CAISO Resource Adequacy: Forecasts, RA Market Insights & Merchant Curves

Last updated: April 2026. Reviewed quarterly alongside Noreva’s merchant curve releases.

CAISO operates California’s wholesale electricity market, one of the most dynamic and policy-driven power markets in the world. Unlike PJM, MISO, or ISO-NE, CAISO does not operate a traditional centralized forward capacity auction. Instead, California’s capacity market is structured around the Resource Adequacy (RA) framework, under which Load Serving Entities (LSEs) must procure sufficient capacity to meet customer demand plus a reliability reserve margin. RA obligations sit at the center of project finance, valuation, and procurement strategy across California.

The RA framework is complex, multi-layered, and subject to continuous regulatory evolution driven by California’s clean energy transition. For developers, lenders, investors, and utilities active in the state, understanding how RA obligations interact with market prices is essential.

Noreva provides institutional-grade CAISO capacity data and forward-looking RA market forecasts, covering all layers of California’s resource adequacy framework.

California’s Resource Adequacy Framework: How It Works

California’s RA framework imposes three core capacity obligations on LSEs, System RA, Flexible RA, and Local RA, plus the forward-looking Mid-Term Reliability (MTR) procurement program. Each addresses a different aspect of grid reliability.

System RA is the base Resource Adequacy obligation. Each Load-Serving Entity (LSE) must procure sufficient capacity to serve its forecasted load plus a 15% reserve margin, both on an annual and monthly basis. It is the broadest RA category and can generally be satisfied through resources located within CAISO or through qualifying external imports.

In this study, the modeled product is 24/7 Monthly System RA. Therefore, System RA serves as the central compliance layer for our analysis. Other RA categories may be discussed for contextual purposes, but the price forecasts provided in this report refer specifically to 24/7 Monthly System RA.

Flexible RA addresses California’s defining operational challenge: integrating large volumes of solar and wind while maintaining reliability during rapid changes in net load. It is designed for resources that can respond quickly to the evening ramp created by the duck curve, including batteries, pumped hydro, gas peakers, and demand response. The duck curve dynamic and its implications for California’s resource mix are explored in The CAISO Duck Curve Explained.

Local RA addresses transmission constraints and local reliability needs inside constrained areas that cannot always be served by imports. California’s local RA zones include Greater Los Angeles, San Diego, Big Creek/Ventura, and others. Resources located inside these constrained areas can command a local RA premium because they are locally deliverable to load. This is California’s expression of locational capacity value.

The California Public Utilities Commission manages the annual RA compliance cycle, but LSEs must also demonstrate monthly RA compliance. That monthly structure matters because seasonal tightness can make summer or shoulder-month prices diverge sharply from annual averages.

RA Type

What It Covers

Who Can Qualify

Procurement Horizon

System RA

Load + 15% reserve margin, system-wide

Any CAISO or qualifying import resource

Annual + monthly

Flexible RA

Fast-ramping capacity for the duck curve evening ramp

Batteries, pumped hydro, gas peakers, demand response

Annual + monthly

Local RA

Reliability inside transmission-constrained zones

Resources physically inside the constrained zone

Annual + monthly

Mid-Term Reliability (MTR)

Forward adequacy procurement supporting future reliability

New or existing resources with multi-year forward commitments

3 to 5 years forward

What Is CAISO Mid-Term Reliability (MTR)?

Recognizing that annual RA procurement does not always provide sufficient lead time for new resources to enter service, California regulators developed the Mid-Term Reliability (MTR) procurement program. MTR provides a more forward-looking RA signal, designed to support new project development and bankable underwriting.

MTR has become increasingly important as California manages a changing generation mix, thermal retirements, rapid battery deployment, and tightening evening reliability conditions.

What Drives CAISO Capacity Prices?

CAISO capacity prices are primarily driven by the balance between accredited supply and forecasted reliability demand. On the supply side, prices are shaped by California’s changing fuel mix, resource accreditation rules, and state clean energy policy. On the demand side, the main driver is the load forecast used to determine RA procurement obligations.

Changing Fuel Mix

California’s resource mix has changed significantly with the rapid growth of solar and battery storage, alongside continued pressure on conventional thermal generation. High solar penetration has contributed to the “duck curve,” where net load falls during midday hours and rises sharply in the evening as solar generation declines while demand remains elevated. This increases the reliability value of flexible resources such as battery storage, fast-ramping gas plants, and demand response.

Thermal retirement pressure also affects available RA supply. California’s Once-Through Cooling (OTC) regulations have contributed to the retirement pressure on older coastal gas-fired power plants. Although the planned retirement of Diablo Canyon was postponed under SB 846 due to reliability concerns, thermal retirements remain an important structural driver of RA market tightness.

Battery storage has become a major component of California’s capacity mix. California remains one of the largest U.S. battery storage markets, with more than 16,900 MW of installed battery storage reported by the California Energy Commission by mid-2025. However, this figure includes residential, commercial, and utility-scale installations, so it should not be treated as fully equivalent to RA-eligible capacity. Batteries now support system reliability by shifting energy across the day and providing flexible capacity during tighter system hours.

 

Accreditation

Installed capacity does not translate directly into RA value. Resources receive different accredited capacity values depending on their expected contribution to reliability during critical system conditions. Flexible and dispatchable resources, such as batteries and thermal plants, generally receive stronger accreditation than variable renewable resources, while solar and wind receive lower accredited values because their output depends on weather conditions and time of day.

Seasonality is also important. A resource’s RA value can vary by month depending on its expected availability and contribution to system reliability. Under California’s RA framework, Net Qualifying Capacity and Slice-of-Day rules are central to determining how resources count toward RA obligations. The CPUC’s 2025 RA guide presents the Slice-of-Day framework used for RA compliance. For batteries, accreditation expectations are central to revenue modeling because the marginal reliability contribution of additional storage can change as storage penetration increases.

 

State Clean Energy Policy

California’s clean energy policy framework also shapes RA supply. The Integrated Resource Planning process, CPUC procurement orders, and long-term decarbonization objectives influence both new resource development and retirement timelines. Therefore, CAISO RA prices cannot be analyzed only through market fundamentals; the policy pipeline must also be considered.

Load Forecast

On the demand side, RA procurement requirements are mainly driven by load forecasts. Load-Serving Entities must procure enough accredited capacity to meet expected demand plus the applicable reserve margin. When load forecasts increase, RA obligations rise, which can tighten the market and put upward pressure on capacity prices.

Future load growth from electrification, electric vehicles, weather volatility, and economic activity therefore represents a key demand-side driver for CAISO capacity prices.

How Does RA Capacity Trade in CAISO?

Because CAISO does not run a centralized forward capacity auction, RA capacity is procured bilaterally through contracts between LSEs and generators. Prices are negotiated rather than auction-cleared, which makes markets more opaque than PJM, ISO-NE, and other capacity markets. Key reference prices include:

  • Annual System RA: Typically influenced by CPUC procurement rules and compliance needs. Indicative values have historically fallen in the $3 to $8/kW-month range in adequately supplied periods.
  • Monthly System RA (summer): Summer months, especially July to September, can trade at significant premiums because of evening ramp scarcity.

RA Product

Typical Range

Key Driver

Annual System RA

$3 to $10 / kW-month

LSE compliance needs, CPUC procurement targets

Monthly System RA (summer)

$6 to $20+ / kW-month

Solar drop-off, AC load, evening ramp scarcity

Monthly System RA (Winter)

$2 to $6 / kW-month

Lower peak demand, reduced cooling load, weaker seasonal scarcity

Noreva’s CAISO Capacity Coverage

Noreva’s CAISO capacity datasets provide forward-looking RA price signals at monthly and annualized granularity over the forward 25-year horizon. Forecasts are calibrated to California’s interconnection queue, retirement schedules, and load trajectory.

In California, the firm-versus-deliverable distinction is expressed through Local RA versus System RA. Local RA is the premium product: capacity located inside a transmission-constrained zone with deliverability to local load. System RA is the broader product, deliverable system-wide but not tied to specific constrained-zone transmission rights. For this report, the forecasted product is best understood as a general unit of CAISO RA capacity, most likely 24/7 Monthly System RA, unless otherwise specified. Local RA may be discussed for context, but the forecasts do not separately model a Local RA premium at this stage.

Why Noreva for CAISO Capacity Forecasting

Noreva combines fundamentals-based modeling with trader-informed pricing inputs, a methodology no other CAISO capacity data provider offers at this depth. Learn more about Noreva and the broader capacity services we offer. Our CAISO coverage is built around five differentiators:

  • Fundamentals + transactional insights: We pair our in-house supply, demand, and policy modeling with live broker inputs and bilateral transaction data sourced through our sister company Karbone, which has 15+ years of RA trading and origination experience. Most data providers rely on fundamentals alone; in a bilateral market like CAISO, Noreva ties forecasts directly to where System RA, Flexible RA, and Local RA are actually trading.
  • Low / Base / High scenarios: Every CAISO forecast ships with three calibrated scenarios, enabling risk teams, lenders, and developers to stress-test assumptions on load growth, supply buildout, thermal retirement pace, IRP procurement rules, and MTR deployment without re-running the model.
  • Full data stack through Noreva Data Hub and API: Historical RA pricing, weekly marks, weekly forwards, and monthly and annual system RA merchant curves, all accessible through the Noreva Data Hub or directly via API for integration into risk and finance models.
  • Advisory layer: Beyond data, Noreva supports clients with asset valuation reports, pro-forma reviews, RA procurement strategy, bilateral contract structuring, origination advisory, and project benchmarking, drawing on Karbone’s direct California market experience.

Use Cases: Who Relies on CAISO Capacity Data

California’s dominant development model pairs solar with co-located storage. The storage revenue stack can include energy arbitrage, ancillary services, and RA payments. Noreva’s CAISO forecasts support underwriting of that full stack.

Standalone batteries in CAISO derive a large share of value from energy arbitrage and RA payments. Noreva’s forward RA price signals help developers model how that balance may evolve as the battery fleet expands.

Project finance requires a defensible RA revenue assumption that accounts for seasonality, regional premiums, and regulatory sensitivity testing. The rigor of capacity price forecasting is central to debt sizing and DSCR modeling forassets.

LSEs must comply with CPUC RA requirements annually and monthly. Forward RA price views help inform procurement timing, bilateral contract strategy, and the mix between annual and monthly procurement.

CAISO Capacity Market: Key Concepts

How CAISO Compares to Other US Capacity Markets

US Capacity Market Design Comparison

Market

Auction Format

Procurement Horizon

Commitment Period

Locational Granularity

Performance Obligation

CAISO

Bilateral (no centralized auction)

Annual + monthly + 3 to 5yr (MTR)

Annual + monthly

System / Local RA zones

RA showings

ISO-NE

Descending clock, transitioning to prompt/seasonal at FCA 19

~3 years forward currently; prompt from FCA 19

Annual currently; seasonal from FCA 19

System + CT, ME zones

Pay-for-Performance

MISO

Bilateral + seasonal PRA

Annual

Four seasons

10 Local Resource Zones

ELCC + accreditation

NYISO

Spot + strip + bilateral

Seasonal, Monthly, Monthly-Spot

Summer / Winter capability periods

NYC, LHV, LI, ROS localities

UCAP derating + ICAP demand curve

PJM

Sealed-bid (BRA) + bilateral

~3 years forward

Annual

RTO + LDAs

Capacity Performance

SPP

Bilateral

Annual

Summer + Winter

System + sub-zones

ELCC & PBA

For broader market commentary across all US capacity markets, see Noreva’s Market Views.

Frequently Asked Questions: CAISO Capacity

No. CAISO does not operate a centralized forward capacity auction. Instead, California relies on Resource Adequacy obligations that LSEs satisfy through bilateral procurement under CPUC requirements.

System RA is the base obligation to serve load plus reserves. Flexible RA is designed for fast-ramping resources that can manage the duck-curve evening ramp. Local RA is capacity located in transmission-constrained zones that cannot always be served by imports.

California’s solar fleet creates low-price midday conditions and a steep evening ramp. Resources that can provide reliability during that evening period, especially batteries and fast-ramping dispatchable resources, tend to command the strongest RA premiums.

The MTR program requires LSEs to procure capacity 3 to 5 years forward, creating a more bankable forward revenue signal for new development. MTR connects directly to reliability planning and project finance relevance following California’s recent stress events.

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oreva’s CAISO capacity datasets cover Annual System RA and Monthly Deliveries with monthly seasonality and long-term merchant curves, directly usable for California project finance, asset valuation, and procurement strategy.

To learn how Noreva’s CAISO capacity data can support your California project finance, asset valuation, or procurement strategy, book a demo with our team.