"Electricity prices doubled since 2000." Yes and no.
The headline number is true in nominal terms. The US residential average went from roughly 8.2 ¢/kWh in 2000 to 18.83 ¢/kWh in March 2026. That is a 2.3x increase, often quoted as "prices have doubled".
In real (inflation-adjusted) terms, the same data shows a much smaller increase, around 25 to 30%, depending on the CPI series you use. A 2000 dollar buys roughly half of what a 2026 dollar buys; restating every year in 2026 dollars compresses most of the apparent rise.
That is only half the story. The composition of the bill changed more than the headline. Wholesale energy went down from 2008 to 2020 thanks to cheap shale gas. Capacity charges, transmission build-outs and climate-policy riders went up. The supply portion of a residential bill shrank from roughly 60% in 1998 to 40 to 50% in 2026; the regulated delivery portion grew to match. Two households paying the same total ¢/kWh in 2000 and 2026 are paying for very different cost stacks.
Read the year-by-year table below as a record of the headline change, then read the regional divergence section for what actually happened underneath it.
What the nominal-price line does not show.
A single national line obscures three shifts that actually drove household bills.
Wholesale energy went down
Marcellus and other shale gas plays cut Henry Hub from $8/MMBtu in 2008 to roughly $2 to $4/MMBtu through most of the 2010s. PJM, MISO and ERCOT wholesale energy prices fell with it. Households saw none of this directly, because the energy component became a smaller share of the bill.
Capacity and transmission went up
Cheap gas pushed coal and nuclear retirements faster than new plants came on. PJM capacity prices climbed from a baseline of $20 to $40/MW-day in the 2010s to $329.17/MW-day for 2026/2027. Transmission build-outs (PJM, MISO, SPP) added long-term rate-base charges that residential customers pay over decades.
Climate riders entered the bill
California (wildfire mitigation, ZEC nuclear support), New York (CLCPA), Illinois (CEJA), Massachusetts and others now add 2 to 5 ¢/kWh in named riders that did not exist in 2000. Half the country added none of these; the headline US average mixes the two.
The detail that surprises most readers. The 2000-to-2026 nominal rise is largely inflation. The real rise of 25 to 30% is the net effect of cheaper wholesale energy minus much more expensive capacity, transmission and policy. The composition shifted faster than the total. That is why a 15% discount on the supply portion of your bill in 2026 is worth only 6 to 8% off the all-in bill, not 15%.
US residential average, year by year (nominal).
Source: EIA Electricity Sales, Revenue and Price for annual averages 2000 to 2024; EIA Table 5.6.A for the March 2026 reading. 2025 figure is EIA estimate from the May 2026 STEO.
| Year | US avg ¢/kWh (nominal) |
|---|---|
| 2000 | 8.24 |
| 2005 | 9.45 |
| 2008 | 11.26 |
| 2010 | 11.54 |
| 2014 | 12.52 |
| 2016 | 12.55 |
| 2019 | 13.04 |
| 2020 | 13.20 |
| 2021 | 13.72 |
| 2022 | 15.12 |
| 2023 | 15.95 |
| 2024 | 16.49 |
| 2025 | 17.51 |
| 2026 | 18.83 |
! The three step-ups
2008 (Henry Hub gas spike + gradual repricing); 2014 (polar vortex passing through to variable retail products); 2021-2022 (Uri then EU gas crisis). The 2024-2026 step is not a single event but the cumulative effect of the PJM 2025/2026 and 2026/2027 capacity auctions repricing supply.
PJM is diverging from MISO and ERCOT.
Through the 2010s the three large central US wholesale markets tracked each other closely. Since 2024 they have separated. The cause is market design, not fuel.
A PJM: capacity at the cap
The 2025/2026 BRA cleared at $269.92/MW-day, the 2026/2027 at $329.17 (Net CONE cap). The capacity charge passes through to default supply rates in 13 states + DC. Residential bills in IL ComEd, OH, PA, NJ, MD, DC, VA, DE, WV, eastern KY, NC, IN, MI step up in June 2025 then again in June 2026.
B MISO: seasonal pressure, milder
MISO\'s Planning Resource Auction is seasonal. Summer 2024 cleared at the cap in some zones but the residential pass-through is more muted than PJM\'s footprint-wide RTO step. Ameren IL, Entergy LA, much of the Midwest see modest year-on-year movement.
C ERCOT: energy-only, RTC+B redesign
ERCOT has no capacity auction. The 5 December 2025 RTC+B launch split the system-wide offer cap into a $5,000/MWh day-ahead and $2,000/MWh real-time ceiling, and formally prices battery storage. Texas residential rates moved roughly with gas through 2024 to 2026; the next inflection will come from data-center load growth, not capacity auctions.
The takeaway: "US average residential electricity price" is increasingly a misleading abstraction. From 2024 onward, residential customers in PJM, MISO and ERCOT are paying for different things, with different pressure points and different upside risks.
Why the latest step matters more than the headlines suggest.
Three numbers tell the 2024-to-2026 story in residential pricing.
PJM 2026/27, /MW-day
22 July 2025 auction at the Net CONE cap. The largest single regulatory event repricing PJM residential supply in a decade.
US avg 2024 to 2026
From 16.49 ¢/kWh in 2024 to 18.83 ¢/kWh in March 2026; faster than CPI over the same period. PJM did most of the lifting.
PJM capacity bill, 2026/27
Total cleared supply times clearing price. Up 9.5% from $14.7B the year before. Passed through to retail customers from June 2026.
ERCOT RTC+B live
Real-Time Co-Optimization plus Batteries. Day-ahead cap at $5,000/MWh, real-time at $2,000. Repricing the spot market for batteries.
Three structural shifts behind the latest numbers
- A Data-center load growth. PJM\'s capacity tightness is largely about new demand from hyperscale data centers in Virginia (the Dominion zone), Ohio and northern Illinois. The auction is the signal to build new plants; until they show up, the price stays at the cap.
- B Coal and nuclear retirements outran replacement. Cheap gas drove the retirements through the 2010s; new gas-fired capacity is slower to permit and harder to finance in 2024 to 2026. The gap shows up as a capacity-clearing-price spike.
- C Transmission and resource-adequacy redesigns. PJM\'s new accreditation rules count thermal capacity differently. ERCOT\'s RTC+B prices batteries. MISO\'s seasonal auction is mid-transition. Each redesign produces a one-time step that is not a fuel-price effect.
Why the changing mix matters more than the headline number.
Four reasons the composition shift is the more useful story for household decisions.
A 15% supplier discount is now 6 to 8% off the bill
Because supply shrank to 40 to 50% of the all-in bill, the same percentage discount on the shoppable portion translates to roughly half that percentage on the total. A salesperson quoting "15% off your bill" is almost certainly comparing to the price-to-compare, not to the all-in. Always do the math.
Capacity charges are sticky
Wholesale energy can fall back as fast as it rose. Capacity prices, once cleared, are locked in for the delivery year. The PJM 2026/2027 step is now baked into PJM-state bills regardless of what Henry Hub does in 2026 or 2027.
Climate riders compound
CLCPA in New York, CEJA in Illinois, the California climate credit, the ZEC nuclear payments in NY and IL all carry surcharges that escalate by schedule. They are not market-clearing prices; they are legislatively set, and they go in one direction. The 2026 baseline is the floor, not the ceiling.
Regional divergence will widen
PJM, MISO and ERCOT diverged in 2024 to 2026. The trend will continue because the underlying market designs are diverging. A PJM-state retail offer will price the capacity step in; an ERCOT retail offer will not. National-average price quotes are now actively misleading for any individual household decision.
The honest answer to "where are US electricity prices heading" is: it depends on your ISO, your utility, your state\'s climate-policy stack and your usage profile. The headline US average is a journalist\'s metric, not a household one.
Six things you can actually do with the price trajectory.
Ignore national averages for personal decisions
The US average bundles 50 states and DC; it does not describe any one household. Use your state\'s number from EIA Table 5.6.A instead.
In PJM states, lock in before June 2026
A fixed-rate retail offer signed before the capacity step lands locks in the pre-step price for the term. Most 12- and 24-month products are available in PA, OH, IL, NJ, MD, DC.
Track the supply vs delivery split
Your bill breaks them out. Watch the year-on-year change in each line separately; a stable supply with rising delivery is a different story from a rising supply with stable delivery, and the response is different.
Use real (inflation-adjusted) numbers in long-term decisions
For solar payback, EV total cost of ownership, electrification ROI: convert to real terms. The headline nominal trajectory overstates the real burden by roughly the CPI compounding.
Check EIA STEO monthly
The Short-Term Energy Outlook is the closest the US has to an official forecast. It updates the second Tuesday of each month and explicitly addresses residential pricing.
In regulated states, follow the rate case
If you live in NC, SC, GA, AL, FL, ID, UT, WA or OR, there is no wholesale market to shop. Your only lever is the utility\'s next rate case at the state PUC. Consumer-advocate offices accept public comments.
Common questions about US electricity price evolution.
In nominal terms (no inflation adjustment) the US residential average has gone from roughly 8.2 ¢/kWh in 2000 to 18.83 ¢/kWh in March 2026 per EIA Table 5.6.A. That is roughly a 2.3x increase, or about 130%. In inflation-adjusted terms, using the BLS CPI, the real increase is closer to 25 to 30% over the same period.
It lowered wholesale prices, particularly between 2008 and 2020 thanks to cheap shale gas. It did not consistently lower retail bills for residential customers in most states. The reason is that wholesale supply is now only 40 to 50% of the all-in residential bill; the rest is regulated delivery, capacity and policy riders that no wholesale auction can compress. Texas (ERCOT) is the only state where retail competition produced sustained residential supply savings against a clear benchmark.
Three overlapping pressures. Winter Storm Uri (February 2021) exposed ERCOT to a $9,000/MWh real-time cap event lasting 87 hours. The 2022 European gas crisis pushed Henry Hub above $9/MMBtu briefly, repricing wholesale energy across every ISO. The PJM 2025/2026 and 2026/2027 capacity auctions (cleared 30 July 2024 and 22 July 2025) added a step to the capacity-charge component for 13 states. The 2024 to 2026 acceleration is not a single event but the sum of these three.
Nominal is the ¢/kWh you actually pay, with no adjustment for the changing value of money. Real (or inflation-adjusted) restates each year's nominal price in the dollars of a chosen reference year. The 2000-to-2026 US residential average went from 8.2 to 18.83 ¢/kWh nominal (a 2.3x rise) but only about a 25 to 30% rise in real terms once CPI is factored in. Most of the apparent "increase" since 2000 is just general inflation.
Three patterns. PJM states (IL ComEd, OH, PA, NJ, MD, DC, VA, DE, WV, eastern KY, NC, IN, MI) saw the largest capacity-driven step from June 2025 and again from June 2026. California went from ~22 ¢/kWh in 2020 to ~31 ¢/kWh in 2026, driven by wildfire-mitigation riders and IOU rate cases. Massachusetts, Connecticut and Rhode Island (ISO-NE) saw winter supply step-ups from gas dependence. Texas (ERCOT) and MISO states moved roughly with inflation; the Pacific Northwest and Mountain West moved least.
EIA's May 2026 Short-Term Energy Outlook projects the US residential average will end 2026 modestly above the March reading, driven mostly by the PJM 2026/2027 capacity pass-through hitting from June 2026. Wholesale energy is projected roughly flat as gas stays in the $3 to $4/MMBtu range. The 2027 outlook will firm up after the next PJM auction (expected 2026) and the next round of state rate cases.
It cleared 22 July 2025 at $329.17/MW-day, the maximum FERC allows under the new Net CONE cap. That is up 22% from the previous year's record of $269.92/MW-day, which was itself a 9-fold jump from $28.92. The supply bill PJM owes generators is now $16.1 billion for the delivery year, split across customers as a separate capacity charge. Source: PJM news release, 22 July 2025.
PJM has diverged from MISO and ERCOT since 2024. The PJM footprint is repricing capacity at the cap; MISO's seasonal auction prices a different product on a different schedule; ERCOT has no capacity auction at all and clears scarcity in the spot market. The same physical fuel (natural gas at Henry Hub) produces three different residential price trajectories in PJM, MISO and ERCOT because of the market design layered on top of it. See the FERC RTO map for footprints.
Keep learning about US energy prices
Electricity prices per kWh
EIA-verified state-by-state residential prices, top-5 and bottom-5, May 2026.
Natural gas prices per therm
State-by-state residential gas prices, unit conversions, typical winter bills.
Gas price evolution
Henry Hub spot vs city-gate vs residential retail, 2000 to 2026.
What is a wholesale electricity market?
The seven US ISO/RTOs, marginal pricing, the July 2025 PJM record auction.
Deregulated states map
Which US states have residential retail choice and which do not.
Fixed-rate energy offers
How a fixed-price retail contract actually hedges your kWh price.
Incumbent utilities
The 170 investor-owned utilities, 2,000 munis and 800-900 cooperatives that bill you.
Who regulates US energy?
FERC, the state PUCs, the consumer advocates, and where their jurisdictions meet.
How liberalization affects you
What retail choice means for residential customers, by state and ISO.
Texas energy hub
ERCOT, retail providers, rate plans, RTC+B and the kWh-threshold pricing trap.
New York: 1998 to 2026
NYISO, the Reset Order, the $50M ESCO settlement, and why Zone J prices higher.
Illinois: ComEd, Ameren and PJM
Why the PJM 2026/2027 auction lands hardest on ComEd customers.