Resource Adequacy Explained: 5 Building Blocks and Risks

U.S. power markets are struggling to secure the new generation investments needed to keep pace with surging load growth. While plenty of capital is ready to be deployed, traditional risk-hedging mechanisms still reflect an era of flat demand and abundant thermal supply. Resource adequacy frameworks need to adapt to rapid load growth, or market volatility will increase.

The North American Electric Reliability Corporation’s (NERC) 1-day-in-10-year loss of load expectation (LOLE) sets a national benchmark for reliability, which can be met in several ways. The specific capacity procurement frameworks used to reach this target vary widely across the different markets. Ultimately, success in building profitable new generation will depend on mastering each region’s unique capacity rules and effectively hedging against market exposure.

North American power markets are now widely recognized as facing tight supply-demand conditions, largely driven by demand from hyperscalers. Still, navigating current price signals and overcoming hurdles to encourage new entry is difficult. 

Is there a gold standard for hedging risk when building new capacity? Before evaluating specific market structures, let’s look at the shared underlying challenge across all power markets in North America.

The General Problem Facing Resource Adequacy

As power markets transition from managing surplus supply to navigating scarcity conditions with tight reserve margins, the risks associated with resource adequacy and capital investment have changed. These issues have moved from technical working groups into broader public discussion, yet the mechanics of aligning projected demand with adequate physical supply are frequently oversimplified.

U.S. power markets are under pressure from two directions.

On one side, large energy consumers such as hyperscalers and industrial facilities are eager to interconnect and secure firm, non-interruptible power. They are ready to commit substantial capital to accelerate “speed to power,” even in supply-constrained regions. Market reforms will consider the “speed to power” need by enabling innovative ways to incentivize new capacity quickly. Where capacity is already sufficient, markets need clear market signals to attract new load so new capacity can help spread fixed infrastructure costs across a larger base and lower retail rates overall.

On the other side, consumers and regulators seek protection from volatile costs of power, often without realizing that price increases are a result of capacity market dynamics rather than spot energy prices. Because end-use retail customers consume energy rather than capacity, these nuances can easily cause confusion. The “speed to power” agenda can pressure capacity and planning efforts, exposing ratepayers to uneconomic generation and stranded infrastructure. In response, market rules are evolving to maintain system reliability through least-cost optimization.

The Core Building Blocks of a Resource Adequacy Framework

Below, we’ll break down the core building blocks of a resource adequacy framework. By understanding how each step works in the overall process, and the specific risks tied to each step, you’ll be far better equipped to evaluate investment opportunities as market reforms unfold.

1. Load Forecast

Each participant responsible for serving load calculates a load forecast that is submitted to the governing body, which aggregates and adjusts to account for uncertainty and double-counting.

Risk tradeoff: Load Serving Entities may be inclined to over-forecast to secure sufficient capital and margin, but this increases the risk of overbuilding and stranded infrastructure.

2. Reserve Requirements

Once projected demand is established, the system mandates a surplus of capacity, known as reserves, to cover contingencies and operational uncertainty. This will ensure compliance with NERC’s LOLE reliability standard.

Risk tradeoff: System operators must ensure sufficient generation can be delivered across the footprint during peak stress periods. Defining these risk periods is shifting rapidly, exposing generation and load during winter and high-ramp hours.

3. Accreditation

To prevent the over-procurement of specific resource types, markets are transitioning from simple forced-outage metrics to sophisticated accreditation models. These models reflect a resource’s actual contribution to reliability during critical risk periods, recognizing that the value of a megawatt fluctuates over time.

Risk tradeoff: System operators will try to send accurate investment signals for reliable fuel mixes without over-indexing on a single technology, but this introduces uncertainty into future capacity valuations for investors.

4. Procurement

After projected peak demand, required reserves, and accredited capacity are determined, participants identify the net capacity needed to maintain long-term reliability. This process should establish clear investment signals, incentivizing the development, upgrading, and interconnection of necessary generation assets.

Risk tradeoff: Investors require capacity revenue to recover “missing money” not captured through marginal energy pricing, but high procurement costs directly impact ratepayer bills.

5. Obligation

Once capacity is procured and compensated for, the system operator mandates that the capacity from the generating units remain available during periods of risk. This requires resources to offer full available capacity into day-ahead and real-time energy and ancillary services markets.

Risk tradeoff: System operators want all available capacity offered into the market during tight conditions to optimize dispatch, but this exposes generators to operational and financial risks (e.g., fuel deliverability constraints or storage limitations).

What Would a Gold Standard Look Like?

A gold standard market would require stable forward pricing signals that provide a reference price that can govern bilateral contracting and transfer risk. Investors, power traders, and risk managers across the country are watching closely to see how these market reforms evolve to meet that gold standard.

We will see major waves of market redesign over the next few years from nearly every power market, driven by tight market conditions. Many of the decisions being made this year will directly impact how to recover costs, how to hedge, and how to turn a profit in North American power markets.

Read the Full White Paper

Want to go deeper? Read the full white paper, Is There a Gold Standard for Hedging New Capacity in Power Markets?, to learn about two different resource adequacy frameworks in PJM versus the Western Resource Adequacy Program (WRAP). PJM’s centralized capacity auction faces a “credibility trap,” in which price spikes trigger caps and collars that dampen long-term investment signals. WRAP is a decentralized bilateral framework without centralized capacity or scarcity pricing, which creates challenges for cleanly hedging risk.