For landowners and developers

What would a data center cost to operate on your land?

Start with your property and planned facility. Estimate the power bill, add operating budgets, and explore solar. See which costs are supported by records and which still need a quote.

Estimate your costs Explore public power deals

One property, one operating plan

Build a budget you can trace.

Budget entries stay in your browser. Optional solar lookups send the address to Census or coordinates and array settings to PVWatts.

No invented financial defaults. Blank means unknown, not free. Enter zero only when a cost does not apply. The starting facility size and usage are editable examples. A location alone does not establish your utility, tariff, power availability or negotiated deal.

A real property above 200,000 square feet

Antwerp Industrial Center · Antwerp, Ohio

5278 County Road 424, Paulding County. The county development listing reports 228,439 SF total, 26 acres, AEP Ohio power and Village of Antwerp water and sewer. Its September 4, 2026 record lists 150,000 SF available. Its description also says 55,000 SF is leasable. Total size does not establish available or usable data-hall area.

The listing shows 480/600-volt service and a substation 0 miles away. That does not establish available MW or the service voltage. AEP Ohio sets both after a load study.

The case models an assumed 20 MW IT, PUE 1.25, 85% average draw and a 30 MW contract for one full 2026 operating year. Above 25 MW, AEP Ohio's Data Center Tariff applies. The screen uses its published primary-voltage charges and 2026 riders. Energy uses the published standard-offer price as a reference only. A new data center load buys supply from a competitive supplier or a separate AEP procurement. Site capacity, taxes and other operating budgets remain unverified. Square footage does not determine MW.

Loading replaces current inputs with this property and planning scenario.

Water, sewer and solar evidence

Village Ordinance 2026-01 sets water inside the village at $105.00 per quarter per tap plus $5.87 per 1,000 gallons. Outside the village it is $115.00 plus $10.27. No volume is included. The latest sewer schedule we found is Ordinance 2017-12: $77.25 per quarter including 6,000 gallons, plus $1.90 per 1,000 gallons. It dates from 2019, so confirm it is current. The estimator converts these to monthly charges. Whether the site is inside village limits is not established. The village has negotiated industrial rates before. Solar requires a roof or site study and an AEP Ohio interconnection agreement.

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Pick up where you left off

Keep up to 20 named budgets in this browser, including entered costs, property details and cooling/solar settings. Nothing is sent to us, and drafts do not sync between devices. Restore replaces current inputs. On a shared computer, delete your drafts when finished.

Draft name

Saved drafts

Utility confirmations and boundary results are not saved. Rerun those checks after restoring. Selecting a draft does not load it. Update replaces only the selected draft with current inputs. Rename uses the name entered above. Reset inputs keeps all saved drafts; delete removes only the selected draft.

Jump to solar sizing · Jump to power distance and connection costs

Your property and facility

County or nearest town

State

Property acres (optional)

Context only; does not establish buildable area or solar fit.

Total building area (SF, optional)

Gross building area, not available data-hall space or approved MW.

Serving electric utility (enter or correct)

Manual entry is always available. Confirm service with the utility.

Target server / IT load (MW)

Average draw (% of deployed peak)

Budget horizon (years)

First full operating year

Likely serving utility

Find candidate electric utilities from geographic rate records. A match does not establish parcel service, tariff eligibility or available power. No price or billing basis changes automatically.

Property street address (optional)

Property latitude

Property longitude

Automatic official boundary checks

Checks United Power, Bluebonnet regional, Denton, CoServ Electric, Austin Energy and Colorado statewide electric territories where available. Coordinates are sent to the utility or government GIS services through this site's lookup. Runs with the likely-utility lookup, or independently below. Older layers show their recorded data-edit date; check date does not mean the map is current.

A 100 m margin flags mapped edges for review. It is not an estimate of address accuracy. Shared areas, map errors and interpolated coordinates still require exact-address confirmation. These checks leave your entered utility and prices unchanged.

Official service-address or boundary check

Use this when co-op service, several suggestions or an empty result need a closer check. Regional tools are suggestions to investigate, not service boundaries. This covers selected utilities; it is not a nationwide automatic verification.

Official verification source

Open the official source and check the exact property. Your address is not sent to that tool automatically. Keep service unresolved if a map, boundary edge or new address is unclear.

What did the official check establish?

Check result / response reference

Address matching uses Census. Utility candidates use OpenEI's Utility Rate Database. Optional lookups send your address to Census or coordinates to OpenEI; your budget is not sent.

Deployment: peak IT load as % of target

Year 1

Year 2

Year 3

Year 4 onward

Cooling and water costs

Cooling approach Manual budget Dry / air Evaporative Liquid

Enter an annual water budget below, or toggle a cooling option to calculate from usage and local tariffs.

PUE: facility power ÷ IT power

Includes cooling electricity and facility overhead. The toggle remembers your edited PUE for each option.

Power rate and commitments

Billing basis for this property

Rate evidence / quote reference

Prices are not supplied. Enter the applicable schedule or quote.

Loading the example resets your property and budget entries. It uses the published LPL base sheet and 2026 fuel and disaster-reserve factors for a hypothetical transmission-service account. Taxes and property terms remain unknown. Its rider factors cover 2026 only. RSE and CNP are already incorporated in the published base energy prices.

Other annual operating costs

Enter annual owner budgets or quotes. Budgets are held constant across the horizon. Cooling electricity is included through PUE so it is not counted twice.

Solar and storage options

Power approach

Solar production approach

Enter array space after excluding occupied land, equipment, access, setbacks and shaded areas. Gross building area and parcel acres are context only. Module coverage allows room between panels and rows.

Solar placement

Usable rooftop array area (SF)

Module coverage of usable array area (%)

Editable 40% planning example. Ground coverage affects row shading in the model; it is not a measured site layout.

Solar module model

PVWatts module and area assumptions. Modeled efficiency, not an equipment selection.

US street address for solar location (optional)

Solar latitude

Solar longitude

Panel tilt (degrees)

Editable layout example, not a roof pitch measurement.

Panel direction (degrees; south = 180)

System losses (%)

Editable PVWatts planning example for shading, dirt, wiring and other losses. Losses are applied once.

Array DC / inverter AC capacity ratio

Hourly generation comes from PVWatts V8 and its named weather dataset. Onsite use is modeled against a steady facility draw within each deployment year. Excess output earns no credit. This is a screening estimate; roof structure, shading, land layout and permits require a site study.

Annual solar maintenance ($)

Entered annual studies are spread equally across modeled months. Area-based estimates follow hourly modeled generation and seasonal output. Solar reduces purchased kWh, not demand minimums. Battery selection adds quoted costs; it does not simulate dispatch or backup. Prices, ongoing fees, financing, incentives, degradation and replacement costs require separate evidence.

Distance to power and connection costs

Identify a candidate connection point and the line route to your property. A nearby line can lack the capacity or voltage your facility needs. These costs are paid upfront and do not change the annual power bill.

Candidate power connection point

Connection-point evidence

Distance from property to candidate power point

Distance units

Distance measurement

Candidate connection voltage (kV)

Connection sizing power factor

Editable planning assumption; MW ÷ power factor = MVA.

Connection cost approach

Full connection quote evidence / reference

A full quote replaces the component estimate. Confirm which party owns and pays for each asset, including any utility contribution in aid of construction. Refundable deposits and collateral require a separate cash budget.

Other upfront costs

Refundable utility deposits and collateral require a separate cash budget and are not included in these cost subtotals.

Construction, connections and installation are not annual operating expenses. Financing, depreciation, incentives, IT hardware purchase, battery replacement and exit fees are outside this pilot.

Annual operating budget

Partial subtotals omit unknown costs. Calculated water replaces the manual water budget. Annual operating budgets are separate from upfront costs.
Year	Facility peak MW	Grid energy GWh	Power subtotal	Calculated water/sewer	Other operating budgets	Solar/storage maintenance	Known operating subtotal

Check the property before committing capital.

Bring the site, intended MW and utility response. Confirm service availability, connection costs, operating assumptions and development requirements.

Discuss my property

Evidence from filed agreements

What public power deals tell an owner

These records establish specific commitments and cost structures. They do not offer those customers' prices or capacity to another property. Redacted prices remain unknown.

Records reviewed October 5, 2026.

Direct records: Denton and Muskogee campus agreements · OG&E / Google settlement · Alabama filed contract copy.

What the estimate includes

Power, operating budgets and solar method

Peak facility kW = target IT MW × 1,000 × deployment percentage × PUE. Average kW = peak facility kW × average draw percentage. Consumption uses 8,760 hours/year and 730 hours/month, with constant monthly load within each year. Year four continues through the horizon. Billing commitments are modeled independently of usage.

Texas Oncor transmission-service rules use an actual-peak distribution ratchet and separately entered 4CP transmission demand. The Evergy illustration applies the selected large-load commitment and excludes transitional agreements. Standard Alabama LPL uses kVA and capacity minimums; the historical example includes both energy tiers. Oklahoma's negotiated terms require an entered quote. State selection does not establish utility service territory.

Other costs and utility taxes are entered annual budgets, held constant. Cooling electricity is already in PUE. Energy riders apply to grid kWh; fixed riders apply monthly. Alabama summer means June through September. Do not add a rider already included in your blended energy or monthly charge. This pilot excludes unentered riders and taxes, annual minimum-energy true-ups, outages, hourly tariffs, IT hardware, financing and future negotiated changes. It does not confirm buildability or available megawatts.

Cooling water uses IT kWh times entered makeup liters/IT kWh divided by 3.785411784 liters/US gallon. It adds other monthly usage, applies the entered sewer-billed share, and prices water and sewer separately using monthly minimums and included-gallon blocks. Annual volumes are allocated equally to 12 modeled months. Meter/class eligibility, cooling design, seasonal loads, fire rates, surcharges and approved sewer credits need confirmation. Makeup withdrawals include blowdown and differ from evaporation-only water consumption. Examples do not establish a preferred cooling technology or available water capacity.

Alabama's published 2026 transmission ECR is 23.329 mills/kWh outside summer and 26.453 mills/kWh in summer. Divide mills by 1,000 to obtain dollars/kWh. Nonresidential NDR is $4.50 per account per month. 2026 bill factors. Parallel onsite generation requires review of Rider RGB; solar screening does not price standby or interconnection obligations.

Solar can use an entered study or a usable-area screen. Area mode converts square feet or acres to module area, applies the PVWatts nominal module efficiency, then scales an hourly 1 kW DC model for the entered location, mounting, orientation and losses. Each hour's modeled generation is capped at steady facility draw. Monthly savings follow seasonal generation; the utility consumption screen still uses 730 hours per month. Typical weather repeats across operating years without degradation. Unused output has no sale value. No demand reduction, battery dispatch, engineered roof suitability, financing or payback is promised. Prices and utility parallel-generation terms remain separate.