RESEARCH · POWER
American power demand
is growing again
After two decades of flat load, US electricity demand rose 101 terawatt-hours in 2025 — the biggest one-year jump in a generation. And for the first time, a winter cold snap came within 10 GW of the summer peak. The whole year in two charts, with every number resolving to a SHA-256-verified EIA row.
Ask an agent how fast US electricity demand is growing and you'll get a confident number with no receipt. So here is the answer built from the raw record — every hour of 2025 rolled up into EIA's own national total, set against 2024, with each figure one call from the cell it came from. The answer: faster than it has in twenty years.
Two decades flat, then +101 terawatt-hours.
The Lower-48 consumed 4,297 TWh of electricity in 2025, up from 4,196 TWh in 2024 — an increase of 101 TWh in a single year. For context, that is roughly 88% of everything the entire New England grid uses in a year (115 TWh), added on top of what the country was already drawing. After a 2000s-to-early-2020s era when US load barely moved, the line has turned up.
source EIA Grid Monitor (EIA-930 rollup, US48) · series Adjusted demand · window 2024-01 → 2025-12 · sha256-verified raw · eia.gov ↗
One honest adjustment: 2024 was a leap year, so it had an extra day of load baked into its total. Correct for that and the picture is stronger, not weaker — average load rose 2.7% per hour, even as the headline reads +2.4%.
Ten of twelve months ran hotter than 2024.
The growth isn't one weather event — it's broad. In ten of twelve months, 2025 drew more average power than the same month a year earlier. Only May (−0.9%) and August (−1.5%) came in slightly below.
source EIA Grid Monitor (EIA-930 rollup, US48) · metric per-hour average load, leap-day-normalized · sha256-verified raw · eia.gov ↗
The biggest gains are in the cold months — February ran +9.6%, January +5.7%, December +4.4% — which a hard winter explains. But the quieter signal matters more: the mild shoulder months — March, April, September, October, November — all ran above 2024 too, with no weather to credit. When demand rises in months that have nothing to do with heating or cooling, you are looking at a higher baseline, not a hotter year.
Winter is catching summer.
For decades the US peak has been a summer story — air conditioning sets the highest day of the year, every year. In 2025 that near-monopoly cracked. A January cold snap came within ten gigawatts of the July heat wave.
10 GW separates the hottest and coldest days of the year — gauges scaled 400–700 GW
source EIA Grid Monitor (EIA-930 rollup, US48) · grain daily-average demand · sha256-verified raw · eia.gov ↗
Rank every day of 2025 by demand and the top four interleave the seasons: Jul 29 (640 GW), Jul 30 (632), Jan 22 (630), Jan 21 (627) — two summer days, two winter days, all inside a 13 GW band. A grid that has to be built for one annual peak now has to be built for two, six months apart. That is electrification showing up in the data: heat pumps, and the steady, weather-blind load underneath everything else.
The same heat wave, priced two ways.
The late-July heat event isn't only the year's demand peak. It shows up — independently — in a completely different dataset. As US48 load topped out on July 29, the wholesale market caught the strain the next evening: ERCOT's North hub day-ahead price hit $500/MWh in the July 30 peak hours (8–9pm), against a $95 daily average. One physical event, two cited sources that never reference each other — national demand from EIA, Texas prices from ERCOT — both pointing at the same week.
sources EIA-930 rollup (US48 demand, Jul 29) · ERCOT DAM settlement prices (HB_NORTH, 2025-07-30, HE 20–21) · both sha256-verified raw
What lifts demand in mild months, around the clock, is new always-on load. The most-cited candidate is the data-center buildout, and the platform shows that demand arriving directly rather than asking you to infer it: NYISO's load-interconnection queue alone carries ~14 GW of new demand requests. The growth is in this national series; the cause is one query deeper, in the queue. Neither asks you to take a number on faith.
Every number above is one call from a verified source row.
This isn't a narrative — it's auditable. Each figure resolves through get_source_evidence_v1, which re-opens the raw EIA file server-side, re-checks its SHA-256, and hands back the exact cell.
Built with the live exascale.build power API — the agent-ready OSINT layer for the US machine-economy buildout. Demand figures are EIA's own published US48 rollup (EIA-930 Grid Monitor, Adjusted series), served verbatim; annual totals sum hourly demand over the calendar year (2024 = 4,196.04 TWh / 8,784 hours; 2025 = 4,297.33 TWh / 8,760 hours). Monthly and peak figures are per-hour average load in GW, which normalizes for differing day counts. The 2024-vs-2025 total comparison is on raw annual sums; the +2.7% figure adjusts for 2024's leap day. Data through 2025-12-31; the most recent hours of any EIA series are preliminary and revised. Demand is a flow (MWh / average MW), never conflated with installed capacity (a stock).