By Jason Guck, Delta Edge CI
The average U.S. business now has a working electricity benchmark of roughly $862 a month, while the latest U.S. Energy Information Administration commercial rate benchmark available as of May 26, 2026 sits at 14.37 cents per kWh. That commercial rate is up 10.7% from February 2025. Most operators I talk to budgeted for a 2% to 3% increase. They are not getting it.
This is a piece for the people writing those budgets: CFOs, controllers, facilities VPs, and multi-site operations leads who want a straight answer to a simple question. What does the average business pay for utilities right now, and where is the number going?
The short answer is below. The longer answer, with the state breakdown and the line-item math, is underneath it.
Key Takeaways
- The average U.S. commercial electricity bill benchmark is about $862/month. The latest EIA commercial rate benchmark available now is 14.37¢/kWh.
- Commercial rates are up 10.7% year over year. Industrial customers pay less per kWh, but often write much larger checks because they consume far more.
- The fastest-rising regions for commercial customers include Maine, New Jersey, Washington, D.C., and parts of Pennsylvania, with PJM capacity costs doing real damage to budgets.
- The single biggest demand-side pressure is load growth from data centers, AI, advanced manufacturing, and electrification.
- For a multi-site C&I operator spending $100,000/month on utilities today, a 4% to 6% annual rate trajectory points toward $150,000+/month by 2034 without consuming a single extra kWh.
- The DOE reports that 30% of the energy used in commercial buildings is wasted. That waste is where the Delta lives. It is also where the relief comes from.
What the Average Business Actually Pays
Two numbers do most of the work in answering this question.
The first is the rate, the price per kWh of energy. The U.S. commercial average sits at 14.37¢/kWh in the latest EIA Electric Power Monthly benchmark available as of this writing. Industrial customers often buy power at lower rates because they buy in bulk and at higher voltage, but they consume far more, so their monthly bills are often far larger.
The second is the consumption, the number of kWh a building actually uses. A small office in a temperate state burns through a few thousand kWh per month. A regional grocery store with refrigeration runs 30,000 to 80,000. A cold-storage facility, food processor, or hotel can hit hundreds of thousands. A manufacturing plant or data center is in its own league.
Multiply the two and you get the bill. The national business benchmark is roughly $862/month, but the range is enormous. Hawaii sits at the expensive end of the rate table. North Dakota and Iowa remain among the lowest-cost places to operate. And those are only averages. Multi-site operators routinely live an order of magnitude above the mean.
What is actually on the bill
The number on the invoice is not just the rate times the kWh. A commercial electric bill is built from four buckets:
- Energy. The actual electrons consumed, priced per kWh.
- Delivery, or transmission and distribution. What the utility charges to move the power. Usually 3 to 6¢/kWh on top of the energy charge.
- Demand charges. Billed based on the single highest 15-minute peak in the billing cycle. For large commercial accounts, demand can represent 30% to 70% of the total bill.
- Taxes, riders, and adjustments. Including capacity charges, transition surcharges, renewable-portfolio compliance, and storm-recovery fees.
The mistake most operators make is staring only at the energy line. The relief is rarely there. The relief lives in demand, in rate-structure misclassification, and in the equipment that produces the load profile in the first place.
Year-Over-Year: What Changed in 2026
Three numbers tell the story.
- Commercial rates: +10.7% YoY in the EIA February 2026 benchmark.
- Industrial rates: +8.6% YoY in the same EIA benchmark.
- All-sector average prices: +9.0% YoY, one of the sharpest national moves in more than a decade.
For context: commercial customers are not getting a softer version of the household bill shock. They are getting a structural repricing of the cost to operate a building, and the pressure is concentrated in the commercial and industrial segments.
This is no longer a story of temporary spikes following a hurricane or a cold snap. The structural cost of running a building is being repriced.
Where It Costs the Most to Run a Business in 2026
State rates vary wildly because grid mix, weather exposure, regulatory structure, and load growth vary wildly.
Below is a working snapshot of where commercial customers are seeing the largest pressure right now. Rate per kWh is useful, but the direction of the change matters more for anyone budgeting for the next five years.
| State / Region | Commercial rate snapshot | YoY change / pressure | Notable driver |
|---|---|---|---|
| Hawaii | ~38¢/kWh | High and persistent | Isolated grid, fuel imports |
| California | ~22¢/kWh | +8% to +10% | Wildfire mitigation, renewable portfolio costs |
| New York | ~19¢/kWh | ~+7% | Transition costs, NYISO capacity |
| Massachusetts | ~21¢/kWh | ~+12% | Gas constraint, capacity |
| Maine | ~19¢/kWh | +22.6% | Capacity prices, transition |
| New Jersey | ~17¢/kWh | +21.6% | PJM capacity auction |
| Washington, D.C. | ~16¢/kWh | +24.5% | PJM capacity, distribution |
| Pennsylvania, parts of PJM | ~12¢/kWh | +29% on capacity pressure | Data-center demand on PJM |
| Texas, ERCOT C&I | ~9¢ to 10¢/kWh | +5% to +8% | Load growth, ancillary services |
| North Dakota | ~9¢/kWh | ~+3% | Coal-heavy, lower demand growth |
| Iowa | ~9¢/kWh | ~+4% | Strong wind base, stable demand |
A few patterns are worth naming.
The PJM footprint, which includes New Jersey, Maryland, D.C., much of Pennsylvania, Ohio, and Virginia, is absorbing the brunt of the data-center buildout. Capacity costs are now showing up in commercial bills across the region.
ERCOT in Texas has held the commercial average lower than the coasts, but the curve is bending. Large-load interconnection requests have flooded ERCOT’s queue, and ancillary-service costs are climbing with the load.
The Midwest has been one of the cheapest regions to operate a commercial building for a decade. It still is. But the gap is closing as Midwest utilities sign data-center load contracts of their own.
What Is Actually Driving the Increases
Five drivers compound on each other. None of them resolves on its own.
1. Data centers and AI
This is the dominant demand story. Data centers, AI workloads, advanced manufacturing, and electrification are pushing a grid that was not planned for this pace of load growth. The bidding does not happen at the meter. It happens upstream, in capacity auctions, wholesale markets, transmission planning, and utility capital plans. But the cost lands on every commercial account in the region.
2. Aging infrastructure
Much of the U.S. transmission and distribution system was built decades ago. Utilities are now spending heavily to replace transformers, harden lines, and add capacity. That spend gets approved as rate base by state regulators and is recovered from ratepayers. The energy line on your bill can stay flat. The delivery line will not.
3. The energy transition itself
Cleaner generation is being added at speed. The transition is real, and it is necessary. It is also being paid for in the near term through interconnection costs, storage buildouts, decommissioning of legacy plants, and grid-balancing investments. The bill arrives before the long-term savings.
4. Fuel and inflation
Natural gas remains the marginal fuel in many regions, which means gas prices still influence wholesale clearing prices in many hours. Labor, copper, steel, and transformer costs are also materially higher than they were in 2020. Utilities pass those costs through.
5. Extreme weather
Wildfire mitigation in the West, hurricane hardening on the Gulf, and winter-storm resilience in Texas have all added permanent recurring costs to utility budgets. Reliability is being reinvested in, and ratepayers are funding the work.
What This Means for a Multi-Site Operator
The math compounds quickly.
Take a regional operator running 25 locations at an average $4,000/month per site. That is a $1.2M/year utility line. At a 6% to 8% annual compounding trajectory through 2030, the same 25 sites consuming the same kWh are on track for roughly $1.7M to $1.9M/year by 2030.
That is half a million dollars of pure rate inflation. No new locations. No expanded operations. No additional load. Just the cost of standing still.
For a CFO, that is a structural margin problem. For a facilities lead, it is a multi-year capital-planning problem. For a procurement team, it is a contract-strategy problem that can no longer be solved at the meter.
What to Actually Do About It
There are four levers worth pulling. None of them is switch suppliers and hope.
1. Get visibility into your actual consumption
Most multi-site operators cannot tell you, at the location level, where the waste sits. They can tell you the total invoice. They cannot tell you which sites are running HVAC outside operating hours, which compressors short-cycle, which locations are misclassified on their rate tariff, or which buildings spike demand for fifteen minutes every Tuesday morning and pay for it the rest of the month.
The DOE reports that 30% of the energy used in commercial buildings is wasted. That is not a metaphor. That is dollars leaving the building every billing cycle.
Conservation Intelligence, the discipline of finding the leaks before you talk about solutions, is the first lever. If you cannot see the waste, you cannot price the relief.
2. Optimize before you cut
Cutting energy use blindly hurts operations. Optimization is different. Optimization means using energy at the right time, flattening demand peaks, sizing equipment to actual load, and matching rate structure to real consumption patterns. The same kWh used at 2 p.m. on an August Tuesday and at 11 p.m. on a Sunday can cost very different amounts. Most operators are not pricing that difference into their decisions.
3. Modernize the equipment producing the load
Lighting, HVAC, refrigeration, controls, building envelope, and on-site generation are the levers that move the actual load profile. The capital cost has historically been the obstacle. That is changing.
4. Stop treating utilities as a fixed cost
Electricity, gas, and water are not fixed costs. They are managed costs. The operators who win the next decade will be the ones who put a discipline around the line item and treat it the same way they treat insurance, leases, or capital allocation. The ones who keep treating utilities as a pass-through will absorb every dollar of rate inflation the grid hands them.
Where Delta Edge CI Comes In
Delta Edge CI was built for this exact problem.
We are a virtual utility services platform. We sit on the customer’s side of the meter, find the Delta between what a building pays today and what it should pay tomorrow, and close it. The Zero Cost Program funds 100% of the engineering, equipment, and installation. The customer puts up no capital. We guarantee conservation against the utility consumption.
The model has delivered a 34.4% conservation rate on a $143.8 million enterprise-wide deployment for a regional health system. We are not a broker, not an REP, not a vendor, not a financier, and not a sustainability consultant. We are the accountable operator in a fragmented market.
The Delta is real. It is measurable. It is in your buildings right now.
The Bottom Line
The average U.S. business electricity benchmark is roughly $862 a month. The average multi-site operator pays many multiples of that. Commercial rates are climbing faster than normal budget assumptions, and the data-center buildout is going to keep pressure on grid costs for the rest of the decade.
The rates are not the lever. The rates are set by capacity markets, fuel curves, and infrastructure that no single business controls.
The lever is the consumption, and the discipline around it. That is where the Delta lives, and that is what Conservation Intelligence is for.
If your monthly utility spend is north of $15,000 and you are tired of absorbing every increase the grid hands you, that is the conversation to start.
Sources
- U.S. Energy Information Administration, Electric Power Monthly and February 2026 retail sales and revenue benchmarks.
- U.S. Energy Information Administration, Short-Term Energy Outlook, commercial sector electricity demand commentary.
- Utility Dive, average U.S. electricity prices rose 9% year over year in February 2026, based on EIA data.
- U.S. Department of Energy, Commercial Buildings Integration Program, commercial building waste estimate.
- Electric Choice business electricity rate benchmarks, May 2026.
- Delta Edge CI internal deployment data, regional health-system project: 34.4% conservation rate on a $143.8M enterprise-wide deployment.
Jason Guck is a co-founder and longtime operator in the telecommunications and energy services industries, and works alongside the Delta Edge CI team to bring the Zero Cost conservation model to commercial and industrial operators across the U.S. Based in Rochester, NY.