Why Utility Storm Readiness Requires More Than a Weather Forecast

As Americans celebrated the nation’s 250th anniversary of independence in 2026, utilities across the country were responding to a very different challenge. Extreme heat and thunderstorms left more than one million utility customers without power, according to The New York Times, prompting safety warnings across much of the Upper Midwest and the East Coast.

The consequences of the July storms in Michigan prompted the Michigan Public Service Commission to launch an investigation into how utilities prepared for the storm, including crew staging, mutual aid coordination, operational planning, and customer communications.

The investigation reflects a broader shift in expectations, with regulators looking beyond restoration times to examine the decisions utilities make before a storm arrives.

Michigan is just one example of a broader pattern. Data from the National Oceanic and Atmospheric Administration show that the United States has experienced a growing number of costly weather and climate disasters, each bringing its own operational challenges. The cumulative effect is reshaping utility storm readiness, with preparation increasingly beginning well before the first outage occurs.

From reactive response to proactive utility storm planning

Proactive storm planning starts with creating more time to make operational decisions. Earlier visibility into when and where impacts are likely to develop can give utilities more time to stage crews, coordinate mutual aid, adjust maintenance schedules, and prepare customer communications before conditions deteriorate.

The value isn’t simply knowing a storm is coming. It’s understanding potential impacts early enough to change the plan. As forecasts evolve, utilities can reassess where resources are positioned, which assets may be most exposed, and where restoration could be most difficult.

Why similar storms create different operational risks

Utilities understand that no two summer storms create the same operational challenges. The Fourth of July storms in Michigan are a good example. Wind gusts of 60–70 mph toppled trees and branches across the Lower Peninsula, leaving restoration crews to contend with vegetation interfering with electric restoration work.

Lightning introduces its own set of operational risks. In Florida, frequent summer thunderstorms can trigger momentary power interruptions while also creating risks for crews and electrical infrastructure.

Outages are just one of the challenges with lightning. There is also the immediate threat to crew safety, potential damage to transformers and lines, and strikes on dry vegetation near distribution corridors that can spark secondary fires. Lightning activity can also delay restoration even after a fault has been located because crews often cannot safely approach damaged equipment until the risk in the immediate area has cleared.

Even storms with similar forecasts can create dramatically different challenges depending on where they occur. High winds moving through densely wooded distribution corridors present different restoration risks than similar winds affecting open terrain. Population density, critical infrastructure, planned outages, and regional resource availability all influence how utilities assess storm-related operational risk.

Understanding these factors helps utilities prioritize where to stage crews, where restoration challenges are most likely to occur, and how to deploy resources before conditions worsen.

Turning weather forecasts into utility decisions

Few utilities would say they need more weather forecasts. The challenge is turning weather information into operational decisions early enough to act. Knowing severe thunderstorms are expected is useful. Understanding how storm timing, wind potential, lightning activity, localized rainfall, and changing field conditions may affect crew safety, outage risk, and restoration priorities provides the context needed to make those decisions.

Weather intelligence becomes more actionable when it is considered alongside operational factors such as outage history, asset locations, vegetation exposure, and crew availability. A forecast can show where a storm is headed. Operational context helps determine what that storm could mean for the grid and where resources may be needed most.

Black Hills Energy shows how that additional context can change the operational picture. Serving parts of Colorado, Wyoming, and South Dakota across grasslands, forests, and mountainous terrain, the utility needed more than a regional wildfire forecast to consistently assess risk across its service territory.

Working with DTN, Black Hills Energy developed a tailored Energy Event Index that combines five-day wildfire risk profiles with factors such as circuit-level risk, vegetation density, fire truck response times, nearby population, and topography. Two circuits facing the same fire weather can carry very different consequences depending on what surrounds them and how quickly crews could respond.

Bringing those variables together gives operators a more complete view of operational risk and has helped Black Hills Energy mobilize resources before conditions deteriorate rather than react after the fact.

That is the value of connecting weather intelligence to the factors that shape operational risk.

DTN Weather Hub brings weather intelligence and utility-specific operational context together to help teams evaluate changing conditions, assess potential outage risk, and make informed decisions before disruptions occur.

Storm readiness ultimately depends on the decisions made before, during, and after an event. Giving teams earlier visibility into potential impacts creates more time to prepare resources, adjust plans, and respond as conditions change.