Electricity Bills Set to Rise Higher: LBNL Data Shows Retail Rates Outpacing Inflation Nationwide

The Lead & Key Findings

According to the report 2026 Retail Electricity Rate Trends and Drivers Update—authored by The Brattle Group and released this month by Lawrence Berkeley National Laboratory (LBNL)—retail electricity rates across the United States continue to rise. Data indicates that, after adjusting for inflation, the average U.S. retail electricity rate increased by 2.6% between 2024 and 2025. Since 2019, nominal residential electricity rates have surged by a cumulative 33%, while commercial and industrial rates have risen by 26% and 27%, respectively, further widening the price gap between residential and commercial/industrial end-users.

On the utility operations front, requests for rate hikes have reached a multi-decade high, with the total amount requested in 2025 alone hitting $18 billion. The report highlights that, between 2021 and 2025, state regulators approved 64% of the revenue increase requests submitted by electric utilities. Absent robust policy intervention or market-based adjustments, this 64% approval rate signals that retail electricity prices nationwide will face inevitable, sustained upward pressure in the near term.

Macro-level Electricity Price Trends: Contradictions, Divergence, and Historical Context

Divergence in Price Increases by End-User Type (C&I vs. Residential Gap): 

An analysis of the end-user structure reveals a significant divergence in retail rate inflation across different consumption sectors. Data from LBNL and The Brattle Group show that between 2019 and 2025, nominal residential electricity rates across the U.S. surged by 33%, whereas commercial and industrial rates rose by 26% and 27%, respectively.

This data reflects a long-standing and widening gap in electricity prices between residential and Commercial & Industrial (C&I) customers. When recovering costs associated with grid upgrades, operations, and maintenance, utility companies often shift a larger share of fixed costs onto the residential sector—a segment with limited bargaining power.

Notably, a cross-comparison reveals that while the pace of residential retail price increases significantly outstripped the general inflation rate (representing an inflation-adjusted real increase of approximately 5.6%), these hikes remained lower than the concurrent surge in residential natural gas prices. This indicates that within the broader energy market, electricity costs—despite their rise—have maintained a degree of relative stability compared to directly combusted fossil fuels like natural gas.

Historical Context from a Macro Perspective (The Macro Paradox)

When viewed over a longer timeframe, U.S. electricity cost metrics reveal a seemingly contradictory macro-level phenomenon.

Long-term real electricity prices remain at historical lows:

Although inflation-adjusted average electricity prices in the U.S. are approximately 3% higher than in 2019, real prices in 2025 are actually 6% lower than the 2010 baseline. This demonstrates that, over the course of several decades, technological advancements and improvements in power generation efficiency have largely offset increases in nominal prices.

Divergence between total electricity cost burden and regional variations:

The report indicates that in 2025, household electricity spending accounted for approximately 1.25% of total household expenditures—a figure that remains near an all-time low. However, this macro-level "national average" severely masks stark regional price disparities. In California, the Northeast, and parts of the Mid-Atlantic, surging electricity prices and the resulting financial burden have become an unbearable weight for local residents and businesses; conversely, some states in the South and Midwest enjoy relatively stable rates, thanks to factors such as load growth and their local energy mixes.

Deconstructing the Drivers: Underlying Structural Causes of Rising Electricity Prices

Transmission & Distribution (T&D) Investment and Wildfire Mitigation

The primary factor driving the recent rise in retail electricity prices is not merely the cost of generation, but rather the massive expenditure on grid infrastructure. Research by LBNL identifies Transmission and Distribution (T&D) spending as the leading driver of rate inflation across multiple states. As aging grids face pressure to modernize, investor-owned utilities (IOUs) have significantly increased their capital expenditures (CAPEX).

California serves as a prime example: wildfire risks exacerbated by climate change have compelled utilities to invest billions of dollars in wildfire mitigation programs. These measures include insulating power lines, burying equipment underground, and managing Public Safety Power Shutoffs (PSPS) during high-risk weather conditions. These substantial operating expenses (OPEX) and capital expenditures are ultimately approved by regulators and passed on to end-users in the form of utility rate hikes.

Natural Disaster Restoration and Grid Rebuilding (Storm Cost Recovery)

Beyond long-term grid upgrades, sudden damage caused by extreme weather events is another significant variable driving up retail electric rates. Reports have highlighted the mechanisms for recovering infrastructure repair costs following extreme weather events.

Maine provides a case in point: destructive storms in 2024 caused widespread outages across the local distribution grid. To rebuild the grid infrastructure and restore service reliability, utility companies initiated statutory cost-recovery procedures. This short-term capital investment, necessitated by extreme weather, directly drove up residential electricity rates in the state for the 2024–2025 period.

Spillover Effects from Wholesale Markets and Distributed Energy Subsidies (Market & Policy Spillover)

In addition to costs associated with the physical grid, volatility in commodity markets and the spillover effects of policy-driven subsidy mechanisms also exert upward pressure on rates:

Natural Gas Prices and Wholesale Electricity Markets:

Driven by commodity market dynamics, volatility in natural gas prices translates directly into fluctuations in wholesale power prices. In regions where natural gas-fired generation sets the marginal clearing price, rising wholesale electricity prices have rapidly driven up retail-level power procurement costs.

Community Solar and Net Metering:

While policies supporting distributed energy resources drive decarbonization, they also result in structural cost shifts. Taking Northeastern states like Maine as an example, the rapid expansion of community solar projects relies on high Net Energy Metering (NEM) compensation rates. As the penetration of behind-the-meter (BTM) and community solar systems increases, utilities pass these policy-driven compensation costs on to standard grid customers who do not participate in solar projects, creating a significant cost-shifting effect.

Regional Disparities: National Electricity Price Map and Local Offsets

High-Increase Regional Hotspots

National average electricity price metrics mask extreme geographical disparities. Data from LBNL indicates that over the past seven years (2019–2025), California and several states in the Northeast and Mid-Atlantic regions experienced the most severe regional rate inflation.

Adjusted for inflation, California’s retail electricity rates surged by more than 6 cents per kWh. Although the state’s installed capacity of behind-the-meter solar has surpassed 20.5 GW (equivalent to 40% of the summer peak load forecast by the local independent system operator, CAISO), the decline in total retail electricity sales has further driven up the per-unit fixed costs borne by remaining grid customers. During the same period, real rates in Maine rose by over 4 cents per kWh, while electricity prices in New York, New Jersey, Massachusetts, Maryland, Connecticut, and Rhode Island increased by more than 2 cents per kWh.

Regions with Rate Relief and Offsetting Factors

In stark contrast to the high-increase areas, some states achieved rate stabilization or even reductions through localized commodity price fluctuations or policy design:

Renegotiation of Fuel Supply Contracts (Hawaii):

Electricity consumers in Hawaii saw rate relief in 2025. The state renegotiated fuel supply contracts to reflect the drop in global crude oil prices, directly lowering generation costs for the islands, which rely heavily on oil-fired power.

Implementation of Federal Tax Credits (North Carolina):

North Carolina benefited from new federal tax credits. Tax incentives targeting the state's existing nuclear fleet directly reduced nuclear operating costs, significantly tempering electricity expenses for end-users.

Comparison Table: Electricity Price Changes and Key Drivers in Major U.S. Regions

Livelihood and Social Impact: Class and Geographic Divides in "Energy Burden"

The Paradox of Heating Structures and Bill Burdens: North vs. South

Electricity rates do not directly equate to the actual expenditures of end-users; the composition of heating energy sources creates a distinct geographic divide. An LBNL report examining "household electricity burden" (the proportion of income spent on electricity) reveals a seemingly contradictory phenomenon: electric bill burdens in Southern states are often higher than in Northern states, even though the per-unit cost of electricity in the South is generally lower.

This disparity stems primarily from the vast difference in electric heating adoption rates. In the U.S. South, electric heating—combined with high demand for air conditioning during the summer—drives up total electricity consumption (kWh) and, consequently, total bills. In contrast, the vast majority of households across most of the North rely on propane, natural gas, or heating oil for warmth. While Northern households may appear to have lower electricity bills, the additional fuel expenditures—which are not captured in electricity statistics—constitute a hidden energy cost burden.

Exacerbated "Energy Poverty" Among Low-Income Populations (Socioeconomic Disparities)

From a socioeconomic perspective, rising electricity prices have disproportionately impacted low-income groups, significantly exacerbating inequality in energy burdens. LBNL data indicates that while the national average electricity burden has remained near historic lows since 2019, this figure masks the grim reality facing the lowest-income households:

Low-income households face significant financial pressure: Nearly one-third of U.S. households with annual incomes below $50,000 spend at least 5% of their total household income on electricity bills.

Electricity burdens for the lowest-income group continue to worsen in many states: Between 2019 and 2025, the electric bill burden for the bottom 20% of households trended upward in 27 states and the District of Columbia. Among them, low-income groups in Washington D.C., Pennsylvania, California, and Maryland experienced the sharpest increases in their burden.

Conclusion and Industry Outlook

Short- and Long-Term Outlook

Looking ahead, as state regulators finalize their reviews of pending utility rate hike requests, retail electricity rates across the U.S. are expected to remain high. Driven by essential capital expenditures—such as the modernization of aging grids, spending on transmission and distribution (T&D), and investments in grid climate resilience—there is extremely limited room for retail electricity prices to decline.

Industry Perspectives

The LBNL report highlights the profound contradictions inherent in the current energy transition, placing state Public Utility Commissions (PUCs) at a critical crossroads. Balancing the acceleration of grid decarbonization and the enhancement of resilience against disasters with the need to effectively manage the burden of electricity bills and ensure energy affordability for low-income populations will remain a formidable, long-term challenge for utility regulators and policymakers nationwide in the years to come.