The Texas grid after Uri | The Outlet — Pilot Energy

The short version

Winter Storm Uri in February 2021 was the worst grid emergency in ERCOT's history. Approximately 246 people died according to the official count, with peer-reviewed estimates suggesting the true toll was 700 or more. Economic damages exceeded $130 billion. At the peak of the event, more than 52 GW of generation was offline — roughly half of ERCOT's installed capacity — as a combination of natural gas, wind, coal, and nuclear plants failed in the unprecedented cold. Five years later, ERCOT has implemented major weatherization reforms, considered and ultimately rejected a capacity market overhaul, and is now confronting a new challenge that has eclipsed the original reliability concerns: explosive data center load growth.

What broke in February 2021

The proximate cause of Uri was an arctic air mass that pushed temperatures into the single digits across most of Texas for multiple days. The deeper causes were systemic: most ERCOT generators had not been weatherized for sustained cold weather, natural gas wellheads and pipelines froze (creating fuel supply failures that cascaded into electricity outages), and the energy-only market structure provided weak signals for reliability investment. When the system failed, ERCOT implemented rotating load shed that became extended outages — some lasting four days — because too much generation was offline to restore service safely. Wholesale electricity prices spiked to the $9,000/MWh cap for sustained periods, ultimately producing billions in disputed charges that took years to litigate.

Critically, the natural gas system failed in parallel with the electric grid. Gas wellheads froze, processing plants lost power, and gas pipelines lost compression — creating a feedback loop where electricity generation couldn't get fuel and gas infrastructure couldn't get power. This gas-electricity coupling failure has shaped every reform since.

What got fixed: SB 3 and weatherization

Texas SB 3, signed in June 2021, was the primary legislative response. The bill mandated weatherization standards for ERCOT generators, established a Texas Energy Reliability Council, required improved coordination between the PUC and Railroad Commission (which regulates oil and gas), and authorized the PUCT to revise ERCOT market design. The PUCT implemented Phase 1 generator weatherization rules effective for winter 2021-2022, with progressive standards through subsequent winters. Subsequent cold weather events including the December 2022 Elliott storm validated that the weatherization reforms worked — generation performance during cold events improved substantially compared to 2021.

Natural gas weatherization has progressed more slowly. The Railroad Commission of Texas issued rules requiring critical gas infrastructure to register and weatherize, but enforcement has been weaker than on the electric side. Industry observers continue to flag the gas supply chain as the most likely source of a future Uri-like failure, though no event of similar severity has occurred since.

What didn't happen: the PCM debate

Beyond weatherization, the larger debate was whether ERCOT needed a fundamental market redesign to ensure adequate generation investment. The PUCT considered multiple proposals over 2022-2024, ultimately advancing the Performance Credit Mechanism — a hybrid design that would pay generators for being available during scarcity periods without creating a full capacity market. After years of stakeholder process, escalating cost estimates, and concerns about complexity and effectiveness, the PUCT shelved PCM in December 2024.

ERCOT instead is implementing targeted reforms within the existing energy-only framework. The Dispatchable Reliability Reserve Service (DRRS) creates a new ancillary service paying dispatchable generators to be available during high-risk periods. Real-time co-optimization of energy and ancillary services (RTC+B), planned for implementation in late 2026 or 2027, will allow generators to bid energy and ancillary services jointly. ORDC reforms have adjusted scarcity pricing to better reflect reliability needs without inflating overall market costs. Together, these reforms aim to deliver reliability improvements without the structural cost of a capacity market.

The new challenge: load growth

ERCOT's most pressing challenge in 2026 is not generator weatherization but demand. Large load interconnection requests quadrupled in 2025 according to ERCOT staff, driven by AI data centers, cryptocurrency mining, and industrial electrification. ERCOT now forecasts peak demand growing from roughly 85 GW in 2024 to potentially 150+ GW by the early 2030s — a doubling that would strain transmission, generation adequacy, and water resources simultaneously. The 2025 Texas legislature responded with multiple bills addressing large load interconnection requirements, cost allocation between large loads and other customers, and reliability protections including the ability to curtail large loads during emergencies.

For commercial and industrial buyers in ERCOT, the implications are mixed. Wholesale energy prices remain volatile but generally lower than capacity-market regions, ancillary service revenues for demand-flexible loads are growing, and the lack of capacity charges keeps fixed costs lower than PJM or ISO-NE. However, transmission costs are rising, large load tariffs are evolving rapidly, and the reliability outlook for the late 2020s depends heavily on whether new generation can keep pace with data center deployment. ERCOT's energy-only design — preserved through the PCM debate — remains the cleanest market design in the US, but it is being stress-tested as never before.