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The price in a wholesale market is not the same thing as the rate on a household bill. Wholesale prices can change every few minutes, while most customers pay a regulated tariff with seasonal, fixed, and usage-based charges. In the United States, state public utility commissions usually approve retail rates; the Federal Energy Regulatory Commission (FERC) regulates interstate wholesale sales and much interstate transmission.
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Three prices that are easy to confuse
Before explaining a higher bill, identify which price is being discussed. The U.S. electricity system has three distinct layers.
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Wholesale market price
Generators, utilities, and other market participants buy and sell electricity in wholesale markets. Grid operators generally use economic dispatch: available resources are ordered from lower operating cost to higher operating cost, and enough generation is selected to meet demand.
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FERC calls the price at a particular grid location the locational marginal price (LMP). LMP reflects the cost of producing the next unit of energy, plus the cost of electrical losses over the network and the effect of transmission congestion. Market rules and settlement intervals differ by region, so an hourly wholesale price in one area cannot be treated as a national household rate.
Utility cost of service and approved rates
A utility must recover the costs of obtaining or producing electricity and operating the system that delivers it. Those costs can include fuel and purchased power, generating plants, transmission and distribution equipment, operations and maintenance, depreciation, taxes, and financing costs. A regulator reviews the utility’s evidence and decides which costs are reasonable and how they should be allocated among customer classes.
Your bill and the EIA average retail price
Your bill applies a specific tariff to your metered usage. It may include a fixed customer charge, a per-kilowatt-hour energy charge, demand charges for some commercial customers, time-of-use prices, riders, taxes, and other fees.
The U.S. Energy Information Administration (EIA) publishes an average retail price calculated as retail electricity revenue divided by retail kilowatt-hour sales. That statistic includes generation, transmission, distribution, taxes, and fees across many customers. It is useful for comparing broad trends, but it is not the rate schedule on an individual customer’s bill.
The main forces that push electricity prices higher
Fuel and purchased-power costs
When natural-gas or petroleum prices increase, generators that burn those fuels generally become more expensive to run. The effect is largest where a fuel frequently sets the marginal wholesale price or represents a large share of the local generation mix. Supply disruptions, pipeline constraints, shipping problems, or other limits on fuel availability can raise costs even when overall demand is unchanged.
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Utilities that purchase power under contracts or in spot markets may also pass higher procurement costs through a fuel-adjustment clause or another approved rider. A lower fuel price does not guarantee a lower total bill if delivery or other approved costs rise at the same time.
Heat, cold, and other demand surges
Hot weather increases air-conditioning load; severe cold can drive electric heating and heat-pump use. During a demand peak, the least-cost generators may already be running, requiring operators to dispatch more expensive units. Wholesale prices can rise sharply during those hours. EIA reports that electricity prices are usually highest in summer because high demand brings more expensive generation online.
Retail customers may not see the full hourly spike. A traditional tariff can average costs over a month or season, while a time-of-use plan charges different prices during defined peak and off-peak periods. The same wholesale event therefore produces different bill effects for customers on different tariffs.
Power-plant outages and resource conditions
A generation unit that is offline for planned maintenance or an unexpected failure removes supply from the market. If reserves are tight, the system must rely on costlier units or imports. Weather can reduce renewable output as well: drought can cut hydropower production, and low wind speeds can reduce wind generation. Other generators then have to fill the gap, potentially increasing both wholesale prices and fuel consumption.
Transmission and distribution investment
Electricity must travel through high-voltage transmission lines and local distribution networks before reaching a meter. Utilities and transmission owners spend money to build, replace, inspect, repair, and operate those facilities. They also incur depreciation, taxes, and financing costs and are allowed a regulator-approved return on qualifying investment.
Those costs are recovered through transmission and distribution charges embedded in customer rates. A large grid project can therefore affect bills over several years even if fuel prices are stable. Reliability upgrades, storm hardening, wildfire mitigation, vegetation management, and replacement of aging equipment can have similar effects where regulators approve the spending.
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Local supply mix, geography, and regulation
Prices differ by service territory because every area has a different mix of generators, fuel-delivery costs, weather, terrain, interconnection constraints, and regulatory requirements. An isolated system may have fewer opportunities to import cheaper power. EIA attributed Hawaii’s high 2025 average largely to petroleum generation using imported fuels, illustrating why geography and fuel logistics matter.
Customer class and delivery cost
Residential, commercial, industrial, and transportation customers do not use the grid in the same way. Residential service requires many individual meters, service drops, billing accounts, and local connections. Industrial customers often consume much more electricity at higher voltage, spreading some delivery costs over larger volumes. For these reasons, residential and commercial average prices are commonly higher than industrial averages.
Taxes, fees, and rate design
A bill can increase because of taxes, public-purpose charges, environmental programs, storm-recovery riders, or other itemized fees even when the base energy rate is unchanged. Utilities may also redesign rates by changing fixed charges, energy blocks, demand charges, or time-of-use periods. Two customers with identical kilowatt-hour usage can owe different amounts if they are on different tariffs or have different peak demand.
How a retail utility rate is set
1. The utility documents its costs and revenue need
For an investor-owned utility, a rate proceeding begins with evidence about the cost of providing service. The filing may cover generation procurement, labor, maintenance, fuel, purchased power, depreciation, taxes, capital investment, financing, and a proposed return. The utility also provides forecasts and usage data that help determine how much revenue its rates should collect.
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2. The regulator reviews the filing
A state public utility commission generally reviews an investor-owned utility’s proposed rates. Staff, consumer advocates, industrial customers, and other parties can test the utility’s assumptions, challenge costs, and propose alternatives. The commission decides which expenses are prudent and whether the proposed revenue requirement is justified under the applicable state law.
3. Costs are allocated among customer classes
After determining an overall revenue requirement, the commission and utility examine how different customers use the system. Residential, commercial, industrial, and other classes may receive different combinations of customer, energy, and demand charges. Allocation methods consider usage patterns, peak contribution, voltage level, and the facilities needed to serve each class.
4. The commission approves a tariff
The final order establishes an approved tariff: the legally applicable schedule of charges, conditions, and service rules. The tariff may include seasonal rates, time-of-use periods, minimum bills, fixed customer charges, net-metering provisions, or automatic riders for specified costs. A later proceeding can change those charges when costs, policy requirements, or system conditions change.
5. Adjustments occur between major cases
Some tariffs contain fuel, purchased-power, storm, or other adjustment mechanisms. These riders can change more frequently than the base rate, subject to the commission’s rules and review. A bill can therefore move between full rate cases without a complete redesign of every tariff component.
What FERC regulates—and what it does not
FERC’s jurisdiction is concentrated in interstate wholesale electricity sales and interstate transmission. It approves or oversees wholesale market rules and transmission rates under federal law. FERC does not generally set the retail rate a household pays; state utility commissions usually do that.
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Transmission rates can be established through a traditional cost-of-service case. The approved rate recovers the cost of building, operating, and maintaining transmission facilities plus a reasonable return on investment. FERC can also approve a formula rate. Under a formula rate, defined cost inputs are updated on a recurring schedule—often annually—under protocols that allow customers to review the calculations and challenge errors or unsupported costs.
Distribution service is generally regulated by state or local authorities. Jurisdictional boundaries have exceptions, including special arrangements in Alaska, Hawaii, and much of Texas, so the responsible regulator depends on the service territory and transaction.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.Current U.S. electricity price figures
The following EIA figures are 2025 annual averages based on preliminary February 2026 Electric Power Monthly data. They cover all sales in the stated customer class or state, not a particular household tariff.
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| Measure | Average price | What it represents |
|---|---|---|
| All U.S. sectors | 13.63 cents per kWh | National annual average retail price for 2025 |
| Residential | 17.30 cents per kWh | Annual average across U.S. residential sales |
| Commercial | 13.41 cents per kWh | Annual average across U.S. commercial sales |
| Industrial | 8.62 cents per kWh | Annual average across U.S. industrial sales |
| Transportation | 13.83 cents per kWh | Annual average across U.S. transportation sales |
| Highest state average | 35.72 cents per kWh | Hawaii, all customer types |
| Lowest state average | 8.20 cents per kWh | North Dakota, all customer types |
Because these numbers are preliminary statistical averages, they should not be used as a quote for a current tariff. A comparison should identify the state, utility, customer class, billing period, fixed charges, taxes, fees, and whether the figure is preliminary or final.
How to diagnose a higher electricity bill
A larger bill does not automatically mean the utility raised its per-kilowatt-hour rate. Use the bill’s own data to separate usage from price.
- Compare kilowatt-hours. Check the current and previous meter readings or usage chart. More air-conditioning, electric heating, water-heater use, or appliance use can raise the bill with no rate change.
- Check the tariff name and rate components. Look for the energy charge, fixed customer charge, demand charge, time-of-use period, fuel or purchased-power rider, taxes, and public-purpose fees.
- Compare the effective price. Divide the total bill by the kilowatt-hours used, then compare that result with the prior month. This is a bill-level measure, not necessarily the utility’s posted energy rate, because it includes fixed charges and taxes.
- Check the billing period and meter status. A longer billing cycle, estimated reading, move-in or move-out adjustment, or corrected prior bill can change the total.
- Ask the utility for the applicable tariff. Request the rate schedule in effect for the service address and the date the change began. If the explanation remains unclear, contact the state public utility commission or the consumer-assistance office listed on the bill.
Why wholesale prices and household bills move differently
Wholesale markets respond to conditions immediately: a gas-price shock, a transmission constraint, a sudden heat wave, or a generator outage can change the marginal price within an operating interval. Retail tariffs are designed for billing stability and regulatory oversight. They may recover costs through monthly averages, seasonal schedules, or delayed adjustment clauses.
As a result, a wholesale price spike may be muted or delayed for a customer on a fixed seasonal tariff, while a customer on real-time or time-of-use pricing may see a more direct effect. Conversely, a retail bill can rise because of a distribution project or approved fee even while wholesale energy prices fall.
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- Use the same geography and service territory.
- Compare the same customer class, such as residential with residential.
- Separate wholesale prices, posted tariff rates, and EIA average retail prices.
- Include fixed monthly charges, demand charges, taxes, and other fees.
- State the usage assumption and billing period; cents per kilowatt-hour alone can hide a large fixed charge.
- Identify time-of-use peak and off-peak windows when plans have them.
- Record the data vintage and whether a figure is preliminary or final.
The practical rule is simple: generation is only one part of the bill. A change in fuel or wholesale energy costs can be outweighed by demand, plant availability, transmission investment, distribution costs, taxes, or tariff design. To understand a specific increase, read the usage, rate schedule, and itemized charges together.
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