U.S. electricity use for electric vehicles increasing at a slower pace in 2026

U.S. light-duty EV electricity consumption increased 8% in 1H26 versus 2H25, slowing materially from 13%-24% six-month growth rates in recent years. The deceleration followed a decline in EV sales after federal tax credits expired in September 2025. Despite the slowdown, EVs consumed nearly 14 billion kWh in 1H26, more than double usage in 1H23.

Analysis

The relevant earnings sensitivity is not the absolute load increase but the deceleration in incremental utilization. Public charging operators EVGO, CHPT and BLNK require rising sessions per port to absorb fixed network, depreciation and demand-charge costs; a slower vehicle-fleet ramp can defer breakeven by several quarters even if headline electricity demand remains positive. This is most acute for networks built ahead of demand in lower-density corridors, where utilization—not charger deployments—drives gross-margin inflection.

For automakers, the loss of purchase support shifts competition from demand creation to price, financing and lease-subsidy capacity. TSLA has the balance sheet and software/services gross profit to defend unit volume, but doing so through price or subsidized financing would pressure automotive gross margin; RIVN and legacy OEM EV programs at F and GM have less room to offset weaker retail affordability without higher incentives or lower production. The likely relative beneficiary over the next 6-18 months is TM, whose hybrid mix captures consumers trading down from full BEVs while avoiding dedicated-EV capacity underutilization.

The contrarian point is that fleet electricity consumption is a lagging stock measure and its deceleration partly reflects a larger installed base; it is insufficient evidence alone of a fresh collapse in current EV orders. Before expressing an OEM short, require corroboration from monthly registrations, dealer inventory days, lease-payment trends and 2027 production guidance. Utility load-growth implications are modest at the national level, but localized rate-base upside for charging-heavy utilities remains intact where managed charging can shift load into off-peak periods.

Key Decisions for Investors

• Maintain a 3-6 month short bias in EVGO and CHPT versus a long XLU hedge only after next reported utilization/session data confirms sequential deterioration; target 15-25% downside in charging equities if EBITDA-breakeven timelines move out, with thesis invalidated by sustained utilization growth and improving gross margin.
• Establish a 6-12 month long TM / short RIVN pair, sized beta-neutral: hybrid substitution and lower incentive dependence should support TM relative earnings resilience, while RIVN remains exposed to financing-sensitive discretionary demand and cash-burn valuation risk. Exit if RIVN demonstrates materially improved gross profit and order conversion without incremental incentives.
• For TSLA, avoid directional shorting solely on the demand signal; instead watch the next delivery release and automotive gross-margin guidance. A delivery miss accompanied by renewed price cuts would support 3-6 month downside puts, while stable deliveries with margin protection would falsify the bearish interpretation.
• Reduce exposure to F and GM EV-specific upside narratives until management quantifies incentive spending, EV inventory and production adjustments. Prefer their hybrid and ICE cash-flow exposure over pure-play charging infrastructure during the next two earnings cycles.