Governance Lag in Power Markets Shifts Price Risk to Consumers

When regulators are slow to update electricity market rules, price risk concentrates on consumers rather than being distributed among generators and operators, warns a Latitude Media analysis published June 29. The pace of institutional decision-making, not infrastructure or technology, is the bottleneck of the energy transition.

The analysis documents that in the PJM market, which serves 67 million customers across 13 U.S. states, interconnection queues had accumulated 2,060 GW of projects by end-2025, nearly double the existing generation fleet, according to Lawrence Berkeley National Laboratory. Projects stall due to the fragmented sequence of studies, costs, and permits that no single institution controls end-to-end. The Natural Resources Defense Council projects cumulative capacity costs of up to $163 billion by 2032-2033 if demand outpaces supply, with consumers as the payer of last resort.

The pattern is not unique to advanced economies. The Institute for Energy Economics and Financial Analysis (IEEFA) documented that the May 2026 blackouts in Sumatra and Java-Madura-Bali, Indonesia, triggered by a transmission failure and compounded by insufficient coal supply, revealed the same dysfunction: new capacity coming online without updated grid codes or demand-response mechanisms. Indonesia had accumulated just 853 MW of rooftop solar by end-2025, compared to 6,900 MW in Vietnam.

Mexico has 22 GW of new renewable capacity planned through 2030 under Plan Mexico, along with 100 transmission and distribution projects, according to OilPrice. The March 2025 energy reform created the National Energy Commission (Comisión Nacional de Energía, CNE) as a unified regulator replacing the Comisión Reguladora de Energía (CRE) and the Comisión Nacional de Hidrocarburos (CNH), with a 54 percent minimum generation floor reserved for the Comisión Federal de Electricidad (CFE). The architecture of the Wholesale Electricity Market (Mercado Eléctrico Mayorista, MEM) and the Grid Code, including balancing mechanisms and backup requirements, has not received published amendments to accompany this capacity expansion.

Comparative experience shows that renewable expansion without simultaneous updates to MEM rules shifts imbalance costs onto CFE's industrial and residential tariffs. The CNE's performance in modernizing the Grid Code and MEM governance is the institutional variable that will determine whether risk is distributed or concentrated.

This article was drafted with artificial intelligence assistance from verified sources and reviewed by a human editor before publication.