State agencies report improved short‑term electricity outlook but warn of mid‑term challenges and winter peaks

State energy officials and grid operators briefed the Assembly Committee on Utilities and Energy on California’s electric reliability outlook, saying recent procurement and operational changes reduce the likelihood of summer outages but that mid‑ and long‑term challenges remain.

Alice Reynolds, President of the California Public Utilities Commission, introduced agency roles and was joined by Siva Gunda (Vice Chair, California Energy Commission), Elliot Mainzer (President and CEO, California Independent System Operator), and Delphine Ho (Deputy Director for Statewide Energy, California Department of Water Resources). Reynolds summarized each agency’s responsibility for reliability planning, forecasting and emergency response.

Vice Chair Gunda reviewed the grid conditions that led to rotating outages in 2020 and near‑misses in 2022 and said the outcomes produced three priorities: improve planning to factor in climate change, accelerate procurement and construction of needed resources, and create contingency capacity. Gunda told the committee that after the 2020 outages agencies ‘‘identified three pieces’’ as root causes, including the speed of climate impacts and the need to adapt planning to more intermittent resources.

Elliot Mainzer said CAISO’s probabilistic analysis shows a summer surplus of about 1,450 megawatts under the 1‑in‑10 planning metric, and added CAISO’s deterministic stack analysis also suggests surplus capacity entering summer 2025. ‘‘We do have a surplus of capacity going to the summer of about 1,450 megawatts,’’ Mainzer told the committee, while cautioning that overlapping heat and wildfire events remain a risk.

Panelists credited several near‑term changes for improved summer readiness: more than 25 gigawatts of new capacity online or contracted since 2020 (including a record 7 gigawatts added in 2024), roughly 11 gigawatts of battery storage installed across the CAISO footprint, and contingency programs such as the Department of Water Resources’ Strategic Reliability Reserve (which has provided nearly 3,000 megawatts of contingency capacity). Delphine Ho noted that DWR manages a portion of those contingency resources.

Speakers also highlighted reforms to interconnection and transmission processes intended to speed project delivery. CAISO described queue reforms approved by the Federal Energy Regulatory Commission in September 2024 that have cleared roughly two‑thirds of older, speculative interconnection requests. The CPUC described updates to General Order 131‑E to streamline permitting for transmission and substation projects and to encourage pre‑filing consultation to reduce rework.

While the short‑term summer outlook was described as ‘‘cautiously optimistic,’’ panelists repeatedly warned of tougher mid‑ and long‑term conditions. The Energy Commission’s demand forecast shows as much as 21 gigawatts of new peak load over the next 15 years driven by electric vehicles, building electrification and data centers; the commission said winter peaks will grow and that planners must prepare for ‘‘dual peaks’’ (summer and winter). Sonoma Clean Power’s Ryan Tracy told the committee his service territory is already seeing winter and summer peaks converge and urged immediate action on clean firm resources to avoid reliance on costly natural‑gas backup.

Multiple witnesses said the state needs more clean firm capacity — geothermal, long‑duration storage and other dispatchable options — to sustain winter reliability as electrification expands. Tracy and other panelists suggested incentives, earlier deployment funding, and changes to deliverability rules (which now focus on summer conditions) as steps to support clean firm resource development.

Panelists from investor‑owned utilities and municipal utilities described operational readiness and local differences. PG&E cited large hydro resources, battery capacity and Diablo Canyon unit extension as contributors to summer reliability but warned of tariffs, supply chain uncertainty and permitting delays. The Los Angeles Department of Water and Power said it plans conservatively for peak load and will repower in‑basin thermal units scheduled to retire by 2029 to maintain local reliability.

Speakers also stressed the value of broader Western market coordination. CAISO and several speakers described the Western Energy Imbalance Market and the extended day‑ahead market as tools that have produced substantial production‑cost savings (CAISO cited nearly $7 billion in savings regionally over recent years) and recommended further regional market development to improve both affordability and reliability.

Committee members asked about specific risks and policy choices, including possible extensions of existing firm resources (such as the Diablo Canyon nuclear units), the role of data‑center demand in future planning, the cost‑effectiveness of transmission investments, and the merits of simplifying overlapping planning and procurement programs across state agencies.

No formal action was taken; the hearing served as oversight and as a public update on coordination among CAISO, CPUC, CEC and DWR. Witnesses asked for continued legislative support for transmission permitting reform, transmission financing and targeted incentives for clean firm resources to address winter reliability.

The committee adjourned after public comment and thanked witnesses for the coordinated presentation.