Little Hoover Commission hears experts: wildfire hardening, distribution upgrades and rate-funded programs driving higher electricity bills

The Little Hoover Commission on Feb. 27 heard testimony that most of California’s recent retail electricity increases are driven not by the wholesale cost of power but by fixed, bill-funded programs and distribution upgrades tied to wildfire risk and other public-purpose policies.

At a virtual public hearing chaired by Pedro Nava, commissioners invited academic, consumer‑advocate and rural county witnesses to explain why residential bills have climbed — and to propose options for reducing the burden on ratepayers.

Commissioners were told the scale of the issue matters: “The total revenues required for the 3 investor owned utilities is about $60,000,000,000 a year for 2024,” said Severin Borenstein, professor and faculty director of the Energy Institute at UC Berkeley’s Haas School of Business. “Most of the increases are not California’s attempt to reduce California’s greenhouse gas emissions. Most of the increases are due to things that climate change is already doing to California, and most of that is wildfires.”

Why it matters: Many Californians face sharply higher monthly bills, particularly in hot inland regions where air‑conditioning drives seasonal spikes. Witnesses warned those increases can push households into arrears and worsen affordability for low‑income residents and renters who cannot access rooftop solar.

Experts’ diagnoses: fixed costs, wildfire and cross‑subsidies

Professor Borenstein and Matthew Friedman, staff attorney at the Utility Reform Network (TURN), said wholesale generation prices have been relatively stable in recent years and cannot explain the recent retail jumps. Instead, they singled out three categories that flow through bills: costs tied to public‑purpose programs and subsidies, distribution and grid hardening to reduce wildfire risk, and certain legacy contracts and capital investments pushed onto ratepayers.

Borenstein said distribution upgrades and wildfire liability — including the effects of inverse condemnation — are a major driver: utility expenses for vegetation management, covered conductor and undergrounding are collected through customer rates after liability and recovery rules. Friedman told the commission that wildfire mitigation spending has become a large share of some utilities’ revenue requirements and that potential wildfire liability could generate multibillion‑dollar exposures that would further pressure rates if existing backstops are exhausted.

On rooftop solar and net metering, witnesses diverged on scale but agreed the interaction matters. Borenstein estimated the residential cost shift from rooftop solar in 2024 at about $4 billion per year (the CPUC public advocate’s office has a larger estimate); he said that if customers buy less from the grid, the remaining customers must cover the same fixed revenue requirement. Friedman echoed concerns that legacy net‑metering protections and high retail tariffs create a “cost shift” if compensation remains tied to rising retail rates.

Rural impacts and low‑income concerns

John Kennedy, senior policy advocate for the Rural County Representatives of California, and Lee Kamrick, policy advocate for the same organization, described how low population density, greater wildfire risk and groundwater pumping in many rural counties combine to raise bills and limit access to resilience measures. “Many of these low, moderate, and fixed income households have been unable to cope with the multiple rate increases,” Kennedy said, noting risks to medically dependent residents and to small businesses.

Proposed responses discussed

Witnesses proposed several policy levers: moving some program costs to the state general fund or other non‑ratepayer sources (for example, using more cap‑and‑trade or state budget funding for public‑purpose programs), securitizing certain utility investments, expanding public ownership or alternative financing for transmission, and reforming net‑metering legacy protections.

“We think that the utility should be directed to apply up to $15,000,000,000 in securitization to offset shareholder investments in new capital investments for wildfire mitigation and for the cost of connecting customers to the grid,” Friedman told commissioners, arguing that securitization could cut financing costs relative to traditional utility debt and equity. He also urged stricter oversight of capital spending by the California Public Utilities Commission (CPUC).

Counterpoints from industry and community groups

Public commenters and stakeholder representatives offered competing perspectives. Rocky Fernandez of the Center for Sustainable Energy said an important recent change is that “ratepayer collections for SGIP actually ended as of December 31 of last year,” noting the program’s transition to other funding in some territories and stressing program specifics and timing matter for assessing who pays what.

Representing rooftop solar interests, Richard McCann of the California Solar and Storage Association disputed the magnitude and attribution of cost shifts in some analyses and urged deeper technical review. “Peak loads have been relatively constant for 20 years, thanks to rooftop solar,” he said in public comment, arguing that distributed generation can reduce system peak and the need for some upgrades.

What the commission will do next

The hearing was the first in a series. Commissioners asked for more granular breakdowns — for example, separating generation, transmission and distribution costs — and signaled further panels on utilities, the CPUC and other stakeholders. The Commission scheduled the next hearing on this topic for March 27, 2025.

Ending note: witnesses emphasized trade‑offs. Multiple speakers told commissioners that removing costs from rates would usually shift them to taxpayers via the state budget, which raises questions of equity and fiscal priorities. As Borenstein put it, “The distinction is not as clear as you might think,” and the Commission’s follow‑up hearings are likely to test the political and fiscal feasibility of the proposals under discussion.