits, credits and ownership responsibilities.
- A milestone schedule with long-lead equipment and conditions that could change the energization date.
- A list of information the utility still needs from the project team.
How to compare two sites or service options
If you are evaluating multiple parcels or arrangements, require the utility to use the same study year, demand assumptions, outage definitions and contingency criteria. Otherwise, a lower outage number or shorter schedule may simply reflect a different denominator or a less demanding study.
| Comparison | Evidence to place side by side |
|---|---|
| Capacity | Firm MW today, post-upgrade MW, limiting facilities and the assumptions behind each figure. |
| Reliability | Same facilities, time window, planned-event treatment, momentary-event definition and storm treatment. |
| Service terms | Firm versus curtailable status, triggers, notice, maximum reduction and restoration provisions. |
| Cost | Customer-funded work, allocated network work, deposits, credits, refunds and ownership. |
| Schedule | Study milestones, procurement lead times, construction dependencies and energization conditions. |
| Operating duties | Telemetry, monitoring, ramp limits, ride-through, commissioning and coordination requirements. |
What a careful conclusion looks like
You can conclude that a site is ready for the next diligence stage only when the utility has tied a stated MW capability to the exact point of delivery, documented the assumptions and contingencies, identified upgrades and costs, and provided service and outage terms with clear definitions. If any element is conditional, label it conditional. If the utility cannot disclose a study or local outage record, record that limitation rather than replacing it with a generic figure.
A new data center does not automatically cause outages, and a broad regional capacity statement does not establish that a particular parcel can receive reliable service. The defensible answer comes from the serving utility’s dated studies, controlling tariff or agreement, facility-specific outage records and written upgrade commitments.
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