CAISO Draft LCR Report: LA Basin Capacity Is Getting More Expensive

The CAISO's Draft 2027 Local Capacity Technical Report, filed April 3 in R.25-10-003, finds that total local capacity requirements in California will increase by approximately 602 MW (2.6%) from 2026 to 2027, reaching 23,618 MW across CAISO-defined local areas.

The study follows the prior-year methodology:

• 1-in-10 summer peak load forecast;
• N-1/N-1-1/N-2 contingency criteria; and
• NERC/WECC planning standards.

Changes are locational, not uniform. LCR needs will decline in North Coast/North Bay, Big Creek/Ventura, Fresno, Stockton, Kern, and San Diego/Imperial Valley, driven by lower load forecasts, new transmission projects, and shifting contingency conditions.

Needs will increase in Humboldt, Bay Area, Sierra, and the LA Basin. The Greater Bay Area carries the largest raw requirement (8,315 MW), but the LA Basin (at 6,823 MW) has a more revealing story. Greater Fresno follows at 2,090 MW. Several areas carry asterisked resource deficiencies, meaning load shedding is possible immediately following a first contingency at summer peak absent sufficient local procurement.

Non-study estimates (no technical analysis conducted) show 2028 needs at 24,545 MW and 2029 at 25,480 MW, with the 2031 studied estimate reaching 26,271 MW.

An April 3 ALJ ruling grants the CAISO's motion to shift the draft LCR comment deadline from April 16 to April 20, with all subsequent milestones unchanged: the final LCR report is due May 1, comments May 8, reply comments May 13.

INSTANT ANALYSIS

The LA Basin's LCR increase is not primarily a load story. Re-rating of bulk transmission facilities is the driver, and unlike load forecasts, transmission ratings, once established, tend not to move. That makes this year's Basin requirement harder to reverse than the headline MW figure suggests, and raises the floor on procurement in that zone.

The Basin is where constraint, siting difficulty, and transmission limits combine to create genuine capacity scarcity, the conditions that concentrate value and protect incumbents. New entrants there face permitting, siting, and interconnection barriers that existing resources don't. That gap is widening, not narrowing.

The offsetting story is Stockton and Kern. New transmission is compressing local capacity value in both areas. That split widens through the 2028–2029 non-study estimates and shows no sign of closing.

The resource deficiency designations are not academic. They mean a single contingency at summer peak can force load shedding if local procurement falls short. Those areas represent the CPUC's highest near-term reliability exposure and the clearest trigger for CAISO backstop procurement if LSEs underperform.

Procedure-wise: April 20 is the only opportunity to move the record. By May, it will be closed.

WHO IS MOST AFFECTED?

• Load-serving entities/Community Choice Aggregators (LA Basin): Procurement risk is rising in a zone where requirements are unlikely to reverse quickly, and thin or delayed procurement increases exposure to CAISO backstop capacity and unfavorable bilateral pricing.
• Existing in-basin generation (LA Basin): Incumbents' position strengthens because requirements are rising for structural reasons (transmission re-ratings, not load drift) that are hard to undo, making capacity already sited in the Basin harder to substitute and supporting pricing power.
• Developers (new build/storage): Location is the decision that matters most here: constrained load pockets will retain value while areas seeing transmission relief (Stockton, Kern) face compression, and interconnection timelines remain the binding constraint on new entry.
• Traders/capacity buyers: Local area divergence is widening as the Basin tightens and transmission-relieved zones soften, which should produce more pronounced local price separation and fewer substitutes for Basin capacity.
• CPUC: Resource deficiency designations across multiple areas mean a single contingency at summer peak can trigger load shedding, and if LSE procurement falls short, backstop costs will flow back to ratepayers through cost allocation.