Southern California Utilities Deploy Shutoffs as Climate Risk Rises; Infrastructure Investment Lags

Southern California Edison warned it could shut off power to nearly 10,000 customers in Riverside County on Friday and Saturday, while San Diego Gas & Electric flagged potential blackouts for more than 35,000 customers in "at-risk communities" near mountain foothills, as triple-digit heat and falling humidity crisp vegetation and drive wildfire risk across the region.^[1] The shutoffs, formally called Public Safety Power Shutoff (PSPS) events, are meant to de-energize lines before dangerous winds and dry conditions can spark a fire.^[2]

But the tactic reveals a deeper failure of grid maintenance and hardening. When a utility routinely cuts power to avoid equipment ignition, it signals that the equipment itself, the poles, lines, and vegetation clearance around them, has not been adequately maintained or upgraded to operate safely under the climate conditions that now arrive every autumn. Residents have begun asking the obvious question: if shutoffs happen regularly, why haven't the utilities buried the lines or upgraded the infrastructure that forces these cutoffs?^[6]

The answer lies partly in how California regulates utility spending. Under traditional cost-of-service rate setting, utilities recover a guaranteed return on the capital they invest in the grid, but they also collect allowances for operations and maintenance (O&M), including vegetation management and pole inspection, whether or not they spend the full amount authorized. If a utility collects a maintenance allowance for five years and spends less than authorized, the unspent cash can be retained as operating profit or distributed to shareholders. This structure creates no penalty for deferring maintenance that keeps the grid functioning under blue-sky conditions but fails when the weather turns extreme.^[3] The question, whether SCE and SDG&E have systematically underspent on vegetation management and pole maintenance relative to amounts they requested and were granted in recent rate cases, can be answered only by examining the utilities' FERC Form 1 filings (which itemize O&M spending by account) against their own rate-case testimony showing what maintenance funding they sought. That audit trail is public and discoverable; this piece does not yet have those specific year-by-year figures and docket numbers.

What is plain from reliability data is the trend: as PSPS events have become routine, driven by climate-driven extreme weather days that spike outage minutes even as blue-sky reliability metrics remain flat, the utilities have increasingly asked regulators for hardening surcharges, asking ratepayers to fund the grid upgrade that should have been funded from maintenance allowances already collected.^[3] Municipal utilities and rural cooperatives, which serve the same weather-stricken territories, typically report lower outage rates per dollar spent on distribution maintenance, suggesting that ownership structure and dividend pressure do shape maintenance priorities.^[3]

The fix is performance-based regulation: tie utility revenue explicitly to reliability outcomes (SAIDI and SAIFI targets) with symmetric penalties and rewards, and cap total spending allowances (capex plus O&M) so that every dollar of maintenance deferred is a dollar the utility forgoes. States like Hawaii have begun adopting this framework; California has not.^[3] Until reliability performance carries financial risk, shutoffs will remain cheaper than hardening, and the burden will fall on customers who lose power in the very conditions the utility was meant to protect against.