Dual Peaks, Dual Risks: Why Utilities Can No Longer Plan For A Single System Peak

Utilities have long planned their systems around a single defining moment: the annual system peak. But that assumption is breaking down. As electrification accelerates, customer behavior shifts, and weather volatility intensifies, many utilities are now facing dual peak systems, where winter and summer peaks compete in magnitude, timing, and system impact.

In this episode, we explore why dual peaking represents more than a forecasting challenge. It is a planning, governance, and capital-allocation problem that exposes blind spots in traditional top-down load forecasting approaches. When utilities optimize infrastructure, staffing, and capital investments for the wrong peak, or assume seasonal peaks behave independently, the result can be higher costs, operational strain, and increased reliability risk.

Sponsored by Integral Analytics, the conversation dives into how bottom-up, scenario-based forecasting helps utilities move beyond single-scenario planning. We’ll discuss how customer-level intelligence reveals synchronized behaviors, such as electrified heating, EV charging, and commercial load shifts, that drive coincident peaks and reduce margin for error during extreme conditions.

Listeners will gain insight into why historical forecasting accuracy is no longer a reliable indicator of future readiness, how dual peak conditions increase the risk of stranded or misallocated assets, and what planning teams can do today to prepare for competing system constraints rather than betting on a single “most likely” future.

This episode is designed for utility planners, load forecasters, and executives navigating infrastructure investment decisions in an era where the peak you’re planning for may only be half the story.

Episode Guest: Darrin Kinney