How America’s Power Regions Chose Their Futures and How That Has Played Out

Why It Matters

The divergence determines electricity costs, reliability, and the pace of the clean‑energy transition for millions of customers, influencing investment decisions across the power sector.

Key Takeaways

• FERC orders 888/2000 spurred RTO formation
• PJM delivers $2.8‑$3.1B annual customer benefits
• Southeast resists organized markets, launches SEEM with minimal volume
• ERCOT's energy‑only market exposed fragility during Uri
• Data‑center demand accelerates push for transparent market pricing

Pulse Analysis

The 1996 FERC Order 888 opened transmission to non‑discriminatory access, and Order 2000 in 1999 encouraged the voluntary creation of Regional Transmission Organizations. Those provisions launched a natural experiment: the Mid‑Atlantic and Midwest coalesced around PJM, New England formed ISO‑NE, New York built NYISO, and the Midwest‑South created MISO, while Texas and the Southeast opted for separate, largely bilateral structures. This regulatory fork laid the groundwork for today’s stark contrast between organized wholesale markets and traditional utility‑driven systems. These divergent paths continue to shape national reliability and investment strategies.

Organized markets have repeatedly demonstrated economic advantages. PJM alone reports annual customer benefits of $2.8‑$3.1 billion by optimizing dispatch across a wide footprint, while Brattle Group analyses estimate similar savings for regions that could join an RTO. Transparent locational marginal pricing reduces investment risk for wind and solar developers, accelerating renewable integration. However, capacity‑market design remains contentious in PJM, ISO‑NE and NYISO, and ERCOT’s energy‑only model exposed severe reliability gaps during the 2021 winter storm, highlighting that market structures must balance price efficiency with resource adequacy.

The Southeast’s reluctance is eroding as new pressures emerge. The Southeast Energy Exchange Market, launched in 2022, cleared only 0.1 % of regional demand, but it signals a willingness to test market mechanisms. Meanwhile, hyperscale data‑center developers demand transparent pricing and rapid interconnection, favoring RTO environments. As natural‑gas prices rise and legacy coal plants age, the cost advantage of vertically integrated utilities narrows, prompting legislators and regulators to reconsider mandatory market designs. The next decade will likely see incremental reforms that bring the remaining holdouts into organized, competitive electricity markets.