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Ask the serving utility for a current, site-specific capacity study at the proposed point of delivery—not an area-wide figure—and for dated reliability records covering the actual circuit, substation and upstream supply path. Require the assumptions, contingencies, service conditions, upgrade list, cost allocation and construction schedule in writing. Also identify which distribution utility, transmission provider and regional grid operator is responsible for each answer.
No national statistic can tell you whether an unspecified parcel has enough power or what its outage risk will be. Those answers depend on the local network, the size and shape of the proposed load, the queue, planning criteria, tariffs and utility records.
Why “available capacity” is not a single number
A utility may quote spare capacity for a planning area, substation or transmission zone. That is not the same as a commitment to serve a data center at your parcel. The useful question is: How many megawatts can be delivered reliably at this exact point of delivery, under which service terms, and after which upgrades?
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- the proposed point of delivery or interconnection;
- initial demand, ultimate build-out demand, load factor and expected operating hours;
- summer and winter peak assumptions;
- the circuit, substation, transmission path and supply boundary analyzed;
- normal and contingency conditions;
- constraints that remain unresolved; and
- the upgrades or operating restrictions needed for each phase.
FERC’s Form No. 715 planning instructions describe how criteria are used to evaluate transmission availability, identify constraints and anticipate technical-study results, including contingency performance, facility overloads and voltage limits. Those criteria help you understand a study; they do not guarantee service to a particular site.
Identify every organization that controls part of the answer
Start the meeting by mapping responsibility. A distribution utility may own the feeder and substation, while a transmission owner, transmission provider or regional transmission organization (RTO) or independent system operator (ISO) controls another part of the path. Different tariffs and approvals may apply to each layer.
Questions about jurisdiction and process
- Which electric distribution utility serves the parcel?
- What is the proposed point of delivery or point of interconnection?
- Which transmission provider and, if applicable, RTO or ISO are involved?
- Does the requested size enter a large-load, transmission-level or other special process?
- Which tariff, service agreement, interconnection procedure or study manual controls?
- Which parties must review, approve or construct facilities, and what decision belongs to each?
FERC’s large-load docket describes loads generally greater than 20 megawatts (MW) and examines how they can interconnect in a timely, orderly, reliable and non-discriminatory manner. That threshold is a description of the federal proceeding, not a universal rule for every utility. On June 18, 2026, FERC announced show-cause orders to the six RTOs and ISOs under its jurisdiction concerning tariff rules for large-load interconnection and consumer safeguards. Proceedings and tariffs can change, so obtain the current document that applies to your service territory.
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Priority questions for the capacity study
1. What can be served before and after upgrades?
- What firm MW can be delivered at this exact point today, before construction?
- What MW can be delivered after each identified upgrade, and on what date?
- Is the figure net of other projects in the queue, or does it assume they will not proceed?
- Which circuit, transformer, substation, transmission element or generation-supply constraint limits the request?
- What reliability criteria and contingencies were applied?
- Can the utility provide a dated study, assumptions, unresolved issues and the data it still needs from the customer?
Ask for separate numbers for the first energized phase and the ultimate campus build-out. A site that can receive an initial block of load may not have a documented path for the final block.
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2. How is the data-center load represented?
- What maximum demand, load factor, power factor and ramp rate should the project submit?
- Does the model include commissioning, staged occupancy and the final build-out?
- Does the utility require validated dynamic models for servers, cooling, on-site generation, batteries or power-electronic controls?
- How are large blocks of load starting, stopping or transferring between sources represented?
Provide the utility with a realistic operating profile rather than a single nameplate value. Explain expected daily and seasonal variation, redundancy arrangements and whether backup systems can operate in parallel with the grid.
Ask exactly what service you are buying
A connection can be firm, non-firm, interruptible or curtailable. The label alone is not enough; obtain the operational terms and the tariff section that defines them.
| Service feature | Questions to put in writing |
|---|---|
| Firm service | What facilities and planning criteria support the firm designation? Are emergency interruptions still allowed, and under what conditions? |
| Interruptible or curtailable service | What event triggers reduction, how much load can be curtailed, how much notice is provided, how long can it last, and what is the restoration sequence? |
| Seasonal or peak-period limit | Are there separate summer and winter limits, declared peak windows or maximum-hours restrictions? |
| Flexible-load arrangement | What flexibility must the customer provide, and does it change study assumptions, upgrade scope, schedule, deposits or rates? |
FERC’s large-load policy docket specifically raises whether customers that agree to curtail can be treated differently in interconnection studies. Flexibility does not automatically produce faster service. Ask the utility to state the applicable terms, triggers, notice, measurement and restoration obligations.
Request outage and reliability records for the actual site
Do not accept a territory-wide reliability average as a proxy for a new data center. Request records for the serving circuit and substation, then ask how upstream transmission events are represented.
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Define the denominator before comparing numbers
- What facilities and customers are included?
- What measurement period is covered?
- Are planned and unplanned interruptions separated?
- How are momentary interruptions counted?
- Does the record represent this site, a feeder, a substation or a wider customer group?
- How are major storms and other exceptional events treated?
- Are switching events, maintenance outages and equipment failures identified separately?
Ask for the utility’s definitions and calculation method alongside every metric. A statistic based on a broad service territory, a different time window or different storm exclusions cannot be compared fairly with a feeder-level record.
Ask about physical reliability, not only historical averages
- What redundancy exists at the feeder, substation and upstream supply path?
- Are there known equipment-condition issues, maintenance projects or planned construction that affect this parcel?
- Which single contingencies can remove service, and what is the expected restoration process?
- What monitoring, communications or customer-side protection is required?
The cited federal materials do not provide a local outage rate for an unspecified project. If the utility cannot release a record because of confidentiality or security restrictions, ask for a non-sensitive summary, the period covered and a clear explanation of what is omitted.
Examine rapid ramps, sudden trips and ride-through
Large computing facilities can change demand quickly as equipment starts, stops or transfers. FERC’s 2025 reliability-conference materials identify rapid fluctuations and sudden disconnection of large loads as issues for modeling, visibility, monitoring, coordination, ramp rates and voltage- and frequency-ride-through. These are questions for the project study, not proof that a particular data center will cause an outage.
Load-behavior questions
- What ramp-rate limits apply during startup, shutdown and recovery?
- How will the utility model a sudden loss of a large load block?
- Does the project need telemetry, disturbance recording or real-time communications?
- What voltage and frequency ride-through settings are expected?
- What commissioning tests and operating procedures must be approved?
- How will on-site generators, batteries, automatic transfer switches and power-electronic controls interact with the grid?
Request the required model format, validation data and acceptance criteria early. Changing controls after a study can require a revised analysis and affect the schedule.
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Get the upgrade scope, cost allocation and schedule
Feasibility includes the time and money required to make service available. Ask for a facility-by-facility list, not a single allowance.
Upgrade and ownership questions
- Which customer-owned facilities, distribution upgrades and transmission network upgrades are required?
- Who designs, permits, builds, owns and maintains each facility?
- Which work is dedicated to the project and which is allocated under broader transmission or distribution rules?
- What equipment has a long lead time?
- What construction, outage or right-of-way dependencies form the critical path?
Money and security questions
- What study fees, deposits, financial security or milestone payments are due, and when?
- What costs are assigned to the customer?
- Are any upgrade costs eligible for credits, refunds or future-use treatment?
- What happens to deposits if the project is delayed, downsized or cancelled?
- Which contracts, permits, physical site-control evidence or construction milestones must be provided before study or construction proceeds?
FERC’s large-load docket treats upgrade-cost responsibility and flexibility as policy issues, but the project’s actual obligations come from the controlling tariff and agreements. FERC Chairman Rosner’s large-load forecasting letter points to contracts, financial-security deposits and physical site control as objective indicators of commercial readiness. Ask the utility which evidence it uses and at what stage.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.Use a written comparison when evaluating sites or service options
If you have multiple parcels or service arrangements, compare only figures produced with the same definitions and study assumptions.
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|---|---|
| Capacity | Firm MW before upgrades; firm MW after each upgrade; phase and ultimate-build dates. |
| Service conditions | Firm, non-firm, interruptible or curtailable status; triggers, notice, duration and restoration. |
| Reliability evidence | Same facilities, time window, planned-event treatment, momentary-event definition and storm exclusions. |
| Upgrade responsibility | Customer-funded versus allocated work; owner; deposit; credit or refund terms. |
| Schedule | Study completion, approvals, long-lead equipment, construction start and energization milestones. |
| Customer duties | Telemetry, models, ride-through settings, ramp limits, commissioning tests and curtailment capability. |
Mark a value “not stated” when the utility has not documented it. Do not rank one option on a feeder outage metric and another on a territory-wide metric.
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A practical utility-meeting workflow
- Prepare the project brief. State the parcel, requested point of delivery, phase dates, initial and ultimate MW, load shape, power factor, ramp expectations, redundancy and on-site resources.
- Request the governing documents. Obtain the current tariff, service agreement template, study procedure, queue rules and any large-load application checklist.
- Send the capacity questions first. Ask for pre-upgrade and post-upgrade firm MW, assumptions, contingencies, constraints and unresolved data needs.
- Request reliability records separately. Specify the circuit, substation and upstream path, period, event definitions and storm treatment you need.
- Document service conditions. Record whether the offer is firm or interruptible and the exact curtailment, notice and restoration terms.
- Obtain a cost-and-schedule register. Tie every upgrade to an owner, estimated cost responsibility, deposit, milestone and long-lead item.
- Confirm study boundaries. Ask which utility, transmission provider or grid operator produced each result and what it did not analyze.
- Set a dated follow-up. List missing studies, decisions and customer deliverables, with the responsible party and due date.
How to recognize an answer that is not yet decision-ready
- A salesperson quotes “hundreds of megawatts nearby” without naming the point of delivery or study assumptions.
- Capacity is described as available but no distinction is made between physical capability, reserved capacity and tariff eligibility.
- An outage average lacks facilities, dates, event definitions or storm treatment.
- The utility promises a connection date before identifying permits, long-lead equipment, queue dependencies and contingencies.
- “Firm” service is offered without the emergency-interruption language or restoration terms.
- The project is asked for a nameplate MW figure but not a load shape, ramp profile or dynamic model.
- Upgrade costs are summarized as an allowance with no facility list, deposit terms or potential credits.
These gaps do not prove that the site is unsuitable. They show that the answer is not yet a documented, site-specific feasibility determination.
What federal information can—and cannot—tell you
FERC’s current proceedings provide useful questions and planning context, not a capacity reservation for your parcel. The large-load docket concerns generally greater-than-20-MW loads and policy issues such as timely interconnection, flexible service, upgrade costs and reliability assessments. The June 18, 2026 show-cause orders indicate that tariff safeguards for large-load interconnection remain an evolving matter.
FERC’s Form No. 715 instructions explain the role of transmission-planning criteria. The 2025 reliability conference identifies rapid load changes, visibility, monitoring, coordination, ramp rates and ride-through as topics utilities may need to evaluate. None of those federal materials supplies your circuit’s outage rate, queue position, available MW, upgrade cost or energization date. Only the responsible utilities and grid entities, using current project data and controlling agreements, can establish those facts.
What a decision-ready package should contain
Before treating a site as feasible, assemble one dated package containing the capacity-study summary, assumptions and contingencies; facility-level upgrade scope; tariff or service agreement; firm or curtailable-service terms; outage records with definitions; load-model and telemetry requirements; cost allocation, deposits and credits; and a milestone schedule. Keep the utility’s qualifications attached to every number. If a result is confidential, record the limitation and the non-sensitive explanation provided.
The central test is simple: can the utility show, in writing, how this specific load will be served, under what conditions, at what reliability level, after which upgrades, for whose cost and by what sequence of milestones? If not, you have a preliminary indication—not proof that the grid has enough power or that outage risk is acceptable.
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