What's Happening?
On October 9, the Federal Energy Regulatory Commission (FERC) rejected most of PJM Interconnection's proposal for connecting large loads during periods of insufficient generating capacity. While FERC accepted PJM's definition and registry for large loads,
it specifically denied the proposed Interim Resource Adequacy Service framework and its associated 'bring-your-own-new-capacity' provisions. Concurrently, FERC approved changes to Duke Energy Carolinas' transmission agreement, which include a fifteen-year minimum revenue commitment for qualifying large loads. These decisions create uncertainty for developers, as the ability to construct a data center may precede the right to operate it at its intended scale. The core issue revolves around reconciling federal transmission and market rules with state retail authority, particularly concerning the allocation of costs and risks associated with large-scale energy demands.
Why It's Important?
These FERC decisions are critical for the U.S. energy sector, particularly for the development of large-scale energy consumers like data centers and AI infrastructure. The rejection of PJM's proposal highlights a significant challenge in how new, substantial electricity demands are integrated into existing grids, especially in regions with potential generating capacity shortfalls. This creates a complex environment where developers face uncertainty regarding operational rights and financial commitments. The approval of Duke Energy Carolinas' transmission agreement, with its minimum revenue commitment, offers a potential model for how utilities can secure investments for infrastructure upgrades needed to support large loads. However, it also underscores the need for explicit agreements that define risk allocation between customers and utilities, preventing other customers from subsidizing new developments. The broader implication is a potential slowdown in the deployment of energy-intensive technologies if clear, consistent, and equitable interconnection frameworks are not established.
What's Next?
The coming months will be crucial for clarifying the path forward for large-load interconnections. By November 16, five regional operators, including PJM, are expected to respond to FERC’s show-cause proceedings regarding large loads. These responses will detail how proposed connection terms assign costs and reconcile regional requirements with state authority. Southwest Power Pool’s response, due November 20, will be closely watched for potential approaches to connection rights and cost recovery that other regions might adopt. Answers to these filings are due 30 days later, which will likely highlight unresolved cost exposures, jurisdictional conflicts, or unworkable operating obligations. PJM’s planned capacity auction for the 2029–30 delivery year in December 2026 will also indicate whether procured capacity meets reliability requirements. Additionally, Dominion’s GS-5 class, taking effect January 1, 2027, will test how service commitments and minimum payments protect customers if demand falls short.
Beyond the Headlines
The FERC decisions expose deeper implications regarding the future of energy infrastructure and the balance of power between federal and state regulatory bodies. The underlying difficulty lies in the mismatch between a customer's ability to alter its plans and a utility's long-term investment commitments. If customers retain flexibility without bearing the full cost of the exposure they create, other customers effectively insure the development plan, raising questions of fairness and economic efficiency. This situation necessitates the development of large-load tariffs that explicitly allocate risk before construction begins. Furthermore, the market-design objections raised by Commissioner David Rosner, concerning the curtailment of loads before voluntary demand response and the exclusion of their demand from capacity-market demand curves, highlight the need for revised approaches that reconcile procured capacity with the service customers are actually entitled to receive. This ongoing regulatory evolution will shape investment incentives, grid reliability, and the ultimate cost burden on consumers.
