Average US Electricity Prices Rose 9% Year over Year in February: EIA

Why It Matters

Higher retail electricity rates pressure household budgets and corporate operating costs, while the shift in fuel mix signals evolving supply dynamics for utilities and investors.

Key Takeaways

• Average U.S. electricity revenue per kWh up 9% YoY in Feb 2026.
• Virginia saw the steepest price jump at 26.3% YoY.
• Transportation sector led price gains, rising 23.6% YoY.
• Coal use fell 11.3% while natural gas rose 1.5% in Feb.
• 31 states reported higher retail sales volume; Montana fell 10.8%.

Pulse Analysis

The 9% year‑over‑year increase in electricity revenue per kilowatt‑hour marks the steepest annual rise since the early 2020s, reflecting a confluence of higher fuel costs, weather‑driven demand spikes, and lingering supply chain constraints. While the headline figure of 14.36 cents/kWh may appear modest, it translates into billions of dollars of additional revenue for utilities and, more importantly, higher bills for end‑users across the nation. Analysts are watching whether this upward trajectory will persist as the Federal Energy Regulatory Commission evaluates rate cases and as the market digests ongoing natural‑gas price volatility.

Sector‑level data reveal that the transportation segment—largely powered by electric vehicles and freight electrification—experienced the largest price surge at 23.6%, outpacing commercial (10.7%), industrial (8.6%) and residential (7.4%) gains. Regional disparities are stark: Virginia, Ohio and Pennsylvania posted double‑digit jumps, driven by localized grid constraints and colder-than‑average temperatures in the East. Meanwhile, 31 states saw higher retail sales volumes, indicating robust consumption despite price pressure, while Montana’s 10.8% decline underscores the uneven geographic impact of weather patterns and economic activity.

The fuel‑mix shift—an 11.3% drop in coal use and a modest 1.5% rise in natural‑gas generation—highlights the continued transition toward cleaner generation sources, even as short‑term price signals remain volatile. Investors should monitor utility earnings reports for margin compression and potential rate‑case outcomes, while policymakers may need to balance consumer protection with incentives for renewable capacity. As the nation approaches the summer peak, the interplay between wholesale price spreads, regional demand spikes, and evolving generation portfolios will shape the next cycle of electricity pricing.